NUREG-1833 

 1, Rev. 1 

Technical Bases for Revision

to the License Renewal 

Guidance Documents

U.S. Nuclear Regulatory Commission

Office of Nuclear Reactor Regulation

Washington, DC 20555-0001
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 NUREG-1833

Technical Bases for Revision

to the License Renewal

Guidance Documents

Manuscript Completed: October 2005

Date Published: October 2005

Division of Regulatory Improvement Programs

Office of Nuclear Reactor Regulation

U.S. Nuclear Regulatory Commission

Washington, DC 20555-0001
NUREG-1833 ii October 2005

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October 2005 iii NUREG-1833

ABSTRACT

This document establishes the basis for the changes that constitute Revision 1 to NUREG1801, “Generic Aging Lessons Learned (GALL) Report,” and Revision 1 to NUREG-1800, 

“Standard Review Plan for Review of License Renewal Applications for Nuclear Power Plants” 

(SRP-LR). 

The technical changes that were made when revising the guidance contained in NUREG-1801 

are captured in this document, along with the basis for the change. Changes to NUREG-1800, 

many of which derive from the changes to NUREG-1801, are also discussed in this document. 

Consequently, this document provides an understanding of the underlying rationale that NRC 

used in developing the current revisions of these guidance documents.
NUREG-1833 iv October 2005

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October 2005 v NUREG-1833

TABLE OF CONTENTS

Page

Abstract...........................................................................................................................................iii

List of contributors – 2004-2005 .....................................................................................................ix

I. Introduction ......................................................................................................................... 1

I.A Overview of Changes.............................................................................................. 1

I.B Roll-Up Methodology .............................................................................................. 2

I.C Incorporation of NRC Positions Previously Approved............................................ 2

I.D Operating Experience............................................................................................. 3

I.E Technical Clarifications and Corrections................................................................ 3

I.F Clarifications to the Audit and Review Process (SRP-LR only)............................. 3

II. Justification for Inclusion of New Aging Management Review (AMR) Line-Items........... 11

II.A New AMR Line-items related to Mechanical Systems......................................... 13

II.B New AMR Line-items related to Structural Systems............................................ 91

II.C New AMR Line-items related to Electrical Systems............................................. 96

III. Changes to Existing Aging Management Review Line-Items........................................ 109

III.A Containment Structures...................................................................................... 110

III.B Structures and Components Supports ............................................................... 147

III.C Reactor Vessels, Internals, and Reactor Coolant Systems............................... 169

III.D Engineered Safety Features ............................................................................... 192

III.E Electrical Components........................................................................................ 202

III.F Auxiliary Systems................................................................................................ 203

III.G Steam and Power Conversion System............................................................... 217

IV. Description of and Justification for Changes in Aging Management Programs............ 223

V. Justification for Changes to the SRP-LR........................................................................ 259

VI. Abbreviations, Acronyms, and Designations.................................................................. 269
NUREG-1833 vi October 2005

VII. References...................................................................................................................... 275

APPENDIX A Standard Terminology ...........................................................................................A-i

Introduction ..................................................................................................................................A-1

A.1 Structures and/or Components........................................................................................A-1

A.1.1 Listing and Location of Structures and/or Components......................................A-1

A.1.2 Definition of Selected Terminology for Structures and Components................A-16

A.2 Materials.........................................................................................................................A-19

A.2.1 Listing, Location and Frequency of Terms........................................................A-19

A.2.2 Selected Descriptions of Materials ....................................................................A-24

A.2.3 Metals Background for the GALL Update..........................................................A-29

A.3 Environments .................................................................................................................A-47

A.3.1 Listing, Location, and Frequency of Terms used in AMR Tables .....................A-47

A.3.2 Selected Descriptions of Environments.............................................................A-52

A.3.3 Temperature Thresholds ...................................................................................A-61

A.4. Aging Effects and Aging Mechanisms...........................................................................A-63

A.4.1 Listing, Location, and Frequency of Aging Effect/ Aging Mechanism Terms...A-63

A.4.2 Aging Effects......................................................................................................A-70

A.4.3 Aging Mechanisms.............................................................................................A-74

A.5 Aging Management Programs.......................................................................................A-83

A.5.1 Listing, Location, and Frequency of AMPs........................................................A-83

A.6. Summary of MEAP Combinations ...............................................................................A-107

A.7. References:..................................................................................................................A-225

APPENDIX B SRP-LR Development Tools..................................................................................B-i

Introduction ..................................................................................................................................B-1

B.1 Reactor Coolant System SRP-LR Development Tool.....................................................B-2

B.2 Engineered Safety Features SRP-LR Development Tool.............................................B-75
October 2005 vii NUREG-1833

B.3 Auxiliary Systems SRP-LR Development Tool .............................................................B-91

B.4 Steam and Power Conversion SRP-LR Development Tool........................................B-119

B.5 Structures SRP-LR Development Tool........................................................................B-135

B.6 Electrical SRP-LR Development Tool .........................................................................B-169

APPENDIX C GALL Rev. 0 to GALL Rev. 1 Relationship Tables ...............................................C-i

Introduction ................................................................................................................................. C-1

C.1 GALL Rev. 0 to GALL Rev. 1 Relationship Tables ........................................................ C-3
NUREG-1833 viii October 2005

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October 2005 ix NUREG-1833

LIST OF CONTRIBUTORS – 2004-2005

License Renewal and Environmental Programs Section of Division of Regulatory Improvement 

Programs, Office of Nuclear Reactor Regulation

P.T. Kuo Program Director

S. Lee Section Chief

S. West Section Chief

J. Zimmerman Section Chief

A. Hull Team Leader

J. Dozier Mechanical Engineering

K. Chang Mechanical Engineering

K. Cozens Materials Engineering 

G. Cranston Reactor Systems Engineering

D. Guha Systems Engineering

M. Heath Mechanical Engineering

S. Hoffman Mechanical Engineering

K. Hsu Materials Engineering

M. Lintz Mechanical Engineering

D. Merzke Mechanical Engineering

K. Naidu Reactor Engineering

R. Subbaratnam Mechanical Engineering

T. Terry Civil Engineering

L. Tran Electrical Engineering

Office of Nuclear Reactor Regulation

T. Chan Section Chief

S. Coffin Section Chief

R. Jenkins Section Chief

S. Jones Section Chief

L. Lund Section Chief

R. Karas Section Chief

K. Manoly Section Chief

M. Mitchell Section Chief

J. Nakoski Section Chief

D. Terao Section Chief

S. Weerakkody Section Chief

H. Ashar Structural Engineering

S. Bailey Mechanical Engineering

T. Cheng Structural Engineering

R. Davis Materials Engineering

B. Elliot Materials Engineering

J. Fair Mechanical Engineering

G. Georgiev Materials Engineering

N. Iqbal Fire Protection Engineering

D. Jeng Structural Engineering

K. Karwoski Materials Engineering
NUREG-1833 x October 2005

LIST OF CONTRIBUTORS (continued)

A. Keim Materials Engineering

C. Lauron Chemical Engineering

L. Lois Reactor Systems Engineering

Y. Li Mechanical Engineering

R. McNally Mechanical Engineering

J. Medoff Materials Engineering

D. Nguyen Electrical Engineering

A. Pal Electrical Engineering

K. Parczewski Chemical Engineering

J. Rajan Mechanical Engineering

P. Shemanski Electrical Engineering

J. Strnisha Mechanical Engineering

Office of Nuclear Regulatory Research

A. Hiser Section Chief 

J. Vora Team Leader

J. Davis Materials Engineering

P. Kang Electrical Engineering

Parallax, Inc

A. Baione Team Leader

M. Bowman Mechanical Engineering

K. Larsen Technical Editing

E. Patel Mechanical Engineering

R. Wells License Engineering

Argonne National Laboratory

O. Chopra Team Leader

D. Diercks Materials Engineering

V. Sha Materials/Mechanical Engineering

S. Tam Materials Engineering
October 2005 1 NUREG-1833

I. Introduction

This document establishes the basis for the changes that constitute Revision 1 to NUREG1801, “Generic Aging Lessons Learned (GALL) Report,” (which includes Volumes 1 and 2) and 

Revision 1 to NUREG-1800, “Standard Review Plan for Review of License Renewal 

Applications for Nuclear Power Plants” (SRP-LR). These documents were published in 

September 2005. NUREG-1832, “Analysis of Public Comments on the Revised License 

Renewal Guidance Documents,” provides the evaluation and disposition of public comments 

received by the NRC on the revision of the license renewal guidance documents (LRGDs).

Figure 1 shows the historical development of the LRGDs. Figure 2 shows the LRGD update and 

development process.

The technical changes that were made when revising the guidance contained in the GALL 

Report are captured in this document, along with the basis for the change. Changes to the SRPLR, many of which derive from the changes to the GALL Report, are also discussed in this 

document. Consequently, this document provides an understanding of the underlying rationale 

that NRC used in developing the current revisions of these guidance documents.

I.A Overview of Changes

Changes to the GALL Report and SRP-LR (the guidance documents) fall into the following 

categories: 

• Roll-up changes

• NRC positions previously approved in other documents, such as safety evaluation reports 

and approved interim staff guidance

• Lessons learned

• Operating experience 

• Technical clarifications or corrections

• Clarifications to the audit and review process (SRP-LR only) 

Each of these categories is discussed further in the following sub-paragraphs. 

Chapter II, “Justification for Inclusion of new AMR Line-Items,” documents the creation and 

justification for new aging management review (AMR) entries in the GALL Report. Chapter III,

“Justification for Technical Changes,” documents the changes in the existing AMR line-items 

and basis to the guidance document. 

Additionally, to facilitate and ensure consistency in understanding, Chapter IX was added to the 

GALL Report to provide standard terminology nomenclature and definitions. Appendix A, 

“Standard Terminology,” to this NUREG provides the basis for the new GALL Report Chapter 

IX. It also provides the ‘picklist’ used in the selection of terms used within the columns of the 

AMR tables in the GALL Report. 

Lastly, GALL Volume 1 and the SRP-LR present summary information reflecting the AMR table 

data in GALL Volume 2. However, the SRP-LR and GALL Volume 1 do not identify the material 

or environment information contained in the AMR line-items in GALL Volume 2. Appendix B to 

this NUREG was created to bridge that gap.
NUREG-1833 2 October 2005

I.B Roll-Up Methodology

The 2001 version of the GALL Report and the SRP-LR (each of which is referred to as Revision 

0) contained aging management reviews (AMRs) that used very explicit component 

identification, material nomenclature, and environment definitions. In some situations, these 

explicit characterizations were more restrictive than technically necessary. Hence, an applicant 

might be less consistent with the GALL Report than it would have been if the AMR definitions 

were based on more practical component groupings, material nomenclature, and environment 

definitions. 

In a letter from NEI dated May 11, 2004, “Transmittal of proposed method for updating the 

GALL Report, NUREG-1801” from Alex Marion to P.T. Kuo, modifications to the component 

groups, material nomenclature, and environmental definitions were proposed. The NRC Staff

reviewed these proposals and, based on the technical merits of each proposed change either

agreed with the recommendation, agreed with a modified version of the recommendation, or 

rejected the recommendation. The guidance documents were then modified to reflect the NRC 

Staff assessments of the NEI proposed changes. 

As part of these changes, the roll-up process also included standardizing the terminology used 

throughout the GALL Report, the inclusion of certain technical criteria (such as temperature 

thresholds for aging effects in common use by the industry) to further clarify the applicability of 

the results, reformatting and the correction of editorial errors. Chapter IX was added to the 

revised GALL Report to standardize and define terminology used in the document.

I.C Incorporation of NRC Positions Previously Approved

In addition to the roll-up changes discussed above, the update of the GALL Report incorporates 

specific technical changes. These technical changes were based on the incorporation of NRC 

approved positions established in past precedents from approved license renewal safety 

evaluation reports, approved interim staff guidance (ISGs), and more recent operating 

experience. Table 1A, at the end of this chapter, summarizes the status and staff resolution for 

these ISGs. Unlike the roll-up process, these specific technical changes introduce new technical 

content to the updated documents. Section III, “Changes to Existing Aging Management Review 

Line-items,” provides a listing of each new or existing AMR result in GALL that incorporates a 

technical change, and provides a specific basis for this change. 

The NRC drew on two sources of information, previous Staff comments for improving the 

license renewal process (collected since the previous revision of GALL and the SRP-LR were 

issued), and the collection of approved SERs. Previous license renewal SERs were reviewed to 

identify instances where changes to the GALL AMR line-items should be made to improve the 

technical accuracy and consistency of the license renewal process. Over four hundred individual 

items were collected from these two information sources and each was reviewed for its 

applicability, value, and technical adequacy as part of the NRC review process.

In addition, the NUREG-1801 tables were updated to include new material, environment, aging 

effect and aging management program (MEAP) combinations that are common to most license 

renewal applications (LRAs), including those that have already been reviewed. In a letter dated 

July 30, 2004, NEI proposed adding about 40 new AMR line-items. The NRC Staff reviewed 

these items to identify if SERs had been accepted with the proposed MEAP combinations in 
October 2005 3 NUREG-1833

previous LRAs. If a previous NRC Staff position was identified, the Staff determined whether the 

MEAP combination was sufficiently generic to warrant including this item in the revised LRGD. If 

so, it was added either in its proposed or in a modified form. Chapter II of this Bases Document 

further discusses these new AMR line-items. Appendix A.6 provides a listing of all the MEAP 

combinations in GALL Vol. 2 with cross-reference to SRP-LR listings.

I.D Operating Experience

Extended operation of nuclear reactors necessitates critical analysis of existing experience. An 

operating experience review was performed to identify AMR line-items necessary for addition or 

modification in the GALL Report. Both domestic and foreign operating experience was

reviewed.

Domestic Operating Experience: The NRC Office of Research provided a listing of Licensee 

Event Reports (LERs) related to failures, cracking, degradation, etc. of passive components. 

This listing consisted of 128 items. These results were reviewed by the NRC Staff. The Staff 

subsequently modified AMR line-item R-68 and added AMR line-item RP-22 (on the basis of 

LER 528-1992-001). R-68 was modified to emphasize stress corrosion cracking associated with 

nozzle safe end welds. AMR line-item RP-22 was added to identify primary water stress 

corrosion cracking (PWSCC) of the pressurizer steam space nozzles.

Foreign Operating Experience: The international Incident Reporting System (IRS), jointly 

operated by the International Atomic Energy Agency (IAEA) and the Nuclear Energy Agency 

(NEA), compiles and analyses information on nuclear power plant events and promotes a 

systematic approach to the feedback of lessons learned from operating experience. NPP events 

reported to the IRS are significant in terms of causes and safety lessons learned. The main 

objective of the IRS is to assure proper feedback on events to help prevent occurrence or 

recurrence of serious incidents or accidents. Reports from this database are proprietary.

The IRS database was queried for reports relating to passive components with corrosion and 

cracking. Thirty-three reports were identified since 1992 that met these criteria. These reports 

were analyzed to determine if there were any AMR line-items that needed to be included in the 

GALL report. Many of the reports identified MEAP combinations that were already in the GALL 

Report or were addressed by staff ISG documents. A few of the items appeared to be specific to 

foreign plants and not generically applicable to US PWRs and BWRs. Based on the NRC 

review, there were no items warranting addition to the GALL report and, in general, it was 

concluded that the GALL Report’s AMR line-items were comprehensive.

I.E Technical Clarifications and Corrections

Based on use and review of the guidance documents, some editorial changes were made to 

improve the technical clarity or revise inadvertent errors. As shown in Table IV of this Bases 

Document, there were a number of such changes made related to the Aging Management 

Programs (AMPs) in GALL Vol. 2. This also included updating references in the license renewal 

guidance documents.

I.F Clarifications to the Audit and Review Process (SRP-LR only)

A large number of changes made to the GALL Report required parallel changes to the SRP-LR. 

These types of changes are discussed in the preceding paragraphs and are not repeated here.
NUREG-1833 4 October 2005

In addition to the above mentioned changes, the SRP-LR was revised to better reflect the 

methodology of performing the safety audit and reviews associated with the NRC Staff review of 

a LRA. 

These changes include a better description of the work divided among the NRC branches 

performing the safety review. This was achieved by the addition of a new section to the SRPLR, Section 3.0, which adds a step in the safety review of the Safety Review Project Manager 

(PM) to assign and document work assignments dividing the AMR and AMP reviews among 

various NRC branches and sections. 
October 2005 5 NUREG-1833

Table IA Summary of the Effect of the Interim Staff Guidance Process on the Updated License 

Renewal Guidance Documents (LRGDs)

ISG 

No. Title and Reference Purpose Status Resolution Affected LRGDs

01 “Proposed Staff Guidance on 

the Position of the GALL Report 

Presenting One Acceptable 

Way to Manage Aging Effects 

for License Renewal,” dated 

November 23, 2001 (ADAMS 

Accession No. ML013300531)

How to credit plant 

programs and 

activities

Closed 

Incorporated into 

LRGDs

SRP-LR, 

Chapter 3.0

02 “Staff Guidance on Scoping of 

Equipment Relied on to Meet 

the Requirements of the Station 

Blackout (SBO) rule (10 CFR 

50.63) for License Renewal,” 

dated April 1, 2002 (ADAMS 

Accession No. ML020920464)

Station blackout 

scoping

Closed 

Incorporated into 

LRGDs

SRP-LR, 

Chapter 2.0

03 “Proposed Revision of Chapters 

II and III of Generic Aging 

Lessons Learned (GALL) 

Report on Aging Management 

of Concrete Elements,” dated 

November 23, 2001 (ADAMS 

Accession Nos. ML013300440 

and ML013300445)

To clarify the concrete 

aging management 

programs in GALL and 

SRP-LR documents. 

Management of both 

accessible and 

inaccessible areas is 

addressed.

Closed 

Incorporated into 

LRGDs

GALL Volume 

2, AMPs 

XI.S2, and 

XI.S6

04 “Interim Staff Guidance (ISG)-

04: Aging Management of Fire 

Protection Systems for License 

Renewal,” dated December 3, 

2002 (ADAMS Accession No. 

ML023440137)

Fire protection system 

piping. Change the 

visual inspection 

interval from specific 

interval to plant 

specific interval based 

on plant operating 

experience and 

engineering 

evaluation.

Closed 

Incorporated into 

LRGDs

GALL Volume 

2, AMPs 

XI.M26 and 

AMP XI.M27

05 “Interim Staff Guidance (ISG)-5 

on the Identification and 

Treatment of Electrical Fuse 

Holders for License Renewal,” 

dated March 10, 2003 (ADAMS 

Accession No. ML030690512, 

ML030690518 )

To include fuse clips 

and fuse block for fuse 

holders and to add a 

new AMP for fuse clips 

(i.e., metallic)

Closed 

Incorporated into 

LRGDs

SRP-LR, 

Table 2.1-5, 

GALL Volume 

2, AMP XI.E5 

(new)

06 “Proposed Interim Staff 

Guidance on Identification and 

Treatment of Housing for Active 

Components for License 

Renewal,” dated April 8, 2003 

(ADAMS Accession No. 

ML031010423)

Housing for active 

components.

To clarify a need for 

aging management 

review (AMR) for 

housing for fans, 

dampers, and H/C 

coils

Withdrawn and 

Closed 

Incorporated in

final LRGDs

(included in NEI 95-

10, Rev. 6)

SRP-LR, 

Table 2.1-5, 

Chapter 3.0, 

and GALL 

Volume 2, 

IX.B Table 
NUREG-1833 6 October 2005

Table IA Summary of the Effect of the Interim Staff Guidance Process on the Updated License 

Renewal Guidance Documents (LRGDs)

ISG 

No. Title and Reference Purpose Status Resolution Affected LRGDs

07 “Proposed Staff Guidance on 

the Scoping of Fire Protection 

Equipment for License Renewal, 

dated November 13, 2002 

(ADAMS Accession No. 

ML023190479)

Scoping guidance 

To clarify the fire 

protection systems,

structures, and 

components scoping. 

To clarify whether the 

scope would expand to 

include (BTP) APSCB 

9.5-1

Withdrawn and 

closed incorporated 

in LRGDs (ADAMS 

Accession No. 

ML051590234)

GALL Volume 

2, IX.B Table 

08 “Process for Interim Staff 

Guidance Development and 

Implementation,” dated 

December 12, 2003 (ADAMS 

Accession No. ML023520620)

To update and 

establish the interim 

staff guidance 

process.

Closed N/A

09 “Industry Guidance on Revised 

54.4(a)(2) Scoping Criterion for 

license renewal,” dated June 6,

2003 (ADAMS Accession No. 

ML031570613)

Scoping criteria 

54.4(a)(2) 

Scoping of non-safetyrelated systems, 

structures, and 

components 

conducted for license 

renewal is in 

accordance with the 

requirement of 

54.4(a)(2)

Closed – Reg. 

Guide 1.188 

endorsed NEI 95-

10, Rev. 6

N/A

10 “Standardized Format for 

License Renewal Application,” 

April 7, 2003 (ADAMS 

Accession No. ML030990052,

ML030990292)

License renewal 

application format 

To standardize license 

renewal application 

format for 2003 

applicants

Closed – Reg. 

Guide 1.188 

endorsed NEI 95-

10, Rev. 6

N/A

11 “Recommendations for Fatigue 

Environmental Effects in a 

License Renewal Application,” 

dated January 21, 2004 

(ADAMS Accession No. 

ML040220124) 

Environmental fatigue 

for carbon/low-alloy 

steel 

To review the aging 

management of 

environmental fatigue 

in the ISG process, as 

agreed at the 

September 18, 2002, 

meeting: eliminate 

evaluation of carbon 

and low alloy steel 

components for the 

effects of the reactor 

coolant environment 

for LRA

Closed 

Staff concluded 

there is insufficient 

technical basis 

provided to justify 

the elimination of 

the evaluation of 

carbon and low alloy 

steel components 

for the effects of the 

reactor coolant 

environment for LRA 

N/A
October 2005 7 NUREG-1833

Table IA Summary of the Effect of the Interim Staff Guidance Process on the Updated License 

Renewal Guidance Documents (LRGDs)

ISG 

No. Title and Reference Purpose Status Resolution Affected LRGDs

12 “Addition of Generic Aging 

Lessons Learned (GALL) Aging 

Management Program (AMP) 

XI.M35, 'One-time Inspection of 

Small-Bore Piping,’ for License 

Renewal,” dated November 3, 

2003 (ADAMS Accession No. 

ML033100516)

Cracking of Class 1 

small-bore piping 

To capture the 

operational experience 

related to the cracking

of Class 1 small-bore 

piping

Withdrawn and 

Closed 

Incorporated in 

LRGDs

GALL Volume 

2, AMP 

XI.M35 (new) 

and 

corresponding 

AMR lineitems

13 Management of Loss of Preload 

on Reactor Vessel Internals 

Bolting Using the Loose

Parts Monitoring System

To review the use of 

the loose parts 

monitoring system for 

the management of 

the loss of preload on 

reactor vessel internal 

bolting

Withdrawn and 

Closed 

Incorporated in 

LRGDs 

GALL Volume 

2, AMP 

XI.M14

14 Operating Experience with 

Cracking in Bolting

Cracking in bolting 

To capture the 

operational experience 

related to the cracking 

of bolting

Withdrawn and 

Closed 

Incorporated in 

LRGDs - revised 

GALL AMP XI.M18 

and selected AMRs 

portion

GALL Volume 

2, AMP 

XI.M18 and 

the 

corresponding 

AMR lineitems 

15 “Proposed Interim Staff 

Guidance (ISG)-15: Revision of 

Generic Aging Lessons Learned 

(GALL) Aging Management 

Program (AMP) XI.E2, 

'Electrical Cables Not Subject to 

10 CFR 50.49 Environmental 

Qualification Requirements 

Used in Instrumentation 

Circuits,’ for License Renewal,” 

dated August 12, 2003 (ADAMS 

Accession No. ML032250579)

To incorporate NEI’s 

proposed revision to 

GALL AMP XI.E2 (i.e., 

replaced TS 

surveillance with 

specific calibrations or 

surveillance)

Withdrawn and 

Closed 

Incorporated in 

LRGDs

GALL Volume

2, AMP XI.E2

16 “Proposed Interim Staff 

Guidance (ISG)-16: TimeLimited Aging Analyses (TLAAs) 

Supporting Information for 

License Renewal Applications,” 

dated May 12, 2003 (ADAMS 

Accession No. ML031320798)

To maximize the 

efficiency of the LRA 

review process and 

minimize RAIs using 

time-limited aging 

analyses (TLAAs) 

supporting information

Withdrawn and 

Closed 

Incorporated in 

LRGDs

SRP-LR 

Chapter 4

17 “Interim Staff Guidance (ISG)-

17: Proposed Aging 

Management Program (AMP) 

XI.E4, 'Periodic Inspection of 

Bus Ducts," for License 

Renewal”

See Federal Register notice, 

Vol. 69, No. 246, page 76960, 

dated December 23, 2004

Bus ducts 

To review bus 

insulation due to water 

intrusion in bus ducts 

and bus bar 

connection due to 

thermal cycles. To 

develop GALL AMP 

XI.E4 for bus ducts

Withdrawn and 

Closed 

Incorporated in 

LRGDs

GALL Volume 

2, AMP XI.E4 

(new) and 

corresponding 

AMR lineitems
NUREG-1833 8 October 2005

Table IA Summary of the Effect of the Interim Staff Guidance Process on the Updated License 

Renewal Guidance Documents (LRGDs)

ISG 

No. Title and Reference Purpose Status Resolution Affected LRGDs

18 Revision to NUREG-1801 

Program XI.E3 for Inaccessible 

Medium Voltage Cable

Inaccessible cable 

To develop aging 

management 

procedure to prevent 

moisture collection in 

man holes and to 

revise GALL AMP 

XI.E3

Withdrawn and 

Closed 

Incorporated in 

LRGDs - revision to 

GALL AMP XI.E3

GALL Volume 

2, AMP XI.E3

19 “Proposed Aging Management 

Program XI.M11-A, 'Nickel-Alloy 

Penetration Nozzles Welded to 

the Upper Reactor Vessel 

Closure Heads of Pressurized 

Water Reactors (PWRs Only),’ 

for License Renewal”

Nickel-alloy 

Revise aging 

management program 

XI.M11 to include 

nickel-alloy upper 

vessel heads (primary 

water stress corrosion 

cracking in nickel-alloy 

upper reactor vessel 

head penetration 

nozzles)

Withdrawn and 

Closed 

Incorporated in final 

LRGDs

GALL Volume 

2, AMP 

XI.M11-A 

(new) and 

corresponding 

AMR lineitems

20 Include Steam Generator Tube 

Integrity in AMP XI.M19

Steam Generator Tube 

Integrity 

Revise aging 

management program 

XI.M19 to include 

steam generator tube 

integrity

Withdrawn and 

Closed 

Incorporated in 

LRGD - revision to 

XI.M19

GALL Volume 

2, AMP 

XI.M19

21 Improve GALL Guidance on 

Reactor Vessel Internals 

Reactor vessel 

internals 

Revise Chapter IV 

tables, AMP XI.M9 and 

AMP XI.M16, to 

provide improved 

guidance on reactor 

vessel internals

Withdrawn and 

Closed 

Incorporated in 

LRGDs - revision to 

XI.M9 and 

replacement of 

XI.M16 with specific 

guidance in AMR 

line-items

GALL Volume 

2, AMP XI.M9 

and 

corresponding 

AMR lineitems
October 2005 9 NUREG-1833

Figure 1, below, shows that the developing NPP license renewal guidance was an evolutionary 

process. Such LRG documents provide a method for systematic review of plant aging related to 

continued operation and license renewal of operating reactors. Literature on mechanical, 

structural, and thermal-hydraulic components and systems reviewed consisted of Nuclear Plant 

Aging Research (NPAR) reports, NRC Generic Letters, Information Notices, Licensee Event

Reports (LERs), Bulletins, NUMARC Industry Reports and literature on electrical components 

and systems. The results of these reviews were first systematized using a standardized tabular 

format and standardized definitions of aging-related degradation mechanisms and effects 

(GALL 1996). This knowledge base was then expanded upon to provide credit for existing plant 

programs and further systematized to increase the LR review process effectiveness and 

efficiency of the license renewal review process in the 2001 version of the GALL Report (GALL 

Rev. 0). GALL Rev.0 updated the knowledge base to include aging related events reported in 

the LERs and expanded the scope to include evaluation of existing plant programs. 

Concurrently in 2001, NRC published the standard review plan for review of license renewal 

applications for nuclear power plants (SRP-LR) and the Regulatory Guide (RG) 1.188, 

“Standard Format and Content for Applications to Renew Nuclear Power Plant Operating 

Licenses,” which endorses the Nuclear Energy Institute (NEI) guidance in NEI 95-10, Revision 

3, “Industry Guideline for Implementing the Requirements of 10 CFR Part 54 - The License 

Renewal Rule.” The SRP-LR sections are keyed to RG-1.188; the sections are numbered 

correspondingly. These documents were all revised in 2005 to incorporate lessons learned from 

operating experience and the past seven years of reviewing license renewal applications. Figure 

2 shows the relationship between the five LRG NUREGs completed in 2005.

Figure 1 

Historical LRG Development

Operating 

Experience

Nuclear Plant Aging Research - Over 150 Technical Reports

GALL 1996 

Generic Aging Lessons Learned

Active and Passive SSCs

GALL 2001

Existing Programs

Addresses Aging Management 

for Passive SSCs

Maintenance Rule

Issued ’91, Implemented ’96

Addresses Aging Management 

for Active SSCs

Lessons Learned

GALL 2005

License Renewal Guidance Document Update

More efficient, user friendly and universally applicable

Audits and Inspections Review of LRAs
NUREG-1833 10 October 2005

Figure 2

GALL Report 

NUREG-1801 Vol 1

AMR Summaries

GALL Report 

NUREG-1801 Vol 1

AMR Summaries

GALL Report 

NUREG-1801 Vol 2

Definitions

AMRs

AMPs

GALL Report 

NUREG-1801 Vol 2

Definitions

AMRs

AMPs

Public Comment Document 

NUREG-1832

Resolution to all Comments

Comparison between 

1/05 & 9/05 AMR items

Public Comment Document 

NUREG-1832

Resolution to all Comments

Comparison between 

1/05 & 9/05 AMR items

Bases Document NUREG-1833

Usage of MEAP Terms

SRP Development Tool

New and Revised AMRs

Revisions to AMPs

Revisions to SRP-LR 

Bases Document NUREG-1833

Usage of MEAP Terms

SRP Development Tool

New and Revised AMRs

Revisions to AMPs

Revisions to SRP-LR 

SRP-LR 

NUREG-1800

License Renewal Guidance Documents Update and Development Process
October 2005 11 NUREG-1833

II. Justification for Inclusion of New Aging Management Review (AMR) Line-Items

Tables II.A, II.B and II.C identify the new MEAP combinations that were added to the GALL 

Report for the mechanical, structural, and electrical systems, respectively. In addition to the 

MEAPs, the structure and/or component as well as the item identifier are also identified. 

The following describes the information presented in each column of these tables.

GALL Rev. 1 has added new AMR line-items where the staff has accepted the position that a 

given material in the specified environment exhibits no aging effect and that the component or 

structure will therefore remain capable of performing its intended functions consistent with the 

current licensing basis (CLB) for the period of extended operation. Although there is a technical 

basis (e.g.; materials handbook references and industry operating experience) that no aging 

effects are expected for certain material/environment combinations, the position that a certain 

material is not subject to an aging effect may require further confirmation, since industry 

operating experience subsequent to the publication of GALL Rev. 1 should be considered in 

preparing license renewal applications. 

Column Heading Description

Item Identifies the item number in Volume 2, Chapters II through 

VIII presenting the detailed information summarized by this 

row. The first letter identifies the discipline(s) that the 

precedent is associated with (i.e., “A” for Auxiliary Systems, 

“E” for Engineered Safety Features Systems, “L” for 

Electrical Systems, R” for Reactor Coolant Systems, “T” for 

“Structures and Component Supports, “S” for Steam and 

Power Conversion Systems, and “C” for Containment

Structures). The second letter “P” identifies that there is a 

precedent for this new MEAP combination. 

Structure and/or 

Component

Identifies the structure or components to which the row 

applies

Material Identifies the material of construction for the structure or 

components to which the row applies

Environment Identifies the environmental conditions for the structure or 

components to which the row applies

Aging Effect/ 

Mechanism

Identifies the applicable aging effect and mechanism(s). See 

Chapter IX of the GALL Report Volume 2 for more 

information.

Aging Management 

Programs (AMP)

Identifies the time limited aging analysis or aging 

management program found acceptable for properly 

managing the affects of aging. See Chapter X and XI of the 

GALL Report Volume 2.

Precedent and 

Technical Basis for 

New AMR Line-Item

Provides background on the source of NRC positions 

previously approved (such as pertinent SERs in response to 

earlier LRAs) of the SRP-LR that provides further 

information on this evaluation. 

Tables IIA through IIC provide the precedence and technical justification showing the 

relationship between the item number and the item identifier used in the tables found in 

Chapters II through VIII of the GALL Report Volume 2.
NUREG-1833 12 October 2005

This Page Intentionally Left Blank
October 2005 13 NUREG-1833

II.A New AMR Line-items related to Mechanical Systems

Table II.A presents the new AMR line-items that are based on new Material, Environment, Aging Effect/Mechanism, and 

Aging Management Program (MEAP) combinations applicable to mechanical systems.

Table II.A New AMR Line-items based on new ‘MEAP’ combinations relevant to Mechanical Systems (“A” for Auxiliary, “E” for 

Engineered Safety Features, “R” for Reactor Coolant, and “S” for Steam and Power Conversion) 

Item

Structure 

and/or 

Component

Material Environment Aging Effect/ 

Mechanism AMP Precedent and Technical Basis for New Line-Item

AP-1

EP-2

Piping, piping 

components, 

and piping 

elements

Aluminum Air with 

borated water 

leakage

Loss of material/ 

boric acid 

corrosion

Chapter XI.M10, 

“Boric Acid 

Corrosion”

Aluminum piping, piping components, and piping 

elements when subject to air with borated water 

leakage are subject to loss of material due to boric acid 

corrosion. An approved precedent exists for adding this 

material, environment, aging effect, and program 

combination to the GALL Report. As shown in VCS

SER Section 3.0.3.1.1, the Staff has accepted the 

position that loss of material due to boric acid corrosion 

exhibited by aluminum in an air with borated water 

leakage environment is properly managed by the Boric 

Acid Corrosion AMP which provides engineering 

evaluations and corrective actions to ensure that boric 

acid corrosion does not lead to degradation of the 

affected structures or components (including adjacent 

structures or components). The implementation of this 

program provides reasonable assurance that the 

component’s intended functions will be maintained 

within the CLB for the extended period of operation.
NUREG-1833 14 October 200

5

Table II.A New AMR Line-items based on new ‘MEAP’ combinations relevant to Mechanical Systems (“A” for Auxiliary, “E” for 

Engineered Safety Features, “R” for Reactor Coolant, and “S” for Steam and Power Conversion) 

Item

Structure 

and/or 

Component

Material Environment Aging Effect/ 

Mechanism AMP Precedent and Technical Basis for New Line-Item

AP-2

EP-4

SP-1

Piping, piping 

components, 

and piping 

elements

 Steel Air – indoor 

controlled (Ext)

None None An approved precedent exists for adding this material, 

environment, aging effect, and program combination to

the GALL Report. As shown in RNP SER Section 

3.1.2.1, the Staff has accepted the position that steel in 

an indoor controlled air environment exhibits no aging 

effect and that the component or structure will therefore 

remain capable of performing its intended functions 

consistent with the CLB for the period of extended 

operation. This conclusion is based on the fact that both 

oxygen and moisture must be present to corrode steel 

(Metals Handbook, 1987). Experience has shown that 

general corrosion of carbon steel or low alloy steel 

components would only occur if the components were 

exposed to outdoor environments or to indoor 

environments that could promote the condensation of 

water on the external surfaces of the components.

AP-3

EP-5

RP-01

SP-2

Piping, piping 

components, 

and piping 

elements

 Steel Concrete None None An approved precedent exists for adding this material, 

environment, aging effect, and program combination to

the GALL Report. As shown in VCS SER Section 

3.3.2.4.21, the Staff has accepted the position that steel 

in a concrete environment exhibits no aging effect and 

that the component or structure will therefore remain 

capable of performing its intended functions consistent 

with the CLB for the period of extended operation. This 

conclusion is based on the fact that corrosion of 

embedded steel (surrounded by concrete) is not 

significant if the attributes of the concrete design are 

consistent with ACI 318-63, in particular a low water-tocement ratio, low permeability, and adequate air 

entrainment as cited in NUREG-1557. This AMR item is 

not intended to apply to steel tanks simply in contact 

with concrete.
October 2005 15 NUREG-1833

Table II.A New AMR Line-items based on new ‘MEAP’ combinations relevant to Mechanical Systems (“A” for Auxiliary, “E” for 

Engineered Safety Features, “R” for Reactor Coolant, and “S” for Steam and Power Conversion) 

Item

Structure 

and/or 

Component

Material Environment Aging Effect/ 

Mechanism AMP Precedent and Technical Basis for New Line-Item

AP-4 Piping, piping 

components, 

and piping 

elements

Steel Dried air None None An approved precedent exists for adding this material, 

environment, aging effect, and program combination to

the GALL Report. As shown in Ginna SER Section 

3.3.2.4.9.2, the Staff has accepted the position that 

steel in a dry air environment exhibits no aging effect 

and that the component or structure will therefore 

remain capable of performing its intended functions 

consistent with the CLB for the period of extended 

operation. This conclusion is based on the fact that both 

oxygen and moisture must be present to corrode steel 

(Steelwork Corrosion Control, Bayliss and Deacon, 

2002, pg. 5). Components are not subject to moisture in 

a dry air environment.

AP-6

EP-7

SP-4

Piping, piping 

components, 

and piping 

elements

 Steel Gas None None An approved precedent exists for adding this material, 

environment, aging effect, and program combination to

the GALL Report. As shown in RNP SER Section 

3.1.2.4.1.2, the Staff has accepted the position that 

steel in an inert or non-reactive gas environment 

exhibits no aging effect and that the component or 

structure will therefore remain capable of performing its 

intended functions consistent with the CLB for the 

period of extended operation. This conclusion is based 

on the fact that gaseous corrosion (dry corrosion) 

usually involves reaction with high-temperature gases.

This unique MEAP combination refers only to internal 

gas environments from non-reactive and/or inert gases 

that are truly dry and free from possible contaminants. 

The AMP XI.M26 “Fire Protection” is used for the 

periodic inspection and testing of the halon/CO2 fire 

suppression system.
NUREG-1833 16 October 200

5

Table II.A New AMR Line-items based on new ‘MEAP’ combinations relevant to Mechanical Systems (“A” for Auxiliary, “E” for 

Engineered Safety Features, “R” for Reactor Coolant, and “S” for Steam and Power Conversion) 

Item

Structure 

and/or 

Component

Material Environment Aging Effect/ 

Mechanism AMP Precedent and Technical Basis for New Line-Item

AP-8 Piping, piping 

components, 

and piping 

elements

CopperalloyDried air None None An approved precedent exists for adding this material, 

environment, aging effect, and program combination to

the GALL Report. As shown in St. Lucie SER Section 

3.3.8.2.1, the Staff has accepted the position that 

copper alloy in a dry air environment exhibits no aging 

effect and that the component or structure will therefore 

remain capable of performing its intended functions 

consistent with the CLB for the period of extended 

operation. This conclusion is based on the fact that 

comprehensive tests, conducted over a 20-year period 

under the supervision of ASTM, have confirmed the 

suitability of copper and copper alloys for atmospheric 

exposure as cited in Metals Handbook, Volume 13, 

Corrosion, American Society for Metals, 1987.

AP-9

EP-9

SP-5

Piping, piping 

components, 

and piping 

elements

CopperalloyGas None None An approved precedent exists for adding this material, 

environment, aging effect, and program combination to

the GALL Report. As shown in VCS SER Section 

3.3.2.4.4 on page 3-220, the Staff has accepted the 

position that copper alloy in a gas environment exhibits 

no aging effect and that the component or structure will 

therefore remain capable of performing its intended 

functions consistent with the CLB for the period of 

extended operation. Operating experience shows that 

copper piping exposed to an internal gaseous operating 

condition will be resistant to age-related degradation.

This unique MEAP combination refers only to internal 

gas environments from non-reactive and/or inert gases 

that are truly dry and free from possible contaminants. 

The AMP XI.M26 “Fire Protection” is used for the 

periodic inspection and testing of the halon/CO2 fire 

suppression system.
October 2005 17 NUREG-1833

Table II.A New AMR Line-items based on new ‘MEAP’ combinations relevant to Mechanical Systems (“A” for Auxiliary, “E” for 

Engineered Safety Features, “R” for Reactor Coolant, and “S” for Steam and Power Conversion) 

Item

Structure 

and/or 

Component

Material Environment Aging Effect/ 

Mechanism AMP Precedent and Technical Basis for New Line-Item

AP-11

EP-12

Piping, piping 

components, 

and piping 

elements

Copperalloy <15 % 

Zn

Air with 

borated water 

leakage

None None An approved precedent exists for adding this material, 

environment, aging effect, and program combination to

the GALL Report. As shown in RNP SER Section 

3.2.2.4.1.1, the Staff has accepted the position that 

copper alloy with less than 15% Zn in an air with 

borated water leakage environment exhibits no aging 

effect and that the component or structure will therefore 

remain capable of performing its intended functions 

consistent with the CLB for the period of extended 

operation. Ref: Metals Handbook, Volume 13, 

Corrosion, American Society for Metals, 1987, page 

617.

AP-12

EP-36

RP-11

SP-8

Piping, piping 

components, 

and piping 

elements

Copper 

alloy

Closed cycle 

cooling water

Loss of material/ 

pitting, crevice 

and galvanic 

corrosion

Chapter XI.M21, 

“Closed-Cycle 

Cooling Water 

System”

An approved precedent exists for adding this material, 

environment, aging effect, and program combination to

the GALL Report. As shown in FCS SER Section 

3.0.3.7.3, the Staff has accepted the position that loss 

of material from pitting, crevice, and/or galvanic 

corrosion, exhibited by copper alloy in a closed-cycle

cooling water environment, is properly managed by the 

Closed-Cycle Cooling Water System AMP which 

ensures system corrosion inhibitor concentrations are 

maintained within specified limits of EPRI TR-107396. 

The implementation of this program provides 

reasonable assurance that the component's intended 

functions will be maintained within the CLB for the 

extended period of operation.
NUREG-1833 18 October 200

5

Table II.A New AMR Line-items based on new ‘MEAP’ combinations relevant to Mechanical Systems (“A” for Auxiliary, “E” for 

Engineered Safety Features, “R” for Reactor Coolant, and “S” for Steam and Power Conversion) 

Item

Structure 

and/or 

Component

Material Environment Aging Effect/ 

Mechanism AMP Precedent and Technical Basis for New Line-Item

AP-13

EP-14

Piping, piping 

components, 

and piping 

elements

Ducting

Galvanized 

Steel 

Air – indoor

uncontrolled 

Air – indoor 

controlled (Ext)

None None An approved precedent exists for adding this material, 

environment, aging effect, and program combination to

the GALL Report. As shown in Ginna SER Section 

3.3.2.5.4, the Staff has accepted the position that 

galvanized steel in an indoor air environment exhibits 

no aging effect and that the component or structure will 

therefore remain capable of performing its intended 

functions consistent with the CLB for the period of 

extended operation. The zinc coating in galvanized 

steel protects the underlying steel and the corrosion 

rate of zinc (coating the steel) in dry clean air is very 

low (0.13 μm/yr) as cited in references such as J.R. 

Davis, Corrosion, 2000.

Since ducting is thinner than piping and thus potentially 

more prone to aging degradation, the environmental 

constraints are more severe for ducting (air indoor 

control) compared to piping (air indoor-uncontrolled) to 

allow the applicability of this ‘null set’ AMR line-item. 

AP-14

EP-15

SP-9

Piping

elements

Glass Air – indoor 

uncontrolled 

(Ext)

None None An approved precedent exists for adding this material, 

environment, aging effect, and program combination to

the GALL Report. As shown in VCS SER Section 

3.3.2.4.4, the Staff has accepted the position that glass 

in an indoor, uncontrolled air environment exhibits no 

aging effect and that the component or structure will 

therefore remain capable of performing its intended 

functions consistent with the CLB for the period of 

extended operation. This conclusion is based on the 

fact that there have been no aging effects observed for 

glass components in this air environment. Ref: 

Handbook of Glass Properties, N. P. Bansal and R. H. 

Doremua, Academic Press 1986, pg. 646.
October 2005 19 NUREG-1833

Table II.A New AMR Line-items based on new ‘MEAP’ combinations relevant to Mechanical Systems (“A” for Auxiliary, “E” for 

Engineered Safety Features, “R” for Reactor Coolant, and “S” for Steam and Power Conversion) 

Item

Structure 

and/or 

Component

Material Environment Aging Effect/ 

Mechanism AMP Precedent and Technical Basis for New Line-Item

AP-15

EP-16

SP-10

Piping 

elements

Glass Lubricating oil None None An approved precedent exists for adding this material, 

environment, aging effect, and program combination to

the GALL Report. As shown in VCS SER Section 

3.2.2.4.1, the Staff has accepted the position that glass 

in a lubricating oil environment exhibits no aging effect 

and that the component or structure will therefore 

remain capable of performing its intended functions 

consistent with the CLB for the period of extended 

operation. This conclusion is based on the fact that no 

failure due to an aging effect of glass components in 

environments free of hydrofluoric acid, caustics, or hot 

water have been recorded in industry at the 

temperatures or during the time periods of concern for 

extended operation.

AP-16

EP-17

RP-03

SP-11

Piping, piping 

components, 

and piping 

elements

Nickel-alloy Air – indoor 

uncontrolled 

(Ext)

None None An approved precedent exists for adding this material, 

environment, aging effect, and program combination to

the GALL Report. As shown in the St. Lucie SER 

Section 3.2.2.2-1, the Staff has accepted the position 

that nickel alloy in an indoor, uncontrolled air 

environment exhibits no aging effect and that the 

component or structure will therefore remain capable of 

performing its intended functions consistent with the 

CLB for the period of extended operation. This 

conclusion is based on the fact that nickel alloys have 

superior corrosion resistance in normal atmosphere, 

surpassing stainless steel as cited in J. R. Davis, 

Corrosion, 2000.
NUREG-1833 20 October 200

5

Table II.A New AMR Line-items based on new ‘MEAP’ combinations relevant to Mechanical Systems (“A” for Auxiliary, “E” for 

Engineered Safety Features, “R” for Reactor Coolant, and “S” for Steam and Power Conversion) 

Item

Structure 

and/or 

Component

Material Environment Aging Effect/ 

Mechanism AMP Precedent and Technical Basis for New Line-Item

AP-17

EP-18

RP-04

SP-12

Piping, piping 

components, 

and piping 

elements

Stainless 

Steel

Air – indoor 

uncontrolled 

(Ext)

None None An approved precedent exists for adding this material, 

environment, aging effect, and program combination to

the GALL Report. As shown in RNP SER Section 

3.3.2.4.6.1, the Staff has accepted the position that 

stainless steel in an indoor, uncontrolled air 

environment exhibits no aging effect and that the 

component or structure will therefore remain capable of 

performing its intended functions consistent with the 

CLB for the period of extended operation. This 

conclusion is based on the fact that stainless steels are 

highly resistant to corrosion in dry atmospheres in the 

absence of corrosive species, (which would be 

reflective of indoor uncontrolled air) as cited in Metals 

Handbook, Volumes 3 (p. 65) and 13 (p. 555), Ninth 

Edition, American Society for Metals International, 1980 

and 1987. Components are not subject to moisture in a 

dry air environment (and indoor uncontrolled air would 

have limited humidity and condensation).

AP-18

EP-19

RP-05

Piping, piping 

components, 

and piping 

elements

Stainless 

Steel

Air with 

borated water 

leakage

None None An approved precedent exists for adding this material, 

environment, aging effect, and program combination to

the GALL Report. As shown in Ginna SER Section 

3.2.2.4.1.2, the Staff has accepted the position that 

stainless steel in an air with borated water leakage 

environment exhibits no aging effect and that the 

component or structure will therefore remain capable of 

performing its intended functions consistent with the 

CLB for the period of extended operation. This 

conclusion is based on the fact that stainless steel is 

not susceptible to general corrosion when subjected to 

borated water environments as cited in "Boric Acid 

Corrosion Guidebook," November 2001, EPRI 1000975.
October 2005 21 NUREG-1833

Table II.A New AMR Line-items based on new ‘MEAP’ combinations relevant to Mechanical Systems (“A” for Auxiliary, “E” for 

Engineered Safety Features, “R” for Reactor Coolant, and “S” for Steam and Power Conversion) 

Item

Structure 

and/or 

Component

Material Environment Aging Effect/ 

Mechanism AMP Precedent and Technical Basis for New Line-Item

AP-19

EP-20

RP-06

SP-13

Piping, piping 

components, 

and piping 

elements

Stainless 

Steel

Concrete None None An approved precedent exists for adding this material, 

environment, aging effect, and program combination to

the GALL Report. As shown in VCS SER Section 

3.2.2.2.3, the Staff has accepted the position that 

stainless steel in a concrete environment exhibits no 

aging effect and that the component or structure will 

therefore remain capable of performing its intended 

functions consistent with the CLB for the period of 

extended operation. This conclusion is based on the 

fact that industrial experience shows no evidence of 

stainless steel being degraded when embedded in 

concrete. Ref: Steelwork Corrosion Control, D. A. 

Bayliss and D.H. Deacon, 2002. This AMR item is not 

intended to apply to steel tanks simply in contact with 

concrete.
NUREG-1833 22 October 200

5

Table II.A New AMR Line-items based on new ‘MEAP’ combinations relevant to Mechanical Systems (“A” for Auxiliary, “E” for 

Engineered Safety Features, “R” for Reactor Coolant, and “S” for Steam and Power Conversion) 

Item

Structure 

and/or 

Component

Material Environment Aging Effect/ 

Mechanism AMP Precedent and Technical Basis for New Line-Item

AP-20 Piping, piping 

components, 

and piping 

elements

Stainless 

steel

Dried air None None An approved precedent exists for adding this material, 

environment, aging effect, and program combination to

the GALL Report. As shown in St. Lucie SER Section 

3.3.8.2.1, the Staff has accepted the position that 

stainless steel in a dried air environment exhibits no 

aging effect and that the component or structure will 

therefore remain capable of performing its intended 

functions consistent with the CLB for the period of 

extended operation. This conclusion is based on the 

fact that, on the basis of current industry research and 

operating experience, dry air on metal will not result in 

aging that will be of concern during the period of 

extended operation. Wrought austenitic stainless steels 

are not susceptible to significant general corrosion that 

would affect the intended function of components. This 

conclusion is based on the fact that stainless steels are 

highly resistant to corrosion in dry atmospheres in the 

absence of corrosive species. (Ref: Metals Handbook, 

Volumes 3 (p. 65) and 13 (p. 555), Ninth Edition, 

American Society for Metals International, 1980 and 

1987). Components are not subject to moisture in a dry 

air environment.
October 2005 23 NUREG-1833

Table II.A New AMR Line-items based on new ‘MEAP’ combinations relevant to Mechanical Systems (“A” for Auxiliary, “E” for 

Engineered Safety Features, “R” for Reactor Coolant, and “S” for Steam and Power Conversion) 

Item

Structure 

and/or 

Component

Material Environment Aging Effect/ 

Mechanism AMP Precedent and Technical Basis for New Line-Item

AP-22

EP-22

RP-07

SP-15

Piping, piping 

components 

and piping 

elements

Stainless 

Steel

Gas None None An approved precedent exists for adding this material, 

environment, aging effect, and program (MEAP) 

combination to the GALL Report. As shown in Ginna 

SER Section 3.2.2.4.1.1, the Staff has accepted the 

position that stainless steel in a gas environment 

exhibits no aging effect and that the component or 

structure will therefore remain capable of performing its 

intended functions consistent with the CLB for the 

period of extended operation. This conclusion is based 

on the fact that stainless steels are highly resistant to 

corrosion in dry atmospheres in the absence of 

corrosive species (Ref: Metals Handbook, Volumes 3 

(p. 65) and 13 (p. 555), Ninth Edition, American Society 

for Metals International, 1980 and 1987). 

This unique MEAP combination refers only to internal 

gas environments from non-reactive and/or inert gases 

that are truly dry and free from possible contaminants. 

The AMP XI.M26 “Fire Protection” is used for the 

periodic inspection and testing of the halon/CO2 fire 

suppression system.
NUREG-1833 24 October 200

5

Table II.A New AMR Line-items based on new ‘MEAP’ combinations relevant to Mechanical Systems (“A” for Auxiliary, “E” for 

Engineered Safety Features, “R” for Reactor Coolant, and “S” for Steam and Power Conversion) 

Item

Structure 

and/or 

Component

Material Environment Aging Effect/ 

Mechanism AMP Precedent and Technical Basis for New Line-Item

AP-26

EP-24

Closure bolting Steel Air - indoor 

uncontrolled 

(External)

Loss of preload/ 

thermal effects, 

gasket creep, and 

self-loosening

Chapter XI.M18, 

“Bolting 

Integrity”

A previously approved staff position exists for adding 

this material, environment, aging effect, and program 

combination for the auxiliary system in 

GALL Rev. 1. GALL Rev. 0 had this material, 

environment, aging effect, and program combination for

RCS steam generators (IVD2.1-k as an example). As 

noted in EPRI NP-5769, steel gaskets can be subject to 

loss of preload even under conditions of indoor 

uncontrolled air. By requiring periodic inspection of 

closure bolting according to the recommendations of 

EPRI NP-5769 "Degradation and Failure of Bolting in 

Nuclear Power Plants" for loss of preload. AMP XI.M18

provides for proper management of the aging effects for 

this MEAP combination for this component. Thus, 

implementation of this program provides reasonable 

assurance that the component’s intended functions will 

be maintained within the CLB for the period of extended 

operation.

AP-27

EP-25

Closure bolting Steel Air - indoor 

uncontrolled 

(External)

Loss of material/ 

general, pitting, 

and crevice 

corrosion

Chapter XI.M18, 

“Bolting

Integrity”

A previously approved staff position exists for adding 

this material, environment, aging effect, and program 

combination for the auxiliary system in GALL Rev. 1. 

GALL Rev. 0 had a similar material, environment, aging 

effect, and program combination for the general 

corrosion of steel closure bolting (see VII.I.2-a and 

VIII.H.2-a) exposed to "air, moisture, humidity, and 

leaking fluid.” In GALL Rev. 1, the recategorization of 

environments led to this new AMR line-item. By 

requiring periodic inspection of closure bolting for loss 

of material due to corrosion. AMP XI.M18 provides for 

proper management of the aging effects for this MEAP 

combination for this component. Thus, implementation 

of this program provides reasonable assurance that the 

component’s intended functions will be maintained 

within the CLB for the period of extended operation.
October 2005 25 NUREG-1833

Table II.A New AMR Line-items based on new ‘MEAP’ combinations relevant to Mechanical Systems (“A” for Auxiliary, “E” for 

Engineered Safety Features, “R” for Reactor Coolant, and “S” for Steam and Power Conversion) 

Item

Structure 

and/or 

Component

Material Environment Aging Effect/ 

Mechanism AMP Precedent and Technical Basis for New Line-Item

AP-28

EP-1

Bolting Steel Air – outdoor 

(External)

Loss of material/ 

general, pitting, 

and crevice 

corrosion

Chapter XI.M18, 

“Bolting 

Integrity”

A previously approved staff position exists for adding 

this material, environment, aging effect, and program 

combination for the auxiliary system in GALL Rev. 1. 

GALL Rev. 0 had a similar material, environment, aging 

effect, and program combination for the general 

corrosion of steel closure bolting (VII.I.2-a and VIII.H.2-

a) exposed to "air, moisture, humidity, and leaking 

fluid.” In GALL Rev. 1, the recategorization of 

environments led to this new AMR line-item. This 

material, environment, aging effect, and program 

combination is consistent with that of AMR line-item V 

E.2-a in GALL Rev. 0. By requiring periodic inspection 

of closure bolting for loss of material due to corrosion. 

AMP XI.M18 provides for proper management of the 

aging effects for this MEAP combination for this 

component. Thus, implementation of this program 

provides reasonable assurance that the component’s 

intended functions will be maintained within the CLB for 

the period of extended operation.
NUREG-1833 26 October 200

5

Table II.A New AMR Line-items based on new ‘MEAP’ combinations relevant to Mechanical Systems (“A” for Auxiliary, “E” for 

Engineered Safety Features, “R” for Reactor Coolant, and “S” for Steam and Power Conversion) 

Item

Structure 

and/or 

Component

Material Environment Aging Effect/ 

Mechanism AMP Precedent and Technical Basis for New Line-Item

AP-30

SP-25

EP-46

Piping, piping 

components, 

and piping 

elements

Steel Lubricating oil Loss of material/ 

general, pitting, 

and crevice 

corrosion

Chapter XI.M39, 

"Lubricating Oil 

Analysis"

The AMP is to 

be augmented 

by verifying the 

effectiveness of 

the lubricating oil 

analysis 

program. See 

Chapter XI.M32, 

“One-Time 

Inspection,” for 

an acceptable 

verification 

program.

An approved precedent exists for adding this material, 

environment, aging effect, and program combination to

the GALL Report. As shown in Ft. Calhoun Unit 1 SER 

Section 3.3.2.4.4, the Staff has accepted the position 

that steel in a lubricating oil environment exhibits a loss 

of material aging effect and therefore recommends

management by a program. AMP XI.M39 was 

developed to provide for proper management of the 

aging effects for this MEAP combination. This program 

provides an acceptable means of managing aging of 

these components with one-time inspection (AMP 

XI.M32) to provide a mitigative and verification method. 

See Table IV for further discussion of the basis for 

these AMPs. The implementation of this augmented 

program provides reasonable assurance that the 

component’s intended functions will be maintained 

within the CLB for the period of extended operation.
October 2005 27 NUREG-1833

Table II.A New AMR Line-items based on new ‘MEAP’ combinations relevant to Mechanical Systems (“A” for Auxiliary, “E” for 

Engineered Safety Features, “R” for Reactor Coolant, and “S” for Steam and Power Conversion) 

Item

Structure 

and/or 

Component

Material Environment Aging Effect/ 

Mechanism AMP Precedent and Technical Basis for New Line-Item

AP-31

SP-27

Piping, piping 

components, 

and piping 

elements

Gray cast 

iron

Treated water Loss of material/ 

selective leaching

Chapter XI.M33, 

“Selective 

Leaching of 

Materials”

An approved precedent exists for adding this material, 

environment, aging effect, and program combination in 

GALL Rev. 1. GALL Rev. 0 considered this MEAP 

combination for Auxiliary system Chapter VII, item 

C2.3-a for component cooling water environment (which 

is similar to treated water environment). This MEAP 

combination was not included in other Auxiliary systems 

in Chapter VII. In Chapter VII, sections A4, C2, E3, and 

E4, this MEAP combination was added to address the 

potential for selective leaching in gray cast iron 

components in the Spent Fuel Pool Cooling and 

Cleanup (BWR), Closed-Cycle Cooling Water, Reactor 

Water Cleanup, and Shutdown Cooling (for Older 

BWRs) systems. As shown in Ginna SER Section 

3.3.2.4.2, the Staff has accepted the position that gray 

cast iron in a treated water environment exhibits a loss 

of material due to selective leaching and therefore 

recommends management by a program. The aging 

effect is adequately managed by AMP XI.M33, 

“Selective Leaching of Materials,” which includes a 

hardness test or a destructive test to confirm that the 

iron matrix is not selectively leached away and a porous 

matrix of graphite is left. Implementation of this AMP 

provides reasonable assurance that the component’s 

intended functions will be maintained within the CLB for 

the extended period of operation.
NUREG-1833 28 October 200

5

Table II.A New AMR Line-items based on new ‘MEAP’ combinations relevant to Mechanical Systems (“A” for Auxiliary, “E” for 

Engineered Safety Features, “R” for Reactor Coolant, and “S” for Steam and Power Conversion) 

Item

Structure 

and/or 

Component

Material Environment Aging Effect/ 

Mechanism AMP Precedent and Technical Basis for New Line-Item

AP-32

SP-55

Piping, piping 

components, 

and piping 

elements

Copper 

alloy >15% 

Zn

Treated water Loss of material/ 

selective leaching

Chapter XI.M33, 

“Selective 

Leaching of 

Materials”

As shown in FCS Unit 1 SER Section 3.3.2.4.6, the 

Staff has accepted the position that selective leaching 

of copper-alloy in a treated water environment is 

properly managed by the Selective Leaching of 

Materials Program, which includes a one-time visual 

inspection and hardness measurement of selected 

components to determine whether loss of material due 

to selective leaching is occurring. The aging effect is 

adequately managed by AMP XI.M33, “Selective 

Leaching of Materials,” which includes hardness test or 

destructive test to confirm that the zinc is not selectively 

leached away and a porous matrix of copper is left. 

Implementation of this AMP provides reasonable 

assurance that the component’s intended functions will 

be maintained within the CLB for the extended period of 

operation.
October 2005 29 NUREG-1833

Table II.A New AMR Line-items based on new ‘MEAP’ combinations relevant to Mechanical Systems (“A” for Auxiliary, “E” for 

Engineered Safety Features, “R” for Reactor Coolant, and “S” for Steam and Power Conversion) 

Item

Structure 

and/or 

Component

Material Environment Aging Effect/ 

Mechanism AMP Precedent and Technical Basis for New Line-Item

AP-33 Diesel engine 

exhaust 

Piping, piping 

components, 

and piping 

elements

Stainless 

steel

Diesel exhaust Cracking/ stress 

corrosion 

cracking

A plant-specific 

aging 

management 

program is to be 

evaluated

The Staff has accepted the position that the possible 

stress corrosion cracking of stainless steel diesel 

engine exhaust piping, piping components, and piping 

elements is managed by a plant-specific aging 

management program. The FCS SER section 3.3.2.4.3

identifies stainless steel as a material in diesel exhaust 

gas environment with loss of material and cracking as 

viable aging effects. GALL Rev. 0 Chapter VIIH.2.4-a 

only identifies carbon steel and loss of material due to 

general, pitting, and crevice corrosion of steel diesel 

engine combustion air exhaust subsystem components 

that are exposed to hot diesel engine exhaust gases 

containing moisture and particulates. Similar 

components constructed of stainless steel were 

observed to be susceptible to cracking in hot diesel 

exhaust gas. A plant-specific aging management 

program will be evaluated to provide reasonable 

assurance that the component’s intended functions will 

be maintained within the CLB for the period of extended 

operation.

AP-34

EP-13

Heat 

exchanger 

components

Copper 

alloy 

Closed cycle 

cooling water

Loss of material/ 

pitting, crevice, 

and galvanic 

corrosion

Chapter XI.M21,

“Closed-Cycle 

Cooling Water 

System”

An approved precedent exists for adding this material, 

environment, aging effect, and program combination to

the GALL Report. As shown in FCS SER Section 

3.0.3.7.3, the Staff has accepted the position that loss 

of material from pitting, crevice, and/or galvanic 

corrosion, exhibited by copper alloy in a closed-cycle

cooling water (treated water) environment, is properly 

managed by AMP XI.M21, which ensures that system 

corrosion inhibitor concentrations are maintained within 

specified limits of EPRI TR-107396. Implementation of 

AMP XI.M21 provides reasonable assurance that the 

component’s intended functions will be maintained 

within the CLB for the extended period of operation.
NUREG-1833 30 October 200

5

Table II.A New AMR Line-items based on new ‘MEAP’ combinations relevant to Mechanical Systems (“A” for Auxiliary, “E” for 

Engineered Safety Features, “R” for Reactor Coolant, and “S” for Steam and Power Conversion) 

Item

Structure 

and/or 

Component

Material Environment Aging Effect/ 

Mechanism AMP Precedent and Technical Basis for New Line-Item

AP-35 Piping, piping 

components, 

and piping 

elements

Aluminum Fuel oil Loss of 

material/pitting, 

crevice, and 

microbiologically 

influenced 

corrosion

XI.M30 Fuel Oil 

Chemistry

The AMP is to 

be augmented 

by verifying the 

effectiveness of 

fuel oil chemistry 

control. See 

XI.M32, “OneTime 

Inspection,” for 

an acceptable 

verification 

program.

An approved precedent exists for adding this material, 

environment, aging effect, and program combination to

the GALL Report. Pitting, crevice and microbiologically 

influenced corrosion is a concern in stagnant conditions 

and when water is present. As shown in Ginna SER 

Section 3.3.2.4.8, the Staff has accepted the position 

that loss of material exhibited by aluminum in a fuel oil 

environment is properly managed by the Fuel Oil 

Chemistry AMP which monitors fuel oil quality and the 

levels of water and microbiological organisms in the fuel 

oil. Implementation of this program, augmented by 

XI.M32, provides reasonable assurance that the 

component's intended functions will be maintained 

within the CLB for the extended period of operation.
October 2005 31 NUREG-1833

Table II.A New AMR Line-items based on new ‘MEAP’ combinations relevant to Mechanical Systems (“A” for Auxiliary, “E” for 

Engineered Safety Features, “R” for Reactor Coolant, and “S” for Steam and Power Conversion) 

Item

Structure 

and/or 

Component

Material Environment Aging Effect/ 

Mechanism AMP Precedent and Technical Basis for New Line-Item

AP-36 Piping, piping 

components, 

and piping 

elements

Aluminum Air – indoor 

controlled (Ext)

None None An approved precedent exists for adding this material, 

environment, aging effect, and program combination to

the GALL Report. As shown in FCS SER Section 

3.3.2.4.14, the Staff has accepted the position that 

aluminum in an indoor controlled air environment 

exhibits no aging effect and that the component or 

structure will therefore remain capable of performing its 

intended functions consistent with the CLB for the 

period of extended operation. Aluminum has an 

excellent resistance to corrosion when exposed to 

humid air (uncontrolled indoor environment) the 

aluminum oxide film is bonded strongly to its surface 

and that, if damaged, reforms immediately in most 

environments. On a surface freshly abraded and then 

exposed to air, the oxide film is only 5 to 10 nanometer 

thick but is highly effective in protecting the aluminum 

from corrosion (Hollingsworth and Hunsicker 1979). 

Therefore, aluminum exposed to indoor uncontrolled 

environment does not have any applicable aging effect. 

Reference: Hollingsworth, E. H., and Hunsicker, H. Y. 

1979. “Corrosion Resistance of Aluminum and 

Aluminum Alloys,” Metals Handbook Ninth Edition, 

Volume 2, Properties and Selection: Nonferrous Alloys 

and Pure Metals, pp. 204-236.
NUREG-1833 32 October 200

5

Table II.A New AMR Line-items based on new ‘MEAP’ combinations relevant to Mechanical Systems (“A” for Auxiliary, “E” for 

Engineered Safety Features, “R” for Reactor Coolant, and “S” for Steam and Power Conversion) 

Item

Structure 

and/or 

Component

Material Environment Aging Effect/ 

Mechanism AMP Precedent and Technical Basis for New Line-Item

AP-37

SP-23

Piping, piping 

components, 

and piping 

elements

Aluminum Gas None None An approved precedent exists for adding this material, 

environment, aging effect, and program combination to

the GALL Report. As shown in Peach Bottom SER 

Section 3.2.6.2.1, the Staff has accepted the position 

that aluminum in a gas environment exhibits no aging 

effect and that the component or structure will therefore 

remain capable of performing its intended functions 

consistent with the CLB for the period of extended 

operation. This conclusion is based on the fact that 

aluminum is indicated to have excellent corrosion 

resistance in a gas environment (such as nitrogen) as 

cited in Corrosion Resistant Tables, Fifth Edition, Part C 

(Philip A. Schweitzer, ed.) Marcel Dekker, Inc. (2004), 

p. 2201.

This unique MEAP combination refers only to internal 

gas environments from non-reactive and/or inert gases 

that are truly dry and free from possible contaminants. 

The AMP XI.M26 “Fire Protection” is used for the 

periodic inspection and testing of the halon/CO2 fire

suppression system.
October 2005 33 NUREG-1833

Table II.A New AMR Line-items based on new ‘MEAP’ combinations relevant to Mechanical Systems (“A” for Auxiliary, “E” for 

Engineered Safety Features, “R” for Reactor Coolant, and “S” for Steam and Power Conversion) 

Item

Structure 

and/or 

Component

Material Environment Aging Effect/ 

Mechanism AMP Precedent and Technical Basis for New Line-Item

AP-38

SP-24

EP-26

Piping, piping 

components, 

and piping 

elements

Aluminum Treated water Loss of material/ 

pitting and 

crevice corrosion

XI.M2 Water 

Chemistry

The AMP is to 

be augmented 

by verifying the 

effectiveness of 

water chemistry 

control. See 

Chapter XI.M32, 

“One-Time 

Inspection,” for 

an acceptable 

verification 

program.

Chapter XI.M2, 

"Water 

Chemistry" for 

BWR water

The AMP is to 

be augmented 

by verifying the 

effectiveness of 

water chemistry 

control. See 

Chapter XI.M32, 

“One-Time 

Inspection,” for 

an acceptable 

verification 

program.

An approved precedent exists for adding this material, 

environment, aging effect, and program combination to

the GALL Report. As shown in D/QC SER Section 

3.2.2.4.1, the Staff has accepted the position that loss 

of material is exhibited by aluminum in a demineralized 

water environment. Aluminum subjected to a similar 

treated water environment will similarly be subject to 

loss of material due to corrosion. As shown in D/QC 

SER Section 3.2.2.4.1, the aging effect is properly 

managed by the Water Chemistry AMP which includes 

specifications for chemical species, sampling, analysis 

frequencies, and corrective actions for control of reactor 

water chemistry. Implementation of this program, 

augmented by XI.M32, provides reasonable assurance 

that the component's intended functions will be 

maintained within the CLB for the extended period of 

operation.
NUREG-1833 34 October 200

5

Table II.A New AMR Line-items based on new ‘MEAP’ combinations relevant to Mechanical Systems (“A” for Auxiliary, “E” for 

Engineered Safety Features, “R” for Reactor Coolant, and “S” for Steam and Power Conversion) 

Item

Structure 

and/or 

Component

Material Environment Aging Effect/ 

Mechanism AMP Precedent and Technical Basis for New Line-Item

AP-39 Heat 

exchanger 

components

Steel Lubricating oil Loss of material/ 

general, pitting, 

crevice and 

microbiologically 

influenced 

corrosion, and 

fouling

Chapter XI.M39, 

"Lubricating Oil 

Analysis"

The AMP is to 

be augmented 

by verifying the 

effectiveness of 

the lubricating oil 

analysis 

program. See 

Chapter XI.M32, 

“One-Time 

Inspection,” for 

an acceptable

verification 

program.

An approved precedent exists for adding this material, 

environment, aging effect, and program combination to

the GALL Report. As shown in FCS SER Section 

3.3.2.2.4, the Staff has accepted the position that a 

steel heat exchanger shell in a lubricating oil 

environment exhibits a loss of material and, therefore,

necessitates an aging management program. Water 

contained in the lubricating oil will cause corrosion in 

steel materials. AMP XI.M39 was developed to provide 

for proper management of the aging effects for this 

MEAP combination. This program provides an 

acceptable means of managing aging of these 

components with one-time inspection (AMP XI.M32) to 

provide a mitigative and verification method. See Table 

IV for further discussion of the basis for these AMPs.

The implementation of this augmented program 

provides reasonable assurance that the component’s 

intended functions will be maintained within the CLB for 

the period of extended operation.
October 2005 35 NUREG-1833

Table II.A New AMR Line-items based on new ‘MEAP’ combinations relevant to Mechanical Systems (“A” for Auxiliary, “E” for 

Engineered Safety Features, “R” for Reactor Coolant, and “S” for Steam and Power Conversion) 

Item

Structure 

and/or 

Component

Material Environment Aging Effect/ 

Mechanism AMP Precedent and Technical Basis for New Line-Item

AP-40 Heat 

exchanger 

components

Steel Air – outdoor 

(Ext)

Loss of material/ 

general, pitting, 

and crevice 

corrosion

Chapter XI.M36, 

"External 

Surfaces 

Monitoring"

An approved precedent exists for adding this material, 

environment, aging effect, and program combination in 

GALL Rev. 1. GALL Rev. 0 addressed this MEAP 

combination in VII.I.1-b where the external surfaces of 

steel components exposed to air, moisture, and 

humidity are vulnerable to general corrosion (essentially 

captured in GALL Rev. 1 by A-77 and A-78 in VII.I 

addressing external surfaces of components and 

miscellaneous bolting). This additional AMR line-item is 

created to consider the corrosion of steel heat 

exchanger components in outdoor air. AMP XI.M36 was 

developed to provide for proper management of the 

aging effects for this MEAP combination. This program 

provides an acceptable means of managing aging of 

these components. See Table IV for further discussion 

of the basis for this AMP. The implementation of this 

program provides reasonable assurance that the 

component’s intended functions will be maintained 

within the CLB for the period of extended operation.
NUREG-1833 36 October 200

5

Table II.A New AMR Line-items based on new ‘MEAP’ combinations relevant to Mechanical Systems (“A” for Auxiliary, “E” for 

Engineered Safety Features, “R” for Reactor Coolant, and “S” for Steam and Power Conversion) 

Item

Structure 

and/or 

Component

Material Environment Aging Effect/ 

Mechanism AMP Precedent and Technical Basis for New Line-Item

AP-41 Heat 

exchanger 

components

Steel Air – indoor 

uncontrolled 

(Ext)

Loss of material/ 

general, pitting, 

and crevice 

corrosion

Chapter XI.M36, 

"External 

Surfaces 

Monitoring"

An approved precedent exists for adding this material, 

environment, aging effect, and program combination in 

GALL Rev. 1. GALL Rev. 0 addressed this MEAP 

combination in VII.I.1-b where the external surfaces of 

steel components exposed to air, moisture, and 

humidity are vulnerable to general corrosion (essentially 

captured in GALL Rev. 1 by A-77 and A-78 in VII.I 

addressing external surfaces of components and 

miscellaneous bolting). This additional AMR line-item is 

created to consider the corrosion of steel heat 

exchanger components in indoor uncontrolled air. AMP 

XI.M36 was developed to provide for proper 

management of the aging effects for this MEAP 

combination. This program provides an acceptable 

means of managing aging of these components. See 

Table IV for further discussion of the basis for this AMP. 

The implementation of this program provides 

reasonable assurance that the component’s intended 

functions will be maintained within the CLB for the 

period of extended operation.
October 2005 37 NUREG-1833

Table II.A New AMR Line-items based on new ‘MEAP’ combinations relevant to Mechanical Systems (“A” for Auxiliary, “E” for 

Engineered Safety Features, “R” for Reactor Coolant, and “S” for Steam and Power Conversion) 

Item

Structure 

and/or 

Component

Material Environment Aging Effect/ 

Mechanism AMP Precedent and Technical Basis for New Line-Item

AP-43

EP-27

RP-12

SP-29

Piping, piping 

components, 

and piping 

elements

Copper 

alloy >15% 

Zn

Closed cycle 

cooling water

Loss of material/ 

selective leaching

Chapter XI.M33, 

“Selective 

Leaching of 

Materials ”

An approved precedent exists for adding this material, 

environment, aging effect, and program combination to

the GALL Report. As shown in FCS Unit 1 SER Section 

3.3.2.4.6, the Staff has accepted the position that 

selective leaching of copper-alloy in a closed-cycle

cooling water environment is properly managed by the 

Selective Leaching of Materials Program, which 

includes a one-time visual inspection and hardness 

measurement of selected components to determine 

whether loss of material due to selective leaching is 

occurring. The aging effect is adequately managed by 

AMP XI.M33, “Selective Leaching of Materials,” which 

includes hardness test or destructive test to confirm that 

the zinc is not selectively leached away and a porous 

matrix of copper is left. Implementation of this AMP 

provides reasonable assurance that the component’s 

intended functions will be maintained within the CLB for 

the extended period of operation.
NUREG-1833 38 October 200

5

Table II.A New AMR Line-items based on new ‘MEAP’ combinations relevant to Mechanical Systems (“A” for Auxiliary, “E” for 

Engineered Safety Features, “R” for Reactor Coolant, and “S” for Steam and Power Conversion) 

Item

Structure 

and/or 

Component

Material Environment Aging Effect/ 

Mechanism AMP Precedent and Technical Basis for New Line-Item

AP-44 Piping, piping 

components, 

and piping 

elements

CopperalloyFuel oil Loss of material/ 

pitting, crevice 

and 

microbiologically 

influenced 

corrosion

XI.M30 Fuel Oil 

Chemistry

The AMP is to 

be augmented 

by verifying the 

effectiveness of 

water chemistry 

control. See 

Chapter XI.M32, 

“One-Time 

Inspection,” for 

an acceptable 

verification 

program.

An approved precedent exists for adding this material, 

environment, aging effect, and program combination to

the GALL Report. Pitting and crevice corrosion occurs 

in this environment where water contamination could be 

present. MIC could also occur when the affected 

system operates at less than 212°F. As shown in NA/S 

SER Section 3.6.2, the Staff has accepted the position 

that loss of material exhibited by copper-alloy in a fuel 

oil environment is properly managed by the Fuel Oil 

Chemistry AMP, which monitors fuel oil quality and the 

levels of water and microbiological organisms in the fuel 

oil. This program is to be augmented by verifying the 

effectiveness of fuel oil chemistry control.

Implementation of this program, augmented by XI.M32, 

provides reasonable assurance that the component's 

intended functions will be maintained within the CLB for 

the extended period of operation.
October 2005 39 NUREG-1833

Table II.A New AMR Line-items based on new ‘MEAP’ combinations relevant to Mechanical Systems (“A” for Auxiliary, “E” for 

Engineered Safety Features, “R” for Reactor Coolant, and “S” for Steam and Power Conversion) 

Item

Structure 

and/or 

Component

Material Environment Aging Effect/ 

Mechanism AMP Precedent and Technical Basis for New Line-Item

AP-45

SP-31

Piping, piping 

components, 

and piping 

elements

Copper 

alloy 

Raw water Loss of material/ 

pitting, crevice, 

and 

microbiologically 

influenced 

corrosion

Chapter XI.M20, 

“Open-Cycle 

Cooling Water 

System”

An approved precedent exists for adding this material, 

environment, aging effect, and program combination to

the GALL Report. As shown in FCS SER Section 

3.3.2.4.14, the Staff has accepted the position that 

copper-alloy in a raw water environment exhibits a loss 

of material and therefore recommends management by 

a program. GALL Rev. 0 had a similar material, 

environment, aging effect, and program combination for 

auxiliary systems (VII.C1.1-a and C1.2-b) for loss of 

material in various metals exposed to raw water 

(captured in GALL Rev. 1 by AMR line-items A-43 in 

VII.C31 and A-44 in VII.C1 for copper alloy in raw 

water). This related AMR line-item was created to 

expand the environmental scope and thus encompass 

other auxiliary systems such as the emergency diesel 

generator system (H2) and in steam and power 

conversion systems such as auxiliary feedwater. The 

implementation of AMP XIM.20 provides reasonable 

assurance that the component’s intended functions will 

be maintained within the CLB for the extended period of 

operation based on the inspection and surveillance 

performed on these components.
NUREG-1833 40 October 200

5

Table II.A New AMR Line-items based on new ‘MEAP’ combinations relevant to Mechanical Systems (“A” for Auxiliary, “E” for 

Engineered Safety Features, “R” for Reactor Coolant, and “S” for Steam and Power Conversion) 

Item

Structure 

and/or 

Component

Material Environment Aging Effect/ 

Mechanism AMP Precedent and Technical Basis for New Line-Item

AP-47

SP-32

EP-45

Piping, piping 

components, 

and piping 

elements

CopperalloyLubricating oil Loss of 

material/pitting 

and crevice

corrosion

Chapter XI.M39, 

"Lubricating Oil 

Analysis"

The AMP is to 

be augmented 

by verifying the 

effectiveness of 

the lubricating oil 

analysis 

program. See 

Chapter XI.M32, 

“One-Time 

Inspection,” for 

an acceptable 

verification 

program.

An approved precedent exists for adding this material, 

environment, aging effect and program combination 

item to the GALL Report. As shown in FCS SER 

Section 3.3.2.4.14, the Staff has accepted the position 

that copper-alloy in a lubricating oil environment 

exhibits a loss of material and therefore recommends

management by a program. GALL Rev. 0 had a similar 

material, environment, aging effect, and program 

combination for loss of material in steel and copper 

alloy in fire protection auxiliary systems (G.7-b, which is 

captured in GALL Rev. 1 by AMR line-item A-83 in 

VII.G). This related AMR line-item was created to 

address different structures and components. AMP 

XI.M39 was developed to provide for proper 

management of the aging effects for this MEAP 

combination. This program provides an acceptable 

means of managing aging of these components with 

one-time inspection (AMP XI.M32) to provide a 

mitigative and verification method. See Table IV for 

further discussion of the basis for these AMPs. The 

implementation of this augmented program provides 

reasonable assurance that the component’s intended 

functions will be maintained within the CLB for the 

period of extended operation.
October 2005 41 NUREG-1833

Table II.A New AMR Line-items based on new ‘MEAP’ combinations relevant to Mechanical Systems (“A” for Auxiliary, “E” for 

Engineered Safety Features, “R” for Reactor Coolant, and “S” for Steam and Power Conversion) 

Item

Structure 

and/or 

Component

Material Environment Aging Effect/ 

Mechanism AMP Precedent and Technical Basis for New Line-Item

AP-48

SP-33

Piping 

elements

Glass Air None None An approved precedent exists for adding this material, 

environment, aging effect, and program combination to

the GALL Report. As shown in D/QC SER Section 

3.2.2.4.1 and FCS SER Section 3.3.2.4.6, the Staff has 

accepted the position that glass in an air environment 

exhibits no aging effect and that the component or 

structure will therefore remain capable of performing its 

intended functions consistent with the CLB for the 

period of extended operation. This conclusion is based 

on the fact that operating experience cited in St. Lucie 

SER Section 3.3.2.4.1 states that no attack of sight 

glasses in the component water cooling system was 

observed in an air environment. The book, Corrosion 

Guide, Second Edition, by Erich Rabald, (Elsevier 

Publishing Company, 1968), p. 781 states that 

borosilicate glasses exhibit good corrosion resistance to 

steam at temperatures up to 300°C (572°F) under no 

pressure, but these same glasses exhibit corrosion 

rates of between 1.2 and 1.8 g/m2 per hour in steam at 

176°C (349°F) at a pressure of 9 atm. In high-pressure 

steam, these glasses are stated to be unsatisfactory. 
NUREG-1833 42 October 200

5

Table II.A New AMR Line-items based on new ‘MEAP’ combinations relevant to Mechanical Systems (“A” for Auxiliary, “E” for 

Engineered Safety Features, “R” for Reactor Coolant, and “S” for Steam and Power Conversion) 

Item

Structure 

and/or 

Component

Material Environment Aging Effect/ 

Mechanism AMP Precedent and Technical Basis for New Line-Item

AP-49 Piping 

elements

Glass Fuel oil None None An approved precedent exists for adding this material, 

environment, aging effect, and program combination to

the GALL Report. As shown in FCS SER Section 

3.3.2.4.5, the Staff has accepted the position that glass 

in a fuel oil environment exhibits no aging effect and 

that the component or structure will therefore remain 

capable of performing its intended functions consistent 

with the CLB for the period of extended operation. 

Borosilicate glass is identified as compatible with fuel oil 

at temperatures up to 116°C (240°F) as cited in 

Corrosion Resistant Tables, Fifth Edition, Part B (Philip 

A. Schweitzer, ed.) Marcel Dekker, Inc. (2004), p. 1458. 

To summarize, glass as a material is impervious to 

normal plant environments. 

AP-50

EP-28

SP-34

Piping 

elements

Glass Raw water None None An approved precedent exists for adding this material, 

environment, aging effect, and program combination to

the GALL Report. As shown in Handbook of Glass 

Properties, N. P. Bansal and R. H. Doremua, silicate 

glasses are highly inert. Operating experience also 

shows that there are no aging related failures of glass in 

this environment. Therefore, glass in a raw water 

environment exhibits no aging effect and the 

component or structure will therefore remain capable of 

performing its intended functions consistent with the 

CLB for the period of extended operation. 
October 2005 43 NUREG-1833

Table II.A New AMR Line-items based on new ‘MEAP’ combinations relevant to Mechanical Systems (“A” for Auxiliary, “E” for 

Engineered Safety Features, “R” for Reactor Coolant, and “S” for Steam and Power Conversion) 

Item

Structure 

and/or 

Component

Material Environment Aging Effect/ 

Mechanism AMP Precedent and Technical Basis for New Line-Item

AP-51

EP-29

SP-35

Piping 

elements

Glass Treated water None None An approved precedent exists for adding this material, 

environment, aging effect, and program combination to

the GALL Report. As shown in FCS SER Section 

3.3.2.4.16, the Staff has accepted the position that 

glass in a treated water environment exhibits no aging 

effect and that the component or structure will therefore 

remain capable of performing its intended functions 

consistent with the CLB for the period of extended 

operation. This conclusion is based on the fact that 

glass as a material is impervious to normal plant 

environments. 

AP-52

EP-30

Piping 

elements

Glass Treated 

borated water

None None An approved precedent exists for adding this material, 

environment, aging effect, and program combination to

the GALL Report. As shown in St. Lucie SER Section 

3.2.2.1.1, the Staff has accepted the position that glass

in a treated borated water environment exhibits no 

aging effect and that the component or structure will 

therefore remain capable of performing its intended 

functions consistent with the CLB for the period of 

extended operation. 
NUREG-1833 44 October 200

5

Table II.A New AMR Line-items based on new ‘MEAP’ combinations relevant to Mechanical Systems (“A” for Auxiliary, “E” for 

Engineered Safety Features, “R” for Reactor Coolant, and “S” for Steam and Power Conversion) 

Item

Structure 

and/or 

Component

Material Environment Aging Effect/ 

Mechanism AMP Precedent and Technical Basis for New Line-Item

AP-53 Piping, piping 

components, 

and piping 

elements

Nickel-alloy Raw water Loss of 

material/pitting 

and crevice 

corrosion

XI.M20 OpenCycle Cooling 

Water System

Nickel based alloys are particularly susceptible to pitting 

and crevice attack because of the passive nature of 

these alloys. Any localized attack tends to progress 

rapidly at the point of attack as cited in Smithells Metals 

Reference Book, p. 31-5. The Staff has accepted the 

position that loss of material exhibited by nickel-alloy in 

a raw water environment is properly managed by the 

Open-Cycle Cooling Water System AMP which includes 

surveillance and control techniques to manage aging 

effects caused by biofouling, corrosion, erosion, 

protective coating failure, and silting. The 

implementation of this program provides reasonable 

assurance that the component’s intended functions will 

be maintained within the CLB for the extended period of 

operation. 

AP-54 Piping, piping 

components, 

and piping 

elements

Stainless 

Steel

Fuel oil Loss of 

material/pitting, 

crevice, and 

microbiologically 

influenced 

corrosion

Chapter XI.M30, 

“Fuel Oil 

Chemistry”

The AMP is to 

be augmented 

by verifying the 

effectiveness of 

fuel oil chemistry 

control. See 

Chapter XI.M32, 

“One-Time 

Inspection,” for 

an acceptable 

verification 

program.

An approved precedent exists for adding this material, 

environment, aging effect, and program combination to

the GALL Report. As shown in the NA/S SER Section 

3.6.4.2 and the FCS SER Section 3.3.2.4.5, the Staff

has accepted the position that loss of material exhibited 

by stainless steel in a fuel oil environment is properly 

managed by the Fuel Oil Chemistry AMP which 

monitors fuel oil quality and the level of contamination 

from water and micro-organisms in the fuel oil. The 

implementation of this program, as augmented by AMP 

XI.M32, provides reasonable assurance that the 

component’s intended functions will be maintained 

within the CLB for the extended period of operation.
October 2005 45 NUREG-1833

Table II.A New AMR Line-items based on new ‘MEAP’ combinations relevant to Mechanical Systems (“A” for Auxiliary, “E” for 

Engineered Safety Features, “R” for Reactor Coolant, and “S” for Steam and Power Conversion) 

Item

Structure 

and/or 

Component

Material Environment Aging Effect/ 

Mechanism AMP Precedent and Technical Basis for New Line-Item

AP-55

EP-55

SP-36

Piping, piping 

components, 

and piping 

elements

Stainless 

Steel

Raw water Loss of 

material/pitting, 

and crevice, and 

microbiologically 

influenced 

corrosion

Chapter XI.M20 

Open-Cycle 

Cooling Water 

System

An approved precedent exists for adding this material, 

environment, aging effect, and program combination to

the GALL Report. As shown in ANO-1, Unit 1 SER 

Section 3.3.4.2, the Staff has accepted the position that 

stainless steel in a raw water environment exhibits a 

loss of material and therefore recommends

management by a program. The aging effect is 

adequately managed by AMP XI.M20. Implementation 

of AMP XI.M20 provides reasonable assurance that the 

component’s intended functions will be maintained 

within the CLB for the extended period of operation.

AP-56

EP-31

SP-37

Piping, piping 

components, 

and piping 

elements

Stainless 

Steel

Soil Loss of 

material/pitting 

and crevice 

corrosion

A plant-specific 

aging 

management 

program is to be 

evaluated.

An approved precedent exists for adding this material, 

environment, aging effect, and program combination to

the GALL Report. As shown in D/QC SER Section 

3.4.2.4.3, the Staff has accepted the position that 

stainless steel in a soil environment exhibits a loss of 

material and therefore recommends management by a 

program. Soil can present an aggressive environment in 

the context of aging degradation. Such an aggressive 

environment consisting of a wetted surface or pooled 

liquid, oxygen, and contaminants must be present for 

pitting and crevice corrosion to occur. A plant-specific 

aging management program will be evaluated to 

provide reasonable assurance that the component’s 

intended functions will be maintained within the CLB for 

the period of extended operation.
NUREG-1833 46 October 200

5

Table II.A New AMR Line-items based on new ‘MEAP’ combinations relevant to Mechanical Systems (“A” for Auxiliary, “E” for 

Engineered Safety Features, “R” for Reactor Coolant, and “S” for Steam and Power Conversion) 

Item

Structure 

and/or 

Component

Material Environment Aging Effect/ 

Mechanism AMP Precedent and Technical Basis for New Line-Item

AP-59

SP-38

Piping, piping 

components, 

and piping 

elements

Stainless 

Steel

Lubricating oil Loss of 

material/pitting, 

crevice, and 

microbiologically 

influenced 

corrosion

Chapter XI.M39, 

"Lubricating Oil 

Analysis" 

The AMP is to 

be augmented 

by verifying the 

effectiveness of 

the lubricating oil 

analysis 

program. See 

Chapter XI.M32, 

“One-Time 

Inspection,” for 

an acceptable 

verification 

program.

An approved precedent exists for adding this material, 

environment, aging effect, and program combination to

the GALL Report. As shown in NA/S SER Section 3.6.2 

and FCS SER Section 3.3.2.4.14, the Staff has 

accepted the position that stainless steel in a lubricating 

oil environment exhibits a loss of material and therefore 

recommends management by a program. AMP XI.M39 

was developed to provide for proper management of 

the aging effects for this MEAP combination. This 

program provides an acceptable means of managing 

aging of these components with one-time inspection 

(AMP XI.M32) to provide a mitigative and verification 

method. See Table IV for further discussion of the basis 

for these AMPs. The implementation of this augmented 

program provides reasonable assurance that the 

component’s intended functions will be maintained 

within the CLB for the period of extended operation.

AP-60

EP-44

SP-54

Piping, piping 

components, 

and piping 

elements

Stainless 

Steel

Closed cycle 

cooling water 

>60°C 

(>140°F)

Cracking/ stress 

corrosion 

cracking

Chapter XI.M21, 

“Closed-Cycle 

Cooling Water 

System”

An approved precedent exists for adding this material, 

environment, aging effect, and program combination in 

GALL Rev. 1. GALL Rev. 0 had this material, 

environment, aging effect and program combination for 

the heat exchanger channel head and access cover, 

tubesheet, tubes, and shell and access cover in the 

BWR reactor water cleanup system (VII.E3.4-a) which 

is essentially captured in GALL Rev. 1 by A-68. A-68

addressed heat exchanger shell side components 

including tubes. This AMR line-item was created to also 

consider the SCC of stainless steel piping, piping 

components, and piping elements. AMP XI.M21, 

“Closed-Cycle Cooling Water System” has been revised 

to include stress corrosion cracking. Thus, this program 

provides reasonable assurance that the component’s 

intended functions will be maintained within the CLB for 

the period of extended operation.
October 2005 47 NUREG-1833

Table II.A New AMR Line-items based on new ‘MEAP’ combinations relevant to Mechanical Systems (“A” for Auxiliary, “E” for 

Engineered Safety Features, “R” for Reactor Coolant, and “S” for Steam and Power Conversion) 

Item

Structure 

and/or 

Component

Material Environment Aging Effect/ 

Mechanism AMP Precedent and Technical Basis for New Line-Item

AP-61 Heat 

exchanger 

components

Stainless 

Steel

Raw water Reduction of heat 

transfer/ fouling

Chapter XI.M20, 

“Open-Cycle 

Cooling Water 

System”

An approved precedent exists for adding this material, 

environment, aging effect, and program combination to

the GALL Report. As shown in FCS SER Section 

3.3.2.4.15, the Staff has accepted the position that 

reduction of heat transfer exhibited by stainless steel 

heat exchanger components in a raw water 

environment is properly managed by the Open-Cycle 

Cooling Water System AMP which includes surveillance 

and control techniques to manage aging effects caused 

by fouling, corrosion, erosion, protective coating failure, 

and silting. GALL Rev. 0 had this material, environment, 

aging effect and program combination only for the 

steam and power conversion system (VIII: E.4-c, F.4-c 

and G.5-b) which is essentially captured in GALL Rev. 1

by S-28 addressing reduction of heat transfer in the 

PWR steam generator blowdown system heat 

exchanger components. This additional AMR line-item 

AP-61 is created to also consider the reduction of heat 

transfer of stainless steel heat exchanger components 

in auxiliary systems such as the open-cycle cooling 

water, the ultimate heat sink, and the fire protection 

systems. AMP XI.M20 provides reasonable assurance 

that the component’s intended functions will be 

maintained within the CLB for the extended period of 

operation.
NUREG-1833 48 October 200

5

Table II.A New AMR Line-items based on new ‘MEAP’ combinations relevant to Mechanical Systems (“A” for Auxiliary, “E” for 

Engineered Safety Features, “R” for Reactor Coolant, and “S” for Steam and Power Conversion) 

Item

Structure 

and/or 

Component

Material Environment Aging Effect/ 

Mechanism AMP Precedent and Technical Basis for New Line-Item

AP-62

EP-34

SP-40

Heat 

exchanger 

tubes

Stainless 

Steel

Treated water Reduction of heat 

transfer/ fouling

Chapter XI.M2, 

“Water 

Chemistry”

The AMP is to 

be augmented 

by verifying the 

effectiveness of 

water chemistry 

control. See 

Chapter XI.M32, 

“One-Time 

Inspection,” for 

an acceptable 

verification 

program.

An approved precedent exists for adding this material, 

environment, aging effect, and program combination to

the GALL Report. As shown in Ginna SER Section

3.3.2.4.3.2, the Staff has accepted the position that 

stainless steel in a treated water environment exhibits a 

reduction of heat transfer and that control of water 

chemistry provides reasonable assurance that the 

component’s intended functions will be maintained 

within the CLB for the period of extended operation. 

Implementation of AMP XI.M2, as augmented by AMP 

XI.M32, provides reasonable assurance that the 

component’s intended functions will be maintained 

within the CLB for the extended period of operation.

AP-63

EP-35

SP-41

Heat 

exchanger 

tubes

Stainless 

Steel

Closed cycle 

cooling water

Reduction of heat 

transfer/ fouling

Chapter XI.M21 

Closed-Cycle 

Cooling Water 

System

An approved precedent exists for adding this material, 

environment, aging effect, and program combination to

the GALL Report. As shown in Ginna SER Section 

3.3.2.4.2, the Staff has accepted the position that 

reduction of heat transfer exhibited by stainless steel 

heat exchanger components in a closed-cycle cooling 

water (treated water – other) environment is properly 

managed by the Closed-Cycle Cooling Water System 

AMP which ensures system corrosion inhibitor 

concentrations are maintained within specified limits of 

EPRI TR-107396 and surveillance testing and 

inspections are conducted to ensure component 

functionality. The implementation of this program 

provides reasonable assurance that the component’s 

intended functions will be maintained within the CLB for 

the extended period of operation.
October 2005 49 NUREG-1833

Table II.A New AMR Line-items based on new ‘MEAP’ combinations relevant to Mechanical Systems (“A” for Auxiliary, “E” for 

Engineered Safety Features, “R” for Reactor Coolant, and “S” for Steam and Power Conversion) 

Item

Structure 

and/or 

Component

Material Environment Aging Effect/ 

Mechanism AMP Precedent and Technical Basis for New Line-Item

AP-64 Piping, piping 

components, 

and piping 

elements

Copper 

alloy

Treated water Loss of material/ 

pitting, crevice, 

and galvanic 

corrosion

Chapter XI.M2, 

“Water 

Chemistry,” for 

BWR water

The AMP is to 

be augmented 

by verifying the 

effectiveness of 

water chemistry 

control. See 

Chapter XI.M32, 

“One-Time 

Inspection,” for 

an acceptable 

verification 

program.

An approved precedent exists for adding this material, 

environment, aging effect, and program combination to

the GALL Report. As shown in FCS SER Section 

3.0.3.7.3, the Staff has accepted the position that loss 

of material from pitting, crevice, and/or galvanic 

corrosion, exhibited by copper alloy in a closed-cycle

cooling water (treated water) environment recommends

an aging management program. The aging effect is 

adequately managed by AMP XI.M2. Implementation of 

AMP XI.M2, as augmented by AMP XI.M32, provides 

reasonable assurance that the component’s intended 

functions will be maintained within the CLB for the 

extended period of operation. 

AP-65 Heat 

exchanger 

components

Copper 

alloy >15% 

Zn

Treated water Loss of material/ 

selective leaching

Chapter XI.M33, 

“Selective 

Leaching of 

Materials”

As shown in FCS Unit 1 SER Section 3.3.2.4.6, the 

Staff has accepted the position that selective leaching 

of copper-alloy in a treated water environment is 

properly managed by the Selective Leaching of 

Materials Program, which includes a one-time visual 

inspection and hardness measurement of selected 

components to determine whether loss of material due 

to selective leaching is occurring. The aging effect is 

adequately managed by AMP XI.M33, “Selective 

Leaching of Materials,” which includes hardness test or 

destructive test to confirm that the zinc is not selectively 

leached away and a porous matrix of copper is left. 

Implementation of this AMP provides reasonable 

assurance that the component’s intended functions will 

be maintained within the CLB for the extended period of 

operation.
NUREG-1833 50 October 200

5

Table II.A New AMR Line-items based on new ‘MEAP’ combinations relevant to Mechanical Systems (“A” for Auxiliary, “E” for 

Engineered Safety Features, “R” for Reactor Coolant, and “S” for Steam and Power Conversion) 

Item

Structure 

and/or 

Component

Material Environment Aging Effect/ 

Mechanism AMP Precedent and Technical Basis for New Line-Item

AP-66

EP-38

Piping, piping 

components 

and piping 

elements

Copper 

alloy >15% 

Zn

Air with 

borated water 

leakage

Loss of 

material/boric 

acid corrosion

Chapter XI.M10, 

“Boric Acid 

Corrosion”

Copper alloy >15% Zn piping, piping components, and 

piping elements when subject to air with borated water 

leakage are subject to loss of material due to boric acid 

corrosion. An approved precedent exists for adding this 

material, environment, aging effect, and program 

combination to the GALL Report. As shown in VCS

SER Section 3.0.3.1.1, the Staff has accepted the 

position that loss of material due to aggressive chemical 

attack (boric acid corrosion) exhibited by copper alloy > 

15% Zn (brass) in an air with borated water leakage 

environment is properly managed by the Boric Acid 

Corrosion AMP which provides engineering evaluations 

and corrective actions to ensure that boric acid 

corrosion does not lead to degradation of the leakage 

source or adjacent structures or components. The 

implementation of this program provides reasonable 

assurance that the component’s intended functions will 

be maintained within the CLB for the extended period of 

operation.
October 2005 51 NUREG-1833

Table II.A New AMR Line-items based on new ‘MEAP’ combinations relevant to Mechanical Systems (“A” for Auxiliary, “E” for 

Engineered Safety Features, “R” for Reactor Coolant, and “S” for Steam and Power Conversion) 

Item

Structure 

and/or 

Component

Material Environment Aging Effect/ 

Mechanism AMP Precedent and Technical Basis for New Line-Item

AP-73 Piping, piping 

components, 

and piping 

elements

Stainless 

steel

Sodium 

pentaborate 

solution

Loss of material/ 

pitting and 

crevice corrosion

Chapter XI.M2, 

“Water 

Chemistry,” for 

BWR water

The AMP is to 

be augmented 

by verifying the 

effectiveness of 

water chemistry 

control. See 

Chapter XI.M32, 

“One-Time 

Inspection,” for 

an acceptable 

verification 

program.

An approved precedent exists for adding this material, 

environment, and aging effect combination item to the 

GALL Report. The sodium pentaborate solution will 

effectively be a treated water environment. Sodium 

pentaborate solution is relatively benign for stainless

steel. As for other cases of stainless steel in treated 

water (e.g., A-58) loss of material is a possible aging 

effect. XI.M2 and XI.M32 are acceptable AMPS for this 

MEAP combination based on similar rows in the GALL 

(e.g., A-59). AMP XI.M2 can be credited for managing 

the aging mechanism of corrosion. 

AP-74 Piping, piping 

components, 

and piping 

elements

Aluminum Condensation Loss of material/ 

pitting and 

crevice corrosion

A plant-specific 

aging 

management 

program is to be 

evaluated.

An approved precedent exists for adding this material, 

environment, and aging effect combination item to the 

GALL Report. ANO-2 SER Section 3.3.2.3.11 

acknowledged that aluminum components in a 

condensation environment are subject to loss of 

material. Aluminum may be used in HVAC systems 

where condensation is a possible environment. This line 

is similar to lines AP-38, EP-26, and SP-24 which 

address loss of material for aluminum in a treated water 

environment, in that the condensation environment is 

frequently wetted. A plant-specific aging management 

program will be evaluated to provide reasonable 

assurance that the component’s intended functions will 

be maintained within the CLB for the period of extended 

operation.
NUREG-1833 52 October 200

5

Table II.A New AMR Line-items based on new ‘MEAP’ combinations relevant to Mechanical Systems (“A” for Auxiliary, “E” for 

Engineered Safety Features, “R” for Reactor Coolant, and “S” for Steam and Power Conversion) 

Item

Structure 

and/or 

Component

Material Environment Aging Effect/ 

Mechanism AMP Precedent and Technical Basis for New Line-Item

AP-75 Elastomer 

seals and 

components

Elastomers Raw water Hardening and 

loss of strength/

elastomer 

degradation

Chapter XI.M20, 

“Open-Cycle 

Cooling Water 

System”

An approved precedent exists for adding this material, 

environment, and aging effect combination item to the 

GALL Report. CNP SER Section 3.3.2.3.2 

acknowledged the potential for a change of material 

properties for elastomeric components exposed to a 

raw water environment in the open-cycle cooling water 

system. In CNP SER Section 3.3.2.1.2 the Staff

accepted that hardening and loss of strength is 

adequately managed by AMP XI.M20. AMP XI.M20 has 

been revised to specifically address elastomers. 

Cleanliness and material integrity of elastomers that are 

part of the Open-Cycle Cooling Water (OCCW) system 

or that are cooled by the OCCW system are periodically 

inspected, monitored, or tested.

AP-76 Elastomer 

seals and 

components

Elastomers Raw water Loss of material/ 

erosion

Chapter XI.M20, 

“Open-Cycle 

Cooling Water 

System”

An approved precedent exists for adding this material, 

environment, and aging effect combination item to the 

GALL Report. CNP SER Section 3.3.2.3.2 

acknowledged the potential for a change of material 

properties for elastomeric components exposed to a 

raw water environment in the open-cycle cooling water 

system. In CNP SER Section 3.3.2.1.2 the Staff

accepted that loss of material is adequately managed 

by AMP XI.M20. AMP XI.M20 has been revised to 

specifically address elastomers. Cleanliness and 

material integrity of elastomers that are part of the 

Open-Cycle Cooling Water (OCCW) system or that are 

cooled by the OCCW system are periodically inspected, 

monitored, or tested.
October 2005 53 NUREG-1833

Table II.A New AMR Line-items based on new ‘MEAP’ combinations relevant to Mechanical Systems (“A” for Auxiliary, “E” for 

Engineered Safety Features, “R” for Reactor Coolant, and “S” for Steam and Power Conversion) 

Item

Structure 

and/or 

Component

Material Environment Aging Effect/ 

Mechanism AMP Precedent and Technical Basis for New Line-Item

AP-77 Heat 

exchanger 

tubes

Steel Closed cycle 

cooling water

Reduction of heat 

transfer/ fouling

Chapter XI.M21, 

“Closed-Cycle 

Cooling Water 

System”

An approved precedent exists for adding this 

environment, aging effect and program combination to 

the GALL Report. As shown in Ginna SER Section 

3.3.2.4.2, the Staff has accepted the position that 

reduction of heat transfer exhibited by stainless steel 

heat exchanger components in a closed-cycle cooling 

water environment is properly managed by the ClosedCycle Cooling Water System AMP which ensures 

system corrosion inhibitor concentrations are 

maintained within specified limits of EPRI TR-107396 

and surveillance testing and inspections are conducted 

to ensure component functionality. The basis for this 

new line is the same as AP-63 except that the material 

is steel versus stainless steel. Implementation of AMP 

XI.M21 provides reasonable assurance that the 

component’s intended functions will be maintained 

within the CLB for the extended period of operation.

AP-78 Piping, piping 

components, 

and piping 

elements

Copper 

alloy

Condensation 

(Internal)

Loss of material/ 

pitting and 

crevice corrosion

A plant-specific 

aging 

management 

program is to be 

evaluated.

Line-item A-46 addresses copper alloy components in a 

condensation (external) environment. This item has an 

identical aging effect as A-46; the only difference is that 

the condensation is on the internal surface of the 

component in the fire protection system. A plant-specific 

aging management program will be evaluated to 

provide reasonable assurance that the component’s 

intended functions will be maintained within the CLB for 

the period of extended operation.
NUREG-1833 54 October 200

5

Table II.A New AMR Line-items based on new ‘MEAP’ combinations relevant to Mechanical Systems (“A” for Auxiliary, “E” for 

Engineered Safety Features, “R” for Reactor Coolant, and “S” for Steam and Power Conversion) 

Item

Structure 

and/or 

Component

Material Environment Aging Effect/ 

Mechanism AMP Precedent and Technical Basis for New Line-Item

AP-79 Piping, piping 

components, 

and piping 

elements

Stainless 

Steel; Steel 

with 

stainless 

steel 

cladding

Treated 

borated water

Loss of material/ 

pitting and 

crevice corrosion

Chapter XI.M2, 

“Water 

Chemistry,” for 

PWR primary 

water

An approved precedent exists for adding this material, 

environment, aging effect, and program combination in 

GALL Rev. 1. GALL Rev. 0 stated that "the effects of 

pitting and crevice corrosion (loss of material) on 

stainless steel are not significant in reactor coolant (i.e., 

treated borated water), and therefore are not included" 

as an aging effect that required management (i.e., an 

AMR line-item was not included in the GALL Report). 

This statement is true for PWRs in part because water 

chemistry program requirements minimize 

contaminants that could lead to a loss of material. The 

Staff has removed this statement from the GALL Report 

and has added this new AMR line-item in the GALL 

Rev. 1 Report for PWRs, which although no significant 

loss of material is expected, recognizes that applicants 

can manage loss of material in stainless steel in a 

treated borated water environment by virtue of their use 

of a water chemistry program which meets XI.M2.
October 2005 55 NUREG-1833

Table II.A New AMR Line-items based on new ‘MEAP’ combinations relevant to Mechanical Systems (“A” for Auxiliary, “E” for 

Engineered Safety Features, “R” for Reactor Coolant, and “S” for Steam and Power Conversion) 

Item

Structure 

and/or 

Component

Material Environment Aging Effect/ 

Mechanism AMP Precedent and Technical Basis for New Line-Item

AP-80

EP-39

SP-57

Heat 

exchanger 

tubes

Copper 

Alloy

Closed cycle 

cooling water

Reduction of heat 

transfer/ fouling

Chapter XI.M21, 

“Closed-Cycle 

Cooling Water 

System”

An approved precedent exists for adding this 

environment, and aging effect combination to the GALL

Report. As shown in Ginna SER Section 3.3.2.4.2, the 

Staff has accepted the position that reduction of heat 

transfer exhibited by heat exchanger components in a 

closed-cycle cooling water environment is properly 

managed by the Closed-Cycle Cooling Water System 

AMP which ensures system corrosion inhibitor 

concentrations are maintained within specified limits of 

EPRI TR-107396 and surveillance testing and 

inspections are conducted to ensure component 

functionality. Implementation of this AMP provides 

reasonable assurance that the component’s intended 

functions will be maintained within the CLB for the 

extended period of operation. This row is similar to AP63 except that the material is copper alloy instead of 

stainless steel.

AP-81 Piping, piping 

components, 

and piping 

elements

Stainless 

steel

Condensation 

(Internal)

Loss of material/ 

pitting and 

crevice corrosion

Chapter XI.M24, 

“Compressed Air 

Monitoring”

An approved precedent exists for adding this material, 

environment, and aging effect combination item to the 

GALL Report. As shown in FNP SER Section 

3.3.2.3.19, the Staff has accepted the position that loss 

of material from pitting and crevice corrosion is 

exhibited by stainless steel in a condensation internal 

(wetted air/gas) environment and therefore 

recommends management by a program. AMP XI.M24 

provides an acceptable means of managing aging of 

these components. The implementation of this program 

provides reasonable assurance that the component’s 

intended functions will be maintained within the CLB for

the period of extended operation.
NUREG-1833 56 October 200

5

Table II.A New AMR Line-items based on new ‘MEAP’ combinations relevant to Mechanical Systems (“A” for Auxiliary, “E” for 

Engineered Safety Features, “R” for Reactor Coolant, and “S” for Steam and Power Conversion) 

Item

Structure 

and/or 

Component

Material Environment Aging Effect/ 

Mechanism AMP Precedent and Technical Basis for New Line-Item

AP-82 Piping, piping 

components, 

piping 

elements, and 

tanks

Stainless 

steel

Treated 

borated water 

>60°C 

(>140°F)

Cracking/ stress 

corrosion 

cracking

Chapter XI.M2, 

“Water 

Chemistry,” for 

PWR primary 

water

An approved precedent exists for adding this material, 

environment, and aging effect combination item to 

Chapter VII of the GALL Report. This row is identical to 

E-12 in Chapter V of the GALL. This new line has been 

added to the PWR Chemical and Volume Control 

System.

AP-83 Piping, piping 

components, 

and piping 

elements

Aluminum Raw water Loss of material/ 

pitting and 

crevice corrosion

Chapter XI.M26, 

“Fire Protection”

An approved precedent exists for adding this material, 

environment, and aging effect combination item to the 

GALL Report. FNP SER Section 3.3.2.3.13 for the fire 

protection system acknowledged (by reference to Table 

3.3.2-13 of the FNP LRA) that aluminum components in 

a raw water environment are subject to loss of material 

which can be managed by the fire protection program. 

This line is similar to lines AP-38, EP-26, and SP-24 

which address loss of material for aluminum in a treated 

water environment.

AP-85

EP-49

Pump Casings Steel with 

stainless 

steel 

cladding

Treated 

borated water

Loss of material/ 

cladding breach

A plant-specific 

aging 

management 

program is to be 

evaluated. 

Reference NRC 

Information 

Notice 94-63, 

“Boric Acid 

Corrosion of 

Charging Pump 

Casings Caused 

by Cladding 

Cracks."

An approved precedent exists for adding this material, 

environment, aging effect, and program combination to

the GALL Report. The management of aging effects of 

pump casings was addressed by the Staff in FNP SER 

Section 3.0.3.3.4. Unique problems with stainless 

cladding have been identified for high head safety 

injection pump as discussed in NRC Information Notice 

94-63, “Boric Acid Corrosion of Charging Pump Casings 

Caused by Cladding Cracks.” This line-item is similar to 

V.D1.2-a from GALL Rev. 0. A plant-specific aging 

management program will be evaluated to provide 

reasonable assurance that the component’s intended 

functions will be maintained within the CLB for the 

period of extended operation.
October 2005 57 NUREG-1833

Table II.A New AMR Line-items based on new ‘MEAP’ combinations relevant to Mechanical Systems (“A” for Auxiliary, “E” for 

Engineered Safety Features, “R” for Reactor Coolant, and “S” for Steam and Power Conversion) 

Item

Structure 

and/or 

Component

Material Environment Aging Effect/ 

Mechanism AMP Precedent and Technical Basis for New Line-Item

EP-3 Piping, piping 

components, 

and piping 

elements

Aluminum Air – indoor 

uncontrolled 

(Int/Ext)

None None An approved precedent exists for adding this material, 

environment, aging effect, and program combination to

the GALL Report. As shown in RNP SER Section 

3.3.2.4.5.1, the Staff has accepted the position that 

aluminum in an indoor, uncontrolled air environment 

exhibits no aging effect and that the component or 

structure will therefore remain capable of performing its 

intended functions consistent with the CLB for the 

period of extended operation. Aluminum has an 

excellent resistance to corrosion. When exposed to 

humid air (uncontrolled indoor environment), the 

aluminum oxide film bonds strongly to the aluminum 

surface. If damaged, this film reforms immediately in 

most environments. On a surface freshly abraded and 

then exposed to air, the oxide film is only 5 to 10 

nanometer thick but is highly effective in protecting the 

aluminum from corrosion. Therefore, aluminum 

exposed to indoor uncontrolled environment does not 

have any applicable aging effect (Hollingsworth and 

Hunsicker 1979).
NUREG-1833 58 October 200

5

Table II.A New AMR Line-items based on new ‘MEAP’ combinations relevant to Mechanical Systems (“A” for Auxiliary, “E” for 

Engineered Safety Features, “R” for Reactor Coolant, and “S” for Steam and Power Conversion) 

Item

Structure 

and/or 

Component

Material Environment Aging Effect/ 

Mechanism AMP Precedent and Technical Basis for New Line-Item

EP-10

SP-6

Piping, piping 

components, 

and piping 

elements

CopperalloyAir – indoor 

uncontrolled 

(Ext)

None None An approved precedent exists for adding this material, 

environment, aging effect, and program combination to

the GALL Report. As shown in Ginna SER Section 

3.2.2.4.4.2, the Staff has accepted the position that 

copper alloy in an indoor, uncontrolled air environment 

exhibits no aging effect and that the component or 

structure will therefore remain capable of performing its 

intended functions consistent with the CLB for the 

period of extended operation. This conclusion is based 

on the fact that comprehensive tests conducted over a 

20-year period under the supervision of ASTM have 

confirmed the suitability of copper and copper alloys for 

atmospheric exposure as cited in Metals Handbook, 

Volume 13, Corrosion, American Society for Metals, 

1987.

EP-32 Piping, piping 

components, 

and piping 

elements

Stainless 

Steel

Treated water Loss of material/ 

pitting and 

crevice corrosion

Chapter XI.M2, 

“Water 

Chemistry” for 

BWR water

The AMP is to 

be augmented 

by verifying the 

effectiveness of 

water chemistry 

control. See 

Chapter XI.M32, 

“One-Time 

Inspection,” for 

an acceptable 

verification 

program.

An approved precedent exists for adding this material, 

environment, aging effect, and program combination to

the GALL Report. As shown in NA/S SER Section 3.6.2, 

the Staff has accepted the position that stainless steel 

in a treated water environment exhibits a loss of 

material and therefore recommends management by a 

program. Pitting of stainless steel components is 

primarily related to the presence of detrimental ionic 

species such as chlorides, fluorides, and sulfates. 

Crevice corrosion of stainless steel components is 

primarily related to the presence of significant levels of 

dissolved oxygen. Implementation of AMPs XI.M2 and 

M32 provide reasonable assurance that the 

component’s intended functions will be maintained 

within the CLB for the period of extended operation. 

Use of these programs for this material, environment, 

aging effect, and program combination is consistent 

with other AMR line-items in the GALL Report.
October 2005 59 NUREG-1833

Table II.A New AMR Line-items based on new ‘MEAP’ combinations relevant to Mechanical Systems (“A” for Auxiliary, “E” for 

Engineered Safety Features, “R” for Reactor Coolant, and “S” for Steam and Power Conversion) 

Item

Structure 

and/or 

Component

Material Environment Aging Effect/ 

Mechanism AMP Precedent and Technical Basis for New Line-Item

EP-33

SP-39

Piping, piping 

components, 

and piping 

elements

Stainless 

Steel

Closed cycle 

cooling water

Loss of 

material/pitting 

and crevice 

corrosion

Chapter XI.M21 

Closed-Cycle 

Cooling Water 

System

An approved precedent exists for adding this material, 

environment, aging effect, and program combination in 

GALL Rev. 1. GALL Rev. 0 had this material, 

environment, aging effect, and program combination for 

the closed-cycle cooling water system (VII.C2.2-a) 

which is captured in GALL Rev. 1 as the corresponding 

A-52. Since GALL Rev. 0 did not include this material, 

environment, aging effect, and program combination for 

the ESF or SPCS systems, new AMR line-items have 

been created to address this oversight. The aging effect 

is adequately managed by the Closed-Cycle Cooling 

Water System AMP, which ensures system corrosion 

inhibitor concentrations are maintained within specified 

limits of EPRI TR-107396. The implementation of this 

program provides reasonable assurance that the 

component’s intended functions will be maintained 

within the CLB for the extended period of operation.
NUREG-1833 60 October 200

5

Table II.A New AMR Line-items based on new ‘MEAP’ combinations relevant to Mechanical Systems (“A” for Auxiliary, “E” for 

Engineered Safety Features, “R” for Reactor Coolant, and “S” for Steam and Power Conversion) 

Item

Structure 

and/or 

Component

Material Environment Aging Effect/ 

Mechanism AMP Precedent and Technical Basis for New Line-Item

EP-37 Heat 

Exchanger 

components

Copper 

alloy >15% 

Zn

Closed cycle 

cooling water

Loss of material/ 

selective leaching

Chapter XI.M33, 

“Selective 

Leaching of 

Materials ”

An approved precedent exists for adding this material, 

environment, aging effect, and program combination to

the GALL Report. As shown in FCS Unit 1 SER Section 

3.3.2.4.6, the Staff has accepted the position that 

selective leaching of copper-alloy >15% Zn in a closedcycle cooling water environment is properly managed 

by the Selective Leaching of Materials Program, which 

includes a one-time visual inspection and hardness 

measurement of selected components to determine 

whether loss of material due to selective leaching is 

occurring. The aging effect is adequately managed by 

AMP XI.M33, “Selective Leaching of Materials,” which 

includes hardness test or destructive test to confirm that 

the zinc is not selectively leached away and a porous 

matrix of copper is left. Implementation of this AMP 

provides reasonable assurance that the component’s 

intended functions will be maintained within the CLB for 

the extended period of operation.
October 2005 61 NUREG-1833

Table II.A New AMR Line-items based on new ‘MEAP’ combinations relevant to Mechanical Systems (“A” for Auxiliary, “E” for 

Engineered Safety Features, “R” for Reactor Coolant, and “S” for Steam and Power Conversion) 

Item

Structure 

and/or 

Component

Material Environment Aging Effect/ 

Mechanism AMP Precedent and Technical Basis for New Line-Item

EP-40

SP-63

Heat 

exchanger 

tubes

Steel Lubricating oil Reduction of heat 

transfer/ fouling

Chapter XI.M39, 

"Lubricating Oil 

Analysis"

The AMP is to 

be augmented 

by verifying the 

effectiveness of 

the lubricating oil 

analysis 

program. See 

Chapter XI.M32, 

“One-Time 

Inspection,” for 

an acceptable 

verification 

program.

An approved precedent exists for adding this material, 

environment, aging effect, and program combination to

the GALL Report. The D.C. Cook SER Section 3.2.2.3.3 

acknowledged the potential for fouling of copper alloy 

components in a lubricating oil environment. The SER 

addressed components in a PWR ECCS system, but 

these conditions would be equally applicable to 

components of other lube oil systems. Steel heat 

exchanger tubes would also be subject to fouling in a 

lubricating oil environment. The reduction of heat 

transfer due to fouling of heat exchanger tubes will be 

managed by AMP XI.M39, as augmented by XI.M32. 

AMP XI.M39 was developed to provide for proper 

management of the aging effects for this MEAP 

combination. This program provides an acceptable 

means of managing aging of these components with 

one-time inspection (AMP XI.M32) to provide a 

mitigative and verification method. See Table IV for 

further discussion of the basis for these AMPs. The 

implementation of this augmented program provides 

reasonable assurance that the component’s intended 

functions will be maintained within the CLB for the 

period of extended operation.
NUREG-1833 62 October 200

5

Table II.A New AMR Line-items based on new ‘MEAP’ combinations relevant to Mechanical Systems (“A” for Auxiliary, “E” for 

Engineered Safety Features, “R” for Reactor Coolant, and “S” for Steam and Power Conversion) 

Item

Structure 

and/or 

Component

Material Environment Aging Effect/ 

Mechanism AMP Precedent and Technical Basis for New Line-Item

EP-41 Piping, piping 

components, 

piping 

elements, and 

tanks

Stainless 

steel

Treated 

borated water

Loss of material/ 

pitting and 

crevice corrosion

Chapter XI.M2, 

“Water 

Chemistry,” for 

PWR primary 

water

An approved precedent exists for adding this material, 

environment, aging effect, and program combination in 

GALL Rev. 1. GALL Rev. 0 stated that "the effects of 

pitting and crevice corrosion (loss of material) on 

stainless steel are not significant in reactor coolant (i.e., 

treated borated water), and therefore are not included" 

as an aging effect that required management (i.e., an 

AMR line-item was not included in the GALL Report). 

This statement is true for PWRs in part because water 

chemistry program requirements minimize 

contaminates that could lead to a loss of material. The 

Staff has removed this statement from the GALL Report 

and has added this new AMR line-item in the GALL 

Rev. 1 Report for PWRs, which although no significant 

loss of material is expected, recognizes that applicants 

can manage loss of material in stainless steel in a 

treated borated water environment by virtue of their use 

of a water chemistry program which meets XI.M2.
October 2005 63 NUREG-1833

Table II.A New AMR Line-items based on new ‘MEAP’ combinations relevant to Mechanical Systems (“A” for Auxiliary, “E” for 

Engineered Safety Features, “R” for Reactor Coolant, and “S” for Steam and Power Conversion) 

Item

Structure 

and/or 

Component

Material Environment Aging Effect/ 

Mechanism AMP Precedent and Technical Basis for New Line-Item

EP-42 Encapsulation 

Components

Steel Air – indoor 

uncontrolled 

(Internal)

Loss of material/ 

general, pitting, 

and crevice 

corrosion

Chapter XI.M38, 

"Inspection of 

Internal 

Surfaces in 

Miscellaneous 

Piping and 

Ducting 

Components"

An approved precedent exists for adding this material, 

environment, aging effect, and program combination to

the GALL Report. Encapsulation components were 

previously not in the GALL Report, but a precedent 

exists for including these items based on the Millstone 

and FNP LRAs and corresponding NRC Staff reviews. 

The Staff accepted aging management programs 

identified by these applicants for these material and 

environment combinations for loss of material in the 

SERs, Millstone SER Section 2.3A.2.3 and FNP SER 

Section 3.2.2.2.2. AMP XI.M38 was developed to 

provide for proper management of the aging effects for 

this MEAP combination. This program provides an 

acceptable means of managing aging of these 

components. See Table IV for further discussion of the 

basis for this AMP. The implementation of this program 

provides reasonable assurance that the component’s 

intended functions will be maintained within the CLB for 

the period of extended operation.
NUREG-1833 64 October 200

5

Table II.A New AMR Line-items based on new ‘MEAP’ combinations relevant to Mechanical Systems (“A” for Auxiliary, “E” for 

Engineered Safety Features, “R” for Reactor Coolant, and “S” for Steam and Power Conversion) 

Item

Structure 

and/or 

Component

Material Environment Aging Effect/ 

Mechanism AMP Precedent and Technical Basis for New Line-Item

EP-43 Encapsulation 

Components

Steel Air with 

borated water 

leakage 

(Internal)

Loss of material/ 

general, pitting, 

crevice and boric 

acid corrosion

Chapter XI.M38, 

"Inspection of 

Internal 

Surfaces in 

Miscellaneous 

Piping and 

Ducting 

Components"

An approved precedent exists for adding this material, 

environment, aging effect, and program combination to 

the GALL Report. Encapsulation components were 

previously not in the GALL Report, but a precedent 

exists for including these items based on the Millstone 

and FNP LRAs and corresponding NRC Staff reviews. 

The Staff accepted aging management programs 

identified by these applicants for these material and 

environment combinations for loss of material in the 

SERs, Millstone SER Section 2.3A.2.3 and FNP SER 

Section 3.2.2.2.2. AMP XI.M38 was developed to 

provide for proper management of the aging effects for 

this MEAP combination. This program provides an 

acceptable means of managing aging of these 

components. (Note: this leakage is on the inside of the 

encapsulation components). See Table IV for further 

discussion of the basis for this AMP. The 

implementation of this program provides reasonable 

assurance that the component’s intended functions will 

be maintained within the CLB for the period of extended 

operation.
October 2005 65 NUREG-1833

Table II.A New AMR Line-items based on new ‘MEAP’ combinations relevant to Mechanical Systems (“A” for Auxiliary, “E” for 

Engineered Safety Features, “R” for Reactor Coolant, and “S” for Steam and Power Conversion) 

Item

Structure 

and/or 

Component

Material Environment Aging Effect/ 

Mechanism AMP Precedent and Technical Basis for New Line-Item

EP-47

SP-53

Heat 

exchanger 

tubes

Copper 

alloy

Lubricating oil Reduction of heat 

transfer/ fouling

Chapter XI.M39, 

"Lubricating Oil 

Analysis"

The AMP is to 

be augmented 

by verifying the 

effectiveness of 

the lubricating oil 

analysis 

program. See 

Chapter XI.M32, 

“One-Time 

Inspection,” for 

an acceptable 

verification 

program.

An approved precedent exists for adding this material, 

environment, aging effect, and program combination to

the GALL Report. D.C. Cook SER Section 3.2.2.3.3 

acknowledged the potential for fouling of copper alloy 

components in a lubricating oil environment. The SER 

addressed components in a PWR ECCS system, but 

these conditions would be equally applicable to 

components of other lube oil systems. AMP XI.M39 was 

developed to provide for proper management of the 

aging effects for this MEAP combination. This program 

provides an acceptable means of managing aging of 

these components with one-time inspection (AMP 

XI.M32) to provide a mitigative and verification method. 

See Table IV for further discussion of the basis for 

these AMPs. The implementation of this augmented 

program provides reasonable assurance that the 

component’s intended functions will be maintained 

within the CLB for the period of extended operation.

EP-48

RP-10

Piping, piping 

components, 

and piping 

elements

Steel Closed cycle 

cooling water

Loss of material/ 

general, pitting, 

and crevice 

corrosion

Chapter XI.M21, 

“Closed-Cycle 

Cooling Water 

System”

An approved precedent exists for adding this material, 

environment, aging effect, and program combination in 

GALL Rev. 1. GALL Rev. 0 had a similar material, 

environment, aging effect, and program combination for 

the corrosion of steel heat exchanger shell side 

components including tubes in the PWR emergency 

core cooling system (V.D1.6-a). GALL Rev. 1 captured 

this line-item in E-17 but this corresponding AMR lineitem has been extended to the ESF Containment 

Isolation Components section and the RCS Chapter IV. 

AMP XI.M21 provides for proper management of the 

aging effects for this MEAP combination. Thus, 

implementation of this AMP provides reasonable 

assurance that the component’s intended functions will 

be maintained within the CLB for the extended period of 

operation.
NUREG-1833 66 October 200

5

Table II.A New AMR Line-items based on new ‘MEAP’ combinations relevant to Mechanical Systems (“A” for Auxiliary, “E” for 

Engineered Safety Features, “R” for Reactor Coolant, and “S” for Steam and Power Conversion) 

Item

Structure 

and/or 

Component

Material Environment Aging Effect/ 

Mechanism AMP Precedent and Technical Basis for New Line-Item

EP-50

SP-62

Heat 

exchanger 

tubes

Stainless 

steel

Lubricating oil Reduction of heat 

transfer/ fouling

Chapter XI.M39, 

"Lubricating Oil 

Analysis"

The AMP is to 

be augmented 

by verifying the 

effectiveness of 

the lubricating oil 

analysis 

program. See 

Chapter XI.M32, 

“One-Time 

Inspection,” for 

an acceptable 

verification 

program.

CNP SER Section 3.2.2.3.3 acknowledged the potential 

for fouling of copper alloy components in a lubricating 

oil environment. The SER addressed components in a 

PWR ECCS system, but these conditions would be 

equally applicable to components of other lube oil 

systems. Stainless steel heat exchanger tubes would 

also be subject to fouling in a lubricating oil 

environment. AMP XI.M39 was developed to provide for 

proper management of the aging effects for this MEAP 

combination. This program provides an acceptable 

means of managing aging of these components with 

one-time inspection (AMP XI.M32) to provide a 

mitigative and verification method. See Table IV for 

further discussion of the basis for these AMPs. The 

implementation of this augmented program provides 

reasonable assurance that the component’s intended 

functions will be maintained within the CLB for the 

period of extended operation.

EP-51 Piping, piping 

components, 

and piping 

elements

Stainless 

steel

Lubricating oil Loss of material/ 

pitting and 

crevice corrosion

Chapter XI.M39, 

"Lubricating Oil 

Analysis" 

The AMP is to 

be augmented 

by verifying the 

effectiveness of 

the lubricating oil 

analysis 

program. See 

Chapter XI.M32, 

“One-Time 

Inspection,” for 

an acceptable 

verification 

program.

The GALL Report assumes contaminants or moisture 

for the lubricating oil environment; therefore, this item 

was added to address the potential for loss of material 

as a plausible aging effect that should be managed with 

stainless steel. AMP XI.M39 was developed to provide 

for proper management of the aging effects for this 

MEAP combination. This program provides an 

acceptable means of managing aging of these 

components with one-time inspection (AMP XI.M32) to 

provide a mitigative and verification method. See Table 

IV for further discussion of the basis for these AMPs. 

The implementation of this augmented program 

provides reasonable assurance that the component’s 

intended functions will be maintained within the CLB for 

the period of extended operation.
October 2005 67 NUREG-1833

Table II.A New AMR Line-items based on new ‘MEAP’ combinations relevant to Mechanical Systems (“A” for Auxiliary, “E” for 

Engineered Safety Features, “R” for Reactor Coolant, and “S” for Steam and Power Conversion) 

Item

Structure 

and/or 

Component

Material Environment Aging Effect/ 

Mechanism AMP Precedent and Technical Basis for New Line-Item

EP-52 Piping, piping 

components, 

piping 

elements

Gray cast 

iron

Closed cycle 

cooling water

Loss of material/ 

selective leaching

Chapter XI.M33, 

“Selective 

Leaching of 

Materials”

This line is similar to AP-31 and SP-27 except they 

apply to treated water environments. In the closed-cycle

cooling water environment, gray cast iron exhibits a loss 

of material due to selective leaching and therefore 

recommends management by a program. The aging 

effect is adequately managed by AMP XI.M33, 

“Selective Leaching of Materials,” which includes 

hardness test or destructive test to confirm that the iron 

matrix is not selectively leached away and a porous 

matrix of graphite is left. Implementation of this AMP 

provides reasonable assurance that the component’s 

intended functions will be maintained within the CLB for 

the extended period of operation.

EP-53 Piping, piping 

components, 

piping 

elements 

internal 

surfaces, and 

tanks 

Stainless 

steel

Condensation 

(Internal)

Loss of material/ 

pitting and 

crevice corrosion

A plant-specific 

aging 

management 

program is to be 

evaluated.

The basis for this new line-item is similar to AP-72. The 

addition of this item extends the MEAP combination for 

BWRs contained in E-14 to PWRs. A plant-specific 

aging management program will be evaluated to 

provide reasonable assurance that the component’s 

intended functions will be maintained within the CLB for 

the period of extended operation.

RP-13 Bottommounted guide 

tube

Stainless 

steel

Reactor 

coolant 

leakage

Cracking/ stress 

corrosion 

cracking

A plant-specific 

aging 

management 

program is to be 

evaluated.

An approved precedent exists for adding this material, 

environment, aging effect, and program combination to

the GALL Report. In the RNP SER section 3.1.2.4.6.6, 

the Staff has accepted the position that cracking due to 

SCC is exhibited by stainless steel with reactor coolant 

leakage. A plant-specific aging management program 

will be evaluated to provide reasonable assurance that 

the component’s intended functions will be maintained 

within the CLB for the period of extended operation.
NUREG-1833 68 October 200

5

Table II.A New AMR Line-items based on new ‘MEAP’ combinations relevant to Mechanical Systems (“A” for Auxiliary, “E” for 

Engineered Safety Features, “R” for Reactor Coolant, and “S” for Steam and Power Conversion) 

Item

Structure 

and/or 

Component

Material Environment Aging Effect/ 

Mechanism AMP Precedent and Technical Basis for New Line-Item

RP-14 Steam 

generator 

structural

Anti-vibration 

bars

Chrome

plated steel; 

stainless 

steel; Nickel 

alloy

Secondary 

feedwater/ 

steam

Cracking/ stress 

corrosion 

cracking

Chapter XI.M19, 

“Steam 

Generator 

Tubing Integrity” 

and Chapter 

XI.M2, “Water 

Chemistry,” for 

PWR secondary 

water

An approved precedent exists for adding this material, 

environment, aging effect, and program combination to

the GALL Report. In the NA/S SER section 3.4.5, the 

Staff has accepted the position that cracking due to 

SCC is exhibited by stainless steel and nickel alloy in a 

secondary feedwater/steam environment. This aging 

effect/mechanism is properly managed by the Steam 

Generator Tubing Integrity and water chemistry 

programs which ensure that water chemistry is 

maintained to appropriate EPRI standards and 

appropriate inspections are performed on steam 

generator components. AMPs XI.M19 and XI.M2 

provides for proper management of the aging effects for 

this MEAP combination. The implementation of these

AMPs provides reasonable assurance that the 

component’s intended functions will be maintained 

within the CLB for the period of extended operation.
October 2005 69 NUREG-1833

Table II.A New AMR Line-items based on new ‘MEAP’ combinations relevant to Mechanical Systems (“A” for Auxiliary, “E” for 

Engineered Safety Features, “R” for Reactor Coolant, and “S” for Steam and Power Conversion) 

Item

Structure 

and/or 

Component

Material Environment Aging Effect/ 

Mechanism AMP Precedent and Technical Basis for New Line-Item

RP-15 Steam 

generator 

structural 

Anti-vibration 

bars

Chrome 

plated steel; 

stainless 

steel; Nickel 

alloy

Secondary 

feedwater/ 

steam

Loss of material/ 

crevice corrosion 

and fretting

Chapter XI.M19, 

“Steam

Generator 

Tubing Integrity” 

and Chapter 

XI.M2, “Water 

Chemistry,” for 

PWR secondary 

water

An approved precedent exists for adding this material, 

environment, aging effect, and program combination to

the GALL Report. In several PWR plant license renewal 

SERs, the Staff has accepted the position that loss of 

material due to crevice corrosion and fretting is 

exhibited by stainless steel and nickel alloy in a 

secondary feedwater/steam environment. This aging 

effect/mechanism is properly managed by the Steam 

Generator Tubing Integrity and water chemistry 

programs which ensure that water chemistry is 

maintained to appropriate EPRI standards and 

appropriate inspections are performed on steam 

generator components. AMPs XI.M19 and XI.M2 

provides for proper management of the aging effects for 

this MEAP combination. The implementation of these

AMPs provides reasonable assurance that the 

component’s intended functions will be maintained 

within the CLB for the period of extended operation.
NUREG-1833 70 October 200

5

Table II.A New AMR Line-items based on new ‘MEAP’ combinations relevant to Mechanical Systems (“A” for Auxiliary, “E” for 

Engineered Safety Features, “R” for Reactor Coolant, and “S” for Steam and Power Conversion) 

Item

Structure 

and/or 

Component

Material Environment Aging Effect/ 

Mechanism AMP Precedent and Technical Basis for New Line-Item

RP-16 Steam 

generator

Tube bundle 

wrapper

Steel Secondary 

feedwater/ 

steam

Loss of material/ 

erosion, general, 

pitting, and 

crevice corrosion

Chapter XI.M19, 

“Steam 

Generator 

Tubing Integrity” 

and Chapter 

XI.M2, “Water 

Chemistry,” for 

PWR secondary 

water

An approved precedent exists for adding this material, 

environment, aging effect, and program combination to

the GALL Report. In NA/S SER section 3.4.5, the Staff

has accepted the position that loss of material due to 

general, pitting, and crevice corrosion is exhibited by 

steel in a secondary feedwater/steam environment. This 

aging effect/mechanism is properly managed by the 

Steam Generator Tubing Integrity and water chemistry 

programs which ensure that water chemistry is 

maintained to appropriate EPRI standards and 

appropriate inspections are performed on steam 

generator components. AMPs XI.M19 and XI.M2 

provides for proper management of the aging effects for 

this MEAP combination. The implementation of these

AMPs provides reasonable assurance that the 

component’s intended functions will be maintained 

within the CLB for the period of extended operation.
October 2005 71 NUREG-1833

Table II.A New AMR Line-items based on new ‘MEAP’ combinations relevant to Mechanical Systems (“A” for Auxiliary, “E” for 

Engineered Safety Features, “R” for Reactor Coolant, and “S” for Steam and Power Conversion) 

Item

Structure 

and/or 

Component

Material Environment Aging Effect/ 

Mechanism AMP Precedent and Technical Basis for New Line-Item

RP-17 Primary Side

Divider Plate

Stainless 

steel

Reactor 

coolant

Cracking/ Stress 

corrosion 

cracking 

Chapter XI.M2, 

“Water 

Chemistry,” for 

PWR primary 

water

An approved precedent exists for adding this material, 

environment, aging effect, and program combination to

the GALL Report. In RNP SER section 3.1.2.4.6.7, the 

Staff has accepted the position that cracking due to 

SCC is exhibited by nickel alloy in a reactor coolant 

environment. This aging effect/mechanism is properly 

managed by the Inservice Inspection and Water 

Chemistry programs which ensure that water chemistry 

is maintained to appropriate EPRI standards and 

appropriate inspections are performed on steam 

generator components. Stainless steel would behave 

similarly to nickel alloy. While the ISI Program was cited 

in the above SER, this program is not generically used 

to manage the aging effect for this component. Thus, 

the Staff determined that only program XI.M2 is 

necessary to provide reasonable assurance that the 

component’s intended functions will be maintained 

within the CLB for the extended period of operation.

RP-18 Steam Dryers Stainless 

steel

Reactor 

coolant

Cracking/ flowinduced vibrationA plant-specific 

aging 

management 

program is to be 

evaluated.

In the D/QC SER, Appendix A, commitment 9, for plants 

performing extended power uprate, steam dryers are in 

scope for category (a)(2), and may exhibit cracking due 

to flow-induced vibration and therefore require 

management by a program. A plant-specific aging 

management program will be evaluated to provide 

reasonable assurance that the component’s intended 

functions will be maintained within the CLB for the 

period of extended operation.
NUREG-1833 72 October 200

5

Table II.A New AMR Line-items based on new ‘MEAP’ combinations relevant to Mechanical Systems (“A” for Auxiliary, “E” for 

Engineered Safety Features, “R” for Reactor Coolant, and “S” for Steam and Power Conversion) 

Item

Structure 

and/or 

Component

Material Environment Aging Effect/ 

Mechanism AMP Precedent and Technical Basis for New Line-Item

RP-21 Primary Side

Divider Plate

Nickel alloy; 

steel with 

nickel-alloy 

cladding

Reactor 

coolant

Cracking/ primary 

water stress 

corrosion 

cracking 

Chapter XI.M2, 

“Water 

Chemistry,” for 

PWR primary 

water 

An approved precedent exists for adding this material, 

environment, aging effect, and program combination to

the GALL Report. In RNP SER section 3.1.2.4.6.7, the 

Staff has accepted the position that cracking due to 

SCC is exhibited by nickel alloy in a reactor coolant 

environment. This aging effect/mechanism is properly 

managed by the Inservice Inspection and Water 

Chemistry programs which ensure that water chemistry 

is maintained to appropriate EPRI standards and 

appropriate inspections are performed on steam 

generator components. While the ISI Program was cited 

in the above SER, this program is not generically used 

to manage the aging effect for this component. Thus, 

the Staff determined that only program XI.M2 is 

necessary to provide reasonable assurance that the 

component’s intended functions will be maintained 

within the CLB for the extended period of operation. 
October 2005 73 NUREG-1833

Table II.A New AMR Line-items based on new ‘MEAP’ combinations relevant to Mechanical Systems (“A” for Auxiliary, “E” for 

Engineered Safety Features, “R” for Reactor Coolant, and “S” for Steam and Power Conversion) 

Item

Structure 

and/or 

Component

Material Environment Aging Effect/ 

Mechanism AMP Precedent and Technical Basis for New Line-Item

RP-22 Pressurizer 

surge and 

steam space 

nozzles and 

welds

Nickel alloy Reactor 

coolant/ steam

Cracking/ primary 

water stress 

corrosion 

cracking

Chapter XI.M1, 

“ASME Section 

XI Inservice 

Inspection, 

Subsections 

IWB, IWC, and 

IWD” for Class 1 

components, 

and Chapter 

XI.M2, “Water 

Chemistry,” for 

PWR primary 

water and

comply with 

applicable NRC 

Orders and 

provide a 

commitment in 

the FSAR 

supplement to 

implement 

applicable (1) 

Bulletins and 

Generic Letters 

and (2) staffaccepted 

industry

guidelines.

An approved precedent exists for adding this material, 

environment, aging effect, and program combination to

the GALL Report. In the VCS SER section 3.1.2.4.6, the 

Staff has accepted the position that cracking due to 

PWSCC is exhibited by nickel alloy in a reactor coolant 

environment. This aging effect/mechanism is properly 

managed by the Inservice Inspection and Water 

Chemistry programs which ensure that water chemistry 

is maintained to appropriate EPRI standards and 

appropriate inspections are performed on pressurizer 

components. Programs XI.M1 and XI.M2, 

supplemented by NRC Orders, Bulletins or Generic 

Letters and staff accepted industry guidelines, provide 

the additional guidance to ensure that the component’s 

intended functions will be maintained within the CLB for 

the extended period of operation. However, if alloy 600 

or its associated weld materials (alloy 82/182) is used, 

the Staff has requested a commitment in the FSAR 

supplement as stated.

AMR line-item RP-22 was added to identify primary 

water stress corrosion cracking (PWSCC) of the 

pressurizer steam space nozzles and was added on the 

basis of a study of domestic operating experience. The 

NRC Office of Research provided a 128-item listing of 

LERs related to failures, cracking, degradation, etc of 

passive components. 
NUREG-1833 74 October 200

5

Table II.A New AMR Line-items based on new ‘MEAP’ combinations relevant to Mechanical Systems (“A” for Auxiliary, “E” for 

Engineered Safety Features, “R” for Reactor Coolant, and “S” for Steam and Power Conversion) 

Item

Structure 

and/or 

Component

Material Environment Aging Effect/ 

Mechanism AMP Precedent and Technical Basis for New Line-Item

RP-23 Piping, piping 

components, 

and piping 

elements; 

flanges; heater 

sheaths and 

sleeves; 

penetrations; 

thermal 

sleeves; vessel 

shell heads 

and welds

Steel with 

stainless 

steel or 

nickel alloy 

cladding; 

stainless 

steel; nickel 

alloy

Reactor 

coolant

Loss of material/ 

pitting and 

crevice corrosion

Chapter XI.M2, 

“Water 

Chemistry,” for 

PWR primary 

water

GALL Rev. 0 stated that "the effects of pitting and 

crevice corrosion on stainless steel are not significant in 

reactor coolant (i.e., treated borated water), and 

therefore are not included" as an aging effect that 

required management (i.e., an AMR line-item was not 

included in the GALL Report). This statement is true for 

PWRs in part because water chemistry program 

requirements minimize contaminates that could lead to 

a loss of material. The Staff has removed this statement 

from the GALL Report and has added this new AMR 

line-item in the GALL Rev. 1 Report for PWRs, which 

although no significant loss of material is expected, 

recognizes that applicants can manage loss of material 

in stainless steel in a treated borated water environment 

by virtue of their use of a water chemistry program 

which meets XI.M2. The above approach for managing 

loss of material in treated borated water also applies to 

nickel alloy.
October 2005 75 NUREG-1833

Table II.A New AMR Line-items based on new ‘MEAP’ combinations relevant to Mechanical Systems (“A” for Auxiliary, “E” for 

Engineered Safety Features, “R” for Reactor Coolant, and “S” for Steam and Power Conversion) 

Item

Structure 

and/or 

Component

Material Environment Aging Effect/ 

Mechanism AMP Precedent and Technical Basis for New Line-Item

RP-24 Reactor vessel 

internals 

components

Stainless 

steel; nickel 

alloy

Reactor 

coolant

Loss of material/ 

pitting and 

crevice corrosion

Chapter XI.M2, 

“Water 

Chemistry,” for 

PWR primary 

water

GALL Rev. 0 stated that "the effects of pitting and 

crevice corrosion (loss of material) on stainless steel 

are not significant in reactor coolant (i.e., treated 

borated water), and therefore are not included" as an 

aging effect that required management (i.e., an AMR 

line-item was not included in the GALL Report). This 

statement is true for PWRs in part because water 

chemistry program requirements minimize 

contaminates that could lead to a loss of material. The 

Staff has removed this statement from the GALL Report 

and has added this new AMR line-item in the GALL 

Rev. 1 Report for PWRs which, although no loss of 

material is expected, recognizes that applicants can 

manage loss of material in stainless steel in a treated 

borated water environment by virtue of their use of a 

water chemistry program which meets XI.M2. The 

above approach for managing loss of material in treated 

borated water also applies to nickel alloy.

RP-25 Reactor 

Vessel: 

Flanges, 

nozzles; 

penetrations; 

safe ends; 

vessel shells, 

heads and 

welds

Stainless 

steel; steel 

with nickelalloy or 

stainless 

steel 

cladding; 

nickel-alloy

Reactor 

Coolant

Loss of material/ 

pitting and 

crevice corrosion

Chapter XI.M2, 

“Water 

Chemistry,” for 

BWR water

The AMP is to 

be augmented 

by verifying the 

effectiveness of 

water chemistry 

control. See 

Chapter XI.M32, 

“One-Time 

Inspection,” for 

an acceptable 

verification 

program.

Unlike the PWR reactor coolant environment (see RP24 above), the BWR treated water environment does 

not contain boron (which is a recognized corrosion 

inhibitor). Thus for this AMR line-item related to BWRs, 

it is necessary to have the AMP XI.M2, “Water 

Chemistry,” augmented by verifying the effectiveness of 

water chemistry control.
NUREG-1833 76 October 200

5

Table II.A New AMR Line-items based on new ‘MEAP’ combinations relevant to Mechanical Systems (“A” for Auxiliary, “E” for 

Engineered Safety Features, “R” for Reactor Coolant, and “S” for Steam and Power Conversion) 

Item

Structure 

and/or 

Component

Material Environment Aging Effect/ 

Mechanism AMP Precedent and Technical Basis for New Line-Item

RP-26 Reactor vessel 

internals 

components

Stainless 

steel; nickel 

alloy

Reactor 

coolant

Loss of material/ 

pitting and 

crevice corrosion

Chapter XI.M1, 

“ASME Section 

XI Inservice 

Inspection, 

Subsections 

IWB, IWC, and 

IWD,” for Class 

1 components 

and Chapter 

XI.M2, “Water 

Chemistry” for 

BWR water

The Staff added this line-item for consistency with RP28. However, unlike the PWR reactor coolant 

environment, the BWR reactor coolant environment 

(i.e., treated water) does not contain boron, a 

recognized corrosion inhibitor. Therefore, for this AMR 

line-item, it is necessary to have the Chapter XI.M2, 

“Water Chemistry” AMP augmented by verifying the 

effectiveness of water chemistry control. NRC Staff

determined that the appropriate AMP description is 

Chapter XI.M2, “Water Chemistry,” for BWR water and 

Chapter XI.M1, “ASME Section XI Inservice Inspection, 

Subsections IWB, IWC, and IWD" for these Class 1 

components with no further evaluation. The above 

approach for managing any significant loss of material 

in reactor coolant (treated water) also applies to nickel 

alloy.

RP-27 Reactor 

coolant 

pressure 

boundary 

components

Steel with 

stainless 

steel or 

nickel alloy 

cladding; 

stainless 

steel; nickel 

alloy

Reactor 

coolant

Loss of material/ 

pitting and 

crevice corrosion

Chapter XI.M2, 

“Water 

Chemistry,” for 

BWR water

The AMP is to 

be augmented 

by verifying the 

effectiveness of 

water chemistry 

control. See 

Chapter XI.M32, 

“One-Time 

Inspection,” for 

an acceptable 

verification 

program.

The Staff added this line-item for consistency with RP28 and RP-25. However, unlike the PWR reactor 

coolant environment, the BWR reactor coolant 

environment (i.e., treated water) does not contain 

boron, a recognized corrosion inhibitor. Therefore, for 

this AMR line-item, it is necessary to have the Chapter 

XI.M2, “Water Chemistry” AMP augmented by verifying 

the effectiveness of water chemistry control. 
October 2005 77 NUREG-1833

Table II.A New AMR Line-items based on new ‘MEAP’ combinations relevant to Mechanical Systems (“A” for Auxiliary, “E” for 

Engineered Safety Features, “R” for Reactor Coolant, and “S” for Steam and Power Conversion) 

Item

Structure 

and/or 

Component

Material Environment Aging Effect/ 

Mechanism AMP Precedent and Technical Basis for New Line-Item

RP-28 Flanges, 

nozzles; 

penetrations; 

pressure 

housings; safe 

ends; vessel 

shells, heads 

and welds

Stainless 

steel; steel 

with nickelalloy or 

stainless 

steel 

cladding; 

nickel-alloy

Reactor 

Coolant

Loss of material/ 

pitting and 

crevice corrosion

Chapter XI.M2, 

“Water 

chemistry,” for 

PWR primary 

water

GALL Rev. 0 stated that "the effects of pitting and 

crevice corrosion (loss of material) on stainless steel 

are not significant in reactor coolant (i.e., treated 

borated water), and therefore are not included" as an 

aging effect that required management (i.e., an AMR 

line-item was not included in the GALL Report). This 

statement is true for PWRs in part because water 

chemistry program requirements minimize 

contaminants that could lead to a loss of material. As 

part of the public comment process, the Staff has 

removed this statement from the GALL Report and has 

added this new AMR line-item in the GALL Rev. 1

Report for PWRs which, although no significant loss of 

material is expected, recognizes that applicants can 

manage loss of material in stainless steel in a treated 

borated water environment by virtue of their use of a 

water chemistry program that meets XI.M2. The above 

approach for managing loss of material in treated 

borated water also applies to nickel alloy. 
NUREG-1833 78 October 200

5

Table II.A New AMR Line-items based on new ‘MEAP’ combinations relevant to Mechanical Systems (“A” for Auxiliary, “E” for 

Engineered Safety Features, “R” for Reactor Coolant, and “S” for Steam and Power Conversion) 

Item

Structure 

and/or 

Component

Material Environment Aging Effect/ 

Mechanism AMP Precedent and Technical Basis for New Line-Item

RP-31 Piping, piping 

components, 

and piping 

elements

Nickel alloy Reactor 

coolant/ steam

Cracking/ primary 

water stress 

corrosion 

cracking

Chapter XI.M1, 

“ASME Section 

XI Inservice 

Inspection, 

Subsections 

IWB, IWC, and 

IWD” for Class 1 

components, 

and Chapter 

XI.M2, “Water 

Chemistry,” for 

PWR primary 

water and

comply with 

applicable NRC 

Orders and 

provide a 

commitment in 

the FSAR 

supplement to 

implement 

applicable (1) 

Bulletins and 

Generic Letters 

and (2) staffaccepted 

industry 

guidelines.

An approved precedent exists for adding this material, 

environment, aging effect, and program combination to

the GALL Report. In the VCS SER section 3.1.2.2.7, the 

Staff has accepted the position that cracking due to 

PWSCC is exhibited by nickel alloy in a reactor coolant 

environment. This aging effect/mechanism is properly 

managed by the Inservice Inspection and Water 

Chemistry programs which ensure that water chemistry 

is maintained to appropriate EPRI standards and 

appropriate inspections are performed on pressurizer 

components. Implementation of AMPs XI.M1 and 

XI.M2, supplemented by NRC Orders, Bulletins or 

Generic Letters and staff accepted industry guidelines, 

provides the additional guidance to assure that the 

component’s intended functions will be maintained 

within the CLB for the extended period of operation. 

However, if alloy 600 or its associated weld materials 

(alloy 82/182) is used, the Staff has requested a 

commitment in the FSAR supplement as stated. This 

AMR line-item is an expansion of RP-22. AMR line-item

RP-22 was added to identify primary water stress 

corrosion cracking (PWSCC) of the pressurizer steam 

space nozzles and was added on the basis of a study of 

domestic operating experience.
October 2005 79 NUREG-1833

Table II.A New AMR Line-items based on new ‘MEAP’ combinations relevant to Mechanical Systems (“A” for Auxiliary, “E” for 

Engineered Safety Features, “R” for Reactor Coolant, and “S” for Steam and Power Conversion) 

Item

Structure 

and/or 

Component

Material Environment Aging Effect/ 

Mechanism AMP Precedent and Technical Basis for New Line-Item

SP-16 Piping, piping 

components 

and piping 

elements

Stainless 

steel

Treated water Loss of material/ 

pitting and 

crevice corrosion

XI.M2, “Water 

Chemistry”

The AMP is to 

be augmented 

by verifying the 

effectiveness of 

water chemistry 

control. See 

Chapter XI.M32, 

“One-Time 

Inspection,” for 

an acceptable 

verification 

program.

Piping, piping components, and piping elements in the 

PWR feedwater system (VIII.D1) and the steam 

generator blowdown system (VIII.F), if made of 

stainless steel and exposed to treated water, can be 

subject to loss of material due to pitting and crevice 

corrosion. An approved precedent exists for adding this 

material, environment, aging effect, and program 

combination to the GALL Report. As shown in NA/S 

SER Section 3.6.2, the Staff has accepted the position 

that stainless steel in a treated water environment 

exhibits a loss of material and therefore recommends

management by a program. Pitting of stainless steel 

components is primarily related to the presence of 

detrimental ionic species such as chlorides, fluorides, 

and sulfates. Crevice corrosion of stainless steel 

components is primarily related to the presence of 

significant levels of dissolved oxygen. The aging effect 

is adequately managed by the Water Chemistry AMP, 

which includes specifications for chemical species, 

sampling, analysis frequencies, and corrective actions 

for control of reactor water chemistry. Consistent with 

GALL Rev. 0, the AMP is augmented by one-time 

inspection to confirm that unacceptable degradation is 

not occurring and that the concentration of chemical 

contaminants falls within acceptable limits. The 

implementation of this augmented program provides 

reasonable assurance that the component’s intended 

functions will be maintained within the CLB for the 

extended period of operation.
NUREG-1833 80 October 200

5

Table II.A New AMR Line-items based on new ‘MEAP’ combinations relevant to Mechanical Systems (“A” for Auxiliary, “E” for 

Engineered Safety Features, “R” for Reactor Coolant, and “S” for Steam and Power Conversion) 

Item

Structure 

and/or 

Component

Material Environment Aging Effect/ 

Mechanism AMP Precedent and Technical Basis for New Line-Item

SP-17 Piping, piping 

components 

and piping 

elements

Stainless 

steel

Treated water 

>60°C 

(>140°F)

Cracking/ stress 

corrosion 

cracking

XI.M2, “Water 

Chemistry,” for 

PWR secondary.

The AMP is to 

be augmented 

by verifying the 

effectiveness of 

water chemistry 

control. See 

Chapter XI.M32, 

“One-Time 

Inspection,” for 

an acceptable 

verification 

program.

An approved precedent exists for adding this material, 

environment, aging effect, and program combination in 

GALL Rev. 1. GALL Rev. 0 had a similar MEAP 

combination for auxiliary systems (VII.E3.1-a) for crack 

initiation and growth due to SCC and IGSCC in 

stainless steel piping (captured in GALL Rev. 1 by AMR 

line-item A-60 in VII.E3 for the reactor water cleanup 

system). This related AMR line-item was created to 

extend the MEAP combination to the applicable PWR 

steam and power conversion systems. The aging effect 

is adequately managed by the Water Chemistry AMP, 

which includes specifications for chemical species, 

sampling, analysis frequencies, and corrective actions 

for control of reactor water chemistry. The AMP is 

augmented by one-time inspection to confirm that 

unacceptable degradation is not occurring. The 

implementation of this augmented program provides 

reasonable assurance that the component's intended 

functions will be maintained within the CLB for the 

extended period of operation. 
October 2005 81 NUREG-1833

Table II.A New AMR Line-items based on new ‘MEAP’ combinations relevant to Mechanical Systems (“A” for Auxiliary, “E” for 

Engineered Safety Features, “R” for Reactor Coolant, and “S” for Steam and Power Conversion) 

Item

Structure 

and/or 

Component

Material Environment Aging Effect/ 

Mechanism AMP Precedent and Technical Basis for New Line-Item

SP-18 Piping, piping 

components 

and piping 

elements

Nickelbased 

alloys

Steam Loss of material/ 

pitting and 

crevice corrosion

XI.M2, “Water 

Chemistry,” for 

PWR secondary 

water

An approved precedent exists for adding this material, 

environment, aging effect, and program combination to

the GALL Report. As discussed in RNP SER section 

3.1.2.4.1, pg. 3-136, the Staff has accepted the position 

that nickel alloy in a treated water/steam environment 

exhibits a loss of material and therefore recommends

management by a program. In GALL Rev. 0, nickel 

alloy recirculating steam generator tubes and sleeves 

(IV D1.2-f) in steam environment were considered to be 

subject to loss of material due to wastage and pitting 

corrosion. In VCS SER Section 3.1.2.4.7, the Staff

concluded that the chemistry program is acceptable for 

managing loss of material due to pitting and crevice 

corrosion in nickel-based components. Pitting of nickel 

alloy components is primarily related to the presence of 

detrimental ionic species such as chlorides, fluorides, 

and sulfates. Crevice corrosion of nickel alloy 

components is primarily related to the presence of 

significant levels of dissolved oxygen. The aging effect 

is adequately managed by the Water Chemistry AMP, 

which includes specifications for chemical species, 

sampling, analysis frequencies, and corrective actions

for control of reactor water chemistry. Because the 

steam is specified as dry in line-item SP-18 and thus 

not as corrosive, only the Water Chemistry program is 

required and further augmentation is not needed. The 

implementation of this program provides reasonable 

assurance that the component’s intended functions will 

be maintained within the CLB for the extended period of 

operation.
NUREG-1833 82 October 200

5

Table II.A New AMR Line-items based on new ‘MEAP’ combinations relevant to Mechanical Systems (“A” for Auxiliary, “E” for 

Engineered Safety Features, “R” for Reactor Coolant, and “S” for Steam and Power Conversion) 

Item

Structure 

and/or 

Component

Material Environment Aging Effect/ 

Mechanism AMP Precedent and Technical Basis for New Line-Item

SP-19 Piping, piping 

components 

and piping 

elements

Stainless 

steel

Treated water 

>60°C 

(>140°F)

Cracking/ stress 

corrosion 

cracking

Chapter XI.M2, 

“Water 

Chemistry,” for 

BWR Water.

The AMP is to 

be augmented 

by verifying the 

effectiveness of 

water chemistry 

control. See 

Chapter XI.M32, 

“One-Time 

Inspection,” for 

an acceptable 

verification 

program. 

An approved precedent exists for adding this material, 

environment, aging effect, and program combination to

the GALL Report for piping, piping components, and

piping elements in the BWR steam and power 

conversion condensate system (VIII.E). GALL Rev. 0

had a similar MEAP combination for auxiliary systems 

(VII.E3.1-a) for crack initiation and growth due to SCC 

and IGSCC in stainless steel piping (captured in GALL 

Rev. 1 by AMR line-item A-60 in VII.E3 for the reactor 

water cleanup system). The aging effect is adequately 

managed by the Water Chemistry AMP, which includes 

specifications for chemical species, sampling, analysis 

frequencies, and corrective actions for control of reactor 

water chemistry. The AMP is augmented by one-time 

inspection to confirm that unacceptable degradation is 

not occurring. The implementation of this augmented 

program provides reasonable assurance that the 

component's intended functions will be maintained 

within the CLB for the extended period of operation. 
October 2005 83 NUREG-1833

Table II.A New AMR Line-items based on new ‘MEAP’ combinations relevant to Mechanical Systems (“A” for Auxiliary, “E” for 

Engineered Safety Features, “R” for Reactor Coolant, and “S” for Steam and Power Conversion) 

Item

Structure 

and/or 

Component

Material Environment Aging Effect/ 

Mechanism AMP Precedent and Technical Basis for New Line-Item

SP-26

EP-54

Piping, piping 

components, 

and piping 

elements

Gray cast 

iron

Soil Loss of material/ 

selective leaching

Chapter XI.M33, 

“Selective 

Leaching of 

Materials”

An approved precedent exists for adding this material, 

environment, aging effect, and program combination to

the GALL Report. As shown in FCS Unit 1 SER Section 

3.3.2.4.16, the Staff has accepted the position that gray 

cast iron in a soil environment exhibits a loss of material 

due to selective leaching and therefore recommends

management by a program. GALL Rev. 0 had a similar 

MEAP combination for auxiliary systems (VII.C1.1-c) for 

loss of material due to selective leaching and general 

corrosion in cast iron piping in soil (captured in GALL 

Rev. 1 by A-02 in VII.C1). This related AMR line-item

was created to focus only on selective leaching as an 

aging mechanism for specified auxiliary systems. The 

aging effect is adequately managed by AMP XI.M33, 

“Selective Leaching of Materials,” which includes 

hardness test or destructive test to confirm that the iron 

matrix is not selectively leached away and a porous 

matrix of graphite is left. Implementation of this AMP 

provides reasonable assurance that the component’s 

intended functions will be maintained within the CLB for 

the extended period of operation.
NUREG-1833 84 October 200

5

Table II.A New AMR Line-items based on new ‘MEAP’ combinations relevant to Mechanical Systems (“A” for Auxiliary, “E” for 

Engineered Safety Features, “R” for Reactor Coolant, and “S” for Steam and Power Conversion) 

Item

Structure 

and/or 

Component

Material Environment Aging Effect/ 

Mechanism AMP Precedent and Technical Basis for New Line-Item

SP-28 Piping, piping 

components, 

and piping 

elements

Gray cast 

iron

Raw water Loss of material/ 

selective leaching

Chapter XI.M33, 

“Selective 

Leaching of 

Materials”

An approved precedent exists for adding this material, 

environment, aging effect, and program combination to

the GALL Report. As shown in Ginna SER Section 

3.3.2.4.5 and FCS Unit 1 SER Section 3.3.2.4.1, the 

Staff has accepted the position that gray cast iron in a 

raw water environment exhibits a loss of material due to 

selective leaching and therefore recommends

management by a program. The aging effect is 

adequately managed by AMP XI.M33, “Selective 

Leaching of Materials,” which includes hardness test or 

destructive test to confirm that the iron matrix is not 

selectively leached away and a porous matrix of 

graphite is left. Implementation of this AMP provides 

reasonable assurance that the component’s intended 

functions will be maintained within the CLB for the 

extended period of operation.

SP-30 Piping, piping 

components, 

and piping 

elements

Copper 

alloy >15% 

Zn

Raw water Loss of material/ 

selective leaching 

Chapter XI.M33, 

“Selective 

Leaching of 

Materials”

An approved precedent exists for adding this material, 

envi ronment, aging effect, and program combination to

the GALL Report. As shown in FCS SER Section 

3.3.2.4.14, the Staff has accepted the position that 

copper alloy >15%Zn in a raw water environment 

exhibits a loss of material due to selective leaching and 

therefore recommends management by a program. Per 

EPRI TR-1003056, copper alloy >15%Zn is considered 

susceptible to selective leaching. The aging effect due 

to selective leaching is adequately managed by AMP 

XI.M33 which includes a hardness test or a destructive 

test to confirm that zinc is not leaching out, and that the 

material is not becoming soft. Implementation of this 

AMP provides reasonable assurance that the 

component’s intended functions will be maintained 

within the CLB for the extended period of operation.
October 2005 85 NUREG-1833

Table II.A New AMR Line-items based on new ‘MEAP’ combinations relevant to Mechanical Systems (“A” for Auxiliary, “E” for 

Engineered Safety Features, “R” for Reactor Coolant, and “S” for Steam and Power Conversion) 

Item

Structure 

and/or 

Component

Material Environment Aging Effect/ 

Mechanism AMP Precedent and Technical Basis for New Line-Item

SP-42 Tanks Stainless 

Steel

Treated water 

>60°C 

(>140°F)

Cracking/ stress 

corrosion 

cracking

Chapter XI.M2, 

“Water 

Chemistry”

The AMP is to 

be augmented 

by verifying the 

effectiveness of 

water chemistry 

control. See 

Chapter XI.M32, 

“One-Time 

Inspection,” for 

an acceptable 

verification 

program.

An approved precedent exists for adding this material, 

environment, aging effect, and program combination to

the GALL Report. Condensate system storage tanks 

(VIII.E) containing treated water are subject to cracking 

due to SCC, a potential aging mechanism for stainless 

steels with operating temperatures >140°F. Chlorides, 

fluorides, sulfates, and dissolved oxygen are 

contributors to SCC. As shown in NA/S SER Section 

3.5.2, the Staff has accepted the position that cracking 

exhibited by stainless steel in treated water > 140°F 

environment is properly managed by the Chemistry 

Control AMP which includes specifications for chemical 

species, sampling and analysis frequencies, and 

corrective actions for control of reactor water chemistry. 

AMP XI.M2 is augmented by one-time inspection to 

confirm that unacceptable degradation is not occurring. 

The implementation of this augmented program 

provides reasonable assurance that the component’s 

intended functions will be maintained within the CLB for 

the extended period of operation. 

SP-43 Piping, piping 

components, 

and piping 

elements

Stainless 

steel

Steam Loss of material/ 

pitting and 

crevice corrosion

Chapter XI.M2, 

“Water 

Chemistry,” for 

PWR secondary

water

An approved precedent exists for adding this material, 

environment, aging effect, and program combination to

the GALL Report. As shown in RNP SER, section 

3.4.2.4.5, the Staff has accepted the position that loss 

of material due to pitting and crevice corrosion exhibited 

by stainless steel in steam is properly managed by the 

Water Chemistry AMP which includes specifications for 

chemical species, sampling and analysis frequencies, 

and corrective actions for control of reactor water 

chemistry. The implementation of this program provides 

reasonable assurance that the component’s intended 

functions will be maintained within the CLB for the 

extended period of operation.
NUREG-1833 86 October 200

5

Table II.A New AMR Line-items based on new ‘MEAP’ combinations relevant to Mechanical Systems (“A” for Auxiliary, “E” for 

Engineered Safety Features, “R” for Reactor Coolant, and “S” for Steam and Power Conversion) 

Item

Structure 

and/or 

Component

Material Environment Aging Effect/ 

Mechanism AMP Precedent and Technical Basis for New Line-Item

SP-44 Piping, piping 

components, 

and piping 

elements

Stainless 

steel

Steam Cracking/ stress 

corrosion 

cracking

Chapter XI.M2, 

“Water 

Chemistry,” for 

PWR secondary 

water

An approved precedent exists for adding this material, 

environment, aging effect, and program combination to

the GALL Report. As shown in RNP SER, section 

3.4.2.4.5, the Staff has accepted the position that 

cracking due to SCC exhibited by stainless steel in 

steam is properly managed by the Water Chemistry 

AMP which includes specifications for chemical 

species, sampling and analysis frequencies, and 

corrective actions for control of reactor water chemistry. 

The implementation of this program provides 

reasonable assurance that the component’s intended 

functions will be maintained within the CLB for the 

extended period of operation.

SP-45 Piping, piping 

components, 

and piping 

elements

Stainless 

steel

Steam Cracking/ stress 

corrosion 

cracking

Chapter XI.M2, 

“Water 

Chemistry,” for 

BWR water 

The AMP is to 

be augmented 

by verifying the 

effectiveness of 

water chemistry 

control. See 

Chapter XI.M32, 

“One-Time 

Inspection,” for 

an acceptable 

verification 

program.

An approved precedent exists for adding this material, 

environment, aging effect, and program combination to

the GALL Report. As shown in D/QC SER, section 

3.4.2.4.1, the Staff has accepted the position that 

cracking exhibited by stainless steel in steam is 

properly managed by the Water Chemistry AMP which 

includes specifications for chemical species, sampling, 

analysis frequencies, and corrective actions for control 

of reactor water chemistry. The AMP is augmented by 

one-time inspection, based on operating experience for 

BWRs that SCC occurs in this environment, to confirm 

that unacceptable degradation is not occurring. The 

implementation of this augmented program provides 

reasonable assurance that the component’s intended 

functions will be maintained within the CLB for the 

extended period of operation.
October 2005 87 NUREG-1833

Table II.A New AMR Line-items based on new ‘MEAP’ combinations relevant to Mechanical Systems (“A” for Auxiliary, “E” for 

Engineered Safety Features, “R” for Reactor Coolant, and “S” for Steam and Power Conversion) 

Item

Structure 

and/or 

Component

Material Environment Aging Effect/ 

Mechanism AMP Precedent and Technical Basis for New Line-Item

SP-46 Piping, piping 

components, 

and piping 

elements

Stainless 

steel

Steam Loss of material/ 

pitting and 

crevice corrosion

Chapter XI.M2, 

“Water 

Chemistry,” for 

BWR water

An approved precedent exists for adding this material, 

environment, aging effect, and program combination to

the GALL Report. As shown in D/QC SER, section 

3.4.2.4.1, the Staff has accepted the position that loss 

of material due to pitting and crevice corrosion exhibited 

by stainless steel in steam is properly managed by the 

Water Chemistry AMP which includes specifications for 

chemical species, sampling and analysis frequencies, 

and corrective actions for control of reactor water 

chemistry. The implementation of this program provides 

reasonable assurance that the component’s intended 

functions will be maintained within the CLB for the 

extended period of operation.

SP-56 Heat 

exchanger 

tubes

Copper 

alloy

Raw water Reduction of heat 

transfer/ fouling

Chapter XI.M20, 

“Open-Cycle 

Cooling Water 

System”

An approved precedent exists for adding this material, 

environment, aging effect, and program combination to

Chapter VIII of the GALL Report. This line-item has the 

same MEAP combination as A-72.

SP-58 Heat 

exchanger 

tubes

Copper 

alloy

Treated water Reduction of heat 

transfer/ fouling

Chapter XI.M2, 

“Water 

Chemistry”

The AMP is to 

be augmented 

by verifying the 

effectiveness of 

water chemistry 

control. See 

Chapter XI.M32, 

“One-Time 

Inspection,” for 

an acceptable 

verification 

program.

This row applies to heat exchangers in any system with 

treated water on either side of the tubes. The basis for 

this new line-item is similar to SP-40 except that the 

material is copper alloy instead of stainless steel. 

Copper alloy in a treated water environment exhibits the

same aging effect as stainless steel. AMP XI.M2

program provides an acceptable means of managing 

aging of these components with one-time inspection 

(AMP XI.M32) to provide a mitigative and verification 

method. The implementation of this augmented

program provides reasonable assurance that the 

component’s intended functions will be maintained 

within the CLB for the period of extended operation.
NUREG-1833 88 October 200

5

Table II.A New AMR Line-items based on new ‘MEAP’ combinations relevant to Mechanical Systems (“A” for Auxiliary, “E” for 

Engineered Safety Features, “R” for Reactor Coolant, and “S” for Steam and Power Conversion) 

Item

Structure 

and/or 

Component

Material Environment Aging Effect/ 

Mechanism AMP Precedent and Technical Basis for New Line-Item

SP-59 Piping, piping 

components, 

and piping 

elements

Steel Air – outdoor 

(Internal)

Loss of material/ 

general, pitting, 

and crevice 

corrosion

Chapter XI.M38, 

"Inspection of 

Internal 

Surfaces in 

Miscellaneous 

Piping and 

Ducting 

Components"

An approved precedent exists for adding this material, 

environment, aging effect, and program combination to

Chapter VIII of the GALL Report. This row was added to 

cover the interior surfaces of the main steam safety 

vents to the atmosphere downstream of the safety 

valves. This line-item is similar to other lines with the 

combination of steel, outdoor air, and loss of material, 

such as line-item A-24. AMP XI.M38 was developed to 

provide for proper management of the aging effects for 

this MEAP combination. This program provides an 

acceptable means of managing aging of these 

components. See Table IV for further discussion of the 

basis for this AMP. The implementation of this program 

provides reasonable assurance that the component’s 

intended functions will be maintained within the CLB for 

the period of extended operation.

SP-60 Piping, piping 

components, 

and piping 

elements

Steel Condensation 

(Internal)

Loss of material/ 

general, pitting, 

and crevice 

corrosion

Chapter XI.M38, 

"Inspection of 

Internal 

Surfaces in 

Miscellaneous 

Piping and 

Ducting 

Components"

An approved precedent exists for adding this material, 

environment, aging effect, and program combination to

Chapter VIII of the GALL Report. This row covers steam 

piping that is empty in standby condition during normal 

operations, such as AFW turbine steam lines during 

normal operation. This line-item is the same as A-23. 

AMP XI.M38 was developed to provide for proper 

management of the aging effects for this MEAP 

combination. This program provides an acceptable 

means of managing aging of these components. See 

Table IV for further discussion of the basis for this AMP. 

The implementation of this program provides 

reasonable assurance that the component’s intended 

functions will be maintained within the CLB for the 

period of extended operation.
October 2005 89 NUREG-1833

Table II.A New AMR Line-items based on new ‘MEAP’ combinations relevant to Mechanical Systems (“A” for Auxiliary, “E” for 

Engineered Safety Features, “R” for Reactor Coolant, and “S” for Steam and Power Conversion) 

Item

Structure 

and/or 

Component

Material Environment Aging Effect/ 

Mechanism AMP Precedent and Technical Basis for New Line-Item

SP-61 Piping, piping 

components, 

and piping 

elements

Copper 

alloy

Treated water Loss of material/ 

pitting and 

crevice corrosion

Chapter XI.M2, 

"Water 

Chemistry"

The AMP is to 

be augmented 

by verifying the 

effectiveness of 

water chemistry 

control. See 

Chapter XI.M32, 

“One-Time 

Inspection,” for 

an acceptable 

verification 

program.

An approved precedent exists for adding this material, 

environment, aging effect, and program combination to

Chapter VIII of the GALL Report. This new row is 

similar to new row AP-64. Implementation of AMP 

XI.M2, as augmented by AMP XI.M32, provides 

reasonable assurance that the component’s intended 

functions will be maintained within the CLB for the 

extended period of operation.
NUREG-1833 90 October 2005

This Page Intentionally Left Blank
October 2005 91 NUREG-1833

II.B New AMR Line-items related to Structural Systems

Table II.B presents the new AMR line-items that are based on new MEAP combinations applicable to structural systems.

Table II.B New AMR Line-items based on new ‘MEAP’ combinations relevant to Structures (“T” for “Structures and Component 

Supports” )

Item

Structure 

and/or 

Component

Material Environment Aging Effect/ 

Mechanism AMP Precedent and Technical Basis for New Line-Item

TP-1 Sliding support 

bearings and 

sliding support 

surfaces

Lubrite®, 

graphitic tool 

steel

Air – indoor 

uncontrolled

Loss of 

mechanical 

function/

Corrosion, 

distortion, dirt, 

overload, 

fatigue due to 

vibratory and 

cyclic thermal 

loads

Chapter XI.S6, 

“Structures 

Monitoring 

Program”

Similar to T-28. GALL Rev. 0 considered this MEA 

combination for ASME piping and component supports 

for Chapter III; items B1.1.3-a, B1.2.2-a, and B1.3.2-a. 

This line-item is needed to address these supports for 

non-ASME piping and components. Implementation of 

the Structures Monitoring Program adequately 

manages this aging effect by visual inspection.

TP-2 Sliding support 

bearings and 

sliding support 

surfaces

Lubrite®, 

graphitic tool 

steel

Air – outdoor Loss of 

mechanical 

function/

Corrosion, 

distortion, dirt, 

overload, 

fatigue due to 

vibratory and 

cyclic thermal 

loads

Chapter XI.S6, 

“Structures 

Monitoring 

Program”

Similar to T-28 and TP-1. The environment is more 

aggressive, outdoor vs. indoor uncontrolled. However 

the aging effect is the same. GALL Rev. 0 considered 

this MEA combination for ASME piping and component 

supports for Chapter III; items B1.1.3-a, B1.2.2-a, and 

B1.3.2-a. This line-item is needed to address these 

supports for non-ASME piping and components. 

Implementation of the Structures Monitoring Program 

adequately manages this aging effect by visual 

inspection.
NUREG-1833 92 October 200

5

Table II.B New AMR Line-items based on new ‘MEAP’ combinations relevant to Structures (“T” for “Structures and Component 

Supports” )

Item

Structure 

and/or 

Component

Material Environment Aging Effect/ 

Mechanism AMP Precedent and Technical Basis for New Line-Item

TP-3 Support 

members; 

welds; bolted 

connections; 

support 

anchorage to 

building 

structure

Galvanized 

steel,

aluminum

Air with 

borated water 

leakage

Loss of 

material/ boric 

acid corrosion

Chapter XI.M10, 

"Boric Acid 

Corrosion"

An approved precedent exists for adding this material, 

environment, aging effect and program combination to 

the GALL Report. As shown in RNP SER Section 

3.5.2.4.3.2, galvanized steel in a borated water 

environment could result in loss of material due to 

boric acid corrosion. Also, in Millstone SER section 

3.5B.2.3.36, galvanized steel and aluminum in a 

borated water environment could result in loss of 

material due to boric acid corrosion. Aggressive 

chemical attack causes localized corrosion as a result 

of leaks from borated water systems that can 

concentrate boric acid and lead to loss of material in 

galvanized steel and aluminum. Implementation of the 

boric acid corrosion program will adequately manage 

this aging effect. In the GALL Report Rev. 1 this item 

number was inadvertently applied to Table III.B1.3 

(BWR Containment Supports). Boric acid corrosion is 

not a concern for BWRs.

TP-4 Support 

members; 

welds; bolted 

connections; 

support 

anchorage to 

building 

structure

Stainless 

steel

Air with 

borated water 

leakage

None None An approved precedent exists for adding this material, 

environment, aging effect, and program combination to 

the GALL Report. As shown in Ginna SER Section 

3.2.2.4.1.2, stainless steel components and structures 

in an air with borated water leakage environment 

exhibit no aging effect and will therefore remain 

capable of performing their intended functions 

consistent with the CLB for the period of extended 

operation. This conclusion is based on the fact that 

stainless steel is not susceptible to general corrosion 

when subjected to borated water environments as 

cited in “PWR Primary Water Chemistry Guideline,” 

EPRI NP-7077, Revision 2, Project 2493, November 

1990.
October 2005 93 NUREG-1833

Table II.B New AMR Line-items based on new ‘MEAP’ combinations relevant to Structures (“T” for “Structures and Component 

Supports” )

Item

Structure 

and/or 

Component

Material Environment Aging Effect/ 

Mechanism AMP Precedent and Technical Basis for New Line-Item

TP-5 Support 

members; 

welds; bolted 

connections; 

support 

anchorage to 

building 

structure

Stainless 

steel

Air – indoor 

uncontrolled

None None An approved precedent exists for adding this material, 

environment, aging effect, and program combination to 

the GALL Report. As shown in RNP SER Section 

3.3.2.4.6.1, stainless steel components and structures 

in an indoor, uncontrolled air environment exhibit no 

aging effect and will therefore remain capable of 

performing their intended functions consistent with the 

CLB for the period of extended operation. Current 

industry research and operating experience also 

confirms that stainless steel in indoor air is not subject 

to aging effects that could be of concern during the 

period of extended operation. 

TP-6 Support 

members; 

welds; bolted 

connections; 

support 

anchorage to 

building 

structure

Galvanized 

steel, 

aluminum, 

stainless 

steel

Air – outdoor Loss of 

material/ pitting 

and crevice 

corrosion

Chapter XI.S6, 

“Structures 

Monitoring 

Program”

An approved precedent exists for adding this material, 

environment, aging effect, and program combination to 

the GALL Report. As shown in RNP SER Section 

3.5.2.4.3.2, galvanized steel and stainless steel in an 

outdoor air environment could result in loss of material 

due to constant wetting and drying conditions. 

Aluminum would also be susceptible to a similar kind 

of aging effect in the outdoor environment. 

Implementation of the Structures Monitoring Program 

adequately manages the aging effect by performing 

routine visual inspections of the surface of the 

structural components.

TP-7 Seals, gaskets, 

and moisture 

barriers 

(caulking, 

flashing, and 

other sealants)

Elastomers 

such as 

EPDM rubber

Various Loss of sealing/ 

deterioration of 

seals, gaskets, 

and moisture 

barriers 

(caulking, 

flashing, and 

other sealants)

Chapter XI.S6, 

“Structures 

Monitoring 

Program”

Similar to C-18. GALL Rev. 0 considered this MEA 

combination for Chapter II, item A3.3-a, and B4.3-a. 

This MEA combination was not included in Chapter III. 

Implementation of the Structures Monitoring Program 

adequately manages this aging effect, based on visual 

examination for deterioration of seals and gaskets.
NUREG-1833 94 October 200

5

Table II.B New AMR Line-items based on new ‘MEAP’ combinations relevant to Structures (“T” for “Structures and Component 

Supports” )

Item

Structure 

and/or 

Component

Material Environment Aging Effect/ 

Mechanism AMP Precedent and Technical Basis for New Line-Item

TP-8 Support 

members; 

welds; bolted 

connections; 

support 

anchorage to 

building 

structure

Aluminum Air – indoor 

uncontrolled

None None An approved precedent exists for adding this material, 

environment, aging effect, and program combination to 

the GALL Report. As shown in RNP SER Section 

3.3.2.4.5.1, aluminum components and structures in an 

indoor, uncontrolled air environment exhibit no aging 

effect and will therefore remain capable of performing 

their intended functions consistent with the CLB for the 

period of extended operation. Aluminum has an 

excellent resistance to corrosion. When exposed to 

humid air (uncontrolled indoor environment), the 

aluminum oxide film bonds strongly to the aluminum 

surface. If damaged, this film reforms immediately in 

most environments. On a surface freshly abraded and 

then exposed to air, the oxide film is only 5 to 10 

nanometers thick, but is highly effective in protecting 

the aluminum from corrosion. Therefore, aluminum 

exposed to indoor uncontrolled environment does not 

have any aging effect (Hollingsworth and Hunsicker 

1979).

TP-9 High strength 

bolting for 

NSSS 

component 

supports

Low alloy 

steel, yield 

strength 

>150 ksi

Air – indoor 

uncontrolled 

Loss of 

material/ 

general 

corrosion

Chapter XI.M18, 

“Bolting Integrity”

Loss of material is an applicable aging effect for this 

material/environment combination, similar to other 

bolting line-items, such as T-30, and the appropriate 

program is similar to T-27. This item was added to 

address the presence of high strength bolts, which are 

subject to this aging effect. AMP XI.M18 provides for 

proper management of the aging effects for this MEAP 

combination. Thus, implementation of this AMP 

provides reasonable assurance that the component’s 

intended functions will be maintained within the CLB 

for the period of extended operation.
October 2005 95 NUREG-1833

Table II.B New AMR Line-items based on new ‘MEAP’ combinations relevant to Structures (“T” for “Structures and Component 

Supports” )

Item

Structure 

and/or 

Component

Material Environment Aging Effect/ 

Mechanism AMP Precedent and Technical Basis for New Line-Item

TP-10 Support 

members; 

welds; bolted 

connections; 

support 

anchorage to 

building 

structure

Stainless 

steel, 

steel

Treated Water 

< 600C 

(<1400F) 

Loss of 

material/ 

general, pitting, 

and crevice 

corrosion

Chapter XI.M2, 

“Water Chemistry,” 

for BWR water, 

and Chapter XI.S3, 

“ASME Section XI, 

Subsection IWF”

An approved precedent exists for adding this material, 

environment, aging effect, and program combination to 

the GALL Report. As shown in D/QC SER Section 

3.5.2.4.5, loss of material could occur for stainless 

steel and steel component supports in a treated water 

environment due to wetting conditions. The Water 

Chemistry Program and the ASME Section XI, 

Subsection IWF program will provide the necessary 

preventive and detection capability to adequately 

manage this aging effect.

TP-11 Support 

members; 

welds; bolted 

connections; 

support 

anchorage to 

building 

structure

Galvanized 

steel

Air-indoor 

uncontrolled

None None An approved precedent exists for adding this material, 

environment, aging effect, and program combination to 

the GALL Report. As shown in RNP SER Section 

3.5.2.4.3.2, galvanized steel components and 

structures in an air-indoor uncontrolled environment 

exhibit no aging effect will therefore remain capable of 

performing their intended functions consistent with the 

CLB for the period of extended operation. The zinc 

coating in galvanized steel protects the underlying 

steel as cited in references such as J.R. Davis, 

Corrosion, 2000.
NUREG-1833 96 October 200

5

II.C New AMR Line-items related to Electrical Systems

Table II.C presents the new AMR line-items that are based on new MEAP combinations applicable to electrical systems.

Table II.C New AMR Line-items based on new ‘MEAP’ combinations relevant to Electrical Systems (“L” Electrical)

Item

Structure 

and/or 

Component

Material Environment Aging Effect/ 

Mechanism AMP Precedent and Technical Basis for New Line-Item

LP-01 Fuse Holders 

(Not Part of a 

Larger Assembly) 

Metallic Clamp

Copper alloy Air – indoor Fatigue /ohmic heating, 

thermal cycling, electrical 

transients, frequent 

manipulation, vibration, 

chemical contamination, 

corrosion, and oxidation

Chapter XI.E5, 

“Fuse Holder”

This line-item was added consistent 

with ISG-5. Additionally, an approved 

precedent exists for adding this 

material, environment, aging effect, 

and program combination to the GALL 

Report. As shown in VCS SER 

3.6.2.3.1, the Staff has accepted the 

position that copper alloys in an air 

environment for fuse holders exhibit 

fatigue and therefore require 

management by a program. 

Operating experience, as discussed in 

NUREG-1760, “Aging Assessment of 

Safety-Related Fuses Used in Lowand Medium-Voltage Applications in 

Nuclear Power Plants,” indicates that 

aging stressors such as vibration, 

thermal cycling, electrical transients, 

mechanical stress, fatigue, corrosion, 

chemical contamination, or oxidation of 

the connection surfaces can result in 

fuse holder failure. AMP XI.E5 was 

developed to provide for proper 

management of the aging effects for 

this MEAP combination. This program 

provides an acceptable means of 

managing aging of these components. 

See Table IV for further discussion of 

the basis for this AMP. The 

implementation of this program 
October 2005 97 NUREG-1833

Table II.C New AMR Line-items based on new ‘MEAP’ combinations relevant to Electrical Systems (“L” Electrical)

Item

Structure 

and/or 

Component

Material Environment Aging Effect/ 

Mechanism AMP Precedent and Technical Basis for New Line-Item

provides reasonable assurance that the 

component’s intended functions will be 

maintained within the CLB for the 

period of extended operation.

LP-02 Fuse Holders 

(Not Part of a 

Larger 

Assembly); 

Insulation

Insulation 

material –

bakelite, 

phenolic 

melamine or 

ceramic, molded 

polycarbonate 

and other

Air – indoor 

uncontrolled 

(Internal/ 

External)

None None This line-item was added consistent 

with ISG-5. An approved precedent 

exists for adding this material, 

environment, aging effect, and program 

combination to the GALL Report.

As shown in St. Lucie SER 3.6.2.1.4, 

the Staff has accepted the position that 

insulation material as used in fuse 

holders in a mild environment exhibits 

no aging effect and that the component 

or structure will therefore remain 

capable of performing its intended 

functions consistent with the CLB for 

the period of extended operation. 

A mild environment is below the 

threshold temperature and radiation 

dose level that are accepted as 

causing any degradation in these 

materials.
NUREG-1833 98 October 200

5

Table II.C New AMR Line-items based on new ‘MEAP’ combinations relevant to Electrical Systems (“L” Electrical)

Item

Structure 

and/or 

Component

Material Environment Aging Effect/ 

Mechanism AMP Precedent and Technical Basis for New Line-Item

LP-03 Fuse Holders 

(Not Part of a 

Larger 

Assembly); 

Insulation

Insulation 

material –

bakelite, 

phenolic 

melamine or 

ceramic, molded 

polycarbonate 

and other

Adverse 

localized 

environment 

caused by 

heat, radiation, 

or moisture in 

the presence 

of oxygen or > 

60-year 

service limiting 

temperature

Embrittlement, cracking, 

melting, discoloration, 

swelling, or loss of 

dielectric strength 

leading to reduced 

insulation resistance 

(IR); electrical failure/ 

degradation (Thermal/ 

thermoxidative) of 

organics/thermoplastics, 

radiation-induced 

oxidation, moisture 

intrusion and ohmic 

heating

Chapter XI.E1, 

“Electrical Cables 

and Connections 

Not Subject to 10 

CFR 50.49 

Environmental 

Qualification 

Requirements”

This line-item was added consistent 

with ISG-5. The Staff has determined 

that embrittlement, cracking, melting, 

discoloration, swelling, or loss of 

dielectric strength leading to reduced 

insulation resistance, and electrical 

failure are applicable aging effects for 

insulation material of fuse holders. 

GALL Rev. 0 considered this MEAP 

combination for Electrical Components 

Chapter VI, AMR line-item A.1-a. 

The "Electric Cables and Connections 

Not Subject to 10 CFR 50.49 

Environmental Qualification 

Requirements" AMP will adequately 

manage the aging effects based on the 

fact that the fuse block is similar to 

terminal blocks and visual inspection 

will be performed for fuse blocks 

located in adverse environment. 

Implementation of AMP XI.E1 provides 

reasonable assurance that the 

component’s intended functions will be 

maintained within the CLB for the 

extended period of operation.
October 2005 99 NUREG-1833

Table II.C New AMR Line-items based on new ‘MEAP’ combinations relevant to Electrical Systems (“L” Electrical)

Item

Structure 

and/or 

Component

Material Environment Aging Effect/ 

Mechanism AMP Precedent and Technical Basis for New Line-Item

LP-04 Metal enclosed 

bus 

Bus/connections

Aluminum / 

Silver Plated 

Aluminum 

Copper / Silver 

Plated Copper; 

Stainless steel, 

steel

Air – indoor 

and outdoor

Loosening of bolted 

connections/ thermal 

cycling and ohmic 

heating

Chapter XI.E4, 

"Metal Enclosed 

Bus"

An approved precedent exists for 

adding this material, environment, 

aging effect, and program combination

to the GALL Report. 

As shown in Ginna SER 3.6.2.4.4.2,

the Staff has accepted the position that 

loosening of fastener components 

(bolted bus connections) is a valid 

aging effect and therefore recommends

management by a program. NRC IN 

2000-14 identifies the phenomenon of 

“torque relaxation” of bus splice plate 

connecting bolts. 

AMP XI.E4 was developed to provide 

for proper management of the aging 

effects for this MEAP combination. This 

program provides an acceptable 

means of managing aging of these 

components. See Table IV for further 

discussion of the basis for this AMP. 

The implementation of this program 

provides reasonable assurance that the 

component’s intended functions will be 

maintained within the CLB for the 

period of extended operation. This item 

is based, in part, on the information 

contained in ISG-17. 
NUREG-1833 100 October 200

5

Table II.C New AMR Line-items based on new ‘MEAP’ combinations relevant to Electrical Systems (“L” Electrical)

Item

Structure 

and/or 

Component

Material Environment Aging Effect/ 

Mechanism AMP Precedent and Technical Basis for New Line-Item

LP-05 Metal enclosed 

bus Insulation/

insulators

Porcelain,

xenoy, thermoplastic organic 

polymers

Air – indoor 

and outdoor

Embrittlement, cracking, 

melting, discoloration, 

swelling, or loss of 

dielectric strength 

leading to reduced 

insulation resistance 

(IR); electrical failure/ 

thermal/thermoxidative 

degradation of 

organics/thermoplastics, 

radiation-induced 

oxidation; 

moisture/debris intrusion, 

and ohmic heating

Chapter XI.E4, 

"Metal Enclosed

Bus"

An approved precedent exists for 

adding this material, environment, 

aging effect, and program combination 

to the GALL Report. 

As shown in D/QC SER, section 

3.6.2.4.1, the Staff has accepted the 

position that porcelain, xenoy, or 

thermo-plastic organic polymers 

exposed to an air environment may be 

vulnerable to embrittlement, cracking, 

melting, discoloration, swelling, or loss 

of dielectric strength leading to reduced 

insulation resistance (IR); electrical 

failure and therefore require 

management by a program. 

NRC IN 89-64 also identified bus duct 

insulation problems. AMP XI.E4 was 

developed to provide for proper 

management of the aging effects for 

this MEAP combination. This program 

provides an acceptable means of 

managing aging of these components. 

See Table IV for further discussion of 

the basis for this AMP. The 

implementation of this program 

provides reasonable assurance that the 

component’s intended functions will be 

maintained within the CLB for the 

period of extended operation. This item 

is based, in part, on the information 

contained in ISG-17.
October 2005 101 NUREG-1833

Table II.C New AMR Line-items based on new ‘MEAP’ combinations relevant to Electrical Systems (“L” Electrical)

Item

Structure 

and/or 

Component

Material Environment Aging Effect/ 

Mechanism AMP Precedent and Technical Basis for New Line-Item

LP-06 Metal enclosed 

bus 

Enclosure 

assemblies

Steel;

galvanized steel

Air – indoor 

and outdoor

Loss of material/ general 

corrosion

Chapter XI.S6, 

“Structures 

Monitoring 

Program”

The Staff has determined that loss of 

material due to general corrosion is an 

applicable aging effect. An approved 

precedent exists for adding this 

material, environment, aging effect, 

and program combination to the GALL 

Report. 

As shown in RNP SER 3.5.2.4.3.2, the 

Staff has accepted the position that 

galvanized steel in an outdoor air 

environment results in loss of material 

due to constant wetting and drying 

conditions. 

GALL Rev. 0 addressed this material, 

environment, aging effect, and program 

combination in the Structures section III 

(item A1.2-a et.al. and B2.1-a et.al.)

The Structures Monitoring Program will 

adequately manage this aging effect by 

visual inspection for corrosion. This 

item is based, in part, on the 

information contained in ISG-17.
NUREG-1833 102 October 200

5

Table II.C New AMR Line-items based on new ‘MEAP’ combinations relevant to Electrical Systems (“L” Electrical)

Item

Structure 

and/or 

Component

Material Environment Aging Effect/ 

Mechanism AMP Precedent and Technical Basis for New Line-Item

LP-07 High voltage

insulators

Porcelain,

Malleable iron, 

aluminum, 

galvanized steel, 

cement

Air – outdoor Degradation of insulator 

quality/presence of any 

salt deposits or surface 

contamination

A plant-specific 

aging 

management 

program is to be 

evaluated for 

plants located 

such that the 

potential exists for 

salt deposits or 

surface 

contamination 

(e.g., in the vicinity 

of salt water 

bodies or industrial 

pollution). 

The Staff has determined that the 

degradation of insulator quality is an 

applicable aging effect. Information 

Notice IN 93-95 applicable to insulator 

contamination relates to loss of power 

due to salt build-up. 

Per St. Lucie SER, section 3.6.4.2.2, 

high-voltage insulators at St. Lucie are 

washed and coated with silicon to 

prevent salt buildup. 

Other LER precedents related to salt 

deposits and surface contamination as 

aging mechanisms causing 

degradation of insulator quality include: 

St Lucie – LER 94-007-0; Pilgrim –

LER 91-024-00; Pilgrim – 85-025-00. 

A plant-specific aging management 

program will be evaluat ed to provide 

reasonable assurance that the 

component’s intended functions will be 

maintained within the CLB for the 

period of extended operation.
October 2005 103 NUREG-1833

Table II.C New AMR Line-items based on new ‘MEAP’ combinations relevant to Electrical Systems (“L” Electrical)

Item

Structure 

and/or 

Component

Material Environment Aging Effect/ 

Mechanism AMP Precedent and Technical Basis for New Line-Item

LP-08 Transmission 

conductors and 

connections

Aluminum, steel Air – outdoor Loss of material/wind 

induced abrasion, fatigue

Loss of conductor 

strength/ corrosion

Increased resistance of 

connection/ oxidation or 

loss of pre-load

A plant-specific 

aging 

management 

program is to be 

evaluated

The Staff has determined that the loss 

of material, loss of conductor strength,

and increased resistance of 

connections are applicable aging 

effects. The most prevalent mechanism 

contributing to loss of conductor 

strength of aluminum-core steelreinforced (ACSR) conductors is 

corrosion. For ACSR conductors, 

degradation begins as a loss of zinc 

from galvanized steel wire cores and 

depends largely on air quality. Loss of 

material due to wear could be caused 

by vibration and sway caused by wind 

loading. Loss of pre-load could be 

caused because aluminum conductor 

material expands faster than most 

bolting material. If plastic deformation 

occurs during thermal loading (i.e., 

heatup) when the connection cools, the 

joint will be loose. 

In the FCS SER, section 3.6.2.4.3, a 

plant-specific program is provided to 

manage these aging effects. 

A plant-specific aging management 

program will be evaluated to provide 

reasonable assurance that the 

component’s intended functions will be 

maintained within the CLB for the 

period of extended operation.
NUREG-1833 104 October 200

5

Table II.C New AMR Line-items based on new ‘MEAP’ combinations relevant to Electrical Systems (“L” Electrical)

Item

Structure 

and/or 

Component

Material Environment Aging Effect/ 

Mechanism AMP Precedent and Technical Basis for New Line-Item

LP-09 Switchyard bus 

and connections

Aluminum, 

copper, bronze, 

stainless steel, 

galvanized steel

Air – outdoor Loss of material/wind 

induced abrasion, fatigue

Loss of conductor 

strength/ corrosion

Increased resistance of 

connection/ oxidation or 

loss of pre-load

A plant-specific 

aging 

management 

program is to be 

evaluated

The Staff has determined that the loss 

of material, loss of conductor strength,

and increased resistance of 

connections are applicable aging 

effects. In both the Ginna SER section 

3.6.2.4.5.2 and the FCS SER section 

3.6.2.4.3, the Staff accepted the 

position that loss of pre-load is a valid 

aging mechanism that could cause 

torque relaxation and thereby 

increased resistance of connection. 

In the FCS SER, 3.6.2.4.3, a plantspecific program is provided to manage 

these aging effects. 

A plant-specific aging management 

program will be evaluated to provide 

reasonable assurance that the 

component’s intended functions will be 

maintained within the CLB for the 

period of extended operation.
October 2005 105 NUREG-1833

Table II.C New AMR Line-items based on new ‘MEAP’ combinations relevant to Electrical Systems (“L” Electrical)

Item

Structure 

and/or 

Component

Material Environment Aging Effect/ 

Mechanism AMP Precedent and Technical Basis for New Line-Item

LP-10 Metal enclosed 

bus 

Enclosure 

assemblies

Elastomers Air – indoor 

and outdoor

Hardening and loss of 

strength/ elastomers 

degradation

Chapter XI.S6, 

“Structures 

Monitoring 

Program”

The Staff has determined that the 

hardening and loss of strength are 

applicable aging effects. 

Hardening and loss of strength 

exhibited by elastomers in an air 

environment is properly managed by 

the Structures Monitoring AMP based 

on inspection for degradation of 

elastomers surface. 

GALL Rev. 0 included this MEA 

combination in section V, item B.1-b; 

and also in section VII, items F1.1-b, et 

al. Implementation of AMP XI.S6

provides reasonable assurance that the 

component’s intended functions will be 

maintained within the CLB for the 

period of extended operation. 

This item is based, in part, on the 

information contained in ISG-17.
NUREG-1833 106 October 200

5

Table II.C New AMR Line-items based on new ‘MEAP’ combinations relevant to Electrical Systems (“L” Electrical)

Item

Structure 

and/or 

Component

Material Environment Aging Effect/ 

Mechanism AMP Precedent and Technical Basis for New Line-Item

LP-11 High voltage 

insulators

Porcelain,

Malleable iron, 

aluminum, 

galvanized steel, 

cement

Air – outdoor Loss of material/ 

mechanical wear due to 

wind blowing on 

transmission conductors

A plant-specific 

aging 

management 

program is to be 

evaluated

The Staff has determined that loss of 

material is the applicable aging effect. 

Mechanical wear due to wind blowing 

on transmission conductors is an aging 

mechanism for strain and suspension 

insulators in that they are subject to 

movement. 

Movement can be caused by wind 

blowing the supported transmission 

conductor, causing it to swing from side 

to side. If this swinging is frequent 

enough, it could cause wear in the 

metal contact points of the insulator 

string and between the insulator and 

the supporting hardware. 

A plant-specific aging management 

program will be evaluated to provide 

reasonable assurance that the 

component’s intended functions will be 

maintained within the CLB for the 

period of extended operation.
October 2005 107 NUREG-1833

Table II.C New AMR Line-items based on new ‘MEAP’ combinations relevant to Electrical Systems (“L” Electrical)

Item

Structure 

and/or 

Component

Material Environment Aging Effect/ 

Mechanism AMP Precedent and Technical Basis for New Line-Item

LP-12 Cable 

Connections 

(Metallic Parts)

Various metals 

used for 

electrical 

contacts

Air – indoor 

and outdoor

Loosening of bolted 

connections due to 

thermal cycling, ohmic 

heating, electrical 

transients, vibration, 

chemical contamination, 

corrosion, and oxidation

Chapter XI.E6, 

"Electrical 

Connections Not 

Subject to 10 CFR 

50.49 

Environmental 

Qualification 

Requirements"

This item is included in the GALL 

Report to address the metallic portion 

of connections (similar to fuse holder). 

SAND 96-0344, “Aging Management 

Guidelines For Electrical Cable and 

Terminations,” identified loosened 

terminations at several plants. 

Additionally, EPRI TR -104213 

recommends inspection of bolted joints 

for evidence of overheating, signs of 

burning or discoloration, and indication 

of loose bolts. It recommends checking 

the joint resistance of bolted joints 

using a low range ohmmeter. 

AMP XI.E6 was developed to provide 

for proper management of the aging 

effects for this MEAP combination. This 

program provides an acceptable 

means of managing aging of these 

components. See Table IV for further 

discussion of the basis for this AMP. 

The implementation of this program 

provides reasonable assurance that the 

component’s intended functions will be 

maintained within the CLB for the 

period of extended operation.
NUREG-1833 108 October 2005

This Page Intentionally Left Blank
October 2005 109 NUREG-1833

III. Changes to Existing Aging Management Review Line-Items

The following tables identify “significant changes” that were made to the MEAP line-items in the 

tables in Chapters II through VIII of Volume 2 to NUREG-1801. A change was deemed 

“significant” if it involved a technical change to an aging effect, an Aging Management Program 

(AMP), or a change to the “Further Evaluation” column. Editorial changes were not deemed 

significant. Examples of editorial changes include, but are not limited to, the following:

• “Crack initiation and growth/ stress corrosion cracking” was replaced with “Cracking/ stress 

corrosion cracking”

• Deleted the reference to the EPRI document in the AMP column for AMP XI.M2, “”Water 

Chemistry.” The reference to the specific EPRI document does not need to be included in 

the Aging Management Program column. This information is identified in the AMP 

description in Chapter XI of the GALL Report.

The following tables identify the Item Number in the revised GALL (GALL Rev. 1), the GALL 

Rev. 0 MEAP Item Number, the material, environment, aging effect/ mechanism, the AMP, the 

further evaluation recommended, and the basis for the change. Changes in each table row are 

identified by bold, italics. Also, in some cases, aging effects/mechanisms originally presented in 

GALL Rev. 0 were encompassed by other aging effects/mechanisms and; therefore, these 

changes were not deemed significant. For example, loss of material/flow accelerated corrosion 

was replaced with wall thinning/flow accelerated corrosion. As noted in Appendix A to this 

Bases Document, wall thinning is defined as a loss of material due to flow-accelerated 

corrosion.

Additionally, in cases where a change affected multiple AMR lines items, these line-items are 

shown in one row in their respective table. For example, line-items E-35, E-44, and E-46, the 

only change was to revise their AMPs to Chapter XI.M36, "External Surfaces Monitoring.” For 

simplicity, these line-items are shown in one row in Table III.D even though these line-items 

have different environments.

It should be noted that the process used to develop these tables leaves the cells in a column 

blank if the entry would duplicate the entry in the row above. Therefore, to determine the value 

that applies where a cell is blank, the reader must scan back up the column to the previous nonblank cell. Similarly, if one or more cells do not have a lower border when the table spans a 

page, the absence of this border indicates the continuation of the cell’s value onto the following 

page.

Finally, a new section B1.2 was added in Chapter II, Containment Structures, to address Mark I 

concrete containment structures, which was not previously included in NUREG-1801, Volume 2, 

July 2001. No new rows beyond those that already existed in Chapter II were required to be 

added. The existing rows included in new section B1.2 are C-06, C-07, C-23, C-31, C-35, C-39,

and C-41.
NUREG-1833 110 October 200

5

III.A Containment Structures

Table III.A presents the changes made to existing AMR line-items for containment structures.

IIIA. Changes in Existing AMR Line-Items for Containment Structures (Chapter II in GALL Vol. 2)

Item

Structures 

and/or 

Components

GALL 

Rev. 0

Item 

Number

Material Environment Aging Effect/ 

Mechanism

Aging Management 

Program

Further 

Evaluation

Recommended

Basis for Change

C-01 Concrete 

Dome; wall; 

basemat; ring 

girder; 

buttresses

II.A1.1-a Concrete Air-outdoor Loss of material 

(spalling, 

scaling) and 

cracking/ freezethaw

Chapter XI.S2, “ASME 

Section XI, Subsection 

IWL” 

Accessible areas: 

Inspections performed in 

accordance with IWL will 

indicate the presence of 

loss of material (spalling, 

scaling) and cracking due 

to freeze-thaw.

Inaccessible Areas:

Evaluation is needed for 

plants that are located in 

moderate to severe 

weathering conditions 

(weathering index >100 

day-inch/yr) (NUREG1557). Documented 

evidence confirms that 

where the existing 

concrete had air content 

of 3% to 6%, subsequent 

inspection did not exhibit 

degradation related to 

freeze-thaw. Such 

inspections should be 

considered a part of the 

Yes, for 

inaccessible 

areas of plants 

located in 

moderate to 

severe 

weathering 

conditions

The AMP column was 

revised to clearly 

address concrete in 

accessible and 

inaccessible areas. 

The basis for this 

revision was the 

approved ISG-3. 

Documented evidence 

exists in NUREG-1557 

that based on initial 

and subsequent 

inspections of 

concrete that had air 

content of 3% to 6%, 

these inspections did 

not show any 

degradation related to 

freeze thaw.

The environment was 

revised to air-outdoor 

instead of outside 

containment to better 

reflect the actual 

environment. 

The FE column was 

revised to clarify the 

conditions where 
October 2005 111 NUREG-1833

IIIA. Changes in Existing AMR Line-Items for Containment Structures (Chapter II in GALL Vol. 2)

Item

Structures 

and/or 

Components

GALL 

Rev. 0

Item 

Number

Material Environment Aging Effect/ 

Mechanism

Aging Management 

Program

Further 

Evaluation

Recommended

Basis for Change

evaluation.

The weathering index for 

the continental US is 

shown in ASTM C33-90, 

Fig. 1.

further evaluation is 

required for plants 

located in moderate to 

severe weathering 

conditions. If the 

applicant meets the 

conditions specified in 

the AMP column for 

inaccessible areas, 

then no specific AMP 

is necessary to 

manage this aging 

effect. However, 

opportunistic 

inspections are 

recommended.

C-02 Concrete 

Dome; wall; 

basemat; ring 

girder; 

buttresses

II.A1.1-b Concrete Water -

flowing

Increase in 

porosity, 

permeability/

leaching of 

calcium 

hydroxide

Chapter XI.S2, “ASME 

Section XI, Subsection 

IWL”

Accessible areas:

Inspections performed in 

accordance with IWL will 

indicate the presence of 

increase in porosity, and 

permeability due to

leaching of calcium 

hydroxide.

Inaccessible Areas:

An aging management 

program is not necessary, 

even if reinforced 

concrete is exposed to 

Yes, if concrete 

was not 

constructed as 

stated for 

inaccessible 

areas

The AMP column was 

revised to clearly 

address concrete in 

accessible and 

inaccessible areas. 

The basis for this 

revision was the

approved ISG-3. 

Documented evidence 

exists in NUREG1557, that leaching is 

not significant if the 

concrete is 

constructed to ensure 

that it is dense, wellcured, has low 

permeability, and that 

cracking is well 
NUREG-1833 112 October 200

5

IIIA. Changes in Existing AMR Line-Items for Containment Structures (Chapter II in GALL Vol. 2)

Item

Structures 

and/or 

Components

GALL 

Rev. 0

Item 

Number

Material Environment Aging Effect/ 

Mechanism

Aging Management 

Program

Further 

Evaluation

Recommended

Basis for Change

flowing water, if there is 

documented evidence that

confirms the in-place 

concrete was constructed 

in accordance with the 

recommendations in ACI

201.2R.

controlled. Cracking is 

controlled through 

proper arrangement 

and distribution of 

reinforcing bars. All of 

the above 

characteristics are 

assured if the concrete 

was constructed in 

accordance with 

ACI 201.2R-77 or later 

revisions.

The FE column was 

revised to clarify the 

conditions where 

further evaluation is 

recommended.

C-03 Concrete 

Dome; wall; 

basemat; ring 

girder; 

buttresses

II.A1.1-c Concrete Ground 

water/soil or 

air –indoor 

uncontrolled 

or air -

outdoor

Increase in 

porosity and 

permeability, 

cracking, loss of 

material 

(spalling, 

scaling)/

aggressive 

chemical attack

Chapter XI.S2, “ASME 

Section XI, Subsection 

IWL.”

Accessible Areas:

Inspections performed in 

accordance with IWL will 

indicate the presence of 

increase in porosity and 

permeability, cracking, or 

loss of material (spalling, 

scaling) due to aggressive 

chemical attack.

Inaccessible Areas:

For plants with nonYes, plant 

specific if 

environment is 

aggressive

The AMP column was 

revised to clearly 

address concrete in 

accessible and 

inaccessible areas. 

The basis for this 

revision was the 

approved ISG-3. The 

environment was 

revised to reflect the 

actual environment. 

The FE column was 

revised to make it 

consistent with other 

lines where a plantspecific program is 
October 2005 113 NUREG-1833

IIIA. Changes in Existing AMR Line-Items for Containment Structures (Chapter II in GALL Vol. 2)

Item

Structures 

and/or 

Components

GALL 

Rev. 0

Item 

Number

Material Environment Aging Effect/ 

Mechanism

Aging Management 

Program

Further 

Evaluation

Recommended

Basis for Change

aggressive ground 

water/soil; i.e. pH > 5.5, 

chlorides < 500 ppm, or 

sulfates <1500 ppm, as a 

minimum, consider (1) 

Examination of the 

exposed portions of the 

below grade concrete, 

when excavated for any 

reason, and (2) Periodic 

monitoring of below-grade 

water chemistry, including 

consideration of potential 

seasonal variations. For 

plants with aggressive 

groundwater/soil, and/or 

where the concrete 

structural elements have 

experienced degradation, 

a plant specific AMP 

accounting for the extent 

of the degradation 

experienced should be 

implemented to manage 

the concrete aging during 

the period of extended 

operation.

called out.

C-04 Concrete: 

Dome; wall; 

basemat; ring 

girders; 

buttresses

II.A1.1-d Concrete Any Cracking due 

to expansion/ 

reaction with 

aggregates

Chapter XI.S2, “ASME 

Section XI, Subsection IWL.”

Accessible Areas:

Inspections performed in 

accordance with IWL will 

indicate the presence of 

Yes, if concrete 

was not 

constructed as 

stated for 

inaccessible 

areas

The AMP column was 

revised to clearly 

address concrete in 

accessible and 

inaccessible areas. 

The basis for this 

revision was the 
NUREG-1833 114 October 200

5

IIIA. Changes in Existing AMR Line-Items for Containment Structures (Chapter II in GALL Vol. 2)

Item

Structures 

and/or 

Components

GALL 

Rev. 0

Item 

Number

Material Environment Aging Effect/ 

Mechanism

Aging Management 

Program

Further 

Evaluation

Recommended

Basis for Change

cracking due to reaction 

with aggregates.

Inaccessible Areas:

 As described in NUREG1557, investigations, tests, 

and petrographic 

examinations of aggregates 

performed in accordance 

with ASTM C295-54 or 

ASTM C227-50 can 

demonstrate that those 

aggregates do not react 

within reinforced concrete. 

For potentially reactive 

aggregates, aggregatereinforced concrete reaction 

is not significant if the

concrete was constructed in 

accordance with ACI 

201.2R. 

Therefore, if these 

conditions are satisfied, 

aging management is not 

necessary.

approved ISG-3. The 

environment was 

revised to “any” since 

the aging effect could 

occur in any 

environment – more 

dependent on 

aggregates than 

environment. The FE 

column was revised to 

clarify the conditions 

where further 

evaluation is 

recommended.

Use of ACI 201.2R-77 

or later revisions is 

acceptable.

C-05 Concrete: 

Dome; wall; 

basemat; ring 

girders; 

buttresses; 

reinforcing 

steel

II.A1.1-e Concrete, 

steel

Air-indoor 

uncontrolled 

or air-outdoor

Cracking, loss of 

bond, and loss 

of material 

(spalling, 

scaling)/ 

corrosion of 

embedded steel

Chapter XI.S2, “ASME 

Section XI, Subsection 

IWL.”

Accessible Areas: 

Inspections performed in 

accordance with IWL will 

indicate the presence of 

Yes, if 

environment is 

aggressive

The AMP column was 

revised to clearly 

address concrete in 

accessible and 

inaccessible areas. 

The basis for this 

revision was the 

approved ISG-3. The 
October 2005 11

5 NUREG-1833

IIIA. Changes in Existing AMR Line-Items for Containment Structures (Chapter II in GALL Vol. 2)

Item

Structures 

and/or 

Components

GALL 

Rev. 0

Item 

Number

Material Environment Aging Effect/ 

Mechanism

Aging Management 

Program

Further 

Evaluation

Recommended

Basis for Change

cracking, loss of bond, 

and loss of material 

(spalling, scaling) due to 

aggressive chemical 

attack.

Inaccessible Areas: 

 For plants with nonaggressive ground 

water/soil; i.e. pH > 5.5, 

chlorides < 500 ppm, or 

sulfates <1500 ppm, as a 

minimum, consider (1) 

Examination of the 

exposed portions of the 

below grade concrete, 

when excavated for any 

reason, and (2) Periodic 

monitoring of below-grade 

water chemistry, including 

consideration of potential 

seasonal variations. For 

plants with aggressive 

groundwater/soil, and/or 

where the concrete 

structural elements have 

experienced degradation, 

a plant specific AMP 

accounting for the extent 

of the degradation 

experienced should be 

implemented to manage 

the concrete aging during 

the period of extended 

environment was 

revised to air-indoor 

uncontrolled or airoutdoor instead of 

inside or outside 

containment to better 

reflect the actual 

environment. The FE 

column was revised to 

clarify the conditions 

where further 

evaluation is 

recommended.
NUREG-1833 116 October 200

5

IIIA. Changes in Existing AMR Line-Items for Containment Structures (Chapter II in GALL Vol. 2)

Item

Structures 

and/or 

Components

GALL 

Rev. 0

Item 

Number

Material Environment Aging Effect/ 

Mechanism

Aging Management 

Program

Further 

Evaluation

Recommended

Basis for Change

operation.

C-06 Concrete 

elements:

All

II.B2.2.1-e 

II.B3.2.1-f

Concrete Soil Cracks and 

distortion due to 

increased stress 

levels from 

settlement

Chapter XI.S6, “Structures 

Monitoring Program.” If a 

de-watering system is relied 

upon for control of 

settlement, then the licensee 

is to ensure proper 

functioning of the dewatering system through the

period of extended 

operation.

Yes, if not 

within the 

scope of the 

applicant’s 

structures 

monitoring 

program or a 

de-watering 

system is 

relied upon

The AMP column was 

revised to delete 

reference to initial 

licensing basis for 

settlement and the 

NRC approval to 

delete the program. 

The FE column was 

revised to clarify the 

conditions where 

further evaluation is 

recommended.

C-07 Concrete:

foundation; 

subfoundation

II.A1.1-g 

II.A2.2-g 

II.B2.2.1-f 

II.B3.1.2-f 

II.B3.2.1-g

Concrete:

porous 

concrete

Water-flowing Reduction in 

foundation 

strength, 

cracking, 

differential 

settlement/ 

erosion of 

porous concrete 

subfoundation

Chapter XI.S6, “Structures 

Monitoring Program”

Erosion of cement from 

porous concrete 

subfoundations beneath 

containment basemats is 

described in NRC IN 97-11. 

IN 98-26 proposes 

Maintenance Rule 

Structures Monitoring for 

managing this aging effect, if 

applicable. If a de-watering 

Yes, if not 

within the 

scope of the 

applicant’s 

structures 

monitoring 

program or a 

de-watering 

system is 

relied upon

The FE column was 

revised to clarify the 

conditions where 

further evaluation is 

recommended.
October 2005 117 NUREG-1833

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and/or 

Components

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Item 

Number

Material Environment Aging Effect/ 

Mechanism

Aging Management 

Program

Further 

Evaluation

Recommended

Basis for Change

system is relied upon for 

control of erosion of cement 

from porous concrete 

subfoundations, then the 

licensee is to ensure proper 

functioning of the dewatering system through the 

period of extended 

operation.

C-08 Concrete:

Dome, wall, 

basemat, ring 

girder, 

buttress

II.A1-1h Concrete Air-indoor 

uncontrolled 

or air-outdoor

Reduction of 

strength and 

modulus/ 

elevated 

temperature 

(>150°F 

general; >200°F 

local)

Plant-specific aging 

management program. The 

implementation of 

10 CFR 50.55a and ASME 

Section XI, Subsection IWL 

would not be able to identify 

the reduction of strength and 

modulus of elasticity due to 

elevated temperature. Thus, 

for any portions of concrete 

containment that exceed 

specified temperature limits, 

further evaluations are 

warranted. Subsection CC3400 of ASME Section III, 

Division 2, specifies the 

concrete temperature limits 

for normal operation or any 

other long-term period. The 

temperatures shall not 

exceed 150°F except for 

local areas, such as around 

penetrations, which are not 

allowed to exceed 200°F. If 

significant equipment loads 

Yes, if 

temperature 

limits are 

exceeded

The FE column was 

revised to clarify the 

conditions where 

further evaluation is 

recommended. If the 

temperatures as 

shown in the AMP 

column are not 

exceeded, then a plant 

specific program is not 

necessary.
NUREG-1833 118 October 200

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and/or 

Components

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Item 

Number

Material Environment Aging Effect/ 

Mechanism

Aging Management 

Program

Further 

Evaluation

Recommended

Basis for Change

are supported by concrete at 

temperatures exceeding 

150°F, an evaluation of the 

ability to withstand the 

postulated design loads is to 

be made. Higher 

temperatures than given 

above may be allowed in the 

concrete if tests and/or 

calculations are provided to 

evaluate the reduction in 

strength and this reduction 

is applied to the design 

allowables.

C-12 Penetration 

sleeves

II.A3.1-a

II.B4.1-a

Steel;

Dissimilar 

metal 

welds

Air-indoor 

uncontrolled 

or air-outdoor

Loss of 

material/general, 

pitting, and 

crevice 

corrosion

Chapter XI.S1, “ASME 

Section XI, Subsection 

IWE,” (Note: IWE 

examination category E-F, 

surface examination of 

dissimilar metal welds, is 

recommended) and 

Chapter XI.S4, “10 CFR 

Part 50, Appendix J.” 

No A note was added to 

the AMP column 

because NUREG1667 specifically 

recommended this 

examination. Also, 

removed mentioning of 

the relief request for 

coatings program. 

Relief requests 

associated with ISI are 

usually plant-specific 

and only valid during 

the 10-year ISI 

program. They are not 

considered for license 

renewal, in general, 

and therefore the 

mentioning of the relief 

request was removed.
October 2005 119 NUREG-1833

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and/or 

Components

GALL 

Rev. 0

Item 

Number

Material Environment Aging Effect/ 

Mechanism

Aging Management 

Program

Further 

Evaluation

Recommended

Basis for Change

C-16 Personnel 

airlock, 

equipment 

hatch, CRD 

hatch

II.A3.2-a 

II.B4.2-a

Steel Air-indoor 

uncontrolled 

or air-outdoor

Loss of 

material/general, 

pitting, and 

crevice 

corrosion

Chapter XI.S1, “ASME 

Section XI, Subsection 

IWE,” and Chapter XI.S4, 

“10 CFR Part 50, Appendix 

J.”

No In the AMP column, 

removed mentioning of 

the relief request for 

coatings program. 

Relief requests 

associated with ISI are 

usually plant-specific 

and only valid during 

the 10-year ISI 

program. They are not 

considered for license 

renewal, in general, 

and therefore the 

mentioning of the relief 

request was removed.

C-19 Steel 

elements: 

Drywell; 

torus; drywell 

head; 

embedded 

shell and 

sand pocket 

regions; 

drywell 

support skirt; 

torus ring 

girder; 

downcomers; 

ECCS suction 

header 

NOTE: 

Inspection of 

containment 

II.B1.1.1-a 

II.B3.1.1-a

Steel Air – indoor 

uncontrolled 

or treated 

water (as 

applicable)

Loss of material/ 

general, pitting, 

and crevice 

corrosion

Chapter XI.S1, “ASME 

Section XI, Subsection 

IWE.” For inaccessible 

areas (embedded 

containment steel shell or 

liner), loss of material due 

to corrosion is not 

significant if the following 

conditions are satisfied: 

Concrete meeting the 

specifications of ACI 318 

or 349 and the guidance of 

201.2R was used for the 

containment concrete in 

contact with the 

embedded containment 

shell or liner. The concrete 

is monitored to ensure 

that it is free of 

Yes, if corrosion 

is significant for 

inaccessible 

areas

In the AMP column, 

removed mentioning of 

the relief request for 

coatings program.

Relief requests 

associated with ISI are 

usually plant-specific 

and only valid during 

the 10-year ISI 

program. They are not 

considered for license 

renewal, in general, 

and therefore the 

mentioning of the relief 

request was removed.
NUREG-1833 120 October 200

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and/or 

Components

GALL 

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Item 

Number

Material Environment Aging Effect/ 

Mechanism

Aging Management 

Program

Further 

Evaluation

Recommended

Basis for Change

supports is

addressed by 

ASME 

Section XI, 

Subsection 

IWF (see 

III.B1.3)

penetrating cracks that 

provide a path for water 

seepage to the surface of 

the containment shell or 

liner. The moisture barrier, 

at the junction where the 

shell or liner becomes 

embedded, is subject to 

aging management 

activities in accordance 

with ASME Section XI, 

Subsection IWE 

requirements. Water 

ponding on the 

containment concrete 

floor are not common and 

when detected are cleaned 

up in a timely manner.

 If any of the above 

conditions cannot be 

satisfied, then a plantspecific aging 

management program for 

corrosion is necessary. 

Chapter XI.S4, “10 CFR 

Part 50, Appendix J”

No

C-22 Steel 

elements:

Vent line 

bellows

II.B1.1.1-d Stainless 

steel 

Air-indoor 

uncontrolled

Cracking/stress 

corrosion 

cracking

Chapter XI.S1, “ASME 

Section XI, Subsection IWE 

“ and Chapter XI.S4, 

“10 CFR Part 50, Appendix 

J” 

Yes, detection 

of aging effects 

is to be 

evaluated

Identified the specific 

edition of the ASME 

Code in the AMP 

column, which 

includes the 

referenced IWE 
October 2005 121 NUREG-1833

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and/or 

Components

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Rev. 0

Item 

Number

Material Environment Aging Effect/ 

Mechanism

Aging Management 

Program

Further 

Evaluation

Recommended

Basis for Change

Evaluation of 

10 CFR 50.55a/IWE is 

augmented as follows:

(4) Detection of Aging 

Effects: Stress corrosion 

cracking (SCC) is a concern 

for dissimilar metal welds. In 

the case of bellows 

assemblies, SCC may 

cause aging effects 

particularly if the material is 

not shielded from a 

corrosive environment. 

ASME Code 1995 edition, 

with addenda through 

1996, Subsection IWE 

covers inspection of these 

items under Examination 

Categories E-B, E-F, and EP (10 CFR Part 50, 

Appendix J pressure tests). 

10 CFR 50.55a identifies 

examination categories E-B 

and E-F as optional during 

the current term of 

operation. For the extended 

period of operation, 

Examination Categories E-B 

and E-F, and additional 

appropriate examinations to 

detect SCC in bellows 

assemblies and dissimilar 

metal welds are warranted 

to address this issue.

Examination 

Categories that are no 

longer identified in the 

current versions of the 

code.
NUREG-1833 122 October 200

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and/or 

Components

GALL 

Rev. 0

Item 

Number

Material Environment Aging Effect/ 

Mechanism

Aging Management 

Program

Further 

Evaluation

Recommended

Basis for Change

(10) Operating Experience: 

IN 92-20 describes an 

instance of containment 

bellows cracking, resulting in 

loss of leak tightness.

C-25 Concrete:

Basemat

II.A2.2-c 

II.B.3.1.2-

b

Concrete Ground 

water/soil

Increase in 

porosity and 

permeability, 

cracking, loss of 

material 

(spalling, 

scaling)/

aggressive 

chemical attack

Chapter XI.S2, “ASME 

Section XI, Subsection 

IWL.”

Accessible Areas:

Inspections performed in 

accordance with IWL will 

indicate the presence of 

increase in porosity and 

permeability, cracking, or 

loss of material (spalling, 

scaling) due to aggressive 

chemical attack.

Inaccessible Areas:

For plants with nonaggressive ground 

water/soil; i.e. pH > 5.5, 

chlorides < 500 ppm, or 

sulfates <1500 ppm, as a 

minimum, consider (1) 

Examination of the 

exposed portions of the 

below grade concrete, 

when excavated for any 

reason, and (2) Periodic 

monitoring of below-grade 

water chemistry, including 

consideration of potential 

seasonal variations. For 

Yes, plant 

specific if 

environment is 

aggressive

The AMP column was 

revised to clearly 

address concrete in 

accessible and 

inaccessible areas. 

The basis for this 

revision was the 

approved ISG-3. The 

environment was 

revised to reflect the 

actual environment. 

The FE column was 

revised to make it 

consistent with other 

lines where a plantspecific program is 

called out.
October 2005 123 NUREG-1833

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and/or 

Components

GALL 

Rev. 0

Item 

Number

Material Environment Aging Effect/ 

Mechanism

Aging Management 

Program

Further 

Evaluation

Recommended

Basis for Change

plants with aggressive 

groundwater/soil, and/or 

where the concrete 

structural elements have 

experienced degradation, 

a plant specific AMP 

accounting for the extent 

of the degradation 

experienced should be 

implemented to manage 

the concrete aging during 

the period of extended 

operation.

C-26 Concrete:

Containment, 

wall, basemat

II.B2.2.1-b

II.B1.2.

Concrete Ground 

water/soil

Increase in 

porosity and 

permeability, 

cracking, loss of 

material 

(spalling, 

scaling)/

aggressive 

chemical attack

Chapter XI.S2, “ASME 

Section XI, Subsection 

IWL.”

Accessible Areas:

Inspections performed in 

accordance with IWL will 

indicate the presence of 

increase in porosity and 

permeability, cracking, or 

loss of material (spalling, 

scaling) due to aggressive 

chemical attack.

Inaccessible Areas:

For plants with nonaggressive ground 

water/soil; i.e. pH > 5.5, 

chlorides < 500 ppm, or 

sulfates <1500 ppm, as a 

minimum, consider (1) 

Examination of the 

exposed portions of the 

Yes, plant 

specific if 

environment is 

aggressive

The AMP column was 

revised to clearly 

address concrete in 

accessible and 

inaccessible areas. 

The basis for this 

revision was the 

approved ISG-3. The 

envi ronment was 

revised to reflect the 

actual environment.

The FE column was 

revised to make it 

consistent with other 

lines where plantspecific program is 

called out.
NUREG-1833 124 October 200

5

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and/or 

Components

GALL 

Rev. 0

Item 

Number

Material Environment Aging Effect/ 

Mechanism

Aging Management 

Program

Further 

Evaluation

Recommended

Basis for Change

below grade concrete, 

when excavated for any 

reason, and (2) Periodic 

monitoring of below-grade 

water chemistry, including 

consideration of potential 

seasonal variations. For 

plants with aggressive 

groundwater/soil, and/or 

where the concrete 

structural elements have 

experienced degradation, 

a plant specific AMP 

accounting for the extent 

of the degradation 

experienced should be 

implemented to manage 

the concrete aging during 

the period of extended 

operation.

C-27 Concrete:

Dome, wall, 

basemat

II.B3.2.1-c Concrete Ground 

water/soil

Increase in 

porosity and 

permeability, 

cracking, loss of 

material 

(spalling, 

scaling)/

aggressive 

chemical attack

Chapter XI.S2, “ASME 

Section XI, Subsection 

IWL.”

Accessible Areas:

Inspections performed in 

accordance with IWL will 

indicate the presence of 

increase in porosity and 

permeability, cracking, or 

loss of material (spalling, 

scaling) due to aggressive 

chemical attack.

Inaccessible Areas:

For plants with nonYes, plant 

specific if 

environment is 

aggressive

The AMP column was 

revised to clearly 

address concrete in 

accessible and 

inaccessible areas. 

The basis for this 

revision was the 

approved ISG-3. The 

environment was 

revised to reflect the 

actual environment. 

The FE column was 

revised to make it 

consistent with other 
October 2005 125 NUREG-1833

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Item

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and/or 

Components

GALL 

Rev. 0

Item 

Number

Material Environment Aging Effect/ 

Mechanism

Aging Management 

Program

Further 

Evaluation

Recommended

Basis for Change

aggressive ground 

water/soil; i.e. pH > 5.5, 

chlorides < 500 ppm, or 

sulfates <1500 ppm, as a 

minimum, consider (1) 

Examination of the 

exposed portions of the 

below grade concrete, 

when excavated for any 

reason, and (2) Periodic 

monitoring of below-grade 

water chemistry, including 

consideration of potential 

seasonal variations. For 

plants with aggressive 

groundwater/soil, and/or 

where the concrete 

structural elements have 

experienced degradation, 

a plant specific AMP 

accounting for the extent 

of the degradation 

experienced should be 

implemented to manage 

the concrete aging during 

the period of extended 

operation.

lines where a plantspecific program is 

called out.

C-28 Concrete:

Basemat

II.A2.2-a Concrete Air-outdoor Loss of material 

(spalling, 

scaling) and 

cracking/ freezethaw

Chapter XI.S2, “ASME 

Section XI, Subsection 

IWL” 

Accessible areas: 

Inspections performed in 

accordance with IWL will 

Yes, for 

inaccessible 

areas of plants 

located in 

moderate to 

severe 

weathering 

The AMP column was 

revised to clearly 

address concrete in 

accessible and 

inaccessible areas. 

The basis for this 

revision was the 
NUREG-1833 126 October 200

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and/or 

Components

GALL 

Rev. 0

Item 

Number

Material Environment Aging Effect/ 

Mechanism

Aging Management 

Program

Further 

Evaluation

Recommended

Basis for Change

indicate the presence of 

loss of material (spalling, 

scaling) and cracking due 

to freeze-thaw.

Inaccessible Areas:

Evaluation is needed for 

plants that are located in 

moderate to severe 

weathering conditions 

(weathering index >100 

day-inch/yr) (NUREG1557). Documented 

evidence confirms that 

where the existing 

concrete had air content 

of 3% to 6%, subsequent 

inspection did not exhibit 

degradation related to 

freeze-thaw. Such 

inspections should be 

considered a part of the 

evaluation.

The weathering index for 

the continental US is 

shown in ASTM C33-90, 

Fig. 1.

conditions approved ISG-3. 

Documented evidence 

exists in NUREG-1557 

that based on initial 

and subsequent 

inspections of 

concrete that had air 

content of 3% to 6%, 

these inspections did 

not show any 

degradation related to 

freeze thaw.

The environment was 

revised to air-outdoor 

instead of outside 

containment to better 

reflect the actual 

environment. The FE 

column was revised to 

clarify the conditions 

where further 

evaluation is required 

for plants located in 

moderate to severe 

weathering conditions.

If the applicant meets 

the conditions 

specified in the AMP 

column for 

inaccessible areas, 

then no specific AMP 

is necessary to 

manage this aging 

effect. However, 
October 2005 127 NUREG-1833

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and/or 

Components

GALL 

Rev. 0

Item 

Number

Material Environment Aging Effect/ 

Mechanism

Aging Management 

Program

Further 

Evaluation

Recommended

Basis for Change

opportunistic 

inspections are 

recommended.

C-29 Concrete:

Dome, wall, 

basemat

II.B3.2.1-a Concrete Air-outdoor Loss of material 

(spalling, 

scaling) and 

cracking/ freezethaw

Chapter XI.S2, “ASME 

Section XI, Subsection 

IWL” 

Accessible areas: 

Inspections performed in 

accordance with IWL will 

indicate the presence of 

loss of material (spalling, 

scaling) and cracking due 

to freeze-thaw.

Inaccessible Areas:

Evaluation is needed for 

plants that are located in 

moderate to severe 

weathering conditions 

(weathering index >100 

day-inch/yr) (NUREG1557). Documented 

evidence confirms that 

where the existing 

concrete had air content 

of 3% to 6%, subsequent 

inspection did not exhibit 

degradation related to 

freeze-thaw. Such 

inspections should be 

considered a part of the 

evaluation.

Yes, for 

inaccessible 

areas of plants 

located in 

moderate to 

severe 

weathering 

conditions

The AMP column was 

revised to clearly 

address concrete in 

accessible and 

inaccessible areas. 

The basis for this 

revision was the 

approved ISG-3. 

Documented evidence 

exists in NUREG-1557 

that based on initial 

and subsequent 

inspections of 

concrete that had air 

content of 3% to 6%, 

these inspections did 

not show any 

degradation related to 

freeze thaw.

The environment was 

revised to air-outdoor 

instead of outside 

containment to better 

reflect the actual 

environment. The FE 

column was revised to 

clarify the conditions 

where further 

evaluation is required 

for plants located in 
NUREG-1833 128 October 200

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and/or 

Components

GALL 

Rev. 0

Item 

Number

Material Environment Aging Effect/ 

Mechanism

Aging Management 

Program

Further 

Evaluation

Recommended

Basis for Change

The weathering index for 

the continental US is 

shown in ASTM C33-90, 

Fig. 1.

moderate to severe 

weathering conditions.

If the applicant meets 

the conditions 

specified in the AMP 

column for 

inaccessible areas, 

then no specific AMP 

is necessary to 

manage this aging 

effect. However, 

opportunistic 

inspections are 

recommended.

C-30 Concrete:

Basemat

II.A2.2-b 

II.B3.1.2-a

Concrete Water -

flowing

Increase in 

porosity, 

permeability/

leaching of 

calcium 

hydroxide

Chapter XI.S2, “ASME 

Section XI, Subsection 

IWL”

Accessible areas:

Inspections performed in 

accordance with IWL will 

indicate the presence of 

increase in porosity, and 

permeability due to 

leaching of calcium 

hydroxide.

Inaccessible Areas:

An aging management 

program is not necessary, 

even if reinforced 

concrete is exposed to 

flowing water, if there is 

documented evidence that 

confirms the in-place 

 Yes, if 

concrete was 

not 

constructed as 

stated for 

inaccessible 

areas

The AMP column was 

revised to clearly 

address concrete in 

accessible and 

inaccessible areas. 

The basis for this 

revision was the

approved ISG-3. 

Documented evidence 

exists in NUREG1557, that leaching is 

not significant if the 

concrete is 

constructed to ensure 

that it is dense, wellcured, has low 

permeability, and that 

cracking is well 

controlled. Cracking is 

controlled through 
October 2005 129 NUREG-1833

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and/or 

Components

GALL 

Rev. 0

Item 

Number

Material Environment Aging Effect/ 

Mechanism

Aging Management 

Program

Further 

Evaluation

Recommended

Basis for Change

concrete was constructed 

in accordance with the 

recommendations in ACI

201.2R.

proper arrangement 

and distribution of 

reinforcing bars. All of 

the above 

characteristics are 

assured if the concrete 

was constructed in 

accordance with 

ACI 201.2R-77 or later 

revisions.

The FE column was 

revised to clarify the 

conditions where 

further evaluation is 

recommended.

C-31 Concrete:

Containment, 

wall, basemat

II.B2.2.1-a Concrete Water -

flowing

Increase in 

porosity, 

permeability/

leaching of 

calcium 

hydroxide

Chapter XI.S2, “ASME 

Section XI, Subsection 

IWL”

Accessible areas:

Inspections performed in 

accordance with IWL will 

indicate the presence of 

increase in porosity, and 

permeability due to 

leaching of calcium 

hydroxide.

Inaccessible Areas:

An aging management 

program is not necessary, 

even if reinforced 

concrete is exposed to 

flowing water, if there is 

documented evidence that 

 Yes, if 

concrete was 

not 

constructed as 

stated for 

inaccessible 

areas

The AMP column was 

revised to clearly 

address concrete in 

accessible and 

inaccessible areas. 

The basis for this 

revision was the 

approved ISG-3. 

Documented evidence 

exists in NUREG1557, that leaching is 

not significant if the 

concrete is 

constructed to ensure 

that it is dense, wellcured, has low 

permeability, and that 

cracking is well 

controlled. Cracking is 
NUREG-1833 130 October 200

5

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Item

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and/or 

Components

GALL 

Rev. 0

Item 

Number

Material Environment Aging Effect/ 

Mechanism

Aging Management 

Program

Further 

Evaluation

Recommended

Basis for Change

confirms the in-place 

concrete was constructed 

in accordance with the 

recommendations in ACI

201.2R.

controlled through 

proper arrangement 

and distribution of 

reinforcing bars. All of 

the above 

characteristics are 

assured if the concrete 

was constructed in 

accordance with 

ACI 201.2R-77 or later 

revisions.

The FE column was 

revised to clarify the 

conditions where 

further evaluation is 

recommended.

C-32 Concrete:

Dome, wall, 

basemat

II.B3.2.1-b Concrete Water -

flowing

Increase in 

porosity, 

permeability/

leaching of 

calcium 

hydroxide

Chapter XI.S2, “ASME 

Section XI, Subsection 

IWL”

Accessible areas:

Inspections performed in 

accordance with IWL will 

indicate the presence of 

increase in porosity, and 

permeability due to 

leaching of calcium 

hydroxide.

Inaccessible Areas:

An aging management 

program is not necessary, 

even if reinforced 

concrete is exposed to 

flowing water, if there is 

 Yes, if 

concrete was 

not 

constructed as 

stated for 

inaccessible 

areas

The AMP column was 

revised to clearly 

address concrete in 

accessible and 

inaccessible areas. 

The basis for this 

revision was the

approved ISG-3. 

Documented evidence 

exists in NUREG1557, that leaching is 

not significant if the 

concrete is 

constructed to ensure 

that it is dense, wellcured, has low 

permeability, and that 

cracking is well 
October 2005 131 NUREG-1833

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Item

Structures 

and/or 

Components

GALL 

Rev. 0

Item 

Number

Material Environment Aging Effect/ 

Mechanism

Aging Management 

Program

Further 

Evaluation

Recommended

Basis for Change

documented evidence that 

confirms the in-place 

concrete was constructed 

in accordance with the 

recommendations in ACI

201.2R.

controlled. Cracking is 

controlled through 

proper arrangement 

and distribution of 

reinforcing bars. All of 

the above 

characteristics are 

assured if the concrete 

was constructed in 

accordance with 

ACI 201.2R-77 or later 

revisions.

The FE column was 

revised to clarify the 

conditions where 

further evaluation is 

recommended.

C-33 Concrete:

Dome, wall, 

basemat

II.B3.2.1-h Concrete Air-indoor 

uncontrolled 

or air-outdoor

Reduction of 

strength and 

modulus/ 

elevated 

temperature 

(>150°F 

general; >200°F 

local)

Plant-specific aging 

management program. The 

implementation of 

10 CFR 50.55a and ASME 

Section XI, Subsection IWL 

would not be able to identify 

the reduction of strength and 

modulus of elasticity due to 

elevated temperature. Thus, 

for any portions of concrete 

containment that exceed 

specified temperature limits, 

further evaluations are 

warranted. Subsection CC3400 of ASME Section III, 

Division 2, specifies the 

concrete temperature limits 

Yes, if 

temperature 

limits are 

exceeded

The FE column was 

revised to clarify the 

conditions where 

further evaluation is 

recommended.

If the temperatures as 

shown in the AMP 

column are not 

exceeded, then a plant 

specific program is not 

necessary.
NUREG-1833 132 October 200

5

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Item

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and/or 

Components

GALL 

Rev. 0

Item 

Number

Material Environment Aging Effect/ 

Mechanism

Aging Management 

Program

Further 

Evaluation

Recommended

Basis for Change

for normal operation or any 

other long-term period. The 

temperatures shall not 

exceed 150°F except for 

local areas, such as around 

penetrations, which are not 

allowed to exceed 200°F. If 

significant equipment loads 

are supported by concrete at 

temperatures exceeding 

150°F, an evaluation of the 

ability to withstand the 

postulated design loads is to 

be made. Higher 

temperatures than given 

above may be allowed in the 

concrete if tests and/or 

calculations are provided to 

evaluate the reduction in 

strength and this reduction 

is applied to the design 

allowables.

C-34 Concrete:

Basemat

II.A2.2-h Concrete Air-indoor 

uncontrolled 

or air-outdoor

Reduction of 

strength and 

modulus/ 

elevated 

temperature 

(>150°F 

general; >200°F 

local)

Plant-specific aging 

management program. The 

implementation of 

10 CFR 50.55a and ASME 

Section XI, Subsection IWL 

would not be able to identify 

the reduction of strength and 

modulus of elasticity due to 

elevated temperature. Thus, 

for any portions of concrete 

containment that exceed 

specified temperature limits, 

Yes, if 

temperature 

limits are 

exceeded

The FE column was 

revised to clarify the 

conditions where 

further evaluation is 

recommended.

If the temperatures as 

shown in the AMP 

column are not 

exceeded, then a plant 

specific program is not 

necessary.
October 2005 133 NUREG-1833

IIIA. Changes in Existing AMR Line-Items for Containment Structures (Chapter II in GALL Vol. 2)

Item

Structures 

and/or 

Components

GALL 

Rev. 0

Item 

Number

Material Environment Aging Effect/ 

Mechanism

Aging Management 

Program

Further 

Evaluation

Recommended

Basis for Change

further evaluations are 

warranted. Subsection CC3400 of ASME Section III, 

Division 2, specifies the 

concrete temperature limits 

for normal operation or any 

other long-term period. The 

temperatures shall not 

exceed 150°F except for 

local areas, such as around 

penetrations, which are not 

allowed to exceed 200°F. If 

significant equipment loads 

are supported by concrete at 

temperatures exceeding 

150°F, an evaluation of the 

ability to withstand the 

postulated design loads is to 

be made. Higher 

temperatures than given 

above may be allowed in the 

concrete if tests and/or 

calculations are provided to 

evaluate the reduction in 

strength and this reduction 

is applied to the design 

allowables.

C-35 Concrete:

Containment, 

wall, basemat 

II.B2.2.1-g Concrete Air-indoor 

uncontrolled 

or air-outdoor

Reduction of 

strength and 

modulus/ 

elevated 

temperature 

(>150°F 

general; >200°F 

Plant-specific aging 

management program. The 

implementation of 

10 CFR 50.55a and ASME 

Section XI, Subsection IWL 

would not be able to identify 

the reduction of strength and 

Yes, if 

temperature 

limits are 

exceeded

The FE column was 

revised to clarify the 

conditions where 

further evaluation is 

recommended.

If the temperatures as 

shown in the AMP 
NUREG-1833 134 October 200

5

IIIA. Changes in Existing AMR Line-Items for Containment Structures (Chapter II in GALL Vol. 2)

Item

Structures 

and/or 

Components

GALL 

Rev. 0

Item 

Number

Material Environment Aging Effect/ 

Mechanism

Aging Management 

Program

Further 

Evaluation

Recommended

Basis for Change

local) modulus of elasticity due to 

elevated temperature. Thus, 

for any portions of concrete 

containment that exceed 

specified temperature limits, 

further evaluations are 

warranted. Subsection CC3400 of ASME Section III, 

Division 2, specifies the 

concrete temperature limits 

for normal operation or any 

other long-term period. The 

temperatures shall not 

exceed 150°F except for 

local areas, such as around 

penetrations, which are not 

allowed to exceed 200°F. If 

significant equipment loads 

are supported by concrete at 

temperatures exceeding 

150°F, an evaluation of the 

ability to withstand the 

postulated design loads is to 

be made. Higher 

temperatures than given 

above may be allowed in the 

concrete if tests and/or 

calculations are provided to 

evaluate the reduction in 

strength and this reduction 

is applied to the design 

allowables.

column are not 

exceeded, then a plant 

specific program is not 

necessary.
October 2005 135 NUREG-1833

IIIA. Changes in Existing AMR Line-Items for Containment Structures (Chapter II in GALL Vol. 2)

Item

Structures 

and/or 

Components

GALL 

Rev. 0

Item 

Number

Material Environment Aging Effect/ 

Mechanism

Aging Management 

Program

Further 

Evaluation

Recommended

Basis for Change

C-36 Concrete:

Basemat

II.A2.2-f

II.B3.1.2-e

Concrete Soil Cracks and 

distortion due to 

increased stress 

levels from 

settlement

Chapter XI.S6, “Structures 

Monitoring Program.” If a 

de-watering system is 

relied upon for control of 

settlement, then the 

licensee is to ensure 

proper functioning of the 

de-watering system 

through the period of 

extended operation.

Yes, if not 

within the 

scope of the 

applicant’s 

structures 

monitoring 

program or a 

de-watering 

system is 

relied upon

The AMP column was 

revised to delete 

reference to initial 

licensing basis for 

settlement and the

NRC approval to 

delete the program.

The FE column was 

revised to clarify the 

conditions where 

further evaluation is 

recommended.

C-37 Concrete: 

Dome; wall; 

basemat; ring 

girders; 

buttresses

II.A1.1-f Concrete Soil Cracks and 

distortion due to 

increased stress 

levels from 

settlement

Chapter XI.S6, “Structures 

Monitoring Program.” If a 

de-watering system is 

relied upon for control of 

settlement, then the 

licensee is to ensure 

proper functioning of the 

de-watering system 

through the period of 

extended operation.

Yes, if not 

within the 

scope of the 

applicant’s 

structures 

monitoring 

program or a 

de-watering 

system is 

relied upon

The AMP column was 

revised to delete 

reference to initial 

licensing basis for 

settlement and the

NRC approval to 

delete the program.

The FE column was 

revised to clarify the 

conditions where 

further evaluation is 

recommended.

C-38 Concrete:

Basemat

III.A2.2-d Concrete Any Cracking due 

to expansion/ 

reaction with 

aggregates

Chapter XI.S2, “ASME 

Section XI, Subsection 

IWL.”

Accessible Areas:

Inspections performed in

accordance with IWL will 

 Yes, if 

concrete was 

not 

constructed as 

stated for 

inaccessible 

areas

The AMP column was 

revised to clearly 

address concrete in 

accessible and 

inaccessible areas. 

The basis for this

revision was the 
NUREG-1833 136 October 200

5

IIIA. Changes in Existing AMR Line-Items for Containment Structures (Chapter II in GALL Vol. 2)

Item

Structures 

and/or 

Components

GALL 

Rev. 0

Item 

Number

Material Environment Aging Effect/ 

Mechanism

Aging Management 

Program

Further 

Evaluation

Recommended

Basis for Change

indicate the presence of 

cracking due to reaction 

with aggregates.

Inaccessible Areas:

As described in NUREG1557, investigations, tests, 

and petrographic 

examinations of aggregates 

performed in accordance 

with ASTM C295-54 or 

ASTM C227-50 can 

demonstrate that those 

aggregates do not react 

within reinforced concrete. 

For potentially reactive 

aggregates, aggregatereinforced concrete reaction 

is not significant if the 

concrete was constructed in 

accordance with ACI 

201.2R. Therefore, if these 

conditions are satisfied, 

aging management is not 

necessary.

approved ISG-3. The 

environment was 

revised to “any” since 

the aging effect could 

occur in any 

environment – more 

dependent on 

aggregates than 

environment. The FE 

column was revised to 

clarify the conditions 

where further 

evaluation is 

recommended.

Use of ACI 201.2R-77 

or later revision is 

acceptable.

C-39 Concrete:

Containment, 

wall, basemat

II.B2.2.1-c Concrete Any Cracking due 

to expansion/ 

reaction with 

aggregates

Chapter XI.S2, “ASME 

Section XI, Subsection 

IWL.”

Accessible Areas:

Inspections performed in 

accordance with IWL will 

indicate the presence of 

 Yes, if 

concrete was 

not 

constructed as 

stated for 

inaccessible 

areas

The AMP column was 

revised to clearly 

address concrete in 

accessible and 

inaccessible areas. 

The basis for this 

revision was the 

approved ISG-3. The 
October 2005 137 NUREG-1833

IIIA. Changes in Existing AMR Line-Items for Containment Structures (Chapter II in GALL Vol. 2)

Item

Structures 

and/or 

Components

GALL 

Rev. 0

Item 

Number

Material Environment Aging Effect/ 

Mechanism

Aging Management 

Program

Further 

Evaluation

Recommended

Basis for Change

cracking due to reaction 

with aggregates.

Inaccessible Areas:

As described in NUREG1557, investigations, tests, 

and petrographic 

examinations of aggregates 

performed in accordance 

with ASTM C295-54 or 

ASTM C227-50 can 

demonstrate that those 

aggregates do not react 

within reinforced concrete. 

For potentially reactive 

aggregates, aggregatereinforced concrete reaction 

is not significant if the 

concrete was constructed in 

accordance with ACI 

201.2R. Therefore, if these 

conditions are satisfied, 

aging management is not 

necessary.

environment was 

revised to “any” since 

the aging effect could 

occur in any 

environment – more 

dependent on 

aggregates than 

environment. The FE 

column was revised to 

clarify the conditions 

where further 

evaluation is 

recommended.

Use of ACI 201.2R-77 

or later revision is 

acceptable.

C-40 Concrete:

Dome, wall, 

basemat

II.B3.2.1-d Concrete Any Cracking due 

to expansion/ 

reaction with 

aggregates

Chapter XI.S2, “ASME 

Section XI, Subsection 

IWL.”

Accessible Areas:

Inspections performed in 

accordance with IWL will 

indicate the presence of 

cracking due to reaction 

with aggregates.

 Yes, if 

concrete was 

not 

constructed as 

stated for 

inaccessible 

areas

The AMP column was 

revised to clearly 

address concrete in 

accessible and 

inaccessible areas. 

The basis for this 

revision was the 

approved ISG-3. The 

environment was 

revised to “any” since 
NUREG-1833 138 October 200

5

IIIA. Changes in Existing AMR Line-Items for Containment Structures (Chapter II in GALL Vol. 2)

Item

Structures 

and/or 

Components

GALL 

Rev. 0

Item 

Number

Material Environment Aging Effect/ 

Mechanism

Aging Management 

Program

Further 

Evaluation

Recommended

Basis for Change

Inaccessible Areas:

As described in NUREG1557, investigations, tests, 

and petrographic 

examinations of aggregates 

performed in accordance 

with ASTM C295-54 or 

ASTM C227-50 can 

demonstrate that those 

aggregates do not react 

within reinforced concrete. 

For potentially reactive 

aggregates, aggregatereinforced concrete reaction 

is not significant if the 

concrete was constructed in

accordance with ACI 

201.2R. Therefore, if these 

conditions are satisfied, 

aging management is not 

necessary.

the aging effect could 

occur in any 

environment – more 

dependent on 

aggregates than 

environment. The FE 

column was revised to 

clarify the conditions 

where further 

evaluation is 

recommended.

Use of ACI 201.2R-77 

or later revision is 

acceptable.

C-41 Concrete:

Basemat, 

reinforcing 

steel

II.B2.2.1-d

II.B1.2

Concrete, 

steel

Air-indoor 

uncontrolled 

or airoutdoor

Cracking, loss of 

bond, and loss 

of material 

(spalling, 

scaling)/ 

corrosion of 

embedded steel

Chapter XI.S2, “ASME 

Section XI, Subsection 

IWL.”

Accessible Areas: 

Inspections performed in 

accordance with IWL will 

indicate the presence of 

cracking, loss of bond, 

and loss of material 

(spalling, scaling) due to 

aggressive chemical 

attack.

Yes, plant 

specific if 

environment is 

aggressive

The AMP column was 

revised to clearly 

address concrete in 

accessible and 

inaccessible areas. 

The basis for this 

revision was the 

approved ISG-3. The 

environment was 

revised to air-indoor 

uncontrolled or airoutdoor instead of 

inside or outside 
October 2005 139 NUREG-1833

IIIA. Changes in Existing AMR Line-Items for Containment Structures (Chapter II in GALL Vol. 2)

Item

Structures 

and/or 

Components

GALL 

Rev. 0

Item 

Number

Material Environment Aging Effect/ 

Mechanism

Aging Management 

Program

Further 

Evaluation

Recommended

Basis for Change

Inaccessible Areas: 

For plants with nonaggressive ground 

water/soil; i.e. pH > 5.5, 

chlorides < 500 ppm, or 

sulfates <1500 ppm, as a 

minimum, consider

 (1) Examination of the 

exposed portions of the 

below grade concrete, 

when excavated for any 

reason, and

 (2) Periodic monitoring of 

below-grade water 

chemistry, including 

consideration of potential 

seasonal variations. For 

plants with aggressive 

groundwater/soil, and/or 

where the concrete 

structural elements have 

experienced degradation, 

a plant specific AMP 

accounting for the extent 

of the degradation 

experienced should be 

implemented to manage 

the concrete aging during 

the period of extended 

operation. 

containment to better 

reflect the actual 

environment. The FE 

column was revised to 

clarify the conditions 

where further 

evaluation is 

recommended.

C-42 Concrete: 

Dome; wall; 

basemat; 

II.B3.2.1-e Concrete, 

steel

Air-indoor 

uncontrolled 

or airCracking, loss of 

bond, and loss 

of material 

Chapter XI.S2, “ASME 

Section XI, Subsection 

IWL.”

Yes, plant 

specific if 

environment is 

The AMP column was 

revised to clearly 

address concrete in 
NUREG-1833 140 October 200

5

IIIA. Changes in Existing AMR Line-Items for Containment Structures (Chapter II in GALL Vol. 2)

Item

Structures 

and/or 

Components

GALL 

Rev. 0

Item 

Number

Material Environment Aging Effect/ 

Mechanism

Aging Management 

Program

Further 

Evaluation

Recommended

Basis for Change

reinforcing 

steel

outdoor (spalling, 

scaling)/ 

corrosion of 

embedded steel

Accessible Areas: 

Inspections performed in 

accordance with IWL will 

indicate the presence of 

cracking, loss of bond, 

and loss of material 

(spalling, scaling) due to 

aggressive chemical 

attack.

Inaccessible Areas: 

For plants with nonaggressive ground 

water/soil; i.e. pH > 5.5, 

chlorides < 500 ppm, or 

sulfates <1500 ppm, as a 

minimum, consider

 (1) Examination of the 

exposed portions of the 

below grade concrete, 

when excavated for any 

reason, and

 (2) Periodic monitoring of 

below-grade water 

chemistry, including 

consideration of potential 

seasonal variations. For 

plants with aggressive 

groundwater/soil, and/or 

where the concrete 

structural elements have 

experienced degradation, 

a plant specific AMP 

aggressive accessible and 

inaccessible areas. 

The basis for this 

revision was the 

approved ISG-3. The 

environment was 

revised to air-indoor 

uncontrolled or airoutdoor instead of 

inside or outside 

containment to better 

reflect the actual 

environment. The FE 

column was revised to 

clarify the conditions 

where further 

evaluation is 

recommended.
October 2005 141 NUREG-1833

IIIA. Changes in Existing AMR Line-Items for Containment Structures (Chapter II in GALL Vol. 2)

Item

Structures 

and/or 

Components

GALL 

Rev. 0

Item 

Number

Material Environment Aging Effect/ 

Mechanism

Aging Management 

Program

Further 

Evaluation

Recommended

Basis for Change

accounting for the extent 

of the degradation 

experienced should be 

implemented to manage 

the concrete aging during 

the period of extended 

operation. 

C-43 Concrete:

Basemat, 

reinforcing 

steel

II.A2.2-e 

II.B3.1.2-d

Concrete, 

steel

Air-indoor 

uncontrolled 

or airoutdoor

Cracking, loss of 

bond, and loss 

of material 

(spalling, 

scaling)/ 

corrosion of 

embedded steel

Chapter XI.S2, “ASME 

Section XI, Subsection 

IWL.”

Accessible Areas: 

Inspections performed in 

accordance with IWL will 

indicate the presence of 

cracking, loss of bond, 

and loss of material 

(spalling, scaling) due to 

aggressive chemical 

attack.

Inaccessible Areas: 

For plants with nonaggressive ground 

water/soil; i.e. pH > 5.5, 

chlorides < 500 ppm, or 

sulfates <1500 ppm, as a 

minimum, consider

 (1) Examination of the 

exposed portions of the 

below grade concrete, 

when excavated for any 

reason, and

 (2) Periodic monitoring of 

Yes, plant 

specific if 

environment is 

aggressive

The AMP column was 

revised to clearly 

address concrete in 

accessible and 

inaccessible areas. 

The basis for this 

revision was the 

approved ISG-3. The 

environment was 

revised to air-indoor 

uncontrolled or airoutdoor instead of 

inside or outside 

containment to better 

reflect the actual 

environment. The FE 

column was revised to 

clarify the conditions 

where further 

evaluation is 

recommended.
NUREG-1833 142 October 200

5

IIIA. Changes in Existing AMR Line-Items for Containment Structures (Chapter II in GALL Vol. 2)

Item

Structures 

and/or 

Components

GALL 

Rev. 0

Item 

Number

Material Environment Aging Effect/ 

Mechanism

Aging Management 

Program

Further 

Evaluation

Recommended

Basis for Change

below-grade water 

chemistry, including 

consideration of potential 

seasonal variations. For 

plants with aggressive 

groundwater/soil, and/or 

where the concrete 

structural elements have 

experienced degradation, 

a plant specific AMP 

accounting for the extent 

of the degradation 

experienced should be 

implemented to manage 

the concrete aging during 

the period of extended 

operation.

C-46 Steel 

elements: 

Suppression 

chamber; 

drywell liner; 

drywell head; 

embedded 

shell; sand 

pocket region; 

support skirt; 

downcomer 

pipes; region 

shielded by 

diaphragm 

floor

NOTE: 

II.B2.1.1-a 

II.B2.2.2-a 

Steel Air – indoor 

uncontrolled 

or treated 

water (as 

applicable)

Loss of material/ 

general, pitting, 

and crevice 

corrosion

Chapter XI.S1, “ASME 

Section XI, Subsection 

IWE.” For inaccessible 

areas (embedded 

containment steel shell or 

liner), loss of material due 

to corrosion is not 

significant if the following 

conditions are satisfied: 

Concrete meeting the 

specifications of ACI 318 

or 349 and the guidance of 

201.2R was used for the 

containment concrete in 

contact with the 

embedded containment 

shell or liner. The concrete 

Yes, if corrosion 

is significant for 

inaccessible 

areas

In the AMP column, 

removed mentioning of 

the relief request for 

coatings program.

Relief requests 

associated with ISI are 

usually plant-specific 

and only valid during 

the 10-year ISI 

program. They are not 

considered for license 

renewal, in general, 

and therefore the 

mentioning of the relief 

request was removed.
October 2005 143 NUREG-1833

IIIA. Changes in Existing AMR Line-Items for Containment Structures (Chapter II in GALL Vol. 2)

Item

Structures 

and/or 

Components

GALL 

Rev. 0

Item 

Number

Material Environment Aging Effect/ 

Mechanism

Aging Management 

Program

Further 

Evaluation

Recommended

Basis for Change

Inspection of 

containment 

supports is 

addressed by 

ASME 

Section XI, 

Subsection 

IWF (see 

III.B1.3)

is monitored to ensure 

that it is free of 

penetrating cracks that 

provide a path for water 

seepage to the surface of 

the containment shell or 

liner. The moisture barrier, 

at the junction where the 

shell or liner becomes 

embedded, is subject to 

aging management 

activities in accordance 

with ASME Section XI, 

Subsection IWE 

requirements. Water 

ponding on the 

containment concrete 

floor are not common and 

when detected are cleaned 

up in a timely manner.

 If any of the above 

conditions cannot be 

satisfied, then a plantspecific aging 

management program for 

corrosion is necessary. 

Chapter XI.S4, “10 CFR 

Part 50, Appendix J” No

C-49 Steel 

elements: 

Suppression 

chamber liner 

II.B2.2.2-b

II.B1.2

Stainless 

steel,

steel

Air – indoor 

uncontrolled 

or treated 

water (as 

Loss of 

material/ 

general, pitting, 

and crevice 

Chapter XI.S1, “ASME 

Section XI, Subsection 

IWE,” and Chapter XI.S4, 

“10 CFR Part 50, Appendix 

No Treated water is a 

potential environment 

for the BWR Mark II 

suppression chamber. 
NUREG-1833 144 October 200

5

IIIA. Changes in Existing AMR Line-Items for Containment Structures (Chapter II in GALL Vol. 2)

Item

Structures 

and/or 

Components

GALL 

Rev. 0

Item 

Number

Material Environment Aging Effect/ 

Mechanism

Aging Management 

Program

Further 

Evaluation

Recommended

Basis for Change

(interior 

surface)

applicable) corrosion J" Cracking as an aging 

effect was removed 

because as defined in 

GALL Report, Volume 

2, Chapter IX.D, 

cracking (an issue in 

treated water >140°F) 

is not present, so the 

AE/AM column was 

revised to identify only 

loss of material.

C-50 Concrete:

Basemat, 

concrete fillin-annulus

II.B3.1.2-g Concrete Air-indoor 

uncontrolled 

or air-outdoor

Reduction of 

strength and 

modulus/ 

elevated 

temperature 

(>150°F 

general; >200°F 

local)

Plant-specific aging 

management program. The 

implementation of 

10 CFR 50.55a and ASME 

Section XI, Subsection IWL 

would not be able to identify 

the reduction of strength and 

modulus of elasticity due to 

elevated temperature. Thus, 

for any portions of concrete 

containment that exceed 

specified temperature limits, 

further evaluations are 

warranted. Subsection CC3400 of ASME Section III, 

Division 2, specifies the 

concrete temperature limits 

for normal operation or any 

other long-term period. The 

temperatures shall not 

exceed 150°F except for 

local areas, such as around 

Yes, if 

temperature 

limits are 

exceeded

The FE column was 

revised to clarify the 

conditions where 

further evaluation is 

recommended.

If the temperatures as 

shown in the AMP 

column are not 

exceeded, then a plant 

specific program is not 

necessary.
October 2005 145 NUREG-1833

IIIA. Changes in Existing AMR Line-Items for Containment Structures (Chapter II in GALL Vol. 2)

Item

Structures 

and/or 

Components

GALL 

Rev. 0

Item 

Number

Material Environment Aging Effect/ 

Mechanism

Aging Management 

Program

Further 

Evaluation

Recommended

Basis for Change

penetrations, which are not 

allowed to exceed 200°F. If 

significant equipment loads 

are supported by concrete at 

temperatures exceeding 

150°F, an evaluation of the 

ability to withstand the 

postulated design loads is to 

be made. Higher 

temperatures than given 

above may be allowed in the 

concrete if tests and/or 

calculations are provided to 

evaluate the reduction in 

strength and this reduction 

is applied to the design 

allowables.

C-51 Concrete:

Basemat, 

concrete fill-in 

annulus

II.B3.1.2-c Concrete Any Cracking due 

to expansion/ 

reaction with 

aggregates

Chapter XI.S2, “ASME 

Section XI, Subsection 

IWL.”

Accessible Areas:

Inspections performed in 

accordance with IWL will 

indicate the presence of 

cracking due to reaction 

with aggregates.

Inaccessible Areas:

As described in NUREG1557, investigations, tests, 

and petrographic 

examinations of aggregates 

performed in accordance 

 Yes, if 

concrete was 

not 

constructed as 

stated for 

inaccessible 

areas

The AMP column was 

revised to clearly 

address concrete in 

accessible and 

inaccessible areas. 

The basis for this 

revision was the 

approved ISG-3. The 

environment was 

revised to “any” since 

the aging effect could 

occur in any 

environment – more 

dependent on 

aggregates than 

environment. The FE 

column was revised to 
NUREG-1833 146 October 200

5

IIIA. Changes in Existing AMR Line-Items for Containment Structures (Chapter II in GALL Vol. 2)

Item

Structures 

and/or 

Components

GALL 

Rev. 0

Item 

Number

Material Environment Aging Effect/ 

Mechanism

Aging Management 

Program

Further 

Evaluation

Recommended

Basis for Change

with ASTM C295-54 or 

ASTM C227-50 can 

demonstrate that those 

aggregates do not react 

within reinforced concrete. 

For potentially reactive 

aggregates, aggregatereinforced concrete reaction 

is not significant if the 

concrete was constructed in 

accordance with ACI 

201.2R. Therefore, if these 

conditions are satisfied, 

aging management is not 

necessary.

clarify the conditions 

where further 

evaluation is 

recommended.

Use of ACI 201.2R-77 

or later revision is 

acceptable.
October 2005 147 NUREG-1833

III.B Structures and Components Supports

Table III.B presents the changes made to existing AMR line-items for structures and component supports.

IIIB. Changes in Existing AM R Line-Items related to Structures and Component Supports (Chapter III in GALL Vol. 2)

Item

Structures 

and/or 

Components

GALL 

Rev. 0

Item 

Number

Material Environment Aging Effect/ 

Mechanism

Aging Management 

Program

Further 

Evaluation

Recommended

Basis for Change

T-01Concrete: 

Exterior above 

and below 

grade; 

foundation

III.A1.1-a

III.A2.1-a 

III.A3.1-a 

III.A5.1-a 

III.A7.1-a 

III.A8.1-a 

III.A9.1-a

Reinforced 

concrete

Air– outdoor Loss of material 

(spalling, scaling) 

and cracking/

freeze-thaw

Chapter XI.S6, 

“Structures

Monitoring Program”

Accessible Areas:

Inspections performed 

in accordance with 

Structures Monitoring 

Program will indicate 

the presence of loss of 

material (spalling, 

scaling) and cracking 

due to freeze-thaw.

Inaccessible Areas:

Evaluation is needed 

for plants that are 

located in moderate to 

severe weathering 

conditions (weathering 

index > 100 day-inch/yr) 

(NUREG-1557). 

Documented evidence 

to confirm that the inplace concrete had the 

air content between 3% 

to 6% and water-tocement ratio of 0.35-

0.45 and the 

subsequent 

Yes, if not 

within the 

scope of the 

applicant’s 

structures 

monitoring 

program or 

for 

inaccessible 

areas of 

plants located 

in moderate 

to severe 

weathering 

conditions

The AMP column was 

revised to clearly address 

concrete in accessible and 

inaccessible areas. The 

basis for this revision was 

the approved ISG-3. 

Documented evidence 

exists in NUREG-1557 that 

based on initial and 

subsequent inspections of 

concrete that had air 

content of 3% to 6%, these 

inspections did not show 

any degradation related to 

freeze thaw.

The environment was 

revised to air-outdoor 

instead of weather 

exposed to be consistent 

with Chapter II changes. 

The FE column was 

revised to clarify the 

conditions where further 

evaluation is 

recommended and 

required for plants located 

in moderate to severe 

weathering conditions.

If the applicant meets the 

conditions specified in the 
NUREG/CR-183

3 148 October 2005

IIIB. Changes in Existing AM R Line-Items related to Structures and Component Supports (Chapter III in GALL Vol. 2)

Item

Structures 

and/or 

Components

GALL 

Rev. 0

Item 

Number

Material Environment Aging Effect/ 

Mechanism

Aging Management 

Program

Further 

Evaluation

Recommended

Basis for Change

inspections performed 

did not exhibit 

degradation related to 

freeze-thaw, should be 

considered a part of the 

evaluation.

The weathering index 

for the continental US 

is shown in ASTM C33-

90, Fig.1.

AMP column for 

inaccessible areas, then 

no specific AMP is 

necessary to manage this 

aging effect. However, 

opportunistic inspections 

are recommended.

T-02Concrete: 

Exterior above 

and below 

grade; 

foundation

III.A1.1-b 

III.A2.1-b 

III.A3.1-b 

III.A5.1-b 

III.A7.1-b 

III.A8.1-b 

III.A9.1-b

Reinforced 

concrete

Water – flowing Increase in 

porosity and 

permeability, loss 

of strength/

leaching of 

calcium 

hydroxide

Chapter XI.S6, 

“Structures Monitoring 

Program”

Accessible Areas:

Inspections performed 

in accordance with 

Structures Monitoring 

Program will indicate 

the presence of 

increase in porosity 

and permeability due to 

leaching of calcium 

hydroxide

Inaccessible Areas:

An aging management 

program is not 

necessary, even if 

reinforced concrete is 

exposed to flowing water, 

if there is documented 

evidence that confirms 

Yes, if 

concrete was 

not 

constructed 

as stated for 

inaccessible 

areas

The AMP column was 

revised to clearly address 

concrete in accessible and 

inaccessible areas. The 

basis for this revision was 

with the approved ISG-3. 

Documented evidence 

exists in NUREG-1557, 

that leaching is not 

significant if the concrete is 

constructed to ensure that 

it is dense, well-cured, has 

low permeability, and that 

cracking is well controlled. 

Cracking is controlled 

through proper 

arrangement and 

distribution of reinforcing 

bars. All of the above 

characteristics are assured 

if the concrete was 

constructed in accordance 

with ACI 201.2R-77 or later 
October 2005 149 NUREG-1833

IIIB. Changes in Existing AM R Line-Items related to Structures and Component Supports (Chapter III in GALL Vol. 2)

Item

Structures 

and/or 

Components

GALL 

Rev. 0

Item 

Number

Material Environment Aging Effect/ 

Mechanism

Aging Management 

Program

Further 

Evaluation

Recommended

Basis for Change

the in-place concrete was 

constructed in 

accordance with the 

recommendations in ACI 

201.2R.

revisions.

The FE column was 

revised to clarify the 

conditions where further 

evaluation is 

recommended.

T-03Concrete:

All

III.A1.1-c 

III.A2.1-c 

III.A3.1-c 

III.A4.1-b 

III.A5.1-c 

III.A7.1-c 

III.A8.1-c 

III.A9.1-c

Reinforced 

concrete

Any Cracking due to 

expansion/ 

reaction with 

aggregates

Chapter XI.S6, 

“Structures Monitoring 

Program.”

Accessible Areas:

Inspections/evaluations 

performed in 

accordance with 

Structures Monitoring 

Program will indicate 

the presence of 

expansion and cracking 

due to reaction with 

aggregates.

Inaccessible Areas:

As described in NUREG1557, investigations, 

tests, and petrographic 

examinations of 

aggregates performed in 

accordance with ASTM 

C295-54 or ASTM C227-

50 can demonstrate that 

those aggregates do not 

react within reinforced

concrete. For potentially 

Yes, if not 

within the 

scope of the 

applicant’s 

structures 

monitoring 

program or 

concrete was 

not 

constructed 

as stated for 

inaccessible 

areas

The AMP column was 

revised to clearly address 

concrete in accessible and 

inaccessible areas. The 

basis for this revision was 

the approved ISG-3. The 

FE column was revised to 

clarify the conditions where 

further evaluation is 

recommended.

Use of ACI 201.2R-77 or 

later revision is acceptable.
NUREG/CR-183

3 150 October 2005

IIIB. Changes in Existing AM R Line-Items related to Structures and Component Supports (Chapter III in GALL Vol. 2)

Item

Structures 

and/or 

Components

GALL 

Rev. 0

Item 

Number

Material Environment Aging Effect/ 

Mechanism

Aging Management 

Program

Further 

Evaluation

Recommended

Basis for Change

reactive aggregates, 

aggregate-reinforced 

concrete reaction is not 

significant if the concrete 

was constructed in 

accordance with ACI 

201.2R. Therefore, if 

these conditions are

satisfied, aging 

management is not 

necessary.

T-04Concrete: 

Interior and 

above-grade 

exterior

III.A1.1-d 

III.A2.1-d 

III.A3.1-d 

III.A4.1-d 

III.A5.1-d 

III.A7.1-d 

III.A9.1-d

Reinforced 

concrete

Air – indoor 

uncontrolled or 

air – outdoor 

Cracking, loss of 

bond, and loss of 

material (spalling, 

scaling)/

corrosion of 

embedded steel

Chapter XI.S6, 

“Structures Monitoring 

Program”

Accessible areas:

Inspections performed 

in accordance with 

“Structures Monitoring 

Program” will indicate 

the presence of 

cracking, loss of bond, 

and loss of material 

(spalling, scaling) due 

to corrosion of 

embedded steel.

Yes, if not 

within the 

scope of the 

applicant’s 

structures 

monitoring 

program

The AMP column was 

revised to clearly address 

concrete in accessible 

areas. The basis for this 

revision was to make the 

AMP column consistent 

with the approved ISG-3. 

The environment was 

revised to air-indoor 

uncontrolled or air-outdoor 

to better reflect the actual 

environment. The FE 

column was revised to 

clarify the conditions where 

further evaluation is 

recommended.

T-05Concrete: 

Below-grade 

exterior; 

foundation

III.A1.1-e 

III.A2.1-e 

III.A3.1-e 

III.A5.1-e 

III.A7.1-e 

III.A8.1-d 

III.A9.1-e

Reinforced 

concrete

Groundwater/soil Cracking, loss of 

bond, and loss of 

material (spalling, 

scaling)/

corrosion of 

embedded steel

Chapter XI.S6, 

"Structures Monitoring 

Program"

Accessible Areas: 

Inspections performed 

in accordance with the 

Yes, plantspecific if 

environment 

is aggressive

The AMP column was 

revised to clearly address 

concrete in inaccessible 

areas. The basis for this 

revision was to make the 

AMP column consistent 

with the approved ISG-3. 
October 2005 151 NUREG-1833

IIIB. Changes in Existing AM R Line-Items related to Structures and Component Supports (Chapter III in GALL Vol. 2)

Item

Structures 

and/or 

Components

GALL 

Rev. 0

Item 

Number

Material Environment Aging Effect/ 

Mechanism

Aging Management 

Program

Further 

Evaluation

Recommended

Basis for Change

Structures Monitoring 

Program will indicate 

the cracking, loss of 

bond, or loss of 

material (spalling, 

scaling) due to 

corrosion of embedded 

steel. 

Inaccessible Areas:

For plants with nonaggressive ground 

water/soil; i.e. pH > 5.5, 

chlorides < 500 ppm, or 

sulfates <1500 ppm, as 

a minimum, consider 

(1) Examination of the 

exposed portions of the 

below grade concrete, 

when excavated for any 

reason, and (2) Periodic 

monitoring of belowgrade water chemistry, 

including consideration 

of potential seasonal 

variations. 

For plants with 

aggressive 

groundwater/soil, 

and/or where the 

concrete structural 

elements have 

experienced 

degradation, a plant 

The FE column was 

revised for consistency.
NUREG/CR-183

3 152 October 2005

IIIB. Changes in Existing AM R Line-Items related to Structures and Component Supports (Chapter III in GALL Vol. 2)

Item

Structures 

and/or 

Components

GALL 

Rev. 0

Item 

Number

Material Environment Aging Effect/ 

Mechanism

Aging Management 

Program

Further 

Evaluation

Recommended

Basis for Change

specific AMP 

accounting for the 

extent of the 

degradation 

experienced should be 

implemented to 

manage the concrete 

aging during the period 

of extended operation.

T-06Concrete: 

Interior and 

above-grade 

exterior

III.A1.1-f 

III.A2.1-f 

III.A3.1-f 

III.A4.1-a 

III.A5.1-f 

III.A7.1-f 

III.A9.1-f

Reinforced 

concrete

Air-indoor 

uncontrolled or 

air-outdoor

Increase in 

porosity and 

permeability, 

cracking, loss of 

material (spalling, 

scaling)/

aggressive 

chemical attack

Chapter XI.S6, 

“Structures Monitoring 

Program”

Accessible Areas:

Inspections performed 

in accordance with 

“Structures Monitoring 

Program” will indicate 

the presence of 

increase in porosity 

and permeability, 

cracking, or loss of 

material (spalling, 

scaling) due to 

aggressive chemical 

attack.

Yes, if not 

within the 

scope of the 

applicant’s 

structures 

monitoring 

program

The AMP column was 

revised to address 

concrete in accessible 

areas. The basis for this 

revision was to incorporate 

approved ISG-3. The FE 

column was revised to 

clarify the conditions where 

further evaluation is 

recommended.

T-07Concrete: 

Below-grade 

exterior; 

foundation

III.A1.1-g 

III.A2.1-g 

III.A3.1-g 

III.A5.1-g 

III.A7.1-g 

III.A8.1-e 

III.A9.1-g

Reinforced 

concrete

Aggressive 

environment

Increase in 

porosity and 

permeability, 

cracking, loss of 

material (spalling, 

scaling)/

aggressive 

chemical attack

Inaccessible Areas:

For plants with nonaggressive ground 

water/soil; i.e. pH > 5.5, 

chlorides < 500 ppm, or 

sulfates <1500 ppm, as 

a minimum, consider

(1) Examination of the 

Yes, plantspecific if 

environment 

is aggressive

The AMP column was 

revised to address 

concrete in inaccessible 

areas. Additionally, further 

evaluation was required 

only if an aggressive 

below-grade environment 

existed. The basis for this 
October 2005 153 NUREG-1833

IIIB. Changes in Existing AM R Line-Items related to Structures and Component Supports (Chapter III in GALL Vol. 2)

Item

Structures 

and/or 

Components

GALL 

Rev. 0

Item 

Number

Material Environment Aging Effect/ 

Mechanism

Aging Management 

Program

Further 

Evaluation

Recommended

Basis for Change

exposed portions of the 

below grade concrete, 

when excavated for any 

reason, and

(2) Periodic monitoring 

of below-grade water 

chemistry, including 

consideration of 

potential seasonal 

variations.

For plants with 

aggressive 

groundwater/soil, 

and/or where the 

concrete structural 

elements have 

experienced 

degradation, a plant 

specific AMP 

accounting for the 

extent of the 

degradation 

experienced should be 

implemented to 

manage the concrete 

aging during the period 

of extended operation.

revision was the approved 

ISG-3.

T-08Concrete:

All

III.A1.1-h 

III.A2.1-h 

III.A3.1-h 

III.A5.1-h 

III.A7.1-h 

III.A8.1-f 

III.A9.1-h 

Reinforced 

concrete

Soil Cracks and 

distortion due to 

increased stress 

levels from 

settlement

Chapter XI.S6, 

“Structures Monitoring 

Program.” 

If a de-watering system 

is relied upon for 

control of settlement,

Yes, if not 

within the 

scope of the 

applicant’s 

structures 

monitoring 

program or a 

The AMP column was 

revised to delete reference 

to initial licensing basis for 

settlement and the NRC 

approval to delete the 

program.
NUREG/CR-183

3 154 October 2005

IIIB. Changes in Existing AM R Line-Items related to Structures and Component Supports (Chapter III in GALL Vol. 2)

Item

Structures 

and/or 

Components

GALL 

Rev. 0

Item 

Number

Material Environment Aging Effect/ 

Mechanism

Aging Management 

Program

Further 

Evaluation

Recommended

Basis for Change

III.A6.1-f then the licensee is to 

ensure proper 

functioning of the dewatering system 

through the period of 

extended operation.

de-watering 

system is 

relied upon

The FE column was 

revised to clarify the 

conditions where further 

evaluation is 

recommended.

T-09Concrete;

Foundation, 

subfoundation

III.A1.1-i

III.A2.1-i 

III.A3.1-i 

III.A5.1-i 

III.A6.1-g 

III.A7.1-i 

III.A8.1-g 

III.A9.1-i

Reinforced 

concrete; 

porous 

concrete

Water – flowing 

under foundation

Reduction in 

foundation 

strength, 

cracking, 

differential 

settlement/ 

erosion of porous 

concrete 

subfoundation

Chapter XI.S6, 

“Structures Monitoring 

Program” 

Erosion of cement from 

porous concrete 

subfoundations beneath 

containment basemats is 

described in NRC IN 97-

11. NRC IN 98-26 

proposes Maintenance 

Rule Structures 

Monitoring for managing 

this aging effect, if 

applicable. If a dewatering system is relied 

upon for control of 

erosion of cement from 

porous concrete 

subfoundations, then the 

licensee is to ensure 

proper functioning of the 

de-watering system 

through the period of 

extended operation.

Yes, if not 

within the 

scope of the 

applicant’s 

structures 

monitoring 

program or a 

de-watering 

system is 

relied upon

The FE column was 

revised to clarify the 

conditions where further 

evaluation is 

recommended.
October 2005 155 NUREG-1833

IIIB. Changes in Existing AM R Line-Items related to Structures and Component Supports (Chapter III in GALL Vol. 2)

Item

Structures 

and/or 

Components

GALL 

Rev. 0

Item 

Number

Material Environment Aging Effect/ 

Mechanism

Aging Management 

Program

Further 

Evaluation

Recommended

Basis for Change

T-10Concrete:

All

III.A1.1-j 

III.A2.1-j 

III.A3.1-j 

III.A4.1-c 

III.A5.1-j

Reinforced 

concrete

Air-indoor 

uncontrolled

Reduction of 

strength and 

modulus/ 

elevated 

temperature 

(>150°F general; 

>200°F local)

Plant-specific aging 

management program

For any concrete 

elements that exceed 

specified temperature 

limits, further evaluations 

are warranted. Appendix 

A of ACI 349-85 specifies 

the concrete temperature 

limits for normal 

operation or any other 

long-term period. The 

temperatures shall not 

exceed 150°F except for 

local areas which are 

allowed to have 

increased temperatures 

not to exceed 200°F.

Yes, if 

temperature 

limits are 

exceeded

The FE column was 

revised to clarify the 

conditions where further 

evaluation is 

recommended. If the 

temperatures as shown in 

the AMP column are not 

exceeded, then a plant 

specific program is not 

necessary.

T-11Steel 

components:

All structural 

steel

III.A1.2-a 

III.A2.2-a 

III.A3.2-a 

III.A4.2-a 

III.A5.2-a 

III.A7.2-a 

III.A8.2-a

Steel Air – indoor 

uncontrolled or 

air – outdoor

Loss of 

material/corrosion

Chapter XI.S6,

“Structures Monitoring 

Program.”

If protective coatings are 

relied upon to manage 

the effects of aging, the 

structures monitoring 

program is to include 

provisions to address 

protective coating 

monitoring and 

maintenance.

Yes, if not 

within the 

scope of the 

applicant’s 

structures 

monitoring 

program

The FE column was 

revised to clarify the 

conditions where further 

evaluation is 

recommended.
NUREG/CR-183

3 156 October 2005

IIIB. Changes in Existing AM R Line-Items related to Structures and Component Supports (Chapter III in GALL Vol. 2)

Item

Structures 

and/or 

Components

GALL 

Rev. 0

Item 

Number

Material Environment Aging Effect/ 

Mechanism

Aging Management 

Program

Further 

Evaluation

Recommended

Basis for Change

T-13Steel 

components: 

Radial beam 

seats in BWR 

drywell; RPV 

support shoes 

for PWR with 

nozzle 

supports; 

Steam 

generator 

supports

III.A4.2-b Lubrite® Air – indoor 

uncontrolled

Lock-up/ wear Chapter XI.S3, “ASME 

Chapter XI, Subchapter 

IWF” or

Chapter XI.S6, 

“Structures Monitoring 

Program”

Yes, if not 

within the 

scope of 

Chapter XI, 

IWF or 

structures 

monitoring 

program 

Added "steam generator 

supports" in the 

structure/component list to 

include instances where 

Lubrite® supports are 

used. Also, provided the 

option of using AMP XI.S3 

for those plants that have a 

Section XI, subsection NF 

program in place. The FE 

column was revised to 

clarify the conditions where 

further evaluation is 

recommended.

T-14Steel 

components:

Fuel pool liner

III.A5.2-b Stainless 

steel

Treated water 

or treated 

borated water

Cracking/ stress 

corrosion 

cracking

Loss of 

material/pitting 

and crevice 

corrosion

Chapter XI.M2, "Water 

Chemistry" and, 

Monitoring of the spent 

fuel pool water level in 

accordance with 

technical specifications 

and leakage from the 

leak chase channels.

No Treated water or Treated 

borated water environment 

is a more accurate 

description of spent fuel 

pool environment.

The AMP column was 

revised to provide more 

information on verification 

of water chemistry by 

monitoring leakage from 

the leak chase channel.

T-15Concrete: 

Exterior above 

and below 

grade; 

foundation

III.A6.1-a Reinforced 

concrete

Air-outdoor Loss of material 

(spalling, scaling) 

and cracking/ 

freeze-thaw

Chapter XI.S7, 

“Regulatory Guide 1.127, 

Inspection of WaterControl Structures 

Associated with Nuclear 

Power Plants” or the 

FERC / US Army Corp of 

Engineers dam 

inspections and 

Yes, for 

inaccessible 

areas of 

plants located 

in moderate 

to severe 

weathering 

conditions

Text in the AMP column 

was made consistent with 

other chapters of the GALL 

Report and the approved 

ISG-3. Documented 

evidence exists in 

NUREG-1557 that based 

on initial and subsequent 

inspections of concrete 
October 2005 157 NUREG-1833

IIIB. Changes in Existing AM R Line-Items related to Structures and Component Supports (Chapter III in GALL Vol. 2)

Item

Structures 

and/or 

Components

GALL 

Rev. 0

Item 

Number

Material Environment Aging Effect/ 

Mechanism

Aging Management 

Program

Further 

Evaluation

Recommended

Basis for Change

maintenance

Accessible Areas: 

Inspections performed 

in accordance with 

Chapter XI.S7, 

“Regulatory Guide 

1.127, Inspection of 

Water-Control 

Structures Associated 

with Nuclear Power 

Plants” or the FERC / 

US Army Corp of 

Engineers dam 

inspections and 

maintenance programs 

will indicate the 

presence of loss of 

material (spalling, 

scaling) and cracking 

due to freeze-thaw. 

Inaccessible Areas: As 

described in NUREG1557, freeze-thaw does 

not cause loss of material 

from reinforced concrete 

in foundations, or in

above- and below-grade 

exterior concrete, for 

plants located in a 

geographic region of 

negligible weathering 

conditions (weathering 

that had air content of 3% 

to 6%, these inspections 

did not show any 

degradation related to 

freeze thaw.

The FE column was 

revised to clarify the 

conditions where further 

evaluation is 

recommended and to 

make it consistent with 

other Chapter II and 

Chapter III line-items with 

the same 

material/environment/aging 

effect combination.

If the applicant meets the 

conditions specified in the 

AMP column for 

inaccessible areas, then 

no specific AMP is 

necessary to manage this 

aging effect. However,

opportunistic inspections 

are recommended.
NUREG/CR-183

3 158 October 2005

IIIB. Changes in Existing AM R Line-Items related to Structures and Component Supports (Chapter III in GALL Vol. 2)

Item

Structures 

and/or 

Components

GALL 

Rev. 0

Item 

Number

Material Environment Aging Effect/ 

Mechanism

Aging Management 

Program

Further 

Evaluation

Recommended

Basis for Change

index <100 day-inch/yr). 

Loss of material from 

such concrete is not 

significant at plants 

located in areas in which 

weathering conditions are 

severe (weathering index 

>500 day-inch/yr) or 

moderate (100-500 dayinch/yr), provided that the 

concrete mix design 

meets the air content 

(entrained air 3-6%) and 

water-to-cement ratio 

(0.35-0.45) specified in 

ACI 318-63 or ACI 349-

85. Therefore, if these

conditions are satisfied, 

aging management is not 

necessary. 

The weathering index is 

defined in ASTM C33-90, 

Table 3, Footnote E. Fig. 

1 of ASTM C33-90 

illustrates the various 

weathering index regions 

throughout the U.S.

T-16Concrete: 

Exterior above 

and below 

grade; 

foundation; 

interior slab

III.A6.1-b Reinforced 

concrete

Water-flowing Increase in 

porosity and 

permeability, loss 

of strength/ 

leaching of 

calcium 

hydroxide

Chapter XI.S7, 

“Regulatory Guide 1.127, 

Inspection of WaterControl Structures 

Associated with Nuclear 

Power Plants” or the 

FERC / US Army Corp of 

Yes, if 

concrete was 

not 

constructed 

as stated for 

inaccessible 

areas

Text in the AMP column 

was made consistent with 

other chapters of the GALL

Report and approved ISG3. The FE column was 

revised to clarify the 

conditions where further 
October 2005 159 NUREG-1833

IIIB. Changes in Existing AM R Line-Items related to Structures and Component Supports (Chapter III in GALL Vol. 2)

Item

Structures 

and/or 

Components

GALL 

Rev. 0

Item 

Number

Material Environment Aging Effect/ 

Mechanism

Aging Management 

Program

Further 

Evaluation

Recommended

Basis for Change

Engineers dam 

inspections and 

maintenance programs

Accessible Areas: 

Inspections performed 

in accordance with 

Chapter XI.S7, 

“Regulatory Guide 

1.127, Inspection of 

Water-Control 

Structures Associated 

with Nuclear Power 

Plants” or the FERC / 

US Army Corp of 

Engineers dam 

inspections and 

maintenance programs 

will indicate the 

presence of Increase in 

porosity and 

permeability, loss of 

strength/ leaching of 

calcium hydroxide 

Inaccessible Areas: 

As described in NUREG1557, leaching of calcium 

hydroxide from reinforced 

concrete becomes 

significant only if the 

concrete is exposed to 

flowing water. Even if 

reinforced concrete is 

evaluation is 

recommended and to 

make it consistent with 

other Chapter II and 

Chapter III line-items with 

the same MEA 

combination.
NUREG/CR-183

3 160 October 2005

IIIB. Changes in Existing AM R Line-Items related to Structures and Component Supports (Chapter III in GALL Vol. 2)

Item

Structures 

and/or 

Components

GALL 

Rev. 0

Item 

Number

Material Environment Aging Effect/ 

Mechanism

Aging Management 

Program

Further 

Evaluation

Recommended

Basis for Change

exposed to flowing water, 

such leaching is not 

significant if the concrete 

is constructed to ensure 

that it is dense, wellcured, has low 

permeability, and that 

cracking is well 

controlled. Cracking is 

controlled through proper 

arrangement and 

distribution of reinforcing 

bars. All of the above 

characteristics are 

assured if the concrete 

was constructed with the 

guidance of ACI 201.2R. 

Therefore, if these 

conditions are satisfied, 

aging management is not 

necessary.

T-17Concrete:

All

III.A6.1-c Reinforced 

concrete

Any Cracking due to 

expansion/ 

reaction with 

aggregates

Chapter XI.S7, 

“Regulatory Guide 1.127, 

Inspection of WaterControl Structures 

Associated with Nuclear 

Power Plants” or the 

FERC / US Army Corp of 

Engineers dam 

inspections and 

maintenance programs.

Accessible Areas: 

Inspections/evaluations 

Yes, if 

concrete was 

not 

constructed 

as stated for 

inaccessible 

areas

Text in the AMP column 

was made consistent with 

other chapters of the GALL

Report and approved ISG3. The FE column was 

revised to clarify the 

conditions where further 

evaluation is 

recommended and to 

make it consistent with 

other Chapter II and 

Chapter III line-items with 

the same MEA 
October 2005 161 NUREG-1833

IIIB. Changes in Existing AM R Line-Items related to Structures and Component Supports (Chapter III in GALL Vol. 2)

Item

Structures 

and/or 

Components

GALL 

Rev. 0

Item 

Number

Material Environment Aging Effect/ 

Mechanism

Aging Management 

Program

Further 

Evaluation

Recommended

Basis for Change

performed in 

accordance with 

“Regulatory Guide 

1.127, Inspection of 

Water-Control 

Structures Associated 

with Nuclear Power 

Plants” or the FERC / 

US Army Corp of 

Engineers dam 

inspections and 

maintenance programs 

will indicate the 

presence of expansion 

and cracking due to 

reaction with 

aggregates. 

Inaccessible areas: 

As described in NUREG1557, investigations, 

tests, and petrographic 

examinations of 

aggregates performed in 

accordance with ASTM 

C295-54 or ASTM C227-

50 can demonstrate that 

those aggregates do not 

react within reinforced 

concrete. For potentially 

reactive aggregates, 

aggregate-reinforced

concrete reaction is not 

significant if the concrete 

combination.

Use of ACI 201.2R-77 or 

later revision is acceptable.
NUREG/CR-183

3 162 October 2005

IIIB. Changes in Existing AM R Line-Items related to Structures and Component Supports (Chapter III in GALL Vol. 2)

Item

Structures 

and/or 

Components

GALL 

Rev. 0

Item 

Number

Material Environment Aging Effect/ 

Mechanism

Aging Management 

Program

Further 

Evaluation

Recommended

Basis for Change

was constructed in 

accordance with ACI 

201.2R. Therefore, if 

these conditions are 

satisfied, aging 

management is not 

necessary.

T-18Concrete:

All

III.A6.1-d Reinforced 

concrete

Air-indoor 

uncontrolled or 

air-outdoor

Cracking, loss of 

bond, and loss of 

material (spalling, 

scaling)/ 

corrosion of 

embedded steel

Chapter XI.S7, 

“Regulatory Guide 

1.127, Inspection of 

Water-Control 

Structures Associated 

with Nuclear Power 

Plants” or the FERC / 

US Army Corp of 

Engineers dam 

inspections and 

maintenance programs.

Accessible areas:

As described in 

NUREG-1557, corrosion 

of exterior above-grade 

and interior embedded 

steel is not significant if 

the steel is not exposed 

to an aggressive 

environment (concrete 

pH <11.5 or chlorides 

>500 ppm). If such steel 

is exposed to an 

aggressive 

environment, corrosion 

is not significant if the 

Yes, plantspecific if 

environment 

is aggressive

Text in the AMP column 

was made consistent with 

other chapters of the GALL

Report and approved ISG3. The FE column was 

revised to clarify the 

conditions where further 

evaluation is 

recommended and to 

make it consistent with 

other Chapter II and

Chapter III line-items with 

the same MEA 

combination.
October 2005 163 NUREG-1833

IIIB. Changes in Existing AM R Line-Items related to Structures and Component Supports (Chapter III in GALL Vol. 2)

Item

Structures 

and/or 

Components

GALL 

Rev. 0

Item 

Number

Material Environment Aging Effect/ 

Mechanism

Aging Management 

Program

Further 

Evaluation

Recommended

Basis for Change

concrete in which the 

steel is embedded has 

a low water-to-cement 

ratio (0.35-0.45), 

adequate air 

entrainment (3-6%), low 

permeability, and is 

designed in accordance 

with ACI 318-63 or ACI

349-85. Therefore, if 

these conditions are 

satisfied, aging 

management is not 

necessary.

Inaccessible areas: 

For plants with nonaggressive ground 

water/soil; i.e. pH > 5.5, 

chlorides < 500 ppm, or 

sulfates <1500 ppm, as 

a minimum, consider 

(1) Examination of the 

exposed portions of the 

below grade concrete, 

when excavated for any 

reason, and (2) Periodic 

monitoring of belowgrade water chemistry, 

including consideration 

of potential seasonal 

variations. For plants 

with aggressive 

groundwater/soil, 
NUREG/CR-183

3 164 October 2005

IIIB. Changes in Existing AM R Line-Items related to Structures and Component Supports (Chapter III in GALL Vol. 2)

Item

Structures 

and/or 

Components

GALL 

Rev. 0

Item 

Number

Material Environment Aging Effect/ 

Mechanism

Aging Management 

Program

Further 

Evaluation

Recommended

Basis for Change

and/or where the 

concrete structural 

elements have 

experienced 

degradation, a plant 

specific AMP 

accounting for the 

extent of the 

degradation 

experienced should be 

implemented to 

manage the concrete 

aging during the period 

of extended operation.

T-19Concrete:

All

III.6A.1-e Reinforced 

concrete

Groundwater/soil Increase in 

porosity and 

permeability, 

cracking, loss of 

material (spalling, 

scaling)/ 

aggressive 

chemical attack

Chapter XI.S7, 

“Regulatory Guide 

1.127, Inspection of 

Water-Control 

Structures Associated 

with Nuclear Power 

Plants” or the FERC / 

US Army Corp of 

Engineers dam 

inspections and 

maintenance programs. 

Accessible Areas: 

Inspections performed 

in accordance with 

“Regulatory Guide 

1.127, Inspection of 

Water-Control 

Structures Associated 

with Nuclear Power 

Yes, plantspecific if 

environment 

is aggressive

Text in the AMP column 

was made consistent with 

other chapters of the GALL

Report and approved ISG3. The FE column was 

revised to clarify the 

conditions where further 

evaluation is 

recommended and to 

make it consistent with 

other Chapter II and 

Chapter III line-items with 

the same MEA 

combination.
October 2005 165 NUREG-1833

IIIB. Changes in Existing AM R Line-Items related to Structures and Component Supports (Chapter III in GALL Vol. 2)

Item

Structures 

and/or 

Components

GALL 

Rev. 0

Item 

Number

Material Environment Aging Effect/ 

Mechanism

Aging Management 

Program

Further 

Evaluation

Recommended

Basis for Change

Plants” or the FERC / 

US Army Corp of 

Engineers .

the presence of 

increase in porosity 

and permeability, 

cracking, or loss of 

material (spalling, 

scaling) due to 

aggressive chemical 

attack. 

Inaccessible areas: For 

plants with nonaggressive ground 

water/soil; i.e. pH > 5.5, 

chlorides < 500 ppm, or 

sulfates <1500 ppm, as 

a minimum, consider: 

(1) Examination of the 

exposed portions of the 

below grade concrete, 

when excavated for any 

reason, and (2) Periodic 

monitoring of belowgrade water chemistry, 

including consideration 

of potential seasonal 

variations. For plants 

with aggressive 

groundwater/soil, 

and/or where the 

concrete structural 

elements have 
NUREG/CR-183

3 166 October 2005

IIIB. Changes in Existing AM R Line-Items related to Structures and Component Supports (Chapter III in GALL Vol. 2)

Item

Structures 

and/or 

Components

GALL 

Rev. 0

Item 

Number

Material Environment Aging Effect/ 

Mechanism

Aging Management 

Program

Further 

Evaluation

Recommended

Basis for Change

experienced 

degradation, a plant 

specific AMP 

accounting for the 

extent of the 

degradation 

experienced should be 

implemented to 

manage the concrete 

aging during the period 

of extended operation.

T-21Metal 

components:

all structural 

members

III.A6.2-a Steel,

Copper 

alloys

Air – indoor 

uncontrolled or 

air - outdoor; 

Water – flowing 

or water –

standing

Loss of material/ 

general (steel 

only), pitting and 

crevice corrosion

Chapter XI.S7, 

“Regulatory Guide 

1.127, Inspection of 

Water-Control 

Structures Associated 

with Nuclear Power 

Plants” or the FERC / 

US Army Corp of 

Engineers dam 

inspections and 

maintenance programs. 

If protective coatings 

are relied upon to 

manage the effects of 

aging, this AMP is to 

include provisions to 

address protective 

coating monitoring and 

maintenance.

No Added the environment of 

flowing or standing water 

for items such as sheet 

piles and gates.

T-29Building 

concrete at 

locations of 

expansion and 

III.B1.1.4-

a 

III.B1.2.3-

a 

Reinforced 

concrete;

Grout

Air-indoor 

uncontrolled or 

air-outdoor

Reduction in 

concrete anchor 

capacity due to 

local concrete 

Chapter XI.S6, 

“Structures Monitoring 

Program”

Yes, if not 

within the 

scope of the 

applicant’s 

The FE column was 

revised to clarify the 

conditions where further 

evaluation is 
October 2005 167 NUREG-1833

IIIB. Changes in Existing AM R Line-Items related to Structures and Component Supports (Chapter III in GALL Vol. 2)

Item

Structures 

and/or 

Components

GALL 

Rev. 0

Item 

Number

Material Environment Aging Effect/ 

Mechanism

Aging Management 

Program

Further 

Evaluation

Recommended

Basis for Change

grouted 

anchors; grout 

pads for 

support base 

plates

III.B1.3.3-

a 

III.B2.2-a 

III.B3.2-a 

III.B4.3-a 

III.B5.2-a

degradation/ 

service-induced 

cracking or other 

concrete aging 

mechanisms

structures 

monitoring 

program

recommended.

T-30Support 

members; 

welds; bolted 

connections; 

support 

anchorage to 

building 

structure

III.B2.1-a 

III.B3.1-a 

III.B4.1-a 

III.B5.1-a

Steel Air – indoor 

uncontrolled or 

air – outdoor

Loss of material/ 

general and 

pitting corrosion

Chapter XI.S6, 

“Structures Monitoring 

Program”

Yes, if not 

within the 

scope of the 

applicant’s 

structures 

monitoring 

program

The FE column was 

revised to clarify the 

conditions where further 

evaluation is 

recommended.

T-31Vibration 

isolation 

elements

III.B4.2-a Nonmetallic 

(e.g., 

Rubber)

Air – indoor 

uncontrolled or 

air – outdoor

Reduction or loss 

of isolation 

function/ radiation 

hardening, 

temperature, 

humidity, 

sustained 

vibratory loading

Chapter XI.S6, 

“Structures Monitoring 

Program”

Yes, if not 

within the 

scope of the 

applicant’s 

structures 

monitoring 

program

The FE column was 

revised to clarify the 

conditions where further 

evaluation is 

recommended.

T-32Sliding 

surfaces

III.B1.1.3-

a 

III.B1.2.2-

a 

III.B1.3.2-

a

Lubrite® Air–indoor 

uncontrolled or 

air–outdoor

Loss of 

mechanical 

function/ 

corrosion, 

distortion, dirt, 

overload, 

fatigue due to 

vibratory and 

cyclic thermal 

loads

Chapter XI.S3, “ASME 

Section XI, Subsection 

IWF”

No Split up component type 

from T-28 into three 

separate line-items. This 

makes it consistent with 

GALL Report Chapter 

III.B4. Deleted "elastomer 

hardening" as an aging 

mechanism. These 

component types do not 

include elastomeric

materials.
NUREG/CR-183

3 168 October 2005

IIIB. Changes in Existing AM R Line-Items related to Structures and Component Supports (Chapter III in GALL Vol. 2)

Item

Structures 

and/or 

Components

GALL 

Rev. 0

Item 

Number

Material Environment Aging Effect/ 

Mechanism

Aging Management 

Program

Further 

Evaluation

Recommended

Basis for Change

T-33Vibration 

isolation 

elements

III.B1.1.3-

a 

III.B1.2.2-

a 

III.B1.3.2-

a

Nonmetallic 

(e.g., 

Rubber)

Air–indoor 

uncontrolled or 

air–outdoor

Reduction or 

loss of isolation 

function/ 

radiation 

hardening, 

temperature, 

humidity, 

sustained 

vibratory 

loading

Chapter XI.S3, “ASME 

Section XI, Subsection 

IWF”

No Split up component type 

from T-28 into three 

separate line-items. This 

makes it consistent with 

GALL Report Chapter 

III.B4. 
October 2005 169 NUREG-1833

III.C Reactor Vessels, Internals, and Reactor Coolant Systems

Table III.C presents the changes made to existing AMR line-items for reactor vessels, internals, and reactor coolant systems.

IIIC. Changes in Existing AMR Line-Items related to Reactor Vessels, Internals, and Reactor Coolant Systems (Chapter IV in GALL Vol. 2)

Item

GALL 

Rev.0 Item 

Number

Material Environment Aging Effect/ 

Mechanism

Aging Management 

Program

Further Evaluation

Recommended Basis for Change

R-01

R-06

R-88

R-89

IV.D1.1-I

IV.D1.1-j

IV.D2.1-h

IV.C2.5-k 

IV.C2.5-s

IV.C2.5-m

IV. A2.6-a

IV.A2.7-a

Nickel alloy; 

steel with 

nickel-alloy 

cladding

Reactor 

coolant

Cracking/ primary 

water stress 

corrosion 

cracking

Chapter XI.M1, “ASME 

Section XI Inservice 

Inspection, Subsections 

IWB, IWC, and IWD” for 

Class 1 components, 

and Chapter XI.M2, 

“Water Chemistry,” for 

PWR primary water and 

for nickel alloy, comply 

with applicable NRC 

Orders and provide a 

commitment in the 

FSAR supplement to 

implement applicable (1) 

Bulletins and Generic 

Letters and (2) staffaccepted industry 

guidelines

No, but licensee 

commitments to be 

confirmed

The AMP was changed from 

requiring a plant-specific 

program to calling out XI.M1 

and XI.M2 explicitly, as 

supplemented by the actions 

(identified in Orders, Bulletins, 

and Generic Letters ) that are 

associated with recent 

experience with primary water 

stress corrosion cracking in 

nickel alloy components. These 

sources provide more precise 

guidance on what would 

constitute an acceptable plant 

specific AMP. The Staff

position would encompass 

ISGs and branch technical 

positions published in other 

regulatory guidance 

documents. If alloy 600 or its 

associated weld materials 

(alloy 82/182) is used, the Staff

has requested a commitment in 

the FSAR supplement as 

stated.

Also, added to the further 

evaluation column the 

recommendation for the 

licensee commitment to be 
NUREG-1833 170 October 2005

IIIC. Changes in Existing AMR Line-Items related to Reactor Vessels, Internals, and Reactor Coolant Systems (Chapter IV in GALL Vol. 2)

Item

GALL 

Rev.0 Item 

Number

Material Environment Aging Effect/ 

Mechanism

Aging Management 

Program

Further Evaluation

Recommended Basis for Change

confirmed.

R-02 IV.C2.1-g 

IV.C2.2-h 

Stainless 

steel; steel 

with 

stainless 

steel 

cladding

Reactor 

coolant

Cracking/ stress 

corrosion 

cracking, 

thermal and 

mechanical 

loading

Chapter XI.M1, “ASME 

Section XI Inservice 

Inspection, Subsections 

IWB, IWC, and IWD,” for 

Class 1 components, 

and Chapter XI.M2, 

“Water Chemistry,” for 

PWR water and XI.M35, 

"One-Time Inspection of 

ASME Code Class 1 

Small-bore Piping"

No In GALL Rev. 0, both IV C2.1-g 

and IV C2.2-h addressed Class 

1 piping, fittings and branch 

connections < NPS 4 for the 

PWR reactor coolant systems 

and connected lines. Smallbore RCS piping in PWR 

reactor coolant systems and 

connected lines are generally 

stainless steel. Cracking of 

these components is managed 

by the same AMPs regardless 

of whether the mechanisms are 

SCC or thermal and 

mechanical loading. The 

addition of AMP XI.M35 for 

small bore piping in GALL Rev. 

1 provides specific guidance 

and replaces the prior need for 

a plant specific AMP. As a 

result of this change, the 

Further Evaluation column was 

changed to “No.”

R-03 IV.C1.1-i Stainless 

steel; steel

Reactor 

coolant

Cracking/ stress 

corrosion 

cracking, 

intergranular 

stress corrosion 

cracking (for 

stainless steel 

only), and 

thermal and 

mechanical 

Chapter XI.M1, “ASME 

Section XI Inservice 

Inspection, Subsections 

IWB, IWC, and IWD,” for 

Class 1 components, 

and Chapter XI.M2, 

“Water Chemistry,” for 

BWR water and XI.M35, 

"One-Time Inspection of 

ASME Code Class 1 

No In GALL Rev. 0, the AMR lineitem IV C1.1-i addressed Class 

1 piping, fittings and branch 

connections < NPS 4 for the 

BWR reactor coolant pressure 

boundary. Cracking of these 

components is managed by the 

same AMPs regardless of 

whether the mechanisms are 

SCC or thermal and 
October 2005 171 NUREG-1833

IIIC. Changes in Existing AMR Line-Items related to Reactor Vessels, Internals, and Reactor Coolant Systems (Chapter IV in GALL Vol. 2)

Item

GALL 

Rev.0 Item 

Number

Material Environment Aging Effect/ 

Mechanism

Aging Management 

Program

Further Evaluation

Recommended Basis for Change

loading Small-bore Piping" mechanical loading. The 

addition of AMP XI.M35 for 

small bore piping in GALL Rev. 

1 provides specific guidance 

and replaces the prior need for 

a plant specific AMP. As a 

result of this change, the 

Further Evaluation column was 

changed to “No.”

R-04 IV.A1.1-b 

IV.A1.2-a 

IV.A1.2-b 

IV.A1.3-a 

IV.A1.3-d 

IV.A1.4-b 

IV.A1.5-b 

IV.A1.6-a

Steel; 

stainless 

steel; steel 

with 

nickelalloy or 

stainless 

steel 

cladding; 

nickelalloy

Reactor 

coolant

Cumulative 

fatigue damage/ 

fatigue

Fatigue is a time-limited 

aging analysis (TLAA) to 

be performed for the 

period of extended 

operation, and, for Class 1 

components, 

environmental effects on 

fatigue are to be 

addressed. See the 

Standard Review Plan, 

Section 4.3 “Metal 

Fatigue,” for acceptable 

methods for meeting the 

requirements of 10 CFR 

54.21(c)(1).

Yes, TLAA The Staff decided it was 

appropriate to split R-04 into 6 

separate items. 

• R-04 which includes (for 

BWRs) the IV.A1 links and 

the components defined as 

BWR vessel components: 

flanges; nozzles; 

penetrations; safe ends; 

thermal sleeves, vessel 

shells, heads, and welds.

• R-219 which includes (for 

PWRs) the IV.A2 links and 

the PWR Reactor vessel 

components defined as: 

flanges, nozzles; 

penetrations; pressure 

housings; safe ends, 

thermal sleeves, vessel 

shells, heads and welds. 

• R-220 which includes (for 

BWRs) the IV.C1 links and 

the components defined as

piping, piping components, 

and piping elements.
NUREG-1833 172 October 2005

IIIC. Changes in Existing AMR Line-Items related to Reactor Vessels, Internals, and Reactor Coolant Systems (Chapter IV in GALL Vol. 2)

Item

GALL 

Rev.0 Item 

Number

Material Environment Aging Effect/ 

Mechanism

Aging Management 

Program

Further Evaluation

Recommended Basis for Change

• R-223 which includes (for 

PWRs) the IV.C2 links and 

the components defined as: 

piping, piping components, 

and piping elements; 

flanges; nozzles and safe 

ends; pressurizer vessel 

shell heads and welds; 

heater sheaths and 

sleeves; penetrations; and 

thermal sleeves

• R-221 which includes IV.D1 

link and the components 

defined as recirculating 

steam generator 

components: flanges; 

penetrations; nozzles; safe 

ends, lower heads and 

welds.

• R-222 which includes IV.D2 

link and the components 

defined as: once-through

steam generator 

components: primary side 

nozzles; safe ends and 

welds

R-05 IV.C2.1-e 

IV.C2.2-g 

IV.C2.5-i 

Cast 

austenitic 

stainless 

steel

Reactor 

coolant

Cracking/ stress 

corrosion 

cracking

Monitoring and control of 

primary water chemistry in 

accordance with the 

guidelines in EPRI TR -

105714 (Rev. 3 or later) 

minimize the potential of 

SCC, and material 

selection according to 

Yes, plant-specific The environment was changed 

from chemically treated borated 

water to reactor coolant.

The corresponding sections in 

the SRP-LR (3.1.2.2.7 and 

3.1.3.2.7) both discuss the 

potential for cracking due to

stress corrosion cracking (SCC) 
October 2005 173 NUREG-1833

IIIC. Changes in Existing AMR Line-Items related to Reactor Vessels, Internals, and Reactor Coolant Systems (Chapter IV in GALL Vol. 2)

Item

GALL 

Rev.0 Item 

Number

Material Environment Aging Effect/ 

Mechanism

Aging Management 

Program

Further Evaluation

Recommended Basis for Change

NUREG-0313, Rev. 2 

guidelines of =0.035% C 

and =7.5% ferrite reduces 

susceptibility to SCC.

For CASS components 

that do not meet either 

one of the above 

guidelines, a plant-specific 

aging management 

program is to be 

evaluated. The program is 

to include (a) adequate 

inspection methods to 

ensure detection of 

cracks, and (b) flaw 

evaluation methodology 

for CASS components 

that are susceptible to 

thermal aging 

embrittlement.

to occur in ASME Class 1 PWR 

piping, piping components, and 

piping elements fabricated from 

cast austenitic stainless steel 

(CASS). Although NUREG0313 was written in evaluation 

of BWR piping (and not PWR 

piping) its application is being 

extended to cover materials 

selection, alloying chemistry 

and component fabrication 

criteria to CASS piping in PWRdesigned light-water reactors.

R-09 IV.C2.3-b 

IV.C2.4-b 

Stainless 

steel; steel 

with 

stainless 

steel 

cladding

Reactor 

coolant

Cracking/ stress 

corrosion 

cracking

Chapter XI.M1, “ASME 

Section XI Inservice 

Inspection, Subsections 

IWB, IWC, and IWD,” for 

Class 1 components and 

Chapter XI.M2, “Water 

Chemistry,” for PWR 

primary water

No The AMP column was 

simplified to require both the 

water chemistry and the ISI 

AMPs.

In GALL Rev. 0, these AMR 

line-items stipulated stainless 

steel and/or cast austenitic 

stainless steel (CASS) with the 

recommended AMP described 

as "Monitoring and control of 

primary water chemistry in 

accordance with the guidelines 

in EPRI TR-105714 (Rev. 3 or 

later revisions or update) 
NUREG-1833 174 October 2005

IIIC. Changes in Existing AMR Line-Items related to Reactor Vessels, Internals, and Reactor Coolant Systems (Chapter IV in GALL Vol. 2)

Item

GALL 

Rev.0 Item 

Number

Material Environment Aging Effect/ 

Mechanism

Aging Management 

Program

Further Evaluation

Recommended Basis for Change

minimize the potential of stress 

corrosion cracking and material 

selection according to the 

NUREG-0313, Rev. 2 

guidelines of =0.035% C and 

=7.5% ferrite reduces 

susceptibility to SCC.”

For CASS components that do 

not meet either one of the 

above guidelines, an aging 

management program should 

conform to Chapter XI.M1, 

"ASME Section XI, Subsections 

IWB, IWC, and IWD.” (In other 

words, this is fundamentally a 

combination of GALL AMPs 

XI.M2 and XI.M1)

In GALL Rev. 1, it was 

acknowledged that, with the 

exception of the loss of fracture 

toughness due to thermal and 

neutron irradiation 

embrittlement, CASS and 

stainless steel share the same 

aging effects/mechanisms and 

AMPs in GALL. The change to 

the AMP column effectively 

recommends both the first 

provision (water chemistry, 

XI.M2) of the GALL Rev. 0

entry, and conservatively 

applies the ISI AMP (XI.M1).
October 2005 175 NUREG-1833

IIIC. Changes in Existing AMR Line-Items related to Reactor Vessels, Internals, and Reactor Coolant Systems (Chapter IV in GALL Vol. 2)

Item

GALL 

Rev.0 Item 

Number

Material Environment Aging Effect/ 

Mechanism

Aging Management 

Program

Further Evaluation

Recommended Basis for Change

R-12

R-80

R-27

R-32

IV.C2.3-g 

IV.C2.4-g 

IV.C2.5-p 

IV.A2.2-g

IV.C1.2-e 

IV.C1.3-f 

IV.D1.1-f 

IV.D2.1-k 

Low-alloy 

steel, 

stainless 

steel

Low-alloy 

steel SA 

193 Gr. B7

Steel

Air with 

reactor 

coolant 

leakage

System 

temperature 

up to 288°C 

(550°F)

System 

temperature 

up to 340°C 

(644°F)

Loss of preload/ 

thermal effects, 

gasket creep, 

and selfloosening

Chapter XI.M18, “Bolting 

Integrity”

No The aging effect/mechanism 

was revised to describe a more 

precise description of the loss 

of preload aging effect and to 

be consistent with changes to 

the definitions in Chapter IX.

The AMP continues to provide 

an acceptable means of 

managing aging of these 

components for this revised 

MEAP.

R-16 IV.C1.4-b Stainless 

steel; steel

Reactor 

coolant

Loss of material/ 

general (steel 

only), pitting and 

crevice corrosion

Chapter XI.M2, “Water 

Chemistry,” for BWR 

water

The AMP is to be 

augmented by verifying 

the effectiveness of 

water chemistry control. 

See Chapter XI.M32, 

“One-Time Inspection,” 

for an acceptable 

verification program.

Yes, detection of aging 

effects is to be 

evaluated

The AMP was revised from 

XI.M1 (ISI) and XI.M32 to 

XI.M2 and M32. This revision 

and the basis for change is 

similar to other rows, such as 

RP-25 and RP-27. The OneTime Inspection is to verify the 

water chemistry program is 

achieving its mitigative 

purpose, to satisfy part 54. 

Although not credited, any 

applicable ASME Section XI ISI 

requirements for these 

components will need to be met 

to satisfy 10 CFR 50.55(a).

R-24 IV.C2.5-j Nickel alloy; 

stainless 

steel

Reactor 

coolant

Cracking/ stress 

corrosion 

cracking, primary 

Chapter XI.M2, “Water 

Chemistry,” and Chapter 

XI.M32 "One-Time 

No, unless licensee 

commitment needs to 

be confirmed

The AMP was revised from 

plant-specific to AMPS XI.M2 

and M32. The AMP was 
NUREG-1833 176 October 2005

IIIC. Changes in Existing AMR Line-Items related to Reactor Vessels, Internals, and Reactor Coolant Systems (Chapter IV in GALL Vol. 2)

Item

GALL 

Rev.0 Item 

Number

Material Environment Aging Effect/ 

Mechanism

Aging Management 

Program

Further Evaluation

Recommended Basis for Change

water stress 

corrosion 

cracking

Inspection" and, for 

nickel alloy welded 

spray heads, comply 

with applicable NRC 

Orders and provide a 

commitment in the 

FSAR supplement to 

implement applicable (1) 

Bulletins and Generic 

Letters and (2) staffaccepted industry 

guidelines. 

changed to explicitly call out 

the actions identified by Orders, 

Bulletins, and Generic Letters 

associated with recent 

experience with nickel alloys to 

provide more precise guidance 

on what would constitute an 

acceptable AMP. The Staff

position would encompass 

ISGs and branch technical 

positions published in other 

regulatory guidance 

documents. If alloy 600 or its 

associated weld materials 

(alloy 82/182) is used, the Staff

has requested a commitment in 

the FSAR supplement as 

stated. Also, added to the 

further evaluation column the 

recommendation for the

licensee commitment to be 

confirmed.

In Staff’s SE on WCAP-14574, 

License Renewal Evaluation: 

Aging Management Evaluation 

for Pressurizers (July 1996), 

the Staff did not identify 

pressurizer spray heads as 

passive, long-lived components 

that are within the scope of 

license renewal. Furthermore, 

the scoping and screening 

processes for pressurizer spray 
October 2005 177 NUREG-1833

IIIC. Changes in Existing AMR Line-Items related to Reactor Vessels, Internals, and Reactor Coolant Systems (Chapter IV in GALL Vol. 2)

Item

GALL 

Rev.0 Item 

Number

Material Environment Aging Effect/ 

Mechanism

Aging Management 

Program

Further Evaluation

Recommended Basis for Change

heads in previous PWR 

applications have not always 

identified that pressurizer spray 

heads are within the scope of 

license renewal as passive 

long-lived components nor has 

the Reactor System Branch 

(SXRB) of the Division of 

Safeguards and Safety 

Analysis always required 

pressurizer spray heads to be 

within the scope of license 

renewal. A PWR license 

renewal applicant can take an 

exception to these items if their 

position is that the pressurizer 

spray heads within their 

facilities are not within the 

scope of license renewal. Such 

an exception will need to be 

justified to the satisfaction of 

the RLEP or SXRB Staff

performing the scoping and 

screening review for the 

application. This scoping 

discussion also applies to R-52 

for pressurizer spray heads.

R-35 IV.D2.1-a Steel with 

stainless 

steel or 

nickel alloy 

cladding

Reactor 

coolant

Cracking/ stress 

corrosion 

cracking, primary 

water stress 

corrosion 

cracking

Chapter XI.M1, “ASME 

Section XI Inservice 

Inspection, Subsections 

IWB, IWC, and IWD” for 

Class 1 components, 

and Chapter XI.M2, 

“Water Chemistry,” for 

PWR primary water and, 

No, but licensee 

commitments to be 

confirmed

The AMP was changed to 

explicitly call out the actions 

identified by Orders, Bulletins, 

and Generic Letters associated 

with recent experience with 

nickel alloys to provide more 

precise guidance on what 

would constitute an acceptable 
NUREG-1833 178 October 2005

IIIC. Changes in Existing AMR Line-Items related to Reactor Vessels, Internals, and Reactor Coolant Systems (Chapter IV in GALL Vol. 2)

Item

GALL 

Rev.0 Item 

Number

Material Environment Aging Effect/ 

Mechanism

Aging Management 

Program

Further Evaluation

Recommended Basis for Change

for nickel alloy, comply 

with applicable NRC 

Orders and provide a 

commitment in the 

FSAR supplement to 

implement applicable (1) 

Bulletins and Generic 

Letters and (2) staffaccepted industry 

guidelines.

AMP. The Staff position would 

encompass ISGs and branch 

technical positions published in 

other regulatory guidance 

documents. If alloy 600 or its 

associated weld materials 

(alloy 82/182) is used, the Staff

has requested a commitment in 

the FSAR supplement as 

stated. Also, added to the 

further evaluation column the 

recommendation for the 

licensee commitment to be 

confirmed.

R-41 IV.D1.2-h Steel Secondary 

feedwater/

steam

Wall 

thinning/flowaccelerated 

corrosion

Chapter XI.M19, “Steam 

Generator Tubing 

Integrity” and Chapter 

XI.M2, “Water 

Chemistry,” for PWR 

secondary water

No The AMP was changed from 

plant-specific to AMP XI.M19. 

As part of the GALL Rev. 1

revision, XI.M19 was revised to 

identify recent experience that 

eliminates the need to verify 

the effectiveness of the AMP,

and consequently, the further 

evaluation column was 

changed to “No.”

R-42 IV.D1.2-k Steel Secondary 

feedwater/

steam

Ligament 

cracking/ 

corrosion

Chapter XI.M19, “Steam 

Generator Tubing 

Integrity” and Chapter 

XI.M2, “Water Chemistry,” 

for PWR secondary water

No The AMP and further 

evaluation columns in GALL 

Rev. 0 required a review of the 

effectiveness of XI.M19. As 

part of the GALL Rev. 1

revision, XI.M19 was revised to 

identify recent experience that 

eliminates the need to verify 

the effectiveness of the AMP 

and consequently, the further 
October 2005 179 NUREG-1833

IIIC. Changes in Existing AMR Line-Items related to Reactor Vessels, Internals, and Reactor Coolant Systems (Chapter IV in GALL Vol. 2)

Item

GALL 

Rev.0 Item 

Number

Material Environment Aging Effect/ 

Mechanism

Aging Management 

Program

Further Evaluation

Recommended Basis for Change

evaluation column was 

changed to “No.”

R-43 IV.D1.2-g Nickel alloy Secondary 

feedwater/

steam

Denting/ 

corrosion of 

carbon steel tube 

support plate

Chapter XI.M19, “Steam 

Generator Tubing 

Integrity” and Chapter 

XI.M2, “Water Chemistry,” 

for PWR secondary water. 

For plants that could 

experience denting at the 

upper support plates, the 

applicant should evaluate 

potential for rapidly 

propagating cracks and 

then develop and take 

corrective actions 

consistent with Bulletin 

88-02, “Rapidly 

Propagating Cracks in SG 

Tubes."

No The AMP and further 

evaluation columns in GALL

Rev. 0 required a review of the 

effectiveness of XI.M19. As 

part of the GALL Rev. 1

revision, XI.M19 was revised to 

identify recent experience that 

eliminates the need to verify 

the effectiveness of the AMP 

and consequently, the further 

evaluation column was 

changed to “No.”

R-44 IV.D1.2-a

IV.D2.2-a

Nickel alloy Reactor 

coolant

Cracking/ primary 

water stress 

corrosion 

cracking

Chapter XI.M19, “Steam 

Generator Tubing 

Integrity” and Chapter 

XI.M2, “Water Chemistry,” 

for PWR primary water

No The AMP and further 

evaluation columns in GALL 

Rev. 0 required a review of the 

effectiveness of XI.M19. As 

part of the GALL Rev. 1

revision, XI.M19 was revised to 

identify recent experience that 

eliminates the need to verify 

the effectiveness of the AMP 

and consequently, the further 

evaluation column was 

changed to “No.”

R-47 IV.D1.2-b

IV.D2.2-b

Nickel alloy Secondary 

feedwater/ 

steam

Cracking/ outer 

diameter stress 

corrosion 

Chapter XI.M19, “Steam 

Generator Tubing 

Integrity” and Chapter 

No The AMP and further 

evaluation columns in GALL 

Rev. 0 required a review of the 
NUREG-1833 180 October 2005

IIIC. Changes in Existing AMR Line-Items related to Reactor Vessels, Internals, and Reactor Coolant Systems (Chapter IV in GALL Vol. 2)

Item

GALL 

Rev.0 Item 

Number

Material Environment Aging Effect/ 

Mechanism

Aging Management 

Program

Further Evaluation

Recommended Basis for Change

cracking XI.M2, “Water Chemistry,” 

for PWR secondary water

effectiveness of XI.M19. As 

part of the GALL Rev. 1

revision, XI.M19 was revised to 

identify recent experience that 

eliminates the need to verify 

the effectiveness of the AMP 

and consequently, the further 

evaluation column was 

changed to “No.”

R-48 IV.D1.2-c

IV.D2.2-c

Nickel alloy Secondary 

feedwater/ 

steam

Cracking/ 

intergranular 

attack

Chapter XI.M19, “Steam 

Generator Tubing 

Integrity” and Chapter

XI.M2, “Water Chemistry,” 

for PWR secondary water

No The AMP and further 

evaluation columns in GALL 

Rev. 0 required a review of the 

effectiveness of XI.M19. As 

part of the GALL Rev. 1

revision, XI.M19 was revised to 

identify recent experience that 

eliminates the need to verify 

the effectiveness of the AMP 

and consequently, the further 

evaluation column was 

changed to “No.”

R-49 IV.D1.2-e Nickel alloy Secondary 

feedwater

/steam

Loss of material/ 

fretting and wear

Chapter XI.M19, “Steam 

Generator Tubing 

Integrity” and Chapter 

XI.M2, “Water Chemistry,” 

for PWR secondary water

No The AMP and further 

evaluation columns in GALL 

Rev. 0 required a review of the 

effectiveness of XI.M19. As 

part of the GALL Rev. 1

revision, XI.M19 was revised to 

identify recent experience that 

eliminates the need to verify 

the effectiveness of the AMP 

and consequently, the further 

evaluation column was 

changed to “No.”

R-50 IV.D1.2-f Nickel alloy Secondary Loss of material/ Chapter XI.M19, “Steam No The AMP and further 
October 2005 181 NUREG-1833

IIIC. Changes in Existing AMR Line-Items related to Reactor Vessels, Internals, and Reactor Coolant Systems (Chapter IV in GALL Vol. 2)

Item

GALL 

Rev.0 Item 

Number

Material Environment Aging Effect/ 

Mechanism

Aging Management 

Program

Further Evaluation

Recommended Basis for Change

feedwater

/steam

wastage and 

pitting corrosion

Generator Tubing 

Integrity” and Chapter 

XI.M2, “Water Chemistry,” 

for PWR secondary water

evaluation columns in GALL 

Rev. 0 required a review of the 

effectiveness of XI.M19. As 

part of the GALL Rev. 1

revision, XI.M19 was revised to 

identify recent experience that 

eliminates the need to verify 

the effectiveness of the AMP 

and consequently, the further 

evaluation column was 

changed to “No.”

R-75

R-90

IV.A2.2-a

IV.A2.7-b

Nickel alloy Reactor 

coolant

Cracking/ primary 

water stress 

corrosion 

cracking

Chapter XI.M1, “ASME 

Section XI Inservice 

Inspection, Subsections 

IWB, IWC, and IWD,” for 

Class 1 components and 

Chapter XI.M2, “Water 

Chemistry,” for PWR 

primary water and 

Chapter XI.M11-A, 

"Nickel-Alloy 

Penetration Nozzles 

Welded to the Upper 

Reactor Vessel Closure 

Heads of Pressurized 

Water Reactors (PWRs 

Only)"

No The AMP column was revised 

to replace AMP XI.M11, which 

was deleted, with the new AMP 

XI.M11-A

R-98 B1.2-a Stainless 

steel

Reactor 

coolant

Cracking/ stress 

corrosion

cracking, 

intergranular 

stress corrosion 

cracking, 

irradiationChapter XI.M9, “BWR 

Vessel Internals,” for 

top guide and Chapter 

XI.M2, “Water 

Chemistry,” for BWR 

water. Additionally, for 

top guides with neutron 

No Additional information was 

added to the AMP column 

regarding the top guides. The 

Staff wanted to ensure that this 

guidance was followed by 

licensees during the license 

renewal process. IGSCC is a 
NUREG-1833 182 October 2005

IIIC. Changes in Existing AMR Line-Items related to Reactor Vessels, Internals, and Reactor Coolant Systems (Chapter IV in GALL Vol. 2)

Item

GALL 

Rev.0 Item 

Number

Material Environment Aging Effect/ 

Mechanism

Aging Management 

Program

Further Evaluation

Recommended Basis for Change

assisted stress 

corrosion 

cracking

fluence exceeding the 

IASCC threshold (5E20, 

E>lMeV) prior to the 

period of extended 

operation, inspect five 

percent (5%) of the top 

guide locations using 

enhanced visual 

inspection technique, 

EVT-1 within six years 

after entering the period 

of extended operation. 

An additional 5% of the 

top guide locations will 

be inspected within 

twelve years after 

entering the period of 

extended operation. 

Alternatively, if the 

neutron fluence for the 

limiting top guide 

location is projected to 

exceed the threshold for 

IASCC after entering the 

period of extended 

operation, inspect 5% of 

the top guide locations 

(EVT-1) within six years 

after the date projected 

for exceeding the 

threshold. An additional 

5% of the top guide 

locations will be 

inspected within twelve 

concern for neutron fluence 

exceeding a threshold for 5E 

20 MeV.

The extent of the examination 

and its frequency will be based 

on a ten percent sample of the 

total population, which includes 

all grid beam and beam-tobeam crevice slots.
October 2005 183 NUREG-1833

IIIC. Changes in Existing AMR Line-Items related to Reactor Vessels, Internals, and Reactor Coolant Systems (Chapter IV in GALL Vol. 2)

Item

GALL 

Rev.0 Item 

Number

Material Environment Aging Effect/ 

Mechanism

Aging Management 

Program

Further Evaluation

Recommended Basis for Change

years after the date 

projected for exceeding 

the threshold.

The top guide 

inspection locations are 

those that have high 

neutron fluences 

exceeding the IASCC 

threshold.

The extent and 

frequency of 

examination of the top 

guide is similar to the 

examination of the 

control rod drive 

housing guide tube in 

BWRVIP-47.

R-106

R-109

R-116

R-120

R-123

R-130

R-138

R-143

R-146

R-149

R-155

R-159

R-166

R-172

R-173

R-175

IV.B2.1-a

IV.B2.1-e

IV.B2.2-a

IV.B2.3-a

IV.B2.4-a

IV.B2.5-a

IV.B2.5-k

IV.B2.6-a

IV.B3.1-a

IV.B3.2-a

IV.B3.3-a

IV.B3.4-a

IV.B3.5-a

IV.B4.1-a

IV.B4.1-b

IV.B4.2-a

Stainless 

steel, nickel 

alloy

Reactor 

coolant

Cracking/ stress 

corrosion 

cracking, primary 

water stress 

corrosion 

cracking, 

irradiationassisted stress 

corrosion 

cracking

Chapter XI.M2, "Water 

chemistry" for PWR 

primary water. No 

further aging 

management review is 

necessary if the 

applicant provides a 

commitment in the 

FSAR supplement to (1) 

participate in the 

industry programs for 

investigating and 

managing aging effects 

on reactor internals; (2) 

evaluate and implement 

the results of the 

No, but licensee 

commitment to be 

confirmed.

The AMP column was changed 

to delete reference to XI.M16 

(AMP M16 was also deleted 

from the GALL Report) and add 

a commitment to apply industry 

programs to be developed in 

the future for proper 

management of reactor 

internals. The commitment has 

to be provided in the FSAR 

supplement. Also, added to the 

further evaluation column the 

requirement for the licensee 

commitment to be confirmed.
NUREG-1833 184 October 2005

IIIC. Changes in Existing AMR Line-Items related to Reactor Vessels, Internals, and Reactor Coolant Systems (Chapter IV in GALL Vol. 2)

Item

GALL 

Rev.0 Item 

Number

Material Environment Aging Effect/ 

Mechanism

Aging Management 

Program

Further Evaluation

Recommended Basis for Change

R-176

R-180

R-181

R-185

R-193

R-202

R-209

R-214

IV.B4.2-b

IV.B4.3-a

IV.B4.3-b

IV.B4.4-a

IV.B4.5-a

IV.B4.6-a

IV.B4.7-a

IV.B4.8-a

industry programs as 

applicable to the reactor 

internals; and (3) upon 

completion of these 

programs, but not less 

than 24 months before 

entering the period of 

extended operation, 

submit an inspection 

plan for reactor internals 

to the NRC for review 

and approval.

R-107

R-110

R-113

R-117

R-119

R-121

R-124

R-126

R-131

R-134

R-139

R-144

R-147

R-151

R-158

R-160

R-163

R-168

R-174

R-177

R-182

R-187

R-195

IV.B2.1-b

IV.B2.1-f

IV.B2.1-j

IV.B2.2-b

IV.B2.2-e

IV.B2.3-b

IV.B2.4-b

IV.B2.4-d

IV.B2.5-b

IV.B2.5-f

IV.B2.5-l

IV.B2.6-b

IV.B3.1-b

IV.B3.2-c

IV.B3.3-b

IV.B3.4-b

IV.B3.4-f

IV.B3.5-c

IV.B4.1-c

IV.B4.2-c

IV.B4.3-c

IV.B4.4-c

IV.B4.5-c

Stainless 

steel; nickel 

alloy

Reactor 

coolant

Changes in

dimensions/

void

swelling

No further aging 

management review is 

necessary if the 

applicant provides a 

commitment in the 

FSAR supplement to (1) 

participate in the 

industry programs for 

investigating and 

managing aging effects 

on reactor internals; (2) 

evaluate and implement 

the results of the 

industry programs as 

applicable to the reactor 

internals; and (3) upon 

completion of these 

programs, but not less 

than 24 months before 

entering the period of 

extended operation, 

submit an inspection 

plan for reactor internals 

No, but licensee 

commitment to be 

confirmed.

The AMP and further 

evaluation columns in GALL 

Rev. 0 required a plant-specific 

AMP, participation in industry 

programs to investigate aging 

effects and determine an 

appropriate an AMP. 

Otherwise, the applicant was to 

provide the basis for concluding 

that void swelling is not an 

issue for the component. This 

has been replaced with 

requiring a commitment, to be 

provided in the FSAR 

Supplement, to apply industry 

programs that will be 

developed in the future for 

proper management of reactor 

internals. Also, added to the 

further evaluation column the 

requirement for the licensee 

commitment to be confirmed.
October 2005 185 NUREG-1833

IIIC. Changes in Existing AMR Line-Items related to Reactor Vessels, Internals, and Reactor Coolant Systems (Chapter IV in GALL Vol. 2)

Item

GALL 

Rev.0 Item 

Number

Material Environment Aging Effect/ 

Mechanism

Aging Management 

Program

Further Evaluation

Recommended Basis for Change

R-199

R-204

R-211

R-215

IV.B4.5-h

IV.B4.6-c

IV.B4.7-c

IV.B4.8-b

to the NRC for review 

and approval.

R-108

R-114

R-129

R-136

R-137

R-154

R-165

R-184

R-192

R-197

R-201

R-207

R-213

IV.B2.1-d

IV.B2.1-k

IV.B2-4-h

IV.B2.5-h

IV.B2.5-i

IV.B3.2-g

IV.B3.4-h

IV.B4.3-e

IV.B4.4-h

IV.B4.5-e

IV.B4.5-j

IV.B4.6-g

IV.B4.7-e

Stainless 

steel, nickel 

alloy

Reactor 

coolant

Loss of preload/ 

stress relaxation

 No further aging 

management review is 

necessary if the 

applicant provides a 

commitment in the 

FSAR supplement to:

(1) participate in 

industry programs for

investigating and 

managing aging effects 

applicable to Reactor 

Internals, 

(2) evaluate and 

implement the results of 

the industry programs 

as applicable to the 

Reactor Internals design 

and,

(3) upon completion of 

these programs, but not 

less than 24 months 

before entering the 

period of extended 

operation, submit an 

inspection plan for 

reactor internals to the 

NRC for review and 

approval.

No, but licensee 

commitment to be 

confirmed.

The AMP column was changed 

to delete XI.M1, M14, and M15 

(the current versions of the 

latter two AMPs are no longer 

acceptable to NRC and have 

been deleted from GALL Rev. 

1) and instead recommend a 

commitment, to be provided in 

the FSAR Supplement, to apply 

industry programs that will be 

developed in the future for 

proper management of reactor 

internals. Also, added to the 

further evaluation column the 

requirement for this licensee 

commitment to be confirmed.
NUREG-1833 186 October 2005

IIIC. Changes in Existing AMR Line-Items related to Reactor Vessels, Internals, and Reactor Coolant Systems (Chapter IV in GALL Vol. 2)

Item

GALL 

Rev.0 Item 

Number

Material Environment Aging Effect/ 

Mechanism

Aging Management 

Program

Further Evaluation

Recommended Basis for Change

R-122

R-127

R-128

R-132

R-135

R-141

R-157

R-161

R-164

R-169

R-178

R-188

R-196

R-205

R-212

R-216

IV.B2.3-c

IV.B2.4-e

IV.B2.4-f 

IV.B4.5-i

IV.B2.5-c

IV.B2.5-g

IV.B2.5-n

IV.B3.3-a

IV.B3.4-c

IV.B3.4-g

IV.B3.5-d

IV.B4.2-e

IV.B4.4-d

IV.B4.5-d

IV.B4.6-d

IV.B4.7-d

IV.B4.8-c

Stainless 

steel; nickel 

alloy

Reactor 

coolant and 

neutron flux

Loss of fracture 

toughness/ 

neutron 

irradiation 

embrittlement, 

void swelling

 No further aging 

management review is 

necessary if the 

applicant provides a 

commitment in the 

FSAR supplement to (1) 

participate in industry 

programs for 

investigating and 

managing aging effects 

applicable to Reactor 

Internals, (2) evaluate 

and implement the 

results of the industry 

programs as applicable 

to the Reactor Internals 

design and, (3) upon 

completion of these 

programs, but not less 

than 24 months before 

entering the period of 

extended operation, 

submit an inspection 

plan for reactor internals 

to the NRC for review 

and approval.

No, but licensee 

commitment to be 

confirmed.

The AMP column was changed 

to delete reference to XI.M16 

(AMP M16 was also deleted 

from the GALL Report) and 

instead require a commitment 

in the FSAR Supplement to 

apply industry programs to be 

developed in the future for 

proper management of reactor 

internals. Also, added to the 

further evaluation column the 

requirement for the licensee 

commitment to be confirmed.

R-112

R-118

R-125

R-133

R-150

R-162

R-167

R-186

IV.B2.1-i

IV.B2.2-d

IV.B2.4-c, 

IV.B4.5-g

IV.B2.5-e

IV.B3.2-b

IV.B3.4-e

IV.B3.5-b

IV.B4.4-b

Stainless 

steel, nickel 

alloy

Reactor 

coolant

Cracking/ stress 

corrosion 

cracking, primary 

water stress 

corrosion 

cracking, 

irradiationassisted stress 

corrosion 

Chapter XI.M2, "Water 

chemistry" for PWR 

primary water. No 

further aging 

management review is 

necessary if the 

applicant provides a 

commitment in the 

FSAR supplement to (1) 

No, but licensee 

commitment to be 

confirmed

The AMP column was changed 

to delete reference to XI.M16 

(AMP M16 was also deleted 

from the GALL Report) and 

instead require a commitment 

in the FSAR Supplement to 

apply industry programs to be 

developed in the future for 

proper management of reactor 
October 2005 187 NUREG-1833

IIIC. Changes in Existing AMR Line-Items related to Reactor Vessels, Internals, and Reactor Coolant Systems (Chapter IV in GALL Vol. 2)

Item

GALL 

Rev.0 Item 

Number

Material Environment Aging Effect/ 

Mechanism

Aging Management 

Program

Further Evaluation

Recommended Basis for Change

R-194

R-203

R-210

IV.B4.5-b

IV.B4.6-b

IV.B4.7-b

cracking participate in the 

industry programs for 

investigating and 

managing aging effects 

on reactor internals; (2) 

evaluate and implement 

the results of the 

industry programs as 

applicable to the reactor 

internals; and (3) upon 

completion of these 

programs, but not less 

than 24 months before 

entering the period of 

extended operation, 

submit an inspection 

plan for reactor internals 

to the NRC for review 

and approval.

internals. Also, added to the 

further evaluation column the 

requirement for the licensee 

commitment to be confirmed.

R-145 IV.B2.6-c Stainless 

steel with or 

without 

chrome 

plating

Reactor 

coolant

Loss of material/ 

wear

Chapter XI.M37, “Flux 

Thimble Tube 

Inspection"

No The AMP column was revised 

from AMP XI.M1 to AMP 

XI.M37. 

AMP XI.M37 is a program that 

is based on the 

recommendations of NRC 

Bulletin 88-09, "Thimble Tube 

Thinning in Westinghouse 

Reactors." This program was 

created to monitor for thinning 

of the flux thimble tube walls, 

which provide a path for the 

incore neutron flux monitoring 

system detectors and form part 

of the RCS pressure boundary.
NUREG-1833 188 October 2005

IIIC. Changes in Existing AMR Line-Items related to Reactor Vessels, Internals, and Reactor Coolant Systems (Chapter IV in GALL Vol. 2)

Item

GALL 

Rev.0 Item 

Number

Material Environment Aging Effect/ 

Mechanism

Aging Management 

Program

Further Evaluation

Recommended Basis for Change

(See Table IV for additional 

information on AMP XI.M37.)

R-219 IV.A2.1-b 

IV.A2.2-c 

IV.A2.3-c 

IV.A2.4-a 

IV.A2.5-d 

Steel; 

stainless 

steel; steel 

with 

nickelalloy or 

stainless 

steel 

cladding; 

nickelalloy

Reactor 

coolant

Cumulative 

fatigue damage/ 

fatigue

Fatigue is a time-limited 

aging analysis (TLAA) to 

be performed for the 

period of extended 

operation, and, for Class 1 

components, 

environmental effects on 

fatigue are to be 

addressed. See the 

Standard Review Plan, 

Section 4.3 “Metal 

Fatigue,” for acceptable 

methods for meeting the 

requirements of 10 CFR 

54.21(c)(1).

Yes, TLAA The Staff decided it was 

appropriate to split R-04 into 6 

generic items including R-219 

which includes (for PWRs) the 

IV.A2 links and the PWR 

Reactor vessel components 

defined as Flanges, nozzles; 

penetrations; pressure 

housings; safe ends, Thermal 

sleeves, vessel shells, heads 

and welds. 

R-220 IV.C1.1-b 

IV.C1.1-d 

IV.C1.1-e 

IV.C1.1-h 

IV.C1.2-a 

IV.C1.3-d

Steel; 

stainless 

steel; steel 

with 

nickelalloy or 

stainless 

steel 

cladding; 

nickelalloy

Reactor 

coolant

Cumulative 

fatigue damage/ 

fatigue

Fatigue is a time-limited 

aging analysis (TLAA) to 

be performed for the 

period of extended 

operation, and, for Class 1 

components, 

environmental effects on 

fatigue are to be 

addressed. See the 

Standard Review Plan, 

Section 4.3 “Metal 

Fatigue,” for acceptable 

methods for meeting the 

requirements of 10 CFR 

54.21(c)(1).

Yes, TLAA The Staff decided it was 

appropriate to split R-04 into 6 

generic items including R-220 

which includes (for BWRs) the 

IV.C1 links and the 

components defined as piping, 

piping components, and piping 

elements.

R-221 IV.D1.1-h Steel; 

stainless 

Reactor 

coolant

Cumulative 

fatigue damage/ 

Fatigue is a time-limited 

aging analysis (TLAA) to 

Yes, TLAA The Staff decided it was 

appropriate to split R-04 into 6 
October 2005 189 NUREG-1833

IIIC. Changes in Existing AMR Line-Items related to Reactor Vessels, Internals, and Reactor Coolant Systems (Chapter IV in GALL Vol. 2)

Item

GALL 

Rev.0 Item 

Number

Material Environment Aging Effect/ 

Mechanism

Aging Management 

Program

Further Evaluation

Recommended Basis for Change

steel; steel 

with 

nickelalloy or 

stainless 

steel 

cladding; 

nickelalloy

fatigue be performed for the 

period of extended 

operation, and, for Class 1 

components, 

environmental effects on 

fatigue are to be 

addressed. See the 

Standard Review Plan, 

Section 4.3 “Metal 

Fatigue,” for acceptable 

methods for meeting the 

requirements of 10 CFR 

54.21(c)(1).

generic items including R-221 

which includes IV.D1 link and 

the components defined as 

“Recirculating steam generator 

components: Flanges; 

Penetrations; Nozzles; Safe 

ends, lower heads and welds.”

R-222 IV.D2.1-c Steel; 

stainless 

steel; steel 

with 

nickelalloy or 

stainless 

steel 

cladding; 

nickelalloy

Reactor 

coolant

Cumulative 

fatigue damage/ 

fatigue

Fatigue is a time-limited 

aging analysis (TLAA) to 

be performed for the 

period of extended 

operation, and, for Class 1 

components, 

environmental effects on 

fatigue are to be 

addressed. See the 

Standard Review Plan, 

Section 4.3 “Metal 

Fatigue,” for acceptable 

methods for meeting the 

requirements of 10 CFR 

54.21(c)(1).

Yes, TLAA The Staff decided it was 

appropriate to split R-04 into 6 

generic items including R-222 

which includes IV.D2 link and 

the components defined as 

“Once-through steam generator 

components: Primary side 

nozzles; Safe ends and welds.”

R-223 IV.C2.1-a 

IV.C2.1-b 

IV.C2.2-a 

IV.C2.2-b 

IV.C2.2-c 

IV.C2.3-a 

Steel; 

stainless 

steel; steel 

with 

nickelalloy or 

Reactor 

coolant

Cumulative 

fatigue damage/ 

fatigue

Fatigue is a time-limited 

aging analysis (TLAA) to 

be performed for the 

period of extended 

operation, and, for Class 1 

components, 

Yes, TLAA The Staff decided it was 

appropriate to split R-04 into 6 

generic items including R-223 

which includes (for PWRs) the 

IV.C2 links and the 

components defined as piping, 
NUREG-1833 190 October 2005

IIIC. Changes in Existing AMR Line-Items related to Reactor Vessels, Internals, and Reactor Coolant Systems (Chapter IV in GALL Vol. 2)

Item

GALL 

Rev.0 Item 

Number

Material Environment Aging Effect/ 

Mechanism

Aging Management 

Program

Further Evaluation

Recommended Basis for Change

IV.C2.4-a 

IV.C2.5-a 

IV.C2.5-d 

IV.C2.5-e 

IV.C2.5-f 

IV.C2.5-q 

stainless 

steel 

cladding; 

nickelalloy

environmental effects on 

fatigue are to be 

addressed. See the 

Standard Review Plan, 

Section 4.3 “Metal 

Fatigue,” for acceptable 

methods for meeting the 

requirements of 10 CFR 

54.21(c)(1).

piping components, and piping 

elements; flanges; Nozzles and 

safe ends; Pressurizer vessel 

shell heads and welds; Heater 

sheaths and sleeves; 

Penetrations; and Thermal 

sleeves.

R-224

R-59

IV.D2.1-e

IV.A1.1-a

Steel Secondary 

feedwater/ 

steam

Reactor 

Coolant

Loss of material/ 

general, pitting, 

and crevice 

corrosion

Chapter XI.M2, “Water 

Chemistry,” for PWR 

secondary water

The AMP is to be 

augmented by verifying 

the effectiveness of 

water chemistry control. 

See Chapter XI.M32, 

“One-Time Inspection,” 

for an acceptable 

verification program.

Yes, detection of aging 

effects is to be 

evaluated

The AMP was revised from 

XI.M1 (ISI) and XI.M32 to 

XI.M2 and M32. These AMPs 

are more appropriate to use to 

detect loss of material from 

general, pitting, and crevice 

corrosion to ensure that 

significant degradation is not 

occurring.

R-225 IV.C1.4-a 

IV.C1.4-b 

Stainless 

steel; steel

Reactor 

coolant

Cracking/ cyclic 

loading

Chapter XI.M1, “ASME 

Section XI Inservice 

Inspection, Subsections 

IWB, IWC, and IWD,” for 

Class 1 components The 

AMP in Chapter XI.M1 is 

to be augmented to detect 

cracking due to cyclic 

loading and verification of 

the effectiveness of the 

program is necessary to 

ensure that significant 

degradation is not 

occurring and the 

Yes, detection of aging 

effects is to be 

evaluated

This is identical to GALL Rev. 0

row IV.C.1-4a except that the 

Staff decided to create 

separate rows for the aging 

effect/mechanism of cracking/ 

stress corrosion cracking, 

intergranular stress corrosion 

cracking, and cracking/cyclic 

loading. GALL Row R-15 

addresses the aging 

effect/mechanism of cracking/ 

stress corrosion cracking and 

intergranular stress corrosion 

cracking. 
October 2005 191 NUREG-1833

IIIC. Changes in Existing AMR Line-Items related to Reactor Vessels, Internals, and Reactor Coolant Systems (Chapter IV in GALL Vol. 2)

Item

GALL 

Rev.0 Item 

Number

Material Environment Aging Effect/ 

Mechanism

Aging Management 

Program

Further Evaluation

Recommended Basis for Change

component intended 

function will be maintained 

during the extended 

period of operation. An 

acceptable verification 

program is to include 

temperature and 

radioactivity monitoring of 

the shell side water, and 

eddy current testing of 

tubes.

R-226 IV.D2 Nickel alloy Secondary 

feedwater/ 

steam

Denting/ 

corrosion of 

carbon steel tube 

support plate

Chapter XI.M19, “Steam 

Generator Tubing 

Integrity” and Chapter 

XI.M2, “Water Chemistry,” 

for PWR secondary water. 

No Extended the applicability of R43 (recirculating steam 

generator tubes) to once 

through steam generators, 

except that Bulletin 88-02 does 

not apply.
NUREG-1833 192 October 2005

III.D Engineered Safety Features

Table III.D presents the changes made to existing AMR line-items for engineered safety features.

IIID. Changes in Existing AMR Line-Items related to Engineered Safety Features (Chapter V in GALL Vol. 2)

Item

Structures 

and/or 

Components

GALL 

Rev. 0

Item 

Number

Material Environment

Aging 

Effect/ 

Mechanism

Aging Management 

Program

Further 

Evaluation

Recommended

Basis for Change

E-01 Partially 

encased tanks 

with breached 

moisture 

barrier

V.D1.8-c Stainless 

steel

Raw water Loss of 

material/ 

pitting and 

crevice 

corrosion

A plant-specific aging 

management program is to 

be evaluated for pitting and 

crevice corrosion of tank 

bottom because moisture 

and water can egress under 

the tank due to cracking of 

the perimeter seal from 

weathering.

Yes, plantspecificThe terminology for this 

environment was 

changed to remove 

"Untreated water" and 

instead use "Raw 

water.” The change 

conforms with the 

change made to the 

definitions in Chapter 

IX of the GALL Report.

E-07 Piping, piping 

components, 

and piping 

elements

V.D2.1-f Steel Steam Wall 

thinning/ 

flowaccelerated 

corrosion

Chapter XI.M17, “FlowAccelerated Corrosion”No The environment was 

changed from "Air and 

Steam" to "Steam" 

because it is the steam 

environment that gives 

rise to the potential for 

flow accelerated 

corrosion. 

Additionally, in GALL 

Rev. 0 this line applied 

to the steam lines to 

the HPCI and RCIC 

pump turbine. 

However, the steam 

lines to the HPCI and 

RCIC Turbine are used 

less than 2% of the 

time and, therefore, are
October 2005 193 NUREG-1833

IIID. Changes in Existing AMR Line-Items related to Engineered Safety Features (Chapter V in GALL Vol. 2)

Item

Structures 

and/or 

Components

GALL 

Rev. 0

Item 

Number

Material Environment

Aging 

Effect/ 

Mechanism

Aging Management 

Program

Further 

Evaluation

Recommended

Basis for Change

not susceptible to flow 

accelerated corrosion. 

The steam drain lines 

however, see constant 

steam flow and are 

therefore susceptible to 

flow accelerated 

corrosion. The AMP 

continues to provide an 

acceptable means of 

managing aging of 

these components for 

this revised MEAP.

E-22

E-34

Containment 

isolation 

piping and 

components 

internal 

surfaces

V.C.1-a

V.C.1-b

Steel

Stainless 

Steel

Raw water Loss of 

material/ 

general, 

pitting, 

crevice and 

microbiologically 

influenced 

corrosion 

and fouling

Chapter XI.M20, “OpenCycle Cooling Water 

System”

No The terminology for this 

environment was 

changed to remove 

"Untreated water" and 

instead use "Raw 

water.” The change 

conforms with the 

change made to the 

definitions in Chapter 

IX of the GALL report. 

Fouling was added to 

the aging 

effect/mechanism to 

acknowledge the fact 

that biofouling also 

operates as an aging 

mechanism in a raw 

water environment. 

Also, the AMP was 

changed from plant-
NUREG-1833 194 October 2005

IIID. Changes in Existing AMR Line-Items related to Engineered Safety Features (Chapter V in GALL Vol. 2)

Item

Structures 

and/or 

Components

GALL 

Rev. 0

Item 

Number

Material Environment

Aging 

Effect/ 

Mechanism

Aging Management 

Program

Further 

Evaluation

Recommended

Basis for Change

specific to XI.M20 and 

the further evaluation 

was changed to “No.”

The scope of this 

program notes that this 

program addresses the 

aging effects of 

material loss and 

fouling due to micro- or 

macro-organisms and 

various corrosion 

mechanisms. 

E-25 Ducting and 

components 

internal 

surfaces

V.B.2-a Steel Air – indoor 

uncontrolled 

(Internal)

Loss of 

material/ 

general 

corrosion

Chapter XI.M38, 

"Inspection of Internal 

Surfaces in Miscellaneous 

Piping and Ducting 

Components"

No The AMP and FE 

columns were revised 

to refer to AMP XI.M38. 

AMP XI.M38 was 

developed to provide 

for proper management 

of the aging effects for 

this MEAP 

combination. This 

program provides an 

acceptable means of 

managing aging of 

these components. 

See Table IV for further 

discussion of the basis 

for this AMP. The 

implementation of this 

program provides 

reasonable assurance 

that the component’s 

intended functions will 
October 2005 195 NUREG-1833

IIID. Changes in Existing AMR Line-Items related to Engineered Safety Features (Chapter V in GALL Vol. 2)

Item

Structures 

and/or 

Components

GALL 

Rev. 0

Item 

Number

Material Environment

Aging 

Effect/ 

Mechanism

Aging Management 

Program

Further 

Evaluation

Recommended

Basis for Change

be maintained within 

the CLB for the period 

of extended operation.

E-27 Piping and 

components 

internal 

surfaces

V.D2.1-e Steel Condensation 

(Internal)

Loss of 

material/ 

general, 

pitting, and 

crevice 

corrosion

Chapter XI.M38, 

"Inspection of Internal 

Surfaces in Miscellaneous 

Piping and Ducting 

Components"

No The AMP and FE 

columns were revised 

to refer to AMP XI.M38, 

which identifies an 

acceptable means of 

managing aging of 

these components.

AMP XI.M38 was 

developed to provide 

for proper management 

of the aging effects for

this MEAP 

combination. This 

program provides an 

acceptable means of 

managing aging of 

these components. 

See Table IV for further 

discussion of the basis 

for this AMP. The 

implementation of this 

program provides 

reasonable assurance 

that the component’s 

intended functions will 

be maintained within 

the CLB for the period 

of extended operation.

E-29 Piping and 

components 

V.A.2-a

V.A.5-a

Steel Air – indoor 

uncontrolled 

Loss of 

material/ 

Chapter XI.M38, 

"Inspection of Internal 

No The AMP and FE 

columns were revised 
NUREG-1833 196 October 2005

IIID. Changes in Existing AMR Line-Items related to Engineered Safety Features (Chapter V in GALL Vol. 2)

Item

Structures 

and/or 

Components

GALL 

Rev. 0

Item 

Number

Material Environment

Aging 

Effect/ 

Mechanism

Aging Management 

Program

Further 

Evaluation

Recommended

Basis for Change

internal 

surfaces

V.D2.5-a (Internal) general 

corrosion

Surfaces in Miscellaneous 

Piping and Ducting 

Components"

to refer to AMP XI.M38, 

which identifies an 

acceptable means of 

managing aging of 

these components.

AMP XI.M38 was 

developed to provide 

for proper management 

of the aging effects for 

this MEAP 

combination. This 

program provides an 

acceptable means of 

managing aging of 

these components. 

See Table IV for further 

discussion of the basis 

for this AMP. The 

implementation of this 

program provides 

reasonable assurance 

that the component’s 

intended functions will 

be maintained within 

the CLB for the period 

of extended operation.

E-33 Containment 

isolation 

piping and 

components 

internal 

surfaces

V.C.1-b Stainless 

steel

Treated water Loss of 

material/ 

pitting and 

crevice 

corrosion

Chapter XI.M2, “Water 

Chemistry”

The AMP is to be 

augmented by verifying the 

effectiveness of water 

chemistry control. See 

Chapter XI.M32, “One-Time 

Yes, detection 

of aging effects 

is to be 

evaluated

The AMP was revised 

from plant specific to 

AMP XI.M2 as 

augmented by XI.M32. 

As noted in the 

Preventive Actions 

portion of AMP XI.M2, 
October 2005 197 NUREG-1833

IIID. Changes in Existing AMR Line-Items related to Engineered Safety Features (Chapter V in GALL Vol. 2)

Item

Structures 

and/or 

Components

GALL 

Rev. 0

Item 

Number

Material Environment

Aging 

Effect/ 

Mechanism

Aging Management 

Program

Further 

Evaluation

Recommended

Basis for Change

Inspection,” for an 

acceptable verification 

program.

this program “includes 

specifications for 

chemical species, 

sampling and analysis 

frequencies, and 

corrective actions for 

control of reactor water 

chemistry. System 

water chemistry is 

controlled to minimize 

contaminant 

concentration and 

mitigate loss of 

material due to 

general, crevice, and 

pitting corrosion. . .”

E-35

E-44

E-46

Containment 

isolation 

piping and 

components 

external 

surfaces

External 

surfaces

External 

surfaces

V.C.1-a

V.E.

V.E.1-b

Steel Air – indoor 

uncontrolled 

(External)

Air – indoor 

uncontrolled 

(External)

Condensation 

(External)

Loss of 

material/ 

general 

corrosion

Chapter XI.M36, "External 

Surfaces Monitoring"

No The AMP column was 

revised to eliminate the 

need for a plant 

specific aging 

management program 

in light of the 

development of AMP 

XI.M36, “External 

Surfaces Monitoring.” 

AMP XI.M36 was 

developed to provide 

for proper management 

of the aging effects for 

this MEAP 

combination. This 

program provides an 

acceptable means of 
NUREG-1833 198 October 2005

IIID. Changes in Existing AMR Line-Items related to Engineered Safety Features (Chapter V in GALL Vol. 2)

Item

Structures 

and/or 

Components

GALL 

Rev. 0

Item 

Number

Material Environment

Aging 

Effect/ 

Mechanism

Aging Management 

Program

Further 

Evaluation

Recommended

Basis for Change

managing aging of 

these components. 

See Table IV for further 

discussion of the basis 

for this AMP. The 

implementation of this 

program provides 

reasonable assurance 

that the component’s 

intended functions will 

be maintained within 

the CLB for the period 

of extended operation.

E-40 Ducting 

closure bolting

V.B.1-a Steel Air – indoor 

uncontrolled 

(External)

Loss of 

material/ 

general

corrosion

Chapter XI.M36, "External 

Surfaces Monitoring"

No The AMP column has 

been changed to 

eliminate the need for a 

plant specific aging 

management program 

in light of the 

development of AMP 

XI.M36, “External 

Surfaces Monitoring.” 

AMP XI.M36 was 

developed to provide 

for proper management 

of the aging effects for 

this MEAP 

combination. This 

program provides an 

acceptable means of 

managing aging of 

these components. 

See Table IV for further 
October 2005 199 NUREG-1833

IIID. Changes in Existing AMR Line-Items related to Engineered Safety Features (Chapter V in GALL Vol. 2)

Item

Structures 

and/or 

Components

GALL 

Rev. 0

Item 

Number

Material Environment

Aging 

Effect/ 

Mechanism

Aging Management 

Program

Further 

Evaluation

Recommended

Basis for Change

discussion of the basis 

for this AMP. The 

implementation of this 

program provides 

reasonable assurance 

that the component’s 

intended functions will 

be maintained within 

the CLB for the period 

of extended operation.

For ducting closure 

bolting, this AMP is 

used instead of M18, 

“Bolting Integrity” due 

to the lower operating 

pressures within this 

ducting. Therefore, 

these components 

would not be within the 

scope of AMP XI.M18.

E-42 Piping, 

piping 

components, 

and piping 

elements

V.B. Steel 

(with or 

without 

coating 

or 

wrappin

g)

Soil Loss of 

material/ 

general, 

pitting, 

crevice, and 

microbiologically 

influenced 

corrosion

Chapter XI.M28, “Buried 

Piping and Tanks 

Surveillance,” or 

Chapter XI.M34, “Buried 

Piping and Tanks 

Inspection”

No

Yes, detection 

of aging effects 

and operating 

experience are 

to be further 

evaluated

This row is identical to 

A-01 and was added to 

cover buried piping in 

ESF systems. 

Underground steel 

(with or without coating 

or wrapping) piping, 

piping components, 

and piping elements 

exposed to a soil 

environment are 

subject to loss of 

material due to 
NUREG-1833 200 October 2005

IIID. Changes in Existing AMR Line-Items related to Engineered Safety Features (Chapter V in GALL Vol. 2)

Item

Structures 

and/or 

Components

GALL 

Rev. 0

Item 

Number

Material Environment

Aging 

Effect/ 

Mechanism

Aging Management 

Program

Further 

Evaluation

Recommended

Basis for Change

general, pitting, 

crevice, and 

microbiologically 

influenced corrosion. 

This aging effect can 

be managed by either 

surveillance (XI.M28) 

or inspection (XI.M34).

Although buried steel 

without coating or 

wrapping is not 

commonly found, the 

“with or without” was 

included to ensure that 

all steel pipe in a soil 

environment was 

addressed by this lineitem.

E-43 Motor Cooler V.A

V.D1. 

Gray 

cast iron

Treated water Loss of 

material/ 

selective 

leaching

Chapter XI.M33, “Selective 

Leaching of Materials”

No An approved precedent 

exists for adding this 

material, environment, 

aging effect, and 

program combination 

to the GALL Report. As 

discussed in FNP SER 

section 3.2.2.4.1.2, the 

Staff has accepted the 

position that cast iron 

in a treated water 

environment exhibits a 

loss of material due to 

selective leaching and 

is properly managed by 
October 2005 201 NUREG-1833

IIID. Changes in Existing AMR Line-Items related to Engineered Safety Features (Chapter V in GALL Vol. 2)

Item

Structures 

and/or 

Components

GALL 

Rev. 0

Item 

Number

Material Environment

Aging 

Effect/ 

Mechanism

Aging Management 

Program

Further 

Evaluation

Recommended

Basis for Change

the Selective Leaching 

of Materials Program, 

which includes a onetime visual inspection 

and hardness 

measurement of 

selected components 

to determine whether 

loss of material due to 

selective leaching is 

occurring. 

Implementation of AMP 

XI.M33 provides 

reasonable assurance 

that the component’s 

intended functions will 

be maintained within 

the CLB for the period 

of extended operation.
NUREG-1833 202 October 2005

.

III.E Electrical ComponentsThere were no significant changes to existing AMR line-items for electrical components
October 2005 203 NUREG-1833

III.F Auxiliary Systems

Table III.F presents the changes made to existing AMR line-items for Auxiliary Systems.

IIIF. Changes in Existing AMR Line-Items related to Auxiliary Systems (Chapter VII in GALL Vol. 2)

Item

Structures 

and/or 

Components

GALL 

Rev.0 Item 

Number

Material Environment Aging Effect/ 

Mechanism

Aging 

Management 

Program

Further 

Evaluation

Recommended

Basis for Change

A-02 Piping, piping 

components, 

and piping 

elements

VII.C1.1-c

VII.C3.

VII.G.

VII.H1.

VII.H2.

Gray cast iron Soil Loss of material/ 

selective leaching

Chapter XI.M33, 

“Selective 

Leaching of 

Materials”

No General corrosion 

was removed from 

the aging 

effect/mechanism 

column because it is 

already addressed 

under A-01.

A-08 Ducting and 

components 

internal 

surfaces

VII.F1.1-a 

VII.F1.4-a

VII.F2.1-a 

VII.F2.4-a

VII.F3.1-a 

VII.F3.4-a

VII.F4.1-a 

Steel Condensation 

(Internal)

Loss of material/ 

general, pitting, 

crevice, and (for drip 

pans and drain lines) 

microbiologically 

influenced corrosion 

Chapter XI.M38, 

"Inspection of 

Internal 

Surfaces in 

Miscellaneous 

Piping and 

Ducting 

Components"

No The AMP and FE 

columns were revised 

to refer to AMP 

XI.M38. This AMP 

was developed to 

provide for proper 

management of the 

aging effects for this 

MEAP combination. 

See Table IV for 

further discussion of 

the basis for this 

AMP. The 

environment was 

changed to better 

describe a moist air 

environment which 

could lead to 

condensation. 
NUREG-1833 204 October 2005

IIIF. Changes in Existing AMR Line-Items related to Auxiliary Systems (Chapter VII in GALL Vol. 2)

Item

Structures 

and/or 

Components

GALL 

Rev.0 Item 

Number

Material Environment Aging Effect/ 

Mechanism

Aging 

Management 

Program

Further 

Evaluation

Recommended

Basis for Change

A-10

A-105

A-77

A-78

A-81

Ducting and 

components 

external 

surfaces

Ducting 

closure bolting

External 

surfaces

External 

surfaces

External 

surfaces

VII.F1.1-a 

VII.F1.4-a

VII.F2.1-a 

VII.F2.4-a

VII.F3.1-a 

VII.F3.4-a

VII.F4.1-a

VII.F1.1-a 

VII.F2.1-a 

VII.F3.1-a 

VII.F4.1-a 

VII.I

VII.I.1-b

VII.I.1-b

VII.I.1-b 

Steel Air – indoor 

uncontrolled 

(External)

Air – outdoor 

(External)

Condensation 

(External)

Loss of material/ 

general corrosion

Chapter XI.M36, 

"External 

Surfaces 

Monitoring"

No The AMP column 

was revised to 

eliminate the need for 

a plant specific aging 

management 

program in light of the 

development of AMP 

XI.M36, “External 

Surfaces Monitoring.” 

AMP XI.M36 was 

developed to provide 

for proper 

management of the 

aging effects for this 

MEAP combination. 

This program 

provides an 

acceptable means of 

managing aging of 

these components. 

See Table IV for 

further discussion of 

the basis for this 

AMP. The 

implementation of 

this program provides 

reasonable 

assurance that the 

component’s 

intended functions 

will be maintained 

within the CLB for the 

period of extended 

operation. 

For ducting closure 
October 2005 205 NUREG-1833

IIIF. Changes in Existing AMR Line-Items related to Auxiliary Systems (Chapter VII in GALL Vol. 2)

Item

Structures 

and/or 

Components

GALL 

Rev.0 Item 

Number

Material Environment Aging Effect/ 

Mechanism

Aging 

Management 

Program

Further 

Evaluation

Recommended

Basis for Change

bolting, this AMP is 

used instead of M18, 

“Bolting Integrity” due 

to the lower operating 

pressures within this 

ducting.

A-15

A-16

Elastomer 

lining

VII.A3.2-a 

VII.A3.2-d 

VII.A3.3-a 

VII.A3.3-d 

VII.A3.5-a 

VII.A3.5-c 

VII.A4.2-a 

VII.A4.2-b 

VII.A4.3-a 

VII.A4.3-b 

VII.A4.5-a 

VII.A4.5-b 

Elastomers Treated 

borated water

Hardening and loss 

of 

strength/elastomers 

degradation

A plant-specific 

aging 

management 

program that 

determines and 

assesses the 

qualified life of 

the linings in 

the 

environment is 

to be evaluated.

Yes,

plant specific

The GALL Rev. 0

line-item was for steel 

with elastomer lining. 

However, only the 

metal component 

was covered. This 

line-item was created 

to address the 

elastomer lining. 

(Although 95°F is a 

recognized threshold, 

temperature is not 

the only factor for 

aging of elastomers. 

Discussion of aging 

elastomers should 

consider aging 

effects from other 

factors causing 

degradation such as 

exposure to ozone, 

oxidation, and 

radiation)

A-23 Piping, piping 

components, 

and piping 

elements

VII.H2.2-a 

VII.H2.3-a 

VII.G.

Steel Moist air or 

condensation 

(Internal)

Loss of material/ 

general, pitting, and 

crevice corrosion

Chapter XI.M38, 

"Inspection of 

Internal 

Surfaces in 

Miscellaneous 

Piping and 

No The environment was 

changed to add 

condensation 

(internal) to reflect 

moisture in the 

emergency diesel 
NUREG-1833 206 October 2005

IIIF. Changes in Existing AMR Line-Items related to Auxiliary Systems (Chapter VII in GALL Vol. 2)

Item

Structures 

and/or 

Components

GALL 

Rev.0 Item 

Number

Material Environment Aging Effect/ 

Mechanism

Aging 

Management 

Program

Further 

Evaluation

Recommended

Basis for Change

Ducting 

Components"

starting air system. 

The aging effects are 

the same for both 

environments and the 

definition in Chapter 

IX says the two 

environments are 

similar. The AMP and 

FE columns were 

also revised to refer 

to AMP XI.M38. AMP 

XI.M38 was 

developed to provide 

for proper 

management of the 

aging effects for this 

MEAP combination. 

This program 

provides an 

acceptable means of 

managing aging of 

these components. 

See Table IV for 

further discussion of 

the basis for this 

AMP. The 

implementation of 

this program provides 

reasonable 

assurance that the 

component’s 

intended functions 

will be maintained 

within the CLB for the 

period of extended 
October 2005 207 NUREG-1833

IIIF. Changes in Existing AMR Line-Items related to Auxiliary Systems (Chapter VII in GALL Vol. 2)

Item

Structures 

and/or 

Components

GALL 

Rev.0 Item 

Number

Material Environment Aging Effect/ 

Mechanism

Aging 

Management 

Program

Further 

Evaluation

Recommended

Basis for Change

operation.

A-24 Piping, piping 

components, 

and piping 

elements

VII.H1.1-a 

VII.H1.2-a 

VII.H1.3-a

Steel Air – outdoor 

(External)

Loss of material/ 

general, pitting, and 

crevice corrosion

Chapter XI.M36, 

"External 

Surfaces 

Monitoring"

No The AMP column 

was revised to 

eliminate the need for 

a plant specific aging 

management 

program in light of the 

development of AMP 

XI.M36, “External 

Surfaces Monitoring.” 

AMP XI.M36 was 

developed to provide 

for proper 

management of the 

aging effects for this 

MEAP combination. 

This program 

provides an 

acceptable means of 

managing aging of 

these components. 

See Table IV for 

further discussion of 

the basis for this 

AMP. The 

implementation of 

this program provides 

reasonable 

assurance that the 

component’s 

intended functions 

will be maintained 

within the CLB for the 

period of extended 
NUREG-1833 208 October 2005

IIIF. Changes in Existing AMR Line-Items related to Auxiliary Systems (Chapter VII in GALL Vol. 2)

Item

Structures 

and/or 

Components

GALL 

Rev.0 Item 

Number

Material Environment Aging Effect/ 

Mechanism

Aging 

Management 

Program

Further 

Evaluation

Recommended

Basis for Change

operation.

A-38 Piping, piping 

components, 

and piping 

elements

VII.C1.1-a 

VII.C1.2-a 

VII.C1.5-a 

VII.C1.6-a 

VII.C3.1-a 

VII.C3.2-a 

VII.C3.3-a 

VII.H2.1-b

Steel (with or 

without 

lining/coatin

g or with 

degraded 

lining/coatin

g)

Raw water Loss of material/ 

general, pitting, 

crevice, and 

microbiologically 

influenced

corrosion, fouling, 

and lining/coating 

degradation

Chapter XI.M20, 

“Open-Cycle 

Cooling Water 

System”

No The Materials column 

was expanded to 

indicate that this 

material may exist 

with or without 

lining/coating. The 

aging 

effect/mechanism 

column was also 

revised to add "and 

lining/coating 

degradation" similar 

to rows A-39 and A40. 

A-50 Piping, piping 

components, 

and piping 

elements

VII.C2.3-a 

VII.F3.

Gray cast iron Closed cycle 

cooling water

Loss of material/ 

selective leaching

Chapter XI.M33, 

“Selective 

Leaching of 

Materials”

No Deleted pitting and 

crevice corrosion 

from the aging 

effect/mechanism. 

Deleted AMP XI.M21 

from the AMP 

column. Line-item A25 includes general, 

pitting, and crevice 

corrosion for steel 

which includes gray 

cast iron for these 

mechanisms. Thus, 

only selective 

leaching needs to be 

addressed here. This 

row is similar to AP31; therefore VII.F3 

was added to the 
October 2005 209 NUREG-1833

IIIF. Changes in Existing AMR Line-Items related to Auxiliary Systems (Chapter VII in GALL Vol. 2)

Item

Structures 

and/or 

Components

GALL 

Rev.0 Item 

Number

Material Environment Aging Effect/ 

Mechanism

Aging 

Management 

Program

Further 

Evaluation

Recommended

Basis for Change

related item column 

to reflect that this 

environment may 

also apply to the 

Primary Containment 

Heating and 

Ventilation System.

A-68 Heat 

exchanger 

components

VII.E3.4-a Stainless 

steel; steel 

with stainless 

steel cladding

Closed cycle 

cooling water 

>60°C 

(>140°F)

Cracking/ stress 

corrosion cracking

Chapter XI.M21, 

“Closed-Cycle 

Cooling Water 

System”

No The Structures and/or

Components column 

was simplified to 

state “Heat

exchanger 

components.” The 

reference to the shell 

side or tube side of 

the heat exchanger 

unnecessarily limits 

the applicability of the 

line-item because the 

configuration of the 

heat exchanger does 

not alter the aging 

effects or the 

appropriate aging 

management 

program. 

Consequently, this 

reference has been 

deleted. The program 

was revised from 

plant-specific to 

XI.M21, "Closed -

Cycle Cooling Water 

System.” In the FNP 
NUREG-1833 210 October 2005

IIIF. Changes in Existing AMR Line-Items related to Auxiliary Systems (Chapter VII in GALL Vol. 2)

Item

Structures 

and/or 

Components

GALL 

Rev.0 Item 

Number

Material Environment Aging Effect/ 

Mechanism

Aging 

Management 

Program

Further 

Evaluation

Recommended

Basis for Change

LRA, the Water 

Chemistry Control 

Program satisfies the 

program elements of 

XI.M21 to manage 

cracking due to 

stress corrosion 

cracking in stainless 

steel in this 

environment. This 

was accepted by the 

Staff in Section 

3.0.3.2.1 of the FNP 

SER. AMP XI.M21, 

“Closed –Cycle 

Cooling Water 

System” has also 

been revised to 

include stress 

corrosion cracking.

A-76 High-pressure 

pump

Casing

VII.E1.5-a Stainless 

steel

Treated 

borated water

Cracking/ stress 

corrosion cracking, 

cyclic loading

Chapter XI.M2, 

“Water 

Chemistry,” for 

PWR primary 

water

The AMP is to 

be augmented 

by verifying the 

absence of 

cracking due to 

stress 

corrosion 

cracking and 

cyclic loading. 

Yes, plantspecificClosure bolting was 

removed from the 

Structures and/or 

Components since 

this environment is 

not external and 

closure bolts are 

covered under (high 

strength steel). Steel 

was removed from 

the material column 

since there are no 

steel high pressure 

pump casings. The 

AMP was changed to 
October 2005 211 NUREG-1833

IIIF. Changes in Existing AMR Line-Items related to Auxiliary Systems (Chapter VII in GALL Vol. 2)

Item

Structures 

and/or 

Components

GALL 

Rev.0 Item 

Number

Material Environment Aging Effect/ 

Mechanism

Aging 

Management 

Program

Further 

Evaluation

Recommended

Basis for Change

A plant specific 

aging 

management 

program is to 

be evaluated.

add AMP XI.M2 

augmented by 

XI.M32, and continue 

to call out plant 

specific, consistent 

with ANO-2 SER 

3.3.2.2.4.

A-80 Piping and 

components 

external 

surfaces

VII.D.2-a 

VII.D.3-a 

VII.D.1-a 

VII.D.4-a 

VII.D.6-a 

VII.D.5-a

Steel Air – indoor 

uncontrolled 

(External)

Loss of material/ 

general corrosion

Chapter XI.M36, 

"External 

Surfaces 

Monitoring"

No This line-item was 

added to address the 

external surface of 

compressed air 

components. The 

AMP column was 

revised to eliminate 

the need for a plant 

specific aging 

management 

program in light of the 

development of AMP 

XI.M36, “External 

Surfaces Monitoring.” 

AMP XI.M36 was 

developed to provide 

for proper 

management of the 

aging effects for this 

MEAP combination. 

This program 

provides an 

acceptable means of 

managing aging of 

these components. 

See Table IV for

further discussion of 

the basis for this 
NUREG-1833 212 October 2005

IIIF. Changes in Existing AMR Line-Items related to Auxiliary Systems (Chapter VII in GALL Vol. 2)

Item

Structures 

and/or 

Components

GALL 

Rev.0 Item 

Number

Material Environment Aging Effect/ 

Mechanism

Aging 

Management 

Program

Further 

Evaluation

Recommended

Basis for Change

AMP. The 

implementation of 

this program provides 

reasonable 

assurance that the 

component’s 

intended functions 

will be maintained 

within the CLB for the 

period of extended 

operation.

A-82

A-83

Reactor 

coolant pump 

oil collection 

system

Tank

Reactor 

coolant pump 

oil collection 

system

Piping, tubing, 

valve bodies

VII.G.7-a

VII.G.7-b

Steel Lubricating oil Loss of material/ 

general, pitting, and 

crevice corrosion

Chapter XI.M39, 

"Lubricating Oil 

Analysis"

The AMP is to 

be augmented 

to evaluate the 

thickness of the 

lower portion of 

the tank. See 

Chapter XI.M32, 

“One-Time 

Inspection,” for 

an acceptable 

verification 

program.

Yes, detection 

of aging effects 

is to be 

evaluated

The AMP column 

was revised to 

eliminate the need for 

a plant specific aging 

management 

program in light of the 

development of AMP 

XI.M39, "Lubricating 

Oil Analysis.” 

AMP XI.M39 was 

developed to provide 

for proper 

management of the 

aging effects for this 

MEAP combination. 

This program 

provides an 

acceptable means of 

managing aging of 

these components 

with one-time 

inspection (AMP 

XI.M32) to provide a 

mitigative and 
October 2005 213 NUREG-1833

IIIF. Changes in Existing AMR Line-Items related to Auxiliary Systems (Chapter VII in GALL Vol. 2)

Item

Structures 

and/or 

Components

GALL 

Rev.0 Item 

Number

Material Environment Aging Effect/ 

Mechanism

Aging 

Management 

Program

Further 

Evaluation

Recommended

Basis for Change

verification method. 

See Table IV for 

further discussion of 

the basis for these 

AMPs. The 

implementation of 

this augmented 

program provides 

reasonable 

assurance that the 

component’s 

intended functions 

will be maintained 

within the CLB for the 

period of extended 

operation.

A-90 Structural fire 

barriers:

Walls, ceilings 

and floors

VII.G.1-b 

VII.G.2-b 

VII.G.3-b 

VII.G.4-b 

VII.G.5-a 

Reinforced 

concrete

Air – indoor 

uncontrolled

Concrete cracking 

and spalling/ 

aggressive chemical 

attack, and reaction 

with aggregates

Chapter XI.M26, 

“Fire Protection” 

and Chapter 

XI.S6, 

“Structures 

Monitoring 

Program”

No Freeze-thaw was 

deleted from the 

aging 

effect/mechanism 

column. Freeze-thaw 

is not an applicable 

aging mechanism in 

an air - indoor 

uncontrolled 

environment. The 

AMP continues to 

provide an 

acceptable means of 

managing aging of 

these components for 

this revised MEAP.

A-103 Closure 

bolting

VII.D.2-a Steel Condensation Loss of material/ 

general, pitting, and 

crevice corrosion

Chapter XI.M18, 

“Bolting 

Integrity”

No GALL Rev. 0 lineitem VII.D.2-a was 

split into three AMR 
NUREG-1833 214 October 2005

IIIF. Changes in Existing AMR Line-Items related to Auxiliary Systems (Chapter VII in GALL Vol. 2)

Item

Structures 

and/or 

Components

GALL 

Rev.0 Item 

Number

Material Environment Aging Effect/ 

Mechanism

Aging 

Management 

Program

Further 

Evaluation

Recommended

Basis for Change

line-items in the 

GALL Report Rev. 1 

(i.e., A-26, A-80, and 

A-103). This line-item

(A-103) specifically

treats the closure 

bolts as a separate 

line-item and assigns

the XI.M18, "Bolting 

Integrity" aging 

management 

program to these 

components. This 

program provides an 

acceptable means of 

managing aging of 

these components. 

A-104 High-pressure 

pump

Closure 

bolting

VII.E1.5-a High-strength 

steel

Air with steam 

or water 

leakage

Cracking/ cyclic 

loading, stress 

corrosion cracking

Chapter XI.M18, 

“Bolting 

Integrity.”

The AMP is to 

be augmented 

by appropriate 

inspection to 

detect cracking 

if the bolts are 

not otherwise 

replaced during 

maintenance.

Yes, if the 

bolts are not 

replaced 

during 

maintenance

The AMP column 

was revised from 

plant specific to 

XI.M18, "Bolting 

Integrity" program. 

The AMP is to be 

augmented by bolt 

inspection or

replacement to reflect 

the applicability of the 

revised XI.M18 to 

adequately manage 

the aging effects of 

cracking due to cyclic 

loading and stress 

corrosion cracking on 

high-strength steel 

bolts and to reflect 
October 2005 215 NUREG-1833

IIIF. Changes in Existing AMR Line-Items related to Auxiliary Systems (Chapter VII in GALL Vol. 2)

Item

Structures 

and/or 

Components

GALL 

Rev.0 Item 

Number

Material Environment Aging Effect/ 

Mechanism

Aging 

Management 

Program

Further 

Evaluation

Recommended

Basis for Change

operating experience. 

The FE entry was 

also changed to be 

consistent with the 

change to the AMP.

A-105 Ducting 

closure bolting

VII.F1.1-a 

VII.F2.1-a 

VII.F3.1-a 

VII.F4.1-a

VII.I.

Steel Air – indoor 

uncontrolled 

(External)

Loss of material/ 

general corrosion

Chapter XI.M36, 

"External 

Surfaces 

Monitoring"

No The AMP column has 

been changed to 

eliminate the need for 

a plant specific aging 

management 

program in light of the 

development AMP 

XI.M36, "External 

Surfaces Monitoring 

Program." AMP 

XI.M36 was 

developed to provide 

for proper 

management of the 

aging effects for this 

MEAP combination. 

This program 

provides an 

acceptable means of 

managing aging of 

these components. 

See Table IV for 

further discussion of 

the basis for this 

AMP. The 

implementation of 

this program provides 

reasonable 

assurance that the 

component’s 
NUREG-1833 216 October 2005

IIIF. Changes in Existing AMR Line-Items related to Auxiliary Systems (Chapter VII in GALL Vol. 2)

Item

Structures 

and/or 

Components

GALL 

Rev.0 Item 

Number

Material Environment Aging Effect/ 

Mechanism

Aging 

Management 

Program

Further 

Evaluation

Recommended

Basis for Change

intended functions 

will be maintained 

within the CLB for the 

period of extended 

operation.
October 2005 217 NUREG-1833

III.G Steam and Power Conversion System

Table III.G presents the changes made to existing AMR line-items for the steam and power conversion system.

IIIG. Changes in Existing AMR Line-Items related to Steam and Power Conversion Systems (Chapter VIII in GALL Vol. 2)

Item

Structures 

and/or 

Components

GALL 

Rev. 0

Item 

Number

Material Environment Aging Effect/ 

Mechanism

Aging Management 

Program

Further 

Evaluation

Recommended

Basis for Change

S-08 Piping, piping 

components, 

and piping 

elements

VIII.B1.1-b 

VIII.B2.1-c 

Steel Steam or 

treated 

water

Cumulative 

fatigue damage/ 

fatigue

Fatigue is a timelimited aging 

analysis (TLAA) to 

be evaluated for the 

period of extended 

operation. See the 

Standard Review 

Plan, Section 4.3 

“Metal Fatigue,” for 

acceptable methods 

for meeting the 

requirements of 10 

CFR 54.21(c)(1).

Yes,

TLAA

The environment 

column was revised to 

add treated water 

since fatigue may not 

be limited to piping 

with an internal steam 

environment. The AMP 

continues to 

adequately provide for 

proper management of 

the aging effects for 

this revised MEAP 

combination.
NUREG-1833 218 October 2005

IIIG. Changes in Existing AMR Line-Items related to Steam and Power Conversion Systems (Chapter VIII in GALL Vol. 2)

Item

Structures 

and/or 

Components

GALL 

Rev. 0

Item 

Number

Material Environment Aging Effect/ 

Mechanism

Aging Management 

Program

Further 

Evaluation

Recommended

Basis for Change

S-12 Piping, piping 

components, 

and piping 

elements

VIII.G.1-d Steel Raw water Loss of material/ 

general, pitting, 

crevice, and 

microbiologically 

influenced 

corrosion, and 

fouling

A plant-specific 

aging management 

program is to be 

evaluated.

Yes, plantspecificThe terminology for 

this environment was 

changed to remove 

"Untreated water" and 

instead use "Raw 

water.” The change 

conforms with the 

change made to the 

definitions in Chapter 

IX of the GALL report.

The AMP continues to 

adequately provide for 

proper management of 

the aging effects for 

this revised MEAP 

combination.

S-17

S-20

Heat 

exchanger 

components

VIII.G.5-d Steel

Stainless Steel

Lubricating oil Loss of material/ 

general (steel 

only), pitting, 

crevice, and 

microbiologically 

influenced 

corrosion

Loss of material/ 

pitting, crevice, 

and 

microbiologically 

influenced 

corrosion

Chapter XI.M39, 

"Lubricating Oil 

Analysis" 

The AMP is to be 

augmented by 

verifying the 

effectiveness of the 

lubricating oil 

analysis program. 

See Chapter 

XI.M32, “One-Time 

Inspection,” for an 

acceptable 

verification 

program.

Yes, detection 

of aging 

effects is to be 

evaluated

The Structures and/or 

Components column 

was simplified to state 

“Heat exchanger 

components.” The 

reference to the shell 

side or tube side of the 

heat exchanger 

unnecessarily limits 

the applicability of the 

line-item because the 

configuration of the 

heat exchanger does 

not alter the aging 

effects or the 

appropriate aging 

management program. 
October 2005 219 NUREG-1833

IIIG. Changes in Existing AMR Line-Items related to Steam and Power Conversion Systems (Chapter VIII in GALL Vol. 2)

Item

Structures 

and/or 

Components

GALL 

Rev. 0

Item 

Number

Material Environment Aging Effect/ 

Mechanism

Aging Management 

Program

Further 

Evaluation

Recommended

Basis for Change

Consequently, this 

reference has been 

deleted. The AMP and 

FE columns were also 

revised to refer to AMP 

XI.M39. AMP XI.M39 

was developed to 

provide for proper 

management of the 

aging effects for this 

MEAP combination. 

This program provides 

an acceptable means 

of managing aging of 

these components with 

one-time inspection 

(AMP XI.M32) to 

provide a mitigative 

and verification 

method. See Table IV 

for further discussion 

of the basis for these 

AMPs. The 

implementation of this 

augmented program 

provides reasonable 

assurance that the 

component’s intended 

functions will be 

maintained within the 

CLB for the period of 

extended operation.
NUREG-1833 220 October 2005

IIIG. Changes in Existing AMR Line-Items related to Steam and Power Conversion Systems (Chapter VIII in GALL Vol. 2)

Item

Structures 

and/or 

Components

GALL 

Rev. 0

Item 

Number

Material Environment Aging Effect/ 

Mechanism

Aging Management 

Program

Further 

Evaluation

Recommended

Basis for Change

S-29

S-41

S-42

External 

surfaces

VIII.H.1-b Steel Air – indoor 

uncontrolled 

(External)

Air – outdoor 

(External)

Condensation 

(External)

Loss of material/ 

general 

corrosion

Chapter XI.M36, 

"External Surfaces 

Monitoring"

No The AMP column was 

revised to eliminate 

the need for a plant 

specific aging 

management program 

in light of the 

development of AMP 

XI.M36, “External 

Surfaces Monitoring.” 

AMP XI.M36 was 

developed to provide 

for proper 

management of the 

aging effects for this 

MEAP combination. 

This program provides 

an acceptable means 

of managing aging of 

these components. 

See Table IV for 

further discussion of 

the basis for this AMP. 

The implementation of 

this program provides 

reasonable assurance 

that the component’s 

intended functions will 

be maintained within 

the CLB for the period 

of extended operation.
October 2005 221 NUREG-1833

IIIG. Changes in Existing AMR Line-Items related to Steam and Power Conversion Systems (Chapter VIII in GALL Vol. 2)

Item

Structures 

and/or 

Components

GALL 

Rev. 0

Item 

Number

Material Environment Aging Effect/ 

Mechanism

Aging Management 

Program

Further 

Evaluation

Recommended

Basis for Change

S-33 Closure 

bolting

VIII.H. Steel Air – indoor 

uncontrolled 

(External)

Loss of 

preload/ 

thermal effects, 

gasket creep, 

and selfloosening 

Chapter XI.M18, 

“Bolting Integrity”

No The aging 

effect/mechanism was 

revised to describe a 

more precise 

description of the loss 

of preload aging effect 

and to be consistent 

with changes to the 

definitions in Chapter 

IX. The AMP continues 

to provide an 

acceptable means of 

managing aging of 

these components for 

this revised MEAP.
NUREG-1833 222 October 2005

IIIG. Changes in Existing AMR Line-Items related to Steam and Power Conversion Systems (Chapter VIII in GALL Vol. 2)

Item

Structures 

and/or 

Components

GALL 

Rev. 0

Item 

Number

Material Environment Aging Effect/ 

Mechanism

Aging Management 

Program

Further 

Evaluation

Recommended

Basis for Change

S-39 Heat 

exchanger 

components 

VIII.F.4-a Stainless steel Treated water 

>60°C 

(>140°F)

Cracking/stress 

corrosion 

cracking

Chapter XI.M2, 

“Water Chemistry,” 

for PWR secondary 

water. 

The AMP is to be 

augmented by 

verifying the 

effectiveness of 

water chemistry 

control. See Chapter 

XI.M32, “One-Time 

Inspection,” for an 

acceptable 

verification program.

Yes, detection 

of aging effects 

is to be 

evaluated

The Staff added this 

row to address 

cracking of stainless 

steel in heat 

exchanger 

components in this 

environment for the 

PWR Steam 

Generator Blowdown 

System. The 

implementation of this 

augmented program 

provides reasonable 

assurance that the 

component’s intended 

functions will be 

maintained within the 

CLB for the extended 

period of operation.
October 2005 223 NUREG-1833

IV. Description of and Justification for Changes in Aging Management Programs

The following table describes the technical changes that were made to the Aging Management Programs in Chapters X and XI of 

GALL Revision 1. In GALL Rev. 1, the technical approach (such as visual, surface, and volumetric examination) for each of these 

AMPs is clearly defined. The following table describes the technical approach where there have been changes; otherwise, refer to 

GALL Rev. 1, Chapters X and XI for a given AMP. The following table generally does not include editorial changes.

Table IV. Justification for Changes in Aging Management Programs

GALL 

AMP Title

AMP 

Revised

(Y or N)

Summary of Change and its Basis

Referenced 

GALL Rev.1 

Chapters

X.M1 Metal Fatigue of Reactor 

Coolant Pressure Boundary

Y Revised the Program Description to note that examples of critical 

component locations are identified in NUREG/CR-6260 

Also revised the monitoring and trending section to indicate that the 

minimum sample of critical component locations includes the 

locations identified in NUREG/CR-6260. The revision to this section 

also allows proposing alternative locations based on plant-specific 

considerations in the event the locations identified in NUREG/CR6260 are not applicable to the plant’s configuration.

III, IV, V, VII, 

VIII

X.S1 Concrete Containment 

Tendon Prestress

N N/A II

X.E1 Environmental Qualification 

(EQ) of Electrical 

Components

Y In GALL Rev.0, the program description stated the following 

“However, Generic Safety Issue (GSI) 168, which is related to lowvoltage EQ instrumentation and control cables, is currently an open 

generic issue. NRC research is ongoing to provide information to 

resolve it. An applicant is to address GSI-168 in its application for 

Staff review.”

In GALL Rev.1, the reference to GSI-168 in the Program 

Description was deleted because it is no longer an open issue. 

GSI-168 was closed with NRC Regulatory Issue Summary 2003-

09, “Environmental Qualification of Low-Voltage Instrumentation 

and Control Cables” dated May 2, 2003. 

VI
NUREG-1833 224 October 2005

Table IV. Justification for Changes in Aging Management Programs

GALL 

AMP Title

AMP 

Revised

(Y or N)

Summary of Change and its Basis

Referenced 

GALL Rev.1 

Chapters

XI.M1 ASME Section XI Inservice 

Inspection, Subsections 

IWB, IWC, and IWD

Y In GALL Rev.0, this AMP referred to older editions of the ASME 

Code Section XI (1995 Edition with 1996 Addenda) and 10 CFR 

Part 50 (2000). The GALL Rev.1 version was changed to refer to 

the ASME Code Section XI (2001 Edition with 2002 and 2003 

Addenda) and the 2005 edition of 10 CFR Part 50. The following 

footnote was also added to identify the use of different versions of 

the ASME Code: “An applicant may rely on a different version of 

the ASME Code, but should justify such use. An applicant may 

wish to refer to the SOC for an update of 10 CFR § 50.55a to justify 

use of a more recent edition of the Code.”

References were changed accordingly to conform to these newer 

editions.

IV

XI.M2 Water Chemistry Y A major change was in the AMP XI.M2 Program Description and 

Element 1 “Scope of Program” to allow industry guidelines such as 

BWRVIP-29 or later revisions and “water chemistry control in 

accordance to industry guidelines.” This change was incorporated 

because later versions of these chemistry program guidelines are 

developed from collective operating experience using sound 

technical judgment, and are approved by the electric utility industry 

in an effort to constantly improve water chemistry and thereby 

manage or prevent aging effects.

Element 3 “Parameters Monitored/Inspected” Consistent with 

revisions in the AMR line-item revisions and the definition of steel in 

GALL Rev.1 Chapter IX, the term ‘steel’ has been used to 

encompass carbon steel which is no longer specifically denoted.

References have been updated to include the 2003 EPRI TR1002884, PWR Primary Water Chemistry Guidelines, and the 2005 

10 CFR Part 50.

III, IV, V, VII, 

VIII
October 2005 225 NUREG-1833

Table IV. Justification for Changes in Aging Management Programs

GALL 

AMP Title

AMP 

Revised

(Y or N)

Summary of Change and its Basis

Referenced 

GALL Rev.1 

Chapters

XI.M3 Reactor Head Closure 

Studs

Y In GALL Rev.0, this AMP referred to older editions of the ASME 

Code Section XI (1995 Edition with 1996 Addenda) and 10 CFR 

Part 50 (2000). The GALL Rev.1 version was changed to refer to 

the ASME Code Section XI (2001 Edition with 2002 and 2003 

Addenda) and the 2005 edition of 10 CFR Part 50. The following 

footnote was also added to identify the use of different versions of 

the ASME Code: “An applicant may rely on a different version of 

the ASME Code, but should justify such use. An applicant may 

wish to refer to the SOC for an update of 10 CFR § 50.55a to justify 

use of a more recent edition of the Code.”

References were changed accordingly to conform to these newer 

editions.

IV

XI.M4 BWR Vessel ID Attachment 

Welds

Y Element 3 “Parameters Monitored/Inspected” was revised to state 

that an applicant may use the guidelines of BWRVIP-62 for 

inspection relief for vessel internal components with hydrogen 

water chemistry provided that such relief is submitted under the 

provisions of 10 CFR 50.55a and approved by the Staff. 

In GALL Rev.0, this AMP referred to older editions of the ASME 

Code Section XI (1995 Edition with 1996 Addenda) and 10 CFR 

Part 50 (2000). The GALL Rev.1 version was changed to refer to 

the ASME Code Section XI (2001 Edition with 2002 and 2003

Addenda) and the 2005 edition of 10 CFR Part 50. The following 

footnote was also added to identify the use of different versions of 

the ASME Code: “An applicant may rely on a different version of 

the ASME Code, but should justify such use. An applicant may 

wish to refer to the SOC for an update of 10 CFR § 50.55a to justify 

use of a more recent edition of the Code.”

References were changed accordingly to conform to these newer 

editions.

IV
NUREG-1833 226 October 2005

Table IV. Justification for Changes in Aging Management Programs

GALL 

AMP Title

AMP 

Revised

(Y or N)

Summary of Change and its Basis

Referenced 

GALL Rev.1 

Chapters

XI.M5 BWR Feedwater Nozzle Y In GALL Rev.0, this AMP referred to older editions of the ASME 

Code Section XI (1995 Edition with 1996 Addenda) and 10 CFR 

Part 50 (2000). The GALL Rev.1 version was changed to refer to 

the ASME Code Section XI (2001 Edition with 2002 and 2003 

Addenda) and the 2005 edition of 10 CFR Part 50. The following 

footnote was also added to identify the use of different versions of 

the ASME Code: “An applicant may rely on a different version of 

the ASME Code, but should justify such use. An applicant may 

wish to refer to the SOC for an update of 10 CFR § 50.55a to justify 

use of a more recent edition of the Code.”

References were changed accordingly to conform to these newer 

editions.

IV

XI.M6 BWR Control Rod Drive 

Return Line Nozzle

Y In GALL Rev.0, this AMP referred to older editions of the ASME 

Code Section XI (1995 Edition with 1996 Addenda) and 10 CFR 

Part 50 (2000). The GALL Rev.1 version was changed to refer to 

the ASME Code Section XI (2001 Edition with 2002 and 2003 

Addenda) and the 2005 edition of 10 CFR Part 50. The following 

footnote was also added to identify the use of different versions of 

the ASME Code: “An applicant may rely on a different version of 

the ASME Code, but should justify such use. An applicant may 

wish to refer to the SOC for an update of 10 CFR § 50.55a to justify 

use of a more recent edition of the Code.”

Element 10 “Operating Experience” - NRC IN 2004-08 was added 

to further document that crack initiation and growth (referred to 

throughout the revised LRG documents as cracking) has occurred 

in several BWR plants. 

References were changed accordingly to conform to these newer 

information sources.

IV
October 2005 227 NUREG-1833

Table IV. Justification for Changes in Aging Management Programs

GALL 

AMP Title

AMP 

Revised

(Y or N)

Summary of Change and its Basis

Referenced 

GALL Rev.1 

Chapters

XI.M7 BWR Stress Corrosion 

Cracking

Y The Program Description and Element 1 “Scope of Program” were 

revised to indicate that this program also manages components 

made of nickel-based alloys. This program should also manage 

cast austenitic stainless steel (included in the definition of stainless 

steel as used in the context of these LRG documents).

Element 2 “Preventive Actions” The sentence about reactor coolant 

water chemistry being monitored and maintained in accordance 

with the guidelines in BWRVIP-29 was deleted in GALL Rev.1. 

Instead, the Program Description, and evaluation and technical 

basis of monitoring and maintaining reactor water chemistry are 

addressed through implementation of Section XI.M2, “Water 

Chemistry.”

Element 6 “Acceptance Criteria” The reference to (ASME Code 

Section XI 1995 edition through the 1996 addenda) was revised to 

read:” As recommended in NRC GL 88-01, any indication detected 

is evaluated in accordance with the ASME Section XI, Subsection 

IWB-3600 (1986 edition) and the guidelines of NUREG-0313.”

Element 10 “Operating Experience” NRC IN 2004-08 was added to 

document operating experience with IGSCC. 

References were changed accordingly to conform to these 

revisions in information sources.

IV
NUREG-1833 228 October 2005

Table IV. Justification for Changes in Aging Management Programs

GALL 

AMP Title

AMP 

Revised

(Y or N)

Summary of Change and its Basis

Referenced 

GALL Rev.1 

Chapters

XI.M8 BWR Penetrations Y In GALL Rev.0, this AMP referred to older editions of the ASME 

Code Section XI (1995 Edition with 1996 Addenda) and 10 CFR 

Part 50 (2000). The GALL Rev.1 version was changed to refer to 

the ASME Code Section XI (2001 Edition with 2002 and 2003 

Addenda) and the 2005 edition of 10 CFR Part 50. The following 

footnote was also added to identify the use of different versions of 

the ASME Code: “An applicant may rely on a different version of 

the ASME Code, but should justify such use. An applicant may 

wish to refer to the SOC for an update of 10 CFR § 50.55a to justify 

use of a more recent edition of the Code.”

Nickel-based alloys are used for joint welds as well as for weld 

overlays in BWR reactor coolant pressure boundary piping. Nickelbased alloys are susceptible to IGSCC per Chapter IV of 

NUREG-1801. Specific discussions of inspection frequencies for 

nickel-based alloy materials are contained in applicable BWRVIP 

guidelines. In addition, GALL Rev.1 AMR line-items R-68 and R-21 

specifically address this program and material. 

References were changed accordingly to conform to these 

revisions in information sources.

IV

XI.M9 BWR Vessel Internals Y Element 1 “Scope of Program” was significantly changed to better 

address BWRVIP guidance for top guide components. Relevant 

operating experience of cracking in top guide components was 

reported at the Oyster Creek, Cooper, and Quad Cities, Unit 1 

nuclear plants in the early to mid 1990s. Recent operating 

experience with cracking in U.S. top guides has been reported as a 

result of augmented examinations that were conducted at the Nine 

Mile Point, Unit 1 nuclear plant in 2003 and 2005. Therefore, 

cracking of U.S. BWR top guides is considered to be relevant 

operating experience for the U.S BWR fleet and adequate aging 

management programs for managing cracking of BWR top guides 

should be proposed for any BWR license renewal application.

Some of the top guide locations could experience high neutron 

IV
October 2005 229 NUREG-1833

Table IV. Justification for Changes in Aging Management Programs

GALL 

AMP Title

AMP 

Revised

(Y or N)

Summary of Change and its Basis

Referenced 

GALL Rev.1 

Chapters

fluence exposures and are considered to be more susceptible to 

crack initiation and growth. In D/QC SER section 3.1.2.3.6, the 

applicant proposed and Staff has accepted additional inspections. 

As a result, the former summary of top-guide BWRVIP guidelines in 

GALL Rev.0 was replaced with the following words to clarify the 

intent of the AMP:

“Additionally, for top guides with neutron fluence exceeding the 

IASCC threshold (5E20, E>lMeV) prior to the period of extended 

operation, inspect five percent (5%) of the top guide locations using 

enhanced visual inspection technique, EVT-1 within six years after 

entering the period of extended operation. An additional 5% of the 

top guide locations will be inspected within twelve years after 

entering the period of extended operation. 

Alternatively, if the neutron fluence for the limiting top guide 

location is projected to exceed the threshold for IASCC after 

entering the period of extended operation, inspect 5% of the top 

guide locations (EVT-1) within six years after the date projected for 

exceeding the threshold. An additional 5% of the top guide 

locations will be inspected within twelve years after the date 

projected for exceeding the threshold.

The top guide inspection locations are those that have high neutron 

fluences exceeding the IASCC threshold. The extent of the 

examination and its frequency will be based on a 10% sample of 

the total population, which includes all grid beam and beam-tobeam crevice slots.”

In GALL Rev.0, this AMP referred to older editions of the ASME 

Code Section XI (1995 Edition with 1996 Addenda) and 10 CFR 

Part 50 (2000). The GALL Rev.1 version was changed to refer to 

the ASME Code Section XI (2001 Edition with 2002 and 2003 

Addenda) and the 2005 edition of 10 CFR Part 50. The following 

footnote was also added to identify the use of different versions of 
NUREG-1833 230 October 2005

Table IV. Justification for Changes in Aging Management Programs

GALL 

AMP Title

AMP 

Revised

(Y or N)

Summary of Change and its Basis

Referenced 

GALL Rev.1 

Chapters

the ASME Code: “An applicant may rely on a different version of 

the ASME Code, but should justify such use. An applicant may 

wish to refer to the SOC for an update of 10 CFR § 50.55a to justify 

use of a more recent edition of the Code.”

References were changed accordingly to conform to these 

revisions in information sources.
October 2005 231 NUREG-1833

Table IV. Justification for Changes in Aging Management Programs

GALL 

AMP Title

AMP 

Revised

(Y or N)

Summary of Change and its Basis

Referenced 

GALL Rev.1 

Chapters

XI.M10 Boric Acid Corrosion Y The narrative emphasizes that potential improvements to boric acid 

corrosion program were identified as a result of recent operating 

experience with cracking of certain nickel alloy pressure boundary 

components (NRC Regulatory Issue Summary 2003-013).

Element 1 “Scope of Program” GALL Rev.1 added to the scope of 

the GALL BAC program specific guidance for inspection of all 

components that contain boric acid where leakage could contact 

components, structures, and electrical components that are subject 

to aging management review. GALL Rev.1 added aluminum to 

materials affected. 

Element 4 “Detection of Aging Effects” GALL Rev.1 also added 

requirements for ensuring that boric acid leakage, however it is 

found, is to be evaluated in accordance with this program. 

References were changed accordingly to conform to these 

revisions in information sources GALL Rev.1 updated references to 

include applicable documents issued since 2001.

The basis for adding systems/components beyond the scope of GL 

88-05 to inspections and the interface with other (e.g., 

maintenance) activities is the operating experience accrued since 

2001 as cited in the references added. 

A precedent exists for adding aluminum: In VCS SER Section 

3.0.3.1.1, the Staff accepted the position that loss of material 

exhibited by aluminum in an air with borated water leakage 

environment is properly managed by the Boric Acid Corrosion AMP 

which provides engineering evaluations and corrective actions to 

ensure that boric acid corrosion does not lead to degradation of the 

leakage source or adjacent structures or components. 

III, IV, V, VI,

VII, VIII

XI.M11 Nickel-Alloy Nozzles and 

Penetrations

Y This AMP has been replaced by AMP XI.M11-A. Guidance for the 

aging management of other nickel-alloy nozzles and penetrations is 

provided in the AMR lines of Chapter IV of GALL Rev.1, as 

appropriate. 

Not Used in 

GALL Rev.1

AMR tables
NUREG-1833 232 October 2005

Table IV. Justification for Changes in Aging Management Programs

GALL 

AMP Title

AMP 

Revised

(Y or N)

Summary of Change and its Basis

Referenced 

GALL Rev.1 

Chapters

XI.M11-A Nickel-Alloy Penetration 

Nozzles Welded to the 

Upper Reactor Vessel 

Closure Heads of 

Pressurized Water Reactors

New AMP This program was established to ensure that augmented inservice 

inspections (ISI) of all nickel-alloy vessel head penetration (VHP) 

nozzles welded to the upper reactor vessel (RV) head of a PWRdesigned light-water reactor will continue to be performed as 

mandated by the interim requirements in Order EA-03-009, 

“Issuance of Order Establishing Interim Inspection Requirements 

for Reactor Pressure Vessel Heads at Pressurized Water 

Reactors,” as amended by the First Revision of the Order, or by 

any subsequent NRC requirements that may be established to 

supplement the requirements of Order EA-03-009.

IV

XI.M12 Thermal Aging 

Embrittlement of Cast 

Austenitic Stainless Steel 

(CASS)

N N/A IV, V

XI.M13 Thermal Aging and Neutron 

Irradiation Embrittlement of 

Cast Austenitic Stainless 

Steel (CASS)

N N/A IV

XI.M14 Loose Part Monitoring N N/A Not Used in 

GALL Rev.1

AMR tables

XI.M15 Neutron Noise Monitoring N N/A Not Used in 

GALL Rev.1

AMR tables

XI.M16 PWR Vessel Internals Y Reference to this program by the AMR line-items was replaced by 

specific guidance within the AMR line-items of Chapter IV, as 

appropriate. 

Not Used in 

GALL Rev.1

AMR tables
October 2005 233 NUREG-1833

Table IV. Justification for Changes in Aging Management Programs

GALL 

AMP Title

AMP 

Revised

(Y or N)

Summary of Change and its Basis

Referenced 

GALL Rev.1 

Chapters

XI.M17 Flow-Accelerated Corrosion Y Element 5 ”Monitoring and Trending” was revised to indicate that 

Inspection results are evaluated to determine if additional 

inspections are needed to assure that the extent of wall thinning is 

adequately determined, identify corrective actions, and assure that 

intended function will not be lost.

Plant Flow-Accelerated Corrosion programs typically use a 

threshold limit for sample expansion. A strict threshold based on 

measured degradation being more than predicted would require 

sample expansion where it is necessary.

In a real world application, if the FAC program owner predicts the 

wear to be 5 mils over an 18-month period and the actual as-found 

wear is 6 mils then, per GALL Rev.0, sample expansion is 

necessary. Clearly, the wear is one consideration, but the minimum 

wall thickness is a critical input to the need for sample expansion. 

In this particular example, if the pipe wall is 0.25 inches and has a 

minimum allowable wall thickness of 0.15 inches, then the pipe will 

last 16 refueling cycles. Sample expansion in this case is not 

necessary.

Thus in GALL Rev.0, Element 5, Monitoring and Trending, the 

statement “If degradation is detected such that the wall thickness is 

less than the minimum predicted thickness, additional examinations 

are performed in adjacent areas to bound the thinning” was 

replaced in GALL Rev.1 by “Inspection results are evaluated to 

determine if additional inspections are needed to assure that the 

extent of wall thinning is adequately determined, assure that 

intended function will not be lost, and identify corrective actions.”

IV, V, VII
NUREG-1833 234 October 2005

Table IV. Justification for Changes in Aging Management Programs

GALL 

AMP Title

AMP 

Revised

(Y or N)

Summary of Change and its Basis

Referenced 

GALL Rev.1 

Chapters

XI.M18 Bolting Integrity Y This program was extensively revised to allow the AMP to include 

non-ASME bolting, and thus making the program more broadly 

applicable. The program description and scope were thus 

expanded. Significant changes include the following:

• Better definitions for which aging mechanisms are managed 

by this AMP.

• Better clarification on which type of bolting is within the scope 

of this program, including ASME Code Class 1, 2, and 3 

bolting, structural bolting, and in-scope non-safety related 

bolting or safety-related non-ASME bolting.

• Revised references to ASME Section XI Code C

• Clarifications regarding the use of code editions identified in 10 

CFR 50, Code Cases identified in RG 1.147, Code references 

for Class 3 bolting and reference to the operating experience 

with tee-quencher support bolts. 

• Revised Operating Experience section noting that leakage 

from bolted connections has been observed in reactor building 

closed cooling systems of BWRs (LER 50-341/2005-001).

III, IV, V, VII, 

VIII
October 2005 235 NUREG-1833

Table IV. Justification for Changes in Aging Management Programs

GALL 

AMP Title

AMP 

Revised

(Y or N)

Summary of Change and its Basis

Referenced 

GALL Rev.1 

Chapters

XI.M19 Steam Generator Tube 

Integrity

Y The following changes were made:

• Eliminated the reference to “Staff review of NEI 97-06" & 

eliminated the requirement for NRC plant-specific review of a 

licensee’s steam generator tube integrity AMP - The Staff is 

reviewing generic revisions to the standard technical 

specifications, based on the provisions of NEI 97-06, which are 

intended to upgrade the standard technical specifications to 

assure the condition of the tubes remains adequate for the 

period of time between inspections. Also, considering that there 

is a framework in place, including Code of Federal Regulations, 

plant technical specifications, industry guidelines, and NRC 

oversight and review of plant’s steam generator integrity 

activities, makes the further review of this AMP unnecessary.

• Element 1 “Scope of Program” clarified the inclusion of steam 

generator sleeves and plugs. This makes the AMP consistent 

with the line-item in GALL volume 2 section IV.

• Included tube support lattice bars and tube support plates 

made of carbon steel in the AMP scope, and eliminated the 

requirement for plant-specific aging management program for 

these components - All PWR licensees have committed 

voluntarily to a SG degradation management program 

described in NEI 97-06. The Staff has concluded that if the 

steam generator tube integrity AMP includes the carbon steel 

tube supports, lattice bars and tube support plates in the 

program scope, references the licensee’s response to NRC GL 

97-06 and the licensee’s intent to maintain steam generator 

secondary-side integrity in accordance with NEI 97-06 

guidelines, a separate plant-specific program is not needed. In 

addition, subsequent NRC plant-specific review of the steam 

generator tube integrity AMP for these components is not 

necessary. GALL Rev.1 Chpt. IV AMR line-items R-41 and R42 are examples where this AMP is applied to lattice bars.

IV
NUREG-1833 236 October 2005

Table IV. Justification for Changes in Aging Management Programs

GALL 

AMP Title

AMP 

Revised

(Y or N)

Summary of Change and its Basis

Referenced 

GALL Rev.1 

Chapters

XI.M20 Open-Cycle Cooling Water 

System

Y Elastomers were added to the Parameters Monitored since they 

also are inspected, monitored, or tested by the program. CNP SER 

Section 3.3.2.3.2 acknowledged the potential for a change of 

material properties for elastomeric components exposed to a raw 

water environment in the open-cycle cooling water system. In CNP 

SER Section 3.3.2.1.2 the Staff accepted that hardening and loss 

of strength is adequately managed by AMP XI.M20. 

As an example of its use, the new AMR line-items AP-75 and AP76 in GALL Rev.1 Chpt. VII were added to address the aging 

effects and mechanisms of hardening and loss of 

strength/elastomer degradation and loss of material/erosion of 

elastomers in a raw water environment and to reference AMP 

XI.M20.

Although this program may be used to manage elastomers in the 

service water system, GL 89-13, on which AMP XI.M20 is based, 

does not specifically identify elastomers and recent applications 

such as Palisades and Oyster Creek do not manage elastomers 

with the open-cycle cooling water AMP. In response to RAI 

B2.1.20-1(c), Palisades specifically clarified that elastomers in the 

service water system are not considered long lived components. 

V, VII, VIII
October 2005 237 NUREG-1833

Table IV. Justification for Changes in Aging Management Programs

GALL 

AMP Title

AMP 

Revised

(Y or N)

Summary of Change and its Basis

Referenced 

GALL Rev.1 

Chapters

XI.M21 Closed-Cycle Cooling 

Water System

Y Modified the first paragraph in the Program Description to clarify 

that the focus is on ensuring that intended functions are not 

compromised by aging. This paragraph was also revised to clarify 

the intent of guidance in EPRI TR-107396. 

The Program Description was changed to add cracking/stress 

corrosion cracking in addition to corrosion as aging mechanisms 

managed by this AMP. The EPRI guidelines referenced by this 

AMP include management of this aging effect. This change (the

inclusion of stress corrosion cracking as an aging effect managed 

by the AMP) was also included in other sections of the AMP, where 

appropriate.

Modified Element 4, Detection of Aging Effects, to delete “pump 

wear characteristics.” Pump wear characteristics are an active 

function outside the scope of license renewal.

Modified Element 5, Monitoring and Trending, to remove incorrect 

attributions to EPRI TR -107396 and align better with the EPRI 

document with regard to the periodicity of testing depending on

plant-specific considerations. 

Modified Element 6, Acceptance Criteria, to clarify that acceptance 

criteria are also in accordance with the plant operating license and 

licensing basis (in addition to the EPRI TR). 

Corrected the date of the EPRI TR in the references section. 

IV, V, VII, VIII

XI.M22 Boraflex Monitoring N N/A VII
NUREG-1833 238 October 2005

Table IV. Justification for Changes in Aging Management Programs

GALL 

AMP Title

AMP 

Revised

(Y or N)

Summary of Change and its Basis

Referenced 

GALL Rev.1 

Chapters

XI.M23 Inspection of Overhead 

Heavy Load and Light Load 

(Related to Refueling) 

Handling Systems

Y The Program Description was modified to delete the reference to 

the maintenance rule. The intent of this deletion is to focus the 

AMP on detection of aging effects of components associated with 

the crane within the scope of license renewal, rather than the active 

components which are outside the scope of license renewal. 

Operating experience was revised similarly to delete the reference 

to the maintenance rule. 

The Parameters Monitored/Inspected section was revised to delete 

the sentence related to number of lifts. Operating Experience has 

determined that this is not a parameter that is monitored. The 

number of lifts is typically significantly lower than what the crane is 

designed for.

The Detection of Aging Effect section was revised to delete the 

sentence related to functional testing since this test is primarily 

performed to test the active portions of the crane, which is not 

within the scope of license renewal.

VII

XI.M24 Compressed Air Monitoring N N/A VII
October 2005 239 NUREG-1833

Table IV. Justification for Changes in Aging Management Programs

GALL 

AMP Title

AMP 

Revised

(Y or N)

Summary of Change and its Basis

Referenced 

GALL Rev.1 

Chapters

XI.M25 BWR Reactor Water 

Cleanup System

Y NRC Generic Letter 89-10 was added to the references since it is 

discussed in the scope of the program.

In GALL Rev.0, this AMP referred to older editions of the ASME 

Code Section XI (1995 Edition with 1996 Addenda) and 10 CFR 

Part 50 (2000). The GALL Rev.1 version was changed to refer to 

the ASME Code Section XI (2001 Edition with 2002 and 2003 

Addenda) and the 2005 edition of 10 CFR Part 50. The following 

footnote was also added to identify the use of different versions of 

the ASME Code: “An applicant may rely on a different version of 

the ASME Code, but should justify such use. An applicant may 

wish to refer to the SOC for an update of 10 CFR § 50.55a to justify 

use of a more recent edition of the Code.”

References were changed accordingly to conform to these 

revisions in information sources.

VII

XI.M26 Fire Protection Y Element 3 “Parameters Monitored/Inspected” is revised based on 

guidance in ISG-4. In ISG-4, the Staff stated, “NUREG-1801, 

Chapter XI.M26, “Fire Protection,” currently identifies the need to 

perform a functional test of the halon/carbon dioxide fire 

suppression systems to determine the suppression agent charge 

pressure and verify that the extinguishing agent supply valves are 

open and the system is in automatic mode. Section 54.21 of Title 

10 of the Code of Federal Regulations (CFR) specifies that an 

aging management review is to be performed for those structures 

and components that perform an intended function without moving 

parts, or without a change in configuration or properties, and that 

are not subject to replacement based on a qualified life or specified 

time period. The Staff reviewed these items and determined that 

requiring a monthly valve lineup inspection, charging pressure 

inspection, and an automatic mode of operation verification are 

operational activities pertaining to system or component 

configurations or properties that may change, and therefore are not 

related to aging management. Consequently, the Staff position is to 

revise XI.M26 to continue the performance of functional testing, but 

VII
NUREG-1833 240 October 2005

Table IV. Justification for Changes in Aging Management Programs

GALL 

AMP Title

AMP 

Revised

(Y or N)

Summary of Change and its Basis

Referenced 

GALL Rev.1 

Chapters

to eliminate the monthly halon/carbon dioxide system inspections 

for charging pressure, valve lineups, and automatic mode of 

operation.”

Element 3 “Parameters Monitored/Inspected” was revised 

according to ISG-4. The visual inspection interval was changed 

from a defined interval to a plant-specific interval based on plant 

operating experience and engineering evaluation. As an example, 

in GALL Rev. 0, the AMP stated that hollow metal doors are 

visually inspected at least once bi-monthly for holes in the skin of 

the door. In GALL Rev.1, the AMP states that Fire-rated doors are 

visually inspected on a plant-specific interval to verify the integrity 

of door surfaces and for clearances. The plant-specific inspection 

intervals are to be determined by engineering evaluation in order to 

detect degradation of the fire doors prior to the loss of intended 

function. This change also affects Element 5, “Monitoring and 

Trending.”

Element 4 “Detection of Aging Effects” was revised to replace 

prescriptive inspection requirements with a general requirement 

that inspectors are qualified. As an example, in GALL Rev.1, the 

AMP stipulates that visual inspection by fire protection qualified 

inspectors of approximately 10% of each type of seal in walkdowns 

is performed at least once every fueling cycle. GALL Rev. 0 did not 

stipulate the visual inspection be performed by fire protection 

qualified inspectors. This change was made to emphasize the 

importance of the training and knowledge of fire protection qualified 

inspectors.
October 2005 241 NUREG-1833

Table IV. Justification for Changes in Aging Management Programs

GALL 

AMP Title

AMP 

Revised

(Y or N)

Summary of Change and its Basis

Referenced 

GALL Rev.1 

Chapters

XI.M27 Fire Water System Y In ISG-4, the Staff stated, “Internal inspections performed during 

each refueling cycle by disassembling portions of the FP piping, as 

stated in NUREG-1801, Chapter XI.M27, “Fire Water Systems,” 

may not be the most effective means to detect this aging effect. 

Each time the system is opened, oxygen is introduced into the 

system, and this accelerates the potential for general corrosion. 

Therefore, the Staff recommends that the applicant perform a 

baseline pipe wall thickness evaluation of the fire protection piping 

using a non-intrusive means of evaluating wall thickness, such as 

volumetric inspection, to detect this aging effect before the current 

license term expires.”

ISG-4 also states, “The 50-year service life of sprinkler heads does 

not necessarily occur at the 50th year of operation in terms of 

licensing. The service life is defined from the time the sprinkler 

system is installed and functional. The Staff recommends, in 

accordance with NFPA 25, that sprinkler head testing should be 

performed at year 50 of sprinkler system service life, not at year 50 

of plant operation, with subsequent sprinkler head testing every 10 

years thereafter.” Other appropriate changes were made per ISG-4.

NFPA Code References in this program were revised to reflect the 

most current edition.

VII

XI.M28 Buried Piping and Tanks 

Surveillance

N N/A V, VII, VIII

XI.M29 Aboveground Carbon Steel 

Tanks

N N/A VII, VIII

XI.M30 Fuel Oil Chemistry Y The program was revised to indicate that its scope is focused on 

managing the conditions that cause general, pitting, and 

microbiologically influenced corrosion (MIC) of the diesel fuel tank 

internal surfaces in accordance with the plant’s technical 

specifications (i.e., NUREG-1430, NUREG-1431, NUREG-1432, 

NUREG-1433) on fuel oil purity and the guidelines of ASTM 

Standards D1796, D2276, D2709, D6217, and D4057.

VII
NUREG-1833 242 October 2005

Table IV. Justification for Changes in Aging Management Programs

GALL 

AMP Title

AMP 

Revised

(Y or N)

Summary of Change and its Basis

Referenced 

GALL Rev.1 

Chapters

XI.M31 Reactor Vessel Surveillance Y Added the following paragraph to the Program Description: “All 

capsules in the reactor vessel that are removed and tested must 

meet the test procedures and reporting requirements of ASTM E 

185-82 to the extent practicable for the configuration of the 

specimens in the capsule. Any changes to the capsule withdrawal 

schedule, including spare capsules, must be approved by the NRC 

prior to implementation. Untested capsules placed in storage must 

be maintained for future insertion.” ASTM E-185 is referenced in 10 

CFR Part 50, Appendix H.

IV

XI.M32 One-Time Inspection Y The Program Description was modified to clarify the purpose and 

role of one-time inspections. Added a sentence to indicate that 

Class 1 piping less than or equal to NPS 4 is now covered by a 

new AMP XI.M35, “One Time Inspection of ASME Code Class 1 

Small Bore-Piping.” Consistent with the requirements of 10 CFR 

54.21(a)(1), the AMP XI.M35 stipulates a one-time volumetric 

examination of ASME Code Class 1 small-bore piping and includes 

pipes, fittings, and branch connections. See XI.M35 below for the 

basis for this new AMP.

In the GALL Rev.0 Program Description of AMP XI.M32, the 

sentence “One-time inspection, or any other action or program, is 

to be reviewed by the Staff on a plant-specific basis” was clarified 

in GALL Rev.1 to state “One-time inspection, or any other action or 

program, created to verify the effectiveness of an AMP and confirm 

the absence of an aging effect, is to be reviewed by the Staff on a 

plant-specific basis.”

Modified Element 3, Parameters Monitored/Inspected, to clarify that 

qualified personnel are to perform inspections.

Modified Element 4, Detection of Aging Effects, to clarify 

expectations regarding inspection techniques to be used for 

different aging effects/mechanisms. This included adding a new 

table associating acceptable NDE techniques with aging 

effects/mechanisms. Also added clarification regarding the 

IV, V, VII, VIII
October 2005 243 NUREG-1833

Table IV. Justification for Changes in Aging Management Programs

GALL 

AMP Title

AMP 

Revised

(Y or N)

Summary of Change and its Basis

Referenced 

GALL Rev.1 

Chapters

considerations to be applied in establishing the timing/schedule of 

inspections. This is to ensure that the inspections provide 

reasonable assurance aging effects do not compromise intended 

functions at any point during the period of extended operation. 

Modified Element 5, Monitoring and Trending, to clarify that 

monitoring and trending requirements will depend on the results of 

the inspections and will be established in accordance with the 

corrective action process. 

Modified Element 10, Operating Experience, to clarify that this 

program applies to potential aging effects for which there is 

currently no operating experience indicating the need for an aging 

management program. 

Updated the ASME Section XI edition that applies.

XI.M33 Selective Leaching of 

Materials

Y The Scope of the Program was modified to include visual

inspection and hardness measurements to be consistent with the 

Parameters Monitored/Inspected.

IV, V, VII, VIII

XI.M34 Buried Piping and Tanks 

Inspection

Y Element 4 “Detection of Aging Effects” was revised to clarify the 

emphasis between periodic inspection and opportunistic inspection. 

In GALL Rev.1, the AMP XI.M34 added the following paragraph 

“The applicant’s program is to be evaluated for the extended period 

of operation. It is anticipated that one or more opportunistic 

inspections may occur within a ten-year period. Prior to entering the 

period of extended operation, the applicant is to verify that at least 

one opportunistic or focused inspection has been performed within 

the past ten years. Upon entering the period of extended operation, 

the applicant is to perform a focused inspection within ten years, 

unless an opportunistic inspection occurred within this ten-year 

period. Any credited inspection should be performed in areas with 

the highest likelihood of corrosion problems, and in areas with a 

history of corrosion problems.” 

V, VII, VIII
NUREG-1833 244 October 2005

Table IV. Justification for Changes in Aging Management Programs

GALL 

AMP Title

AMP 

Revised

(Y or N)

Summary of Change and its Basis

Referenced 

GALL Rev.1 

Chapters

XI.M35 One-time Inspection of 

ASME Code Class 1 Small 

Bore-Piping

New AMP This new program is applicable to small-bore ASME Code Class 1 

piping and systems less than or equal to 4 inches nominal pipe size 

(NPS 4), which includes pipes, fittings, and branch connections. 

Consistent with the requirements of 10 CFR 54.21(a)(1), the AMP 

stipulates a one-time volumetric examination of ASME Code Class 

1 small-bore piping.

According to Table IWB-2500-1, Examination Category B-J Item 

No. B9.21 of the current ASME code, for small-bore Class 1 piping, 

a surface examination should be included for piping less than or 

equal to NPS 4 and greater than or equal to NPS 1. Also, 

Examination Category B-P requires system leakage and 

hydrostatic tests. However, for a one-time inspection to detect 

cracking resulting from thermal and mechanical loading or 

intergranular stress corrosion, the inspection should be a 

volumetric examination. This is to provide additional assurance that 

either aging of small-bore ASME Code Class 1 piping is not 

occurring or the aging is insignificant, such that an aging 

management program is not warranted. The AMP recommends 

that the applicant inspect a statistically significant sample size of 

small-bore ASME Code Class 1.

This program is applicable only to plants that have not experienced 

cracking of ASME Code Class 1 small-bore piping resulting from 

stress corrosion or thermal and mechanical loading. Should 

evidence of significant aging be revealed by a one-time inspection 

or previous operating experience, the applicant should propose and 

credit a plant-specific AMP to manage age-related degradation of 

its ASME Code Class 1 small-bore piping.

IV

XI.M36 External Surfaces 

Monitoring

New AMP This aging management program is based on industry practice. 

Nuclear plants have been using a similar type of program for years. 

Most plants have used system engineering or operator walkdowns 

to monitor plant conditions and have maintained the plant through 

appropriate corrective actions.

V, VII, VIII
October 2005 245 NUREG-1833

Table IV. Justification for Changes in Aging Management Programs

GALL 

AMP Title

AMP 

Revised

(Y or N)

Summary of Change and its Basis

Referenced 

GALL Rev.1 

Chapters

Approved precedents exist for adding this aging management 

program to GALL Rev.1 based on current industry practice. Each 

plant may have a different name for the program; however, the ten 

elements of their programs are similar to the ten elements of this 

program. For example, in FNP SER section 3.0.3.3.2, the Staff 

accepted a similar External Surfaces Monitoring program; in RNP 

SER section 3.0.3.11 and in Ginna SER section 3.0.3.11, the Staff 

accepted a similar Systems Monitoring Program and concluded 

that the applicant had demonstrated that the effects of aging would 

be adequately managed so that the intended functions would be 

maintained consistent with the CLB for the period of extended 

operation.

This program is based on system inspections and walkdowns. This 

program consists of periodic visual inspections on external surfaces 

of steel components such as piping, piping components, ducting, 

and other equipment within the scope of license renewal and 

subject to aging management review in order to manage aging 

effects. The program manages aging effects through visual 

inspection of external surfaces for evidence of material loss and 

leakage. The program is based upon the expectation that any 

adverse loss of material condition will manifest itself in the form of 

visually detectable general corrosion or leakage long before the 

aging effect is reasonably expected to impair the component or 

structures ability to perform its intended safety function. 

Furthermore, this program is to be used only when other more 

specific programs are not identified for use. For example, the AMP 

XI.M10, Boric Acid Corrosion Program, performs monitoring for 

borated water leakage and manages the associated aging effects 

and the AMP XI.M29, “Aboveground Steel Tanks“, performs 

inspections on steel tanks and manages the associated aging 

effects.

Surfaces that are inaccessible during plant operations are 

inspected during refueling outages. Surfaces that are inaccessible 
NUREG-1833 246 October 2005

Table IV. Justification for Changes in Aging Management Programs

GALL 

AMP Title

AMP 

Revised

(Y or N)

Summary of Change and its Basis

Referenced 

GALL Rev.1 

Chapters

during both plant operations and refueling outages are inspected 

during the performance of periodic surveillance tests or during 

preventive maintenance activities to provide reasonable assurance 

that effect of aging will be managed such that applicable 

components will perform their intended function during the period of 

extended operation. Additionally, surfaces that are insulated may 

be inspected when the insulation is removed and the external 

surface is exposed during routine maintenance operations, in 

accordance with industry guidelines concerning topics such as 

corrosion under insulation.

The program may also be credited with managing loss of material 

from internal surfaces, for situations in which material and 

environment combinations are the same for internal and external 

surfaces such that external surface condition is representative of 

internal surface condition. For cases such as ducting when it can 

be demonstrated that the internal and external environments are 

the same, results from this program’s inspection on external 

surfaces may be used to indicate the conditions on the internal 

surfaces.

Since this new program is based on industry practice, has been 

implemented in nuclear plants over a number of years, and similar 

programs have been accepted by the NRC in previous application, 

no further evaluation is recommended for this program.

XI.M37 Flux Thimble Tube 

Inspection

New AMP This program was created based on current industry practice and 

to monitor for thinning of the flux thimble tube walls. The flux 

thimble tubes (also referred to as flux detector thimble tubes) 

provide a path for the incore neutron flux monitoring system 

detectors and form part of the RCS pressure boundary. Flux 

thimble tubes are subject to loss of material at certain locations in 

the reactor vessel where flow-induced fretting causes wear at 

discontinuities in the path from the reactor vessel instrument nozzle 

to the fuel assembly instrument guide tube. 

IV
October 2005 247 NUREG-1833

Table IV. Justification for Changes in Aging Management Programs

GALL 

AMP Title

AMP 

Revised

(Y or N)

Summary of Change and its Basis

Referenced 

GALL Rev.1 

Chapters

An NDE methodology, such as eddy current testing (ECT) or other 

applicant-justified and NRC-accepted inspection method, is used to 

monitor for wear of the flux thimble tubes. 

This program implements the recommendations of NRC IE Bulletin 

88-09, "Thimble Tube Thinning in Westinghouse Reactors." The 

scope of the program encompasses all of the flux thimble tubes 

that form part of the reactor coolant system pressure boundary. 

The flux thimble guide tubes are not in the scope of this program. 

Within the scope are the licensee responses to Bulletin 88-09, as 

accepted by the Staff in their closure letters on the Bulletin, and 

any amendments to the licensee responses as approved by the 

Staff. 

The program includes: (1) specific augmented inspections using 

ECT or other applicant-justified and NRC-accepted inspection 

technique for detecting wear in flux detector thimble tubes, (2) 

bases for establishing a base-line monitoring frequency for the 

augmented examinations of the flux detector thimble tube based on 

applicant’s response to NRC Bulletin 88-09 and bases for 

amending the monitoring frequency based on actual plant-specific 

thimble tube wear rate results, (3) specific evaluation acceptance 

criteria to be used if loss of material by wear is detected in the flux 

detector thimble tubes, and (4) specific corrective actions to be 

taken if the acceptance criteria is exceeded.

The program has been referenced in GALL Rev. 1 AMR line-item 

R-145 to manage loss of material due to wear in stainless steel 

instrumentation support structures and flux thimble tubes exposed 

to reactor coolant envi ronment.

XI.M38 Inspection of Internal 

Surfaces in Miscellaneous 

Piping and Ducting 

Components

New AMP This aging management program is based on industry practice. 

Nuclear plants have years of experience using similar programs 

which use periodic surveillance or preventive maintenance 

activities to perform visual inspection of internal surfaces when they 

are accessible.

V, VII, VIII
NUREG-1833 248 October 2005

Table IV. Justification for Changes in Aging Management Programs

GALL 

AMP Title

AMP 

Revised

(Y or N)

Summary of Change and its Basis

Referenced 

GALL Rev.1 

Chapters

The program visually inspects internal surfaces of steel piping, 

piping elements, ducting, and components in an internal 

environment (such as indoor uncontrolled air, condensation and 

steam) that are not included in other aging management programs 

for loss of material. Inspections are performed when the internal 

surfaces are accessible during the performance of periodic 

surveillances, during maintenance activities or during scheduled 

outages. The scope of the inspection and inspection techniques 

are consistent with industry practice and Staff expectations. The 

program is based upon the expectation, based on both industry 

and NRC experience, that any adverse loss of material condition 

will manifest itself in the form of visually detectable general 

corrosion long before the aging effect is reasonably expected to 

impair the component or structures ability to perform its intended 

safety function. 

Results of the periodic inspections are monitored for indications of 

various corrosion mechanisms and fouling. Although this program 

is not credited for detecting fouling, should it be present, fouling 

could be visually detected. Therefore, fouling was included as a 

monitored condition and included in the acceptance criteria.

Furthermore, these programs are to be used only when other more 

specific programs are not identified for use. For example, where 

specific AMPs such as XI.M27, “Fire Water System,” or XI.M24, 

“Compressed Air Monitoring,” is recommended in GALL Rev.1, 

those programs will be used. 

Approved precedents exist for adding this aging management 

program to GALL Rev.1 based on current industry practice. In 

ANO-2 SER section 3.0.3.3.7, the Staff accepted a similar program 

that performs visual inspection of components when the internal 

surfaces are accessible during performance of surveillance tests or 

preventive maintenance and concluded that the applicant had 
October 2005 249 NUREG-1833

Table IV. Justification for Changes in Aging Management Programs

GALL 

AMP Title

AMP 

Revised

(Y or N)

Summary of Change and its Basis

Referenced 

GALL Rev.1 

Chapters

demonstrated that the effects of aging would be adequately 

managed so that the intended functions would be maintained 

consistent with the CLB for the period of extended operation.

The periodic surveillances and preventive maintenance are 

performed at routine intervals when internal surfaces become 

accessible for visual inspection. Since this program is based on 

industry practice, has been implemented in nuclear plants over a 

number of years, and similar programs have been accepted by the 

NRC in previous applications, no further evaluation is 

recommended for this program.

XI.M39 Lubricating Oil Analysis New AMP An approved precedent exists for adding this aging management 

program to GALL Rev.1. In D/QC SER section 3.0.3.16.2, the Staff 

accepted a similar program that performs lubricating oil analysis 

and concluded that the applicant had demonstrated that the effects 

of aging would be adequately managed so that the intended 

functions would be maintained consistent with the CLB for the 

period of extended operation.

This program ensures the oil environment in the mechanical 

systems is maintained to the required quality. The program 

maintains oil systems free of contaminants (primarily water and 

particulates) thereby preserving an environment that is not 

conducive to loss of mat erial, cracking, or reduction of heat 

transfer. Lubricating oil testing activities include sampling and 

analysis of lubricating oil for detrimental contaminants. The 

presence of water or particulates may also be indicative of 

inleakage and corrosion product buildup.

V, VII, VIII
NUREG-1833 250 October 2005

Table IV. Justification for Changes in Aging Management Programs

GALL 

AMP Title

AMP 

Revised

(Y or N)

Summary of Change and its Basis

Referenced 

GALL Rev.1 

Chapters

XI.S1 ASME Section XI, 

Subsection IWE

Y In GALL Rev.0, this AMP referred to older editions of the ASME 

Code Section XI (1995 Edition with 1996 Addenda) and 10 CFR 

Part 50 (2000). The GALL Rev.1 version was changed to refer to 

the ASME Code Section XI (2001 Edition with 2002 and 2003 

Addenda) and the 2005 edition of 10 CFR Part 50. The following 

footnote was also added to identify the use of different versions of 

the ASME Code: “An applicant may rely on a different version of 

the ASME Code, but should justify such use. An applicant may 

wish to refer to the SOC for an update of 10 CFR § 50.55a to justify 

use of a more recent edition of the Code.”

References were changed accordingly to conform to these 

revisions in information sources.

II

XI.S2 ASME Section XI, 

Subsection IWL

Y In GALL Rev.0, this AMP referred to older editions of the ASME 

Code Section XI (1995 Edition with 1996 Addenda) and 10 CFR 

Part 50 (2000). The GALL Rev.1 version was changed to refer to 

the ASME Code Section XI (2001 Edition with 2002 and 2003 

Addenda) and the 2005 edition of 10 CFR Part 50. The following 

footnote was also added to identify the use of different versions of 

the ASME Code: “An applicant may rely on a different version of 

the ASME Code, but should justify such use. An applicant may 

wish to refer to the SOC for an update of 10 CFR § 50.55a to justify 

use of a more recent edition of the Code.”

References were changed accordingly to conform to these 

revisions in information sources.

II
October 2005 251 NUREG-1833

Table IV. Justification for Changes in Aging Management Programs

GALL 

AMP Title

AMP 

Revised

(Y or N)

Summary of Change and its Basis

Referenced 

GALL Rev.1 

Chapters

XI.S3 ASME Section XI, 

Subsection IWF

Y In GALL Rev.0, this AMP referred to older editions of the ASME 

Code Section XI (1995 Edition with 1996 Addenda) and 10 CFR 

Part 50 (2000). The GALL Rev.1 version was changed to refer to 

the ASME Code Section XI (2001 Edition with 2002 and 2003 

Addenda) and the 2005 edition of 10 CFR Part 50. The following 

footnote was also added to identify the use of different versions of 

the ASME Code: “An applicant may rely on a different version of 

the ASME Code, but should justify such use. An applicant may 

wish to refer to the SOC for an update of 10 CFR § 50.55a to justify 

use of a more recent edition of the Code.”

References were changed accordingly to conform to these 

revisions in information sources.

III

XI.S4 10 CFR Part 50, Appendix J N N/A II

XI.S5 Masonry Wall Program N N/A III

XI.S6 Structures Monitoring 

Program

N N/A II, III, VI, VII

XI.S7 RG 1.127, Inspection of 

Water-Control Structures 

Associated with Nuclear 

Power Plants

Y In the Program Description, added a statement that aging 

management of certain structures and components may be 

included in the Structures Monitoring Program (XI.S6). 

III

XI.S8 Protective Coating 

Monitoring and 

Maintenance Program

Y Updated the references to the ASTM standards in the elements to 

this AMP.

II

XI.E1 Electrical Cables and 

Connections Not Subject to 

10 CFR 50.49 

Environmental Qualification 

Requirements

N N/A VI
NUREG-1833 252 October 2005

Table IV. Justification for Changes in Aging Management Programs

GALL 

AMP Title

AMP 

Revised

(Y or N)

Summary of Change and its Basis

Referenced 

GALL Rev.1 

Chapters

XI.E2 Electrical Cables and 

Connections Not Subject to 

10 CFR 50.49 

Environmental Qualification 

Requirements Used in 

Instrumentation Circuits

Y Included “Connections” in the title, was missed in GALL Rev.0.

Revised the AMP to allow two methods of identifying degradation. 

In the first method, calibration results or findings of surveillance 

testing programs are evaluated to identify the existence of cable 

aging degradation. In cases where calibration or surveillance 

program does not include the cabling system in the testing circuit, 

or as an alternative to the review of calibration results, the applicant 

will perform cable system testing. In this second method, direct 

testing of the cable system is performed. This incorporates the 

alternate method in the ISG-15. 

In GALL Rev.1, AMP XI.E2, the appropriate elements were revised 

to address these two methods discussed above.

Clarified that this AMP applies to high-range-radiation and neutron 

flux monitoring instrumentation cables in addition to other cables 

used in high voltage, low-level signal applications that are sensitive 

to reduction in insulation resistance. For these cables XI.E1 does 

not apply.

Element 7 “Corrective Actions” was revised to require engineering 

evaluation when acceptance criteria are not met.

VI
October 2005 253 NUREG-1833

Table IV. Justification for Changes in Aging Management Programs

GALL 

AMP Title

AMP 

Revised

(Y or N)

Summary of Change and its Basis

Referenced 

GALL Rev.1 

Chapters

XI.E3 Inaccessible Medium 

Voltage Cables Not Subject 

to 10 CFR 50.49 

Environmental Qualification 

Requirements

Y Noted in the Program Description that potential uncertainties 

involved with water trees exist even with duct banks that are sloped 

to minimize water accumulation. The above actions are not 

sufficient to assure that water is not trapped elsewhere in the 

raceways. For example, if duct bank conduit has low points in the 

routing, there could be potential for long term submergence at 

these low points. In addition, concrete raceways may crack due to 

soil settling over a long period of time and manhole covers may not 

be water tight. Additionally, in certain areas, the water table is high 

in seasonal cycles and therefore, the raceways may get refilled 

soon after purging. 

Element 2, Preventive Actions – Based on added information in the 

Program Description, deleted the sentence in Element 2 that stated 

that medium voltage cables for which inspecting for water collection 

in cable manholes and conduit, and draining water, was performed, 

did not need to be tested. 

In Element 4, Detection of Aging Effects, a second paragraph was 

added in GALL Rev.1 that clarified how to determine the conditions 

when the cables are exposed to significant moisture. This new 

paragraph states, “The inspection for water collection should be 

performed based on actual plant experience with water 

accumulation in the manhole. However, the inspection frequency 

should be at least once every two years. The first inspection for 

license renewal is to be completed before the period of extended 

operation.”

These changes are also based on ISG-18.

VI
NUREG-1833 254 October 2005

Table IV. Justification for Changes in Aging Management Programs

GALL 

AMP Title

AMP 

Revised

(Y or N)

Summary of Change and its Basis

Referenced 

GALL Rev.1 

Chapters

XI.E4 Metal Enclosed Bus New AMP This new AMP was based upon information from ISG-17. This is an 

inspection program that checks bolted connections, internal 

portions of bus ducts, bus insulating systems, and bus supports for 

signs of aging degradation. Per Ginna SER 3.6.2.4.4.2, and D/QC 

SER 3.6.2.4.1, the industry has proposed and the Staff has 

accepted plant-specific programs that are similar to this program. 

A sample of accessible bolted connections will be checked for 

loose connection by using thermography or by measuring 

connection resistance using a low range ohmmeter. MEB internal 

surfaces will be visually inspected for aging degradation of 

insulating material and for foreign debris and excessive dust 

buildup, and evidence of moisture intrusion. Bus insulation will be 

visually inspected for signs of embrittlement, cracking, melting, 

swelling, or discoloration, which may indicate overheating or aging 

degradation. Internal bus supports will be visually inspected for 

structural integrity and signs of cracks.

As an alternative to thermography or measuring connection 

resistance of bolted connections, for the accessible bolted 

connections that are covered with heat shrink tape, sleeving, 

insulating boots, etc., the applicant may use visual inspection of 

insulation material to detect surface anomalies, such as 

discoloration, cracking, chipping or surface contamination. 

However, since the visual inspection is less effective than testing, 

this inspection is to be performed once every five years instead of 

once every 10 years.

This AMP will provide reasonable assurance that the component’s 

intended functions will be maintained within the CLB for the period 

of extended operation.

VI
October 2005 255 NUREG-1833

Table IV. Justification for Changes in Aging Management Programs

GALL 

AMP Title

AMP 

Revised

(Y or N)

Summary of Change and its Basis

Referenced 

GALL Rev.1 

Chapters

XI.E5 Fuse Holders New AMP This program addresses metallic clamp portion of fuse holders. 

Fuse holders within the scope of license renewal will be tested at 

least once every 10 years for aging degradation. Testing may 

include thermography, contact resistance testing, or other 

appropriate testing methods. This is an adequate period to 

preclude failures of the fuse holders since experience has shown 

that aging degradation is a slow process. A 10- year testing interval 

will provide two data points during a 20-year period, which can be 

used to characterize the degradation rate.

Operating experience as discussed in NUREG-1760 (Aging 

Assessment of Safety-Related Fuses Used in Low- and MediumVoltage Applications in Nuclear Power Plants) identified that aging 

stressors such as vibration, thermal cycling, electrical transients, 

mechanical stress, fatigue, corrosion, chemical contamination, or 

oxidation of the connections surfaces can result in fuse holder 

degradation. In VCS SER 3.6.2.3.1, the Staff has accepted a 

similar program. This AMP will provide reasonable assurance that 

the component’s intended functions will be maintained within the 

CLB for the period of extended operation.

ISG-5 was issued to define the fuse holders to be included within 

the scope of license renewal. This new AMP was written to address 

the aging management of these fuse holders.

VI

XI.E6 Electrical Cable 

Connections Not Subject To 

10 CFR 50.49 

Environmental Qualification 

Requirements

New AMP This program addresses metallic parts of the cable connection. 

GALL AMP XI.E1 manages the aging of insulating material but not 

the metallic parts of the electrical connections.

Connections associated with cables in scope of license renewal are 

part of this program, regardless of their association with active or 

passive components. Cable lugs are integral part of cables. 

Integrity of lugs can be verified by testing connections. Loosening 

of bolted connections is due to thermal cycling, ohmic heating, 

electrical transients, vibration, chemical contamination, corrosion, 

and oxidation. GALL AMP XI.E1 manages connections in adverse 

VI
NUREG-1833 256 October 2005

Table IV. Justification for Changes in Aging Management Programs

GALL 

AMP Title

AMP 

Revised

(Y or N)

Summary of Change and its Basis

Referenced 

GALL Rev.1 

Chapters

locations only and inspects insulation degradation. Most 

connections are not located in adverse locations.

SAND 96-0344, “Aging Management Guidelines For Electrical 

Cable and Terminations,” indicated that several plants identified 

terminations loosening. The major concern is that failures of a 

deteriorated cable system (cables, connections including fuse 

holders, and penetrations) might be induced during accident 

conditions. Since the connections are not subject to the 

environmental qualification requirements of 10 CFR 50.49, an 

aging management program is required to manage the aging 

effects.

EPRI -TR-104213, "Bolted Joint maintenance & Application Guide," 

indicates that it is difficult to maintain tightness of electrical 

connections and good conductivity through a large temperature 

range if the materials for the bolt and the conductor are different 

and have different rates of thermal expansion. For example, copper 

and aluminum expand faster than most bolting materials. If thermal 

stress is added to stresses inherent at assembly, the joint members 

or fasteners can yield. If plastic deformation occurs during thermal 

loading when the connection cools, the joint will loosen. 

Some plants have been using thermography to detect weak 

connections and correct them as soon as possible. 

Operating experience has shown evidence of loosening of metallic 

parts of cable connections. Several licensees reported in their 

Licensee Event Report (LER) loose connections due to corrosion, 

vibration, thermal cycling, etc.

LER-2541987023 dated 11/11/1987 at Quad Cities 1 - Corrosion, 

LER-2651998003 dated 6/28/1998 at Quad Cities 2 - Vibration,

LER-2751985015 dated 5/20/1985 at Diablo Canyon 1 - Vibration

LER-3741988008 dated 6/17/1988 at LaSalle 2 - Thermal Cycling

LER-3211994005 dated 5/1/1994 at Hatch 1 & 2 - Not human error
October 2005 257 NUREG-1833

Table IV. Justification for Changes in Aging Management Programs

GALL 

AMP Title

AMP 

Revised

(Y or N)

Summary of Change and its Basis

Referenced 

GALL Rev.1 

Chapters

LER-3681999002 dated 2/2/1999 at ANO-2 - Not human error

LER-3731991016 dated 10/24/1991 at LaSalle 1 - Not human 

error)

The program recommends a representative sample of cable 

connections to be tested. Testing may include thermography, 

contact resistance testing, or other appropriate testing methods. 

This AMP will provide reasonable assurance that the component’s 

intended functions will be maintained within the CLB for the period 

of extended operation.
NUREG-1833 258 October 2005

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October 2005 259 NUREG-1833

V. Justification for Changes to the SRP-LR

The following tables summarize changes that were made to the SRP-LR (NUREG-1800). The following tables identify the 

SRP Section in the revised SRP-LR, provide a summary of the changes, and the basis for the changes.

Table V Summary of Changes to the SRP-LR

SRP Section Summary of Changes Basis

Chapter 1

Chapter 2.1

Chapter 2.3

Chapter 2.4

Chapter 2.5

Minor editorial changes No basis is required for editorial changes.

Chapter 2.1 Revised Table 2.1-5, “Typical Structures, Components, and Commodity Groups, 

and

10 CFR 54.21(a)(1)(i) Determinations for Integrated Plant Assessment.”

Revised Chapter 2.1.3.1.3, “Regulated Events,” to provide further guidance on 

scoping of equipment relied on to meet the requirements of the station blackout 

(SBO) rule (10 CFR 50.63) for license renewal (10 CFR 54.4(a)(3)).

This table was revised to reflect the current 

Staff guidance reflected in ISGs (e.g., ISG7) and the current guidance to applicants in 

NEI 95-10. Further information regarding 

the basis for this change can be found in 

NEI 95-10.

This revision is based on the guidance 

provided in ISG-02, “Staff Guidance on 

Scoping of Equipment Relied on to Meet 

the Requirements of the Station Blackout 

(SBO) rule (10 CFR 50.63) for License 

Renewal.”
NUREG-1833 260 October 2005

Table V Summary of Changes to the SRP-LR

SRP Section Summary of Changes Basis

Chapter 2.2 The Review Responsibilities defined at the beginning of Chapter 2.2 “Plant-Level 

Scoping Results” was changed from being defined as in SRP-LR, Rev.0 

Primary – Branches responsible for systems

Secondary – Branch responsible for electrical engineering

To the new assignment in SRP-LR, Rev.1 of 

Primary – Plant Systems Branch

Secondary – Branches responsible for systems and structures

Revised the disposition for the recirculation cooling water system in Table 2.2-1 to 

remove the discussion regarding the fuel handling accident for the spent fuel pool 

cooling system. 

The changes on primary and secondary 

reviewer responsibilities were made to 

reflect the roles and responsibilities of the 

Staff reviewers. These changes are 

consistent with the current review practices 

of the NRC Staff.

The spent fuel pool cooling system is not 

safety-related, and, following a seismic 

event, the safety-related spent fuel pool 

structure and spent fuel pool makeup water 

supplies ensure the adequate removal of 

decay heat to prevent potential offsite 

exposures comparable to those described 

in 10 CFR Part 100. Therefore, the 

recirculation cooling water system is not 

within the scope of license renewal based 

on the spent fuel decay heat removal 

function. The Calvert Cliffs LRA places the 

service water system that cools the spent 

fuel pool cooling system in scope for the 

spent fuel decay heat removal function 

because the spent fuel cooling system is 

safety related and the pool structure is not 

designed for pool boiling. The St. Lucie 

LRA has only the safety-related makeup 

water supply to the spent fuel pool and the 

spent fuel pool structure within scope for 

the decay heat removal function because 

these systems are credited for decay heat 

removal following a seismic event or loss of 

the non-safety related spent fuel pool 

cooling loop.
October 2005 261 NUREG-1833

Table V Summary of Changes to the SRP-LR

SRP Section Summary of Changes Basis

Chapter 2.4 The Review Responsibilities defined at the beginning of Chapter 2.4 “Scoping and 

Screening Results: Structures” was changed from being defined as in SRP-LR, 

Rev.0 

Primary – Branches responsible for plant systems

Secondary – None

To the new assignment in SRP-LR, Rev.1 of 

Primary – Mechanical and Civil Engineering Branch

Secondary – None

The changes on primary and secondary 

reviewer responsibilities were made to 

reflect the roles and responsibilities of the 

Staff reviewers. These changes are 

consistent with the current review practices 

of the NRC Staff.

Chapter 3.0 Added new chapter 3.0 to more accurately reflect the roles and responsibilities of 

the Staff reviewers. This chapter also addresses applications with approved 

extended power uprates.

The changes to this chapter are consistent 

with the current review practices of the Staff 

and reflect the audit and review process 

used by the NRC for review of LRAs. The 

basis for addressing applications with 

approved extended power uprates is to 

ensure applicants perform an operating 

experience review and its impact on aging 

management programs for structures, and 

components before entering the period of 

extended operation.

Chapter 3.1

Chapter 3.2

Chapter 3.3

Chapter 3.4

Chapter 3.5

Chapter 3.6

The chapters were revised to reflect the changes that were made to the AMR lineitems in Chapters II, III, IV, V, VI, VII, and VIII to Volume 2 of the GALL Report.The basis for these changes is described in 

the individual chapters of this document 

(see Tables II.A, II.B, II.C, and Tables IIIA 

through IIIG).

Chapter 4.1

Table 4.1-3

Added “Ductility reduction of fracture toughness for the reactor vessel internals” as 

an additional example of plant-specific TLAAs as identified by the License Renewal 

Applicants (LRAs).

This TLAA was added to be consistent with 

TLAAs contained in LRAs.

Chapter 4.2

4.2.1

Areas of 

Review

Added a fifth area of review as follows:

(5) other plant-specific TLAAs on reactor vessel neutron embrittlement

Some plants may have plant-specific 

TLAAs for neutron embrittlement analysis, 

such as RPV Reflood Reshock Analyses.
NUREG-1833 262 October 2005

Table V Summary of Changes to the SRP-LR

SRP Section Summary of Changes Basis

Chapter 4.2

4.2.2.1.1.2

Added the following for re-evaluation of USE:

10 CFR Part 50, Appendix G, Section IV.A.1 (the rule) requires licensees to take 

further corrective actions for those cases where the 75 ft-lb unirradiated USE 

(UUSE) criterion or 50 ft-lbs end-of-life USE criterion cannot be met (i.e., when the 

respective UUSE value falls below 75 ft-lb or the EOL USE falls below 50 ft-lb). 

When this occurs, the rule requires a licensee to submit a supplemental analysis for 

NRC approval for any case where the UUSE value is less than 75 ft-lb or where the 

projected USE value for a given material is projected to be less than the 50 ft-lb 

acceptance criteria at the expiration of the operating license. Thus, if the USE value 

for a PWR RV material, as projected to the expiration of the period of extended 

operation, falls below either the 50 ft-lb acceptance criterion or the USE value 

criterion specified in a previously NRC-approved EMA, or where the %-drop in USE 

value for a BWR RV material, as projected to the expiration of the period of 

extended operation, falls below that %-drop in USE value approved by the NRC in 

its safety evaluation of the BWRVIP’s generic EMA for BWRs, an applicant will need 

to submit a plant-specific engineering analysis (usually an EMA) for NRC approval 

as supplemental information for license renewal. Otherwise, failure to meet the USE 

requirements of 10 CFR Part 50, Appendix for the RV materials as evaluated using 

the neutron fluence that are projected for the period of extended operation 

mandates imposition of additional commitments or license condition on USE for the 

license renewal application.

Provides more clarity on use of 10 CFR 

54.21(c)(1)(ii) criteria for re-evaluation of 

USE for period of extended operation. Also 

indicates that the SER may impose a 

license condition if the end-of life USE 

criterion cannot be met.

Chapter 4.2

4.2.2.1.3

P-T limits

Added the following:

P-T limits are TLAAs for the application if the plant currently has P-T limit curves 

approved for the expiration of the current period of operation (i.e., 32 EFPY or other 

licensed EFPY values at expiration of the current license). However, the P-T limits 

for the period of extended operation will not need to be submitted as part of the LRA 

since the P-T limits will need to be updated through the 10 CFR 50.90 licensing 

process when necessary for P-T limits that are located in the limiting conditions of 

operation (LCOs) of the Technical Specifications (TS). For those plants that have 

approved pressure-temperature limit reports (PTLRs), the P-T limits for the period of 

extended operation will be updated at the appropriate time through the plant’s 

Administrative Section of the TS and the plant’s PTLR process. In either case, the 

10 CFR 50.90 or the PTLR processes, which constitute the current licensing basis 

will ensure that the P-T limits for the period of extended operation will be updated 

prior to expiration of the P-T limit curves for the current period of operation.

Provides information that the P-T limit 

curves for period of extended operation do 

not need to be submitted with the 

application. Also, provides information on 

how the P-T limit curves are updated.
October 2005 263 NUREG-1833

Table V Summary of Changes to the SRP-LR

SRP Section Summary of Changes Basis

Chapter 4.2

4.2.2.1.3.3

Deleted the phrase “not applicable and modified as follows:

Updated P-T limits for the period of extended operation must be available prior to 

entering the period of extended operation. The 10 CFR 50.90 process for P-T limits 

located in the LCOs or the Administrative Controls Process for P-T limits that are 

administratively amended through a PTLR process can be considered to be 

adequate aging management programs within the scope of 10 CFR 54.21(c)(1)(iii) 

such that P-T limits will be maintained through the period of extended operation.

Clarifies that 10 CFR 50.90 process or the 

PTLR process is considered adequate 

aging management program for 10 CFR 

54.21(c)(1)(iii) criteria.
NUREG-1833 264 October 2005

Table V Summary of Changes to the SRP-LR

SRP Section Summary of Changes Basis

Chapter 4.2

4.2.3.1.1.2

(Upper-Shelf 

Energy)

Added the following:

The Staff should confirm that the applicant has provided sufficient information for all 

Upper Shelf Energy (USE) and/or equivalent margins analysis calculations for the 

period of extended operation as follows:

Neutron Fluence: Identified the neutron fluence at the inside surface and the 1/4T 

location for each beltline material at the expiration of the license renewal period. 

Identified the methodology used in determining the neutron fluence and identified 

whether the methodology followed the guidance in Regulatory Guide (RG) 1.190 

(Ref. 12).

To confirm the USE analysis meets the requirements of Appendix G of 10 CFR Part 

50 at the end of the license renewal period, the Staff should determine whether:

1. For each beltline material that is projected to exceed 50 ft-lb at the end of the 

license renewal period, the applicant has provided the unirradiated Charpy 

USE, the projected Charpy USE at the end of the license renewal period, 

whether the drop in Charpy USE was determined using the limit lines in Figure 2 

of RG 1.99, Revision 2 or from surveillance data and the percentage copper.

2. If an equivalent margins analysis was required to demonstrate compliance with 

the USE requirements in Appendix G of 10 CFR Part 50, the applicant has 

provided the analysis or identified an approved topical report that contains the 

analysis. Information the Staff will require to assess the equivalent margins 

analysis includes: the unirradiated USE (if available) for the limiting material, its 

copper content, the fluence (1/4T and at 1 inch depth), the EOLE USE (if 

available), the operating temperature in the downcomer at full power, the vessel 

radius, the vessel wall thickness, the J-applied analysis for Service Level C and 

D, the vessel accumulation pressure, and the vessel bounding heatup/cooldown 

rate during normal operation.

For Boiling Water Reactors, the Staff should confirm that the beltline materials are 

evaluated in accordance with Renewal Applicant Action Items 10, 11 and 12 in the 

Staff’s SER, for BWRVIP-74 (Letter to C. Terry dated October 18, 2001) (Ref.11). 

The applicant should also identify whether there are two or more surveillance 

material available that are relevant to the RPV beltline materials. If there are two or 

more data points for a surveillance material, the applicant should provide analyses 

of the data to determine whether the data is consistent with the RG 1.99, Revision 2 

methodology that was utilized in the BWRVIP-74 analyses.

Provides more information to the NRC Staff

to assist in the review of license renewal 

application for the Upper Shelf Energy 

TLAA if the applicant chooses criteria 10 

CFR 54.21(c)(1)(ii) for dispositioning the 

TLAA. Also provides a consistent guideline 

that the applicant can use for preparation of 

the license renewal application.

ISG-16 was used, in part, for this change.
October 2005 265 NUREG-1833

Table V Summary of Changes to the SRP-LR

SRP Section Summary of Changes Basis

Chapter 4.2

4.2.3.1.2.2

(Pressurized 

Thermal 

Shock)

Added the following:

To confirm that the Pressurized Thermal Shock analysis results in RTPTS values 

below the screening criteria in 10 CFR 50.61 at the end of the license renewal 

period, the applicant should provide the following:

1. For each beltline material provide the unirradiated RTNDT, the method of 

calculating the unirradiated RTNDT (either generic or plant-specific), the margin, 

the chemistry factor, the method of calculating the chemistry factor, the mean 

value for the shift in transition temperature and the RTPTS value.

2. If there are two or more data for a surveillance material that is from the same 

heat of material as the beltline material, provide analyses to determine whether 

the data are credible in accordance with RG 1.99, Revision 2 and whether the 

margin value used in the analysis is appropriate.

3. If a surveillance program does not include the vessel beltline controlling 

material, but two or more data seta are available from other beltline materials, 

then provide an analysis of the data in accordance with Regulatory Guide 1.99, 

Revision 2, Regulatory Position C.2.1, to show that the results either bound or 

are comparable to the values that would be calculated for the same materials 

using Regulatory Position C.1.1.

Provides more information to the NRC Staff

to assist in the review of license renewal 

application for Pressurized Thermal Shock 

TLAA if the applicant chooses criteria 10 

CFR 54.21(c)(1)(ii) for dispositioning the 

TLAA. Also provides a consistent guideline 

that the applicant can use for preparation of 

the license renewal application.

ISG-16 was used, in part, for this change.
NUREG-1833 266 October 2005

Table V Summary of Changes to the SRP-LR

SRP Section Summary of Changes Basis

Chapter 4.2 

subsection

4.2.3.1.2.3

(Pressurized 

Thermal 

Shock)

Deleted existing words and added the following:

The license renewal application must provide an assessment of the current licensing 

basis TLAA for PTS, a discussion of the flux reduction program implemented in 

accordance with §50.61(b)(3), if necessary, and an identification of the viable 

options that exist for managing the aging effect in the future.

A. The applicant should explain its core management plans (e.g., operation with 

a low leakage core design and/or integral burnable neutron absorbers) from 

now through the end of the period of extended operation. Based on this core 

management strategy, the applicant should:

(1) Identify the material in the RPV which has limiting RTPTS value,

(2) Provide the projected fluence value for the limiting material at end of 

license extended (EOLE),

(3) Provide the projected RTPTS value for the limiting material at EOLE, 

and 

(4) Provide the projected date and fluence values at which the limiting 

material will exceed the screening criteria in §50.61.

B. The applicant should discuss aging management programs that they intend to 

implement which will actively “manage” the condition of the facility’s RPV, and 

hence, the risk associated with PTS. This discussion would be expected to 

address, at least, the facility’s reactor pressure vessel material surveillance 

program.

C. The applicant should briefly discuss the options that they are considering with 

respect to “resolving” the PTS issue through EOLE. It is anticipated that this 

discussion would include some or all of the following:

(1) Plant modifications (e.g., heating of ECCS injection water) which could 

limit the risk associated with postulated PTS events [see §50.61(b)(4) 

and/or (b)(6)],

(2) More detailed safety analyses (e.g., using Regulatory Guide 1.154) 

which may be performed to show that the PTS risk for the facility is 

acceptably low through EOLE [see §50.61(b)(4)],

(3) More advanced material property evaluation (e.g., use of Master 

Curve technology) to demonstrate greater fracture resistance for the 

limiting material [applies to §50.61(b)(4)] and/or,

(4) The potential for RPV thermal annealing in accordance with §50.66 

[see §50.61(b)(7)].

Provides more information to the NRC Staff

to assist in the review of license renewal 

application for Pressurized Thermal Shock 

TLAA if the applicant chooses criteria 10 

CFR 54.21(c)(1)(iii) for dispositioning the 

TLAA. Also provides a consistent guideline 

that the applicant can use for preparation of 

the license renewal application.
October 2005 267 NUREG-1833

Table V Summary of Changes to the SRP-LR

SRP Section Summary of Changes Basis

Chapter 4.2

Table 4.2-1

FSAR 

Supplement

Added FSAR Supplement information for other miscellaneous TLAAs on RV neutron 

embrittlement

Provides an example of information to be 

included for miscellaneous TLAAs on RV 

neutron embrittlement. This item was added 

in section 4.2.1.

Chapter 4.3

subsections 

4.3.1.1.1, 

4.3.2.1.1.2, 

4.3.3.1.1.2

Code limit for CUF was revised from “less than one” to “less than or equal to one.” The Code allows for a CUF equal to unity 

over the service life.

Chapter 4.4

subsections 

4.4.1.2, 

4.4.2.2, 4.4.3.2

Generic Safety Issue, GSI-168. Deleted the existing words and replaced as follows:

Regulatory Issue Summary (RIS) 2003-09 was issued on May 2, 2003, (Ref. 16) to 

inform addressees of the results of the technical assessment of GSI-168, 

"Environmental Qualification of Electrical Equipment," (Ref. 10). This RIS requires 

no action on the part of the addressees.

The need to perform a TLAA for certain mechanical equipment in accordance with 

Chapter 4.7, “Other Plant-Specific Time-Limited Aging Analyses,” was also added.

The earlier version stated that GSI-168 was 

scheduled for resolution in March 2001 and 

that an applicant’s consideration of GSI-168 

for license renewal is an area of review. 

Since RIS 2003-09 was issued requiring no 

action on part of addressees, all reference 

to GSI-168 was deleted from section 4.4. 

Addressing the need to perform TLAAs for 

certain mechanical equipment was added 

for completeness.

Chapter 4.5 

subsection 

4.5.1

First paragraph, last sentence stated that it is necessary to perform TLAAs for the 

extended period of operation. The word “perform” was deleted and replaced with, 

“ensure that the applicant addresses existing”...

10 CFR 54 does not require TLAAs to be 

created to address this aging effect; 

however analyses/calculations to address 

the aging effect of loss of prestress in 

containment tendons generally exist and 

generally meet the definition of a TLAA as 

given by 10CFR54.3.

Chapter 4.5 

subsections 

4.5.2.1.1, 

4.5.2.1.2, 

4.5.3.1.2, 

Table 4.5-1

Updated acceptance criteria – replaced “predicted lower limit (PLL)” with “minimum 

required prestress force specified at anchorage”

The update meets the requirement per 

ASME Section XI, Sub-section IWL 

Acceptance Criteria.
NUREG-1833 268 October 2005

Table V Summary of Changes to the SRP-LR

SRP Section Summary of Changes Basis

Chapter 4.6 

subsections 

4.6.1.1.1,

4.6.2.1.1.3,

4.6.3.1.1.3,

Table 4.6-1

Revised Code limit for CUF from “less than one” to “less than or equal to one.” Code allows CUF to be equal to 1.0 for the 

entire service life of the bellows. Many 

calculations on bellows are done to show 

that an extremely large number of the 

design cycles may be experienced without 

CUF = 1.0. In this case, there is no TLAA 

as the assumption is not based upon the 

original license term.

Chapter 4.7 Minor Editorial Changes No basis is required for editorial changes

Chapter 4.7

Subsection 

4.7.3

Modified the first paragraph to state:

“For certain applicants, plant-specific analyses may meet the definition of a TLAA as 

given in 10CFR54.3. The concern for License Renewal is that these analyses may 

not have properly considered the length of the extended period of operation, the 

consideration of which may change conclusions with regard to safety and the 

capability of SSCs within the scope of the Rule to perform or one or more safety 

functions. The review of these TLAAs will provide the assurance that the aging 

effect is properly addressed through the period of extended operation.”

Editorial change to provide clarity for plant 

specific TLAAs.
October 2005 269 NUREG-1833

VI. Abbreviations, Acronyms, and Designations

The following table presents definitions or explanations of the most common abbreviations, acronyms, 

and designations used within the SRP-LR, the GALL Report, and this document (i.e., NUREG-1800, 

NUREG-1801, and NUREG-1833).

Term Definition/Explanation

A ASTM nomenclature

ACI American Concrete Institute

ACRS Advisory Committee on Reactor Safeguards

ACSR aluminum core steel reinforced

ADS automatic depressurization system

AE/AM aging effect/aging mechanism

AE/M aging effect/mechanism

AFW auxiliary feedwater

AISI American Iron and Steel Institute

ALARA as low as reasonably achievable

AMP aging management program

AMR aging management review

ANL Argonne National Laboratory

ANO-1 Arkansas Nuclear One – Unit 1

ANSI American National Standards Institute

ASCE American Society of Civil Engineers

ASM American Society of Materials

ASME American Society of Mechanical Engineers

ASTM American Society for Testing and Materials

ATWS anticipated transients without scram

B&PV boiler and pressure vessel

B&W Babcock and Wilcox

BAC boric acid corrosion

BTP Branch Technical Position (type of NRC communication)

BWR boiling water reactor

BWRVIP Boiling Water Reactor Vessel and Internals Project

CASS cast austenitic stainless steel

CB core barrel

CCNP Calvert Cliffs Nuclear Plant

CCCW closed-cycle cooling water

CDF core damage frequency

CE Combustion Engineering

CEA control element assembly

CEDM control element drive mechanism

CFD cumulative fatigue damage

CFR Code of Federal Regulations

CFS core flood system

CLB current licensing basis

CNP Cook Nuclear Plant

CRD control rod drive

CRDM control rod drive mechanism

CRDRL control rod drive return line

CRGT control rod guide tube

CUF cumulative usage factor

CVCS chemical and volume control system

D/QC Dresden/Quad Cities NPP

DBA design basis accident
NUREG-1833 270 October 2005

Term Definition/Explanation

DBE design basis event

DC direct current

DE Division of Engineering (NRC organizational unit)

DG Draft Regulatory Guide

DHR decay heat removal

DIPM Division of Inspection Program Management (NRC organizational unit)

DOR Division of Operating Reactors (NRC organizational unit)

DRIP Division of Regulatory Improvement Programs (NRC organizational unit)

DSCSS drywell and suppression chamber spray system

DSSA Division of System Safety Analysis (NRC organizational unit)

ECCS emergency core cooling system

ECP electrochemical potential

ECT eddy current testing

EDG emergency diesel generator

EDO Executive Director for Operations (NRC organizational unit)

EFPD effective full power day

EFPY effective full power years

EOL end of life

EOLE end of license extended

EPRI Electric Power Research Institute

EPU extended power uprate

EQ environmental qualification

ESF Engineered Safety Features, Chapter V of GALL Report

Ext. external surfaces of a structure or component. Separate environments may 

be seen by internal surfaces and external surfaces of components or 

structures

FAC flow-accelerated corrosion

FCS Fort Calhoun Station NPP

FE further evaluation

FER further evaluation required

FERC Federal Energy Regulatory Commission

FNP Farley Nuclear Plant

FP fire protection

FR Federal Register

FSAR Final Safety Analysis Report

FW feedwater

GALL Generic Aging Lessons Learned

GE General Electric

GL generic letter

GSI generic safety issue

GVI GALL Volume 1

GV2 GALL Volume 2

HAZ heat affected zone

HELB high-energy line break

HMWPE high molecular weight polyethylene

HP high pressure

HPCI high-pressure coolant injection

HPCS high-pressure core spray

HPSI high-pressure safety injection

HVAC heating, ventilation, and air conditioning

I&C instrumentation and control

IAEA International Atomic Energy Agency
October 2005 271 NUREG-1833

Term Definition/Explanation

IASCC irradiation assisted stress corrosion cracking

IC isolation condenser

ID inside diameter

IEB inspection and enforcement bulletin

IEEE Institute of Electrical and Electronics Engineers

IGA intergranular attack

IGSCC intergranular stress corrosion cracking

IN Information Notice (type of NRC generic communication)

INPO Institute of Nuclear Power Operations

Int. Internal surfaces of a structure or component. Separate environments may 

be seen by internal surfaces and external surfaces of components or 

structures

IPA integrated plant assessment

IPE individual plant examination

IPEEE individual plant examination of external events

IR insulation resistance

IRM intermediate range monitor

ISG Interim Staff Guidance (type of NRC communication)

ISI inservice inspection

ITG Issues Task Group

L low carbon content in stainless steels, nominal 0.03%C maximum

LCD liquid crystal display

LED light-emitting diode

LER licensee event report

LG lower grid

LOCA loss of coolant accident

LP low pressure

LPCI low-pressure coolant injection

LPCS low-pressure core spray

LPM loose part monitoring

LPRM low-power range monitor

LPSI low-pressure safety injection

LR license renewal

LRA License Renewal Application

LRG License renewal guidance

LRGD License Renewal Guidance Document

LRT leak rate test

LTOP low-temperature overpressure protection

LWR light water reactor

MEA materials, environments, and aging effects

MEAP materials, environments, aging effects, and programs

MFW main feedwater

MIC microbiologically influenced corrosion

MRV minimum required value

MS main steam

MSR moisture separator/reheater

MT magnetic particle testing

NA/S North Anna and Surry NPPs

NDE nondestructive examination

NDT nil-ductility temperature

NEI Nuclear Energy Institute

NFPA National Fire Protection Association
NUREG-1833 272 October 2005

Term Definition/Explanation

NG nuclear grade, maximum carbon content of .02% C

NPAR Nuclear Plant Aging Research

NPP nuclear power plant

NPS nominal pipe size

NRC Nuclear Regulatory Commission

NRMS normalized root mean square

NRR Office of Nuclear Reactor Regulation (NRC organizational unit)

NSA National Specialty Alloys

NSAC Nuclear Safety Analysis Center

NSR nonsafety related system

NSSS nuclear steam supply system

NUMARC Nuclear Management and Resources Council

OCCW open-cycle cooling water

OD outside diameter

ODSCC outside diameter stress corrosion cracking

OM operation and maintenance

OTI one-time inspection

OTSG once through steam generator

P&ID piping and instrument diagram

PA plant assessment

PH precipitation hardening

PLL predicted lower limit

PM project manager

POEO period of extended operation

PRA probabilistic risk analysis

PT penetrant testing

P-T pressure-temperature

PTLR pressure-temperature limit report

PTS pressurized thermal shock

PWR pressurized water reactor

PWSCC primary water stress corrosion cracking

QA quality assurance

RAI request for additional information

RCCA rod control cluster assemblies

RCIC reactor core isolation cooling

RCP reactor coolant pump

RCPB reactor coolant pressure boundary

RCS reactor coolant system

RFE requires further evaluation

RG Regulatory Guide

RHR residual heat removal

RICSIL rapid information communication services information letter

RIS Regulatory Issue Summary

RLEP License Renewal and Environmental Impacts Program (NRC organizational 

unit)

RMS root mean square

RNP Robinson Nuclear Plant

RPV reactor pressure vessel

RT reference temperature

RWC, RWCU reactor water cleanup

RWST refueling water storage tank

RWT refueling water tank
October 2005 273 NUREG-1833

Term Definition/Explanation

S/G standards and guides

SA ASME manufacturing specifications referring to product form and heat 

treatment

SAW submerged arc weld

SBO station blackout

SC suppression chamber

SCC stress corrosion cracking

SDC shutdown cooling

SER Safety Evaluation Report

SFP spent fuel pool

SG steam generator

SGTI steam generator tube integrity

SIL services information letter

SIT safety injection tank

SLC standby liquid control

SMP Structures Monitoring Program

SOC statements of consideration

SOER significant operating experience report

SRM source range monitor

SRM Staff requirements memorandum

SRP standard review plan

SRP-LR standard review plan for license renewal

SR safety related

SRS safety-related system

SS stainless steel

SSC systems, structures, and components

SSE safe shutdown earthquake

TGSCC transgranular stress corrosion cracking

TLAA time-limited aging analysis

TS technical specifications

Type AISI nomenclature

UCS Union of Concerned Scientists

UFSAR updated final safety analysis report

UHS ultimate heat sink

UNS Unified numbering system

USE upper shelf energy

USI unresolved safety issue

UT ultrasonic testing

UV ultraviolet

V V vent valve

VCS V.C. Summer Nuclear Station

VIP vessel and internals project

WSLR within scope of license renewal
NUREG-1833 274 October 2005

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October 2005 275 NUREG-1833

VII. References

Note: In addition to the references listed below, which are cited in the previous sections, other 

references are also listed in Appendix A.7. 

ACI 301-84, “Specification of Structural Concrete for Buildings,” American Concrete Institute, Detroit, 

Michigan.

Annual Book of ASTM Standards, Part 10, ASTM, Philadelphia, Pa., 1976.

Annual Book of ASTM Standards, Volume 09.01, ASTM International, 2004.

Arkansas Nuclear One-Unit 1, “License Renewal Application – Appendix C: Process for Identifying Aging 

Effects Requiring Aging Management for Non-Class 1 Mechanical Components,” Entergy Operations, 

Inc., January 31, 2000.

ASM Materials Information – Membership Database consisting of three main content areas - ASM 

Handbooks Online, ASM Alloy Center Online, ASM Micrograph Center Online, 

http://products.asminternational.org/matinfo/index.jsp 

ASME Boiler & Pressure Vessel Code, SECTION II: Part A, Ferrous Material Specification.

ASME Boiler & Pressure Vessel Code, SECTION II: Part B, Nonferrous Material Specifications.

ASTM, SAE and ISO Grade Markings and Mechanical Properties for Steel Fasteners 

http://www.americanfastener.com/techref/grade.htm 

Bansal, N. P. and R. H. Doremua, “Handbook of Glass Properties,” Academic Press, 1986.

Bayliss, D. A., and D. H. Deacon, “Steelwork Corrosion Control,” Second Edition, Spon Press, 2002.

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NUREG-1833 276 October 2005

Fontana, M. G., “Corrosion Engineering,” 3rd ed. Edition, McGraw Hill Book Company, 1986.

Gavrilas, M., P. Hejzlar, N.E. Todreas, and Y. Shatilla, "Safety Features of Operating Light Water 

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Shiryo Kenkyujo, 1980 (HCWS) 143.

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204-236., 1979.

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http://www.indpipe.com/images/PDF/asme_specifications_SA36_toSA423.pdf 

ISG-01, “Proposed Staff Guidance on the Position of the GALL Report Presenting One Acceptable Way 

to Manage Aging Effects for License Renewal,” dated November 23, 2001 (ADAMS Accession No. 

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Blackout (SBO) rule (10 CFR 50.63) for License Renewal,” dated April 1, 2002 (ADAMS Accession 

No. ML020920464)

ISG-03, “Proposed Revision of Chapters II and III of Generic Aging Lessons Learned (GALL) Report on 

Aging Management of Concrete Elements,” dated November 23, 2001 (ADAMS Accession Nos. 

ML013300440 and ML013300445)

ISG-04, “Interim Staff Guidance (ISG)-04: Aging Management of Fire Protection Systems for License 

Renewal,” dated December 3, 2002 (ADAMS Accession No. ML023440123)

ISG-05, “Interim Staff Guidance (ISG)-5 on the Identification and Treatment of Electrical Fuse Holders for 

License Renewal,” dated March 10, 2003 (ADAMS Accession No. ML030690492)

ISG-06, “Proposed Interim Staff Guidance on Identification and Treatment of Housing for Active 

Components for License Renewal,” dated April 8, 2003 (ADAMS Accession No. ML031010423)

ISG-12, “Proposed Interim Staff Guidance (ISG)-12: Addition of Generic Aging Lessons Learned (GALL) 

Aging Management Program (AMP) XI.M35, One-Time Inspection of Small-Bore Piping, For License 

Renewal,” dated November 3, 2003 (ADAMS Accession No. ML033100516)

ISG-15, “Proposed Interim Staff Guidance (ISG)-15: Revision of Generic Aging Lessons Learned (GALL) 

Aging Management Program (AMP) XI.E2, 'Electrical Cables Not Subject to 10 CFR 50.49 

Environmental Qualification Requirements Used in Instrumentation Circuits’, for License Renewal,” 

dated August 12, 2003 (ADAMS Accession No. ML032250579)

ISG-16, “Proposed Interim Staff Guidance (ISG)-16: Time-limited Aging Analyses (TLAAs) Supporting 

Information for License Renewal Applications” dated May 12, 2003 (ADAMS Accession No. 

ML031320798)

ISG-17, “Interim Staff Guidance (ISG)-17: Proposed Aging Management Program (AMP) XI.E4, 'Periodic 

Inspection of Bus Ducts’, for License Renewal.” See FRN /Vol. 69, No. 246, Page 76960, dated 

December 23, 2004. 
October 2005 277 NUREG-1833

ISG-19A: “Proposed Aging Management Program XI.M11-A, 'Nickel-alloy Penetration Nozzles Welded to 

the Upper Reactor Vessel Closure Heads of Pressurized Water Reactors (PWRs Only)’, for License 

Renewal.”

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Report, NUREG-1801,” May 11, 2004.

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Components,” TR -106092, Research Project 2643-33, Final Report, March 1996.

NRC Bulletin No. 88-09, “Thimble Tube Thinning in Westinghouse Reactors,” August 30, 1994.

NRC Generic Letter 88-01, “Position on IGSCC in BWR Austenitic Stainless Steel Piping,” January 25, 

1988.

NRC Generic Letter 89-13, “Service Water System Problems Affecting Safety-Related Equipment,” July 

18, 1989.

NRC Generic Letter 96-04, “Boraflex Degradation in Spent Fuel Pool Storage Racks,” U.S. Nuclear 

Regulatory Commission, 1996.

NRC Information Notice No. 89-64. “Electrical Bus Bar Failures,” U.S. Nuclear Regulatory Commission, 

September 7, 1989.

NRC Information Notice No. 90-04, “Cracking of the Upper Shell-to-Transition Cone Girth Welds in Steam 

Generators,” U.S. Nuclear Regulatory Commission, January 26, 1990.

NRC Information Notice No. 91-19, “Steam Generator Feedwater Distribution Piping Damage,” U.S. 

Nuclear Regulatory Commission, March 12, 1991.

NRC Information Notice No. 92-20, “Inadequate Local Leak Rate Testing,”U.S. Nuclear Regulatory 

Commission, March 3, 1992.

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Switchyard Insulators,” U.S. Nuclear Regulatory Commission, December 13, 1993.

NRC Information Notice 94-63, “Boric Acid Corrosion of Charging Pump Casing caused by Cladding 

Cracks,” U.S. Nuclear Regulatory Commission, August 30, 1994.

NRC Information Notice No. 97-11, “Cement Erosion from Containment Subfoundations at Nuclear Power 

Plants,” U.S. Nuclear Regulatory Commission, March 21, 1997.

NRC Information Notice No. 98-26, “Settlement Monitoring and Inspection of Plant Structures Affected by 

Degradation of Porous Concrete Subfoundations,” U.S. Nuclear Regulatory Commission, July 24, 

1998.
NUREG-1833 278 October 2005

NRC Information Notice No. 2000-14, “Non-Vital Bus Fault Leads to Fire and Loss of Offsite Power,” U.S. 

Nuclear Regulatory Commission, September 27, 2000.

NRC Information Notice No. 2004-08, “Inadequate Assessment of the Effect of Differential Temperatures 

on Safety- Related Pumps,” U.S. Nuclear Regulatory Commission, May 15, 2000.

NRC Licensee Event Report for Pilgrim Nuclear Power Station LER 85-025-00, “Reactor Scram on Load 

Reject,” U.S. Nuclear Regulatory Commission, September 27, 1985.

NRC Licensee Event Report for Pilgrim Nuclear Power Station LER 91-024-00, “Loss of Preferred and 

Secondary Offsite Power Due to Severe Coastal Storm While Shutdown,” U.S. Nuclear Regulatory 

Commission, November 29, 1991.

NRC Licensee Event Report for St. Lucie Unit 1, LER 94-007-0, “Automatic Reactor Trip on Loss of 

Electrical Load due to Flash-over on 240KV Switchyard Potential Transformer,” U.S. Nuclear 

Regulatory Commission, November 23, 1994.

NRC Licensee Event Report LER 50-341/2005-001-00, “Shutdown Due to Containment Cooler Leak,” 

U.S. Nuclear Regulatory Commission, March 23, 2005.

NRC Licensee Event Report LER 528-1992-001, “Reactor Shutdown Required by Technical 

Specifications,” U.S. Nuclear Regulatory Commission, February 3, 1992.

NRC Memorandum, “Alternate ASME Code Editions and Addenda to those Cited in the GALL Report,” 

U.S. Nuclear Regulatory Commission, September 20, 2005.

NRC Regulatory Issue Summary 2003-13, “NRC Review of Responses to Bulletin 2002-01, “Reactor 

Pressure Vessel Head Degradation and Reactor Coolant Pressure Boundary Integrity,” July 29, 2003.

NUMARC Report 90-01, Revision 1, Sept 1991, "Pressurized Water Reactors Containment Structures 

License Renewal Industry Report,” NUMARC, Washington D.C.

NUMARC Report 90-05, Revision 1, December 1992, "PWR Reactor Pressure Vessel Internals License 

Renewal Industry Report,” NUMARC, Washington D.C.

NUMARC Report 90-06, Revision 1, December 1991, "Class 1 Structures License Renewal Industry 

Report,” NUMARC, Washington D.C.

NUMARC Report 90-07, May 1992, "PWR Reactor Coolant system License Renewal Industry Report," 

NUMARC, Washington D.C.

NUREG/CR-2156 (SAND80-2149), R. L. Clough, K. T. Gillen, “Radiation-Thermal Degradation of PE and 

PVCL Mechanism of Synergism and Dose Rate Effects, June 1981.

NUREG/CR-5385, Chopra, O. K. and A. Sather, “Initial Assessment of the Mechanisms and Significance 

of Low-Temperature Embrittlement of Cast Stainless Steels in LWR Systems” NUREG/CR-5385 

(ANL-89/17) Argonne National Laboratory, Argonne, IL (August 1990).

NUREG/CR-6260, "Application of NUREG/CR-5999 Interim Fatigue Curves to Selected Nuclear Power 

Plant Components," March 1995.

NUREG-1557, “Summary of Technical Information and Agreements from Nuclear Management and 

Resources Council Industry Reports Addressing License Renewal,” October 1996.

NUREG-1743, “Safety Evaluation Report Related to the License Renewal of Arkansas Nuclear One, Unit 

1,” May 2001.
October 2005 279 NUREG-1833

NUREG-1760, “Aging Assessment of Safety-Related Fuses Used in Low- and Medium-Voltage 

Applications in Nuclear Power Plants,” May 2002.

NUREG-1766, “Safety Evaluation Report Related to the License Renewal of North Anna Power Station, 

Units 1 and 2, and Surry Power Station, Units 1 and 2,” December 2002.

NUREG-1769, “Safety Evaluation Report Related to the License Renewal of Peach Bottom Atomic Power 

Station, Units 2 and 3,” March 2003.

NUREG-1779, “Safety Evaluation Report Related to the License Renewal of St. Lucie Nuclear Plant, 

Units 1 and 2,” September 2003.

NUREG-1782, “Safety Evaluation Report Related to the License Renewal of the Fort Calhoun Station, 

Unit 1,” October 2003.

NUREG-1785, “Safety Evaluation Report Related to the License Renewal of the H. B. Robinson Steam 

Electric Plant, Unit 2,” March 2004.

NUREG-1786, "Safety Evaluation Report Related to the License Renewal of the Virgil C. Summer 

Nuclear Station," March 2004.

NUREG-1787, "Safety Evaluation Report - Related to the License Renewal of the R. E. Ginna Nuclear 

Power Plant," May 2004.

NUREG-1796, “Safety Evaluation Report Related to the License Renewal of the Dresden Nuclear Power 

Station, Units 2 and 3, and the Quad Cities Nuclear Power Station, Units 1 and 2,” October 2004.

NUREG-1825, “Safety Evaluation Report Related to the License Renewal of the Joseph M. Farley 

Nuclear Plant, Units 1 and 2,” May 2005.

NUREG-1828, “Safety Evaluation Report Related to the License Renewal of Arkansas Nuclear One, Unit 

2,” June 2005.

NUREG-1831, “Safety Evaluation Report Related to the License Renewal of the Donald C. Cook Nuclear 

Plant, Units 1 and 2,” July 2005.

Peckner, D., and I. M. Bernstein, Eds., “Handbook of Stainless Steels,” McGraw-Hill, New York, 1977.

Rabald, E., “Corrosion Guide,” 2nd ed., Elsevier Publishing Company, 1968.

Safety Evaluation Report Related to the License Renewal of the Millstone Power Station, Units 2 and 3, 

Docket Nos. 50-336 and 50-423, August 2005

SAND96-0344, “Aging Management Guideline for Commercial Nuclear Power Plants – Electrical Cable 

and Terminations,” September 1996.

Schweitzer, P.A., Editor, “Corrosion Resistant Tables,” 5th ed., 3-volume set, Marcel Dekker, Inc., 2004.

Shah, V.N., and P.E. Macdonald (eds.) “Aging and Life Extension of Major Light Water Reactor 

Components," Elsevier, Amsterdam, 1993.

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Uhlig, H.H, and R.W. Revie, “Corrosion and Corrosion Control,” 4th ed., John Wiley & Sons, 2000.
NUREG-1833 280 October 2005

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October 2005 A-i NUREG-1833

APPENDIX A

Standard Terminology
NUREG-1833 A-ii October 2005

This Page Intentionally Left Blank
October 2005 A-1 NUREG-1833

Introduction

This Appendix provides definitions of terms used to describe systems, structures, and 

components; materials, environments, aging effects and aging mechanisms utilized in the GALL 

Report and the SRP-LR. It also provides listing of these various terms and where and how 

frequently they are used. Throughout these tables, when a column contains Roman numerals, 

they identify the chapter in GALL Vol. 2 that the parameter is associated with (i.e., “II” for 

Containment Structures, “III” for Structures and Component Supports, “IV” for Reactor Vessel, 

Internals, and Reactor Coolant Systems, “V” for Engineered Safety Features Systems, “VI” for 

Electrical Systems, “VII” for Auxiliary Systems, and “VIII” for Steam and Power Conversion 

Systems).

Finally this appendix provides in A.5 a listing of the way in which the Material, Environment, 

Aging Effect, and Aging Management Programs (MEAP combinations) were used in GALL Vol. 

2 and the SRP-LR. 

It should be noted that the process used to develop these tables leaves the cells in a column 

blank if the entry would duplicate the entry in the row above. Therefore, to determine the value 

that applies where a cell is blank, the reader must scan back up the column to the previous nonblank cell. Similarly, if one or more cells do not have a lower border when the table spans a 

page, the absence of this border indicates the continuation of the cell’s value onto the following 

page.

A.1 Structures and/or Components

The GALL Report does not address scoping of structures and components for license renewal. 

Scoping is plant specific, and the results depend on the plant design and current licensing basis. 

The inclusion of a certain structure or component in the GALL Report does not mean that this 

particular structure or component is within the scope of license renewal for all plants. 

Conversely, the omission of a certain structure or component in the GALL Report does not 

mean that this particular structure or component is not within the scope of license renewal for 

any plants. 

NUREG-1801 identifies aging management review results for many system components. Some 

components are identified in general terms while others are very specifically described. While 

the NUREG AMR results for a system identify a cross-section of typical components, many of 

the components that must be included for the corresponding system in the AMR results of a 

plant LRA are not addressed in the NUREG. To extend the NUREG-1801 AMR results to a 

broader range of plant components, the component descriptions have been generalized as 

much as possible while still retaining enough information to support the conclusions of the AMR 

results.

A.1.1 Listing and Location of Structures and/or Components 

Table A.1.1 provides a complete listing of the identifiers and their locations of usage in the 

revised GALL Report. The table A.1.2 provides more insight to the usage of what can be called 

‘roll-up’ terminology.

The Roman numeral in the first column identifies the chapter in GALL Vol. 2 that the structures 

and/or components are associated with (i.e., “II” for Containment Structures, “III” for Structures 

and Component Supports, “IV” for Reactor Vessel, Internals, and Reactor Coolant Systems, “V” 

for Engineered Safety Features Systems, “VI” for Electrical Systems, “VII” for Auxiliary Systems, 

and “VIII” for Steam and Power Conversion Systems).
NUREG-1833 A-2 October 2005

A.1.1 Structures and/or Components: Listing and Location of Terms used in AMR Tables

Referring 

Chapters in 

GALL Rev. 1

Standardized Expression

IV Baffle/former assembly 

 Baffle and former plates

IV Baffle/former assembly 

 Baffle/former bolts

IV Baffle/former assembly 

 Baffle/former bolts and screws

V, VII, VIII Bolting

IV Bottom-mounted guide tube

III Building concrete at locations of expansion and grouted anchors; grout pads for support 

base plates

VIII Buried piping, piping components, piping elements, and tanks

VI Cable Connections (Metallic Parts)

IV CEA shroud assemblies

IV CEA shroud assemblies 

 CEA shroud extension shaft guides

IV CEA shroud assemblies 

 CEA shrouds bolts

IV Class 1 piping, fittings and branch connections < NPS 4

IV Class 1 piping, fittings, primary nozzles, safe ends, manways, and flanges

IV Class 1 piping, piping components, and piping elements

IV Class 1 pump casings and valve bodies

IV Class 1 pump casings, and valve bodies and bonnets

IV, V, VII, VIII Closure bolting

IV Closure head 

 Stud assembly

IV Closure head 

 Vessel flange leak detection line

VII Compressed air system 

 Piping, piping components, and piping elements

II Concrete elements; All

III Concrete: 

 All

II Concrete: 

 Basemat

II Concrete: 

 Basemat, concrete fill-in annulus

II Concrete: 

 Basemat; reinforcing steel

III Concrete: 

 Below-grade exterior; foundation

II Concrete: 

 Containment; wall; basemat

II Concrete: 

 Dome; wall; basemat

II Concrete: 

 Dome; wall; basemat; reinforcing steel

II Concrete: 

 Dome; wall; basemat; ring girder; buttresses
October 2005 A-3 NUREG-1833

A.1.1 Structures and/or Components: Listing and Location of Terms used in AMR Tables

Referring 

Chapters in 

GALL Rev. 1

Standardized Expression

II Concrete: 

 Dome; wall; basemat; ring girders; buttresses

II Concrete: 

 Dome; wall; basemat; ring girders; buttresses; reinforcing steel

III Concrete: 

 Exterior above- and below-grade; foundation

III Concrete: 

 Exterior above- and below-grade; foundation; interior slab

II, III Concrete: 

 Foundation; subfoundation

III Concrete: 

 Interior and above-grade exterior

VI Conductor insulation for electrical cables and connections

VI Conductor insulation for electrical cables and connections used in instrumentation 

circuits that are sensitive to reduction in conductor insulation resistance (IR)

VI Conductor insulation for inaccessible medium-voltage (2kV to 35kV) cables 

(e.g., installed in conduit or direct buried)

VI Connector contacts for electrical connectors exposed to borated water leakage

III Constant and variable load spring hangers; guides; stops; sliding surfaces; design 

clearances; vibration isolators

V Containment isolation piping and components external surfaces

V Containment isolation piping and components internal surfaces

IV Control rod drive head penetration 

 Flange bolting

IV Control rod drive head penetration 

 Nozzle and welds

IV Control rod drive head penetration 

 Pressure housing

IV Control rod guide tube (CRGT) assembly 

 CRGT pipe and flange 

 CRGT spacer casting 

 CRGT rod guide tubes 

 CRGT rod guide sectors

IV Control rod guide tube (CRGT) assembly 

 CRGT pipe and flange 

 CRGT spacer casting 

 CRGT spacer screws 

 Flange-to-upper grid screws 

 CRGT rod guide tubes 

 CRGT rod guide sectors

IV Control rod guide tube (CRGT) assembly 

 CRGT spacer casting

IV Control rod guide tube (CRGT) assembly 

 CRGT spacer screws 

 Flange-to-upper grid screws

IV Control rod guide tube (CRGT) assembly 

 Flange-to-upper grid screws
NUREG-1833 A-4 October 2005

A.1.1 Structures and/or Components: Listing and Location of Terms used in AMR Tables

Referring 

Chapters in 

GALL Rev. 1

Standardized Expression

IV Core barrel 

 Core barrel (CB) 

 CB flange (upper) 

 CB outlet nozzles 

 Thermal shield

IV Core barrel assembly 

 Baffle/former assembly 

 Baffle/former bolts and screws

IV Core barrel assembly

 Baffle/former bolts and screws

IV Core barrel assembly 

 Core barrel cylinder (top and bottom flange) 

 Baffle plates and formers

IV Core barrel assembly 

 Core barrel cylinder (top and bottom flange) 

 Lower internals assembly-to- core barrel bolts 

 Core barrel-to-thermal shield bolts 

 Baffle plates and formers

IV Core barrel assembly 

 Lower internals assembly-to-core barrel bolts 

 Core barrel-to-thermal shield bolts

IV Core shroud (including repairs) and core plate 

 Core shroud (upper, central, lower)

IV Core shroud (including repairs) and core plate 

 Shroud support structure (shroud support cylinder, shroud support plate, shroud 

support legs)

IV Core shroud and core plate 

 LPCI coupling

IV Core shroud and core plate 

 Access hole cover 

 (mechanical covers)

IV Core shroud and core plate 

 Access hole cover 

 (welded covers)

IV Core shroud and core plate 

 Core plate 

 Core plate bolts (used in early BWRs)

IV Core shroud assembly 

 Core shroud assembly bolts 

 Core shroud tie rods

IV Core shroud assembly 

 Core shroud assembly bolts (later plants are welded)

IV Core shroud assembly 

 Core shroud tie rods (core support plate attached by welds in later plants)

IV Core spray lines and spargers 

 Core spray lines (headers) 

 Spray rings 

 Spray nozzles 

 Thermal sleeves
October 2005 A-5 NUREG-1833

A.1.1 Structures and/or Components: Listing and Location of Terms used in AMR Tables

Referring 

Chapters in 

GALL Rev. 1

Standardized Expression

IV Core support barrel 

 Core support barrel upper flange

IV Core support barrel 

 Core support barrel upper flange 

 Core support barrel alignment keys

IV Core support pads/ core guide lugs

IV Core support shield assembly 

 Core support shield cylinder 

 (top flange) 

 VV assembly locking device

IV Core support shield assembly 

 Core support shield cylinder (top and bottom flange) 

 Core support shield-to-core barrel bolts 

 Outlet and vent valve (VV) nozzles 

 VV assembly locking device

IV Core support shield assembly 

 Core support shield cylinder (top and bottom flange) 

 Core support shield-to-core barrel bolts 

 VV retaining ring 

 VV assembly locking device

IV Core support shield assembly 

 Core support shield cylinder (top and bottom flange) 

 Outlet and vent valve (VV) nozzles 

 VV body and retaining ring

IV Core support shield assembly 

 Core support shield-to-core barrel bolts

IV Core support shield assembly 

 Core support shield-to-core barrel bolts 

 VV assembly locking device

IV Core support shield assembly 

 Outlet and vent valve nozzles 

 VV body and retaining ring

VII Cranes – rails

VII Cranes – Structural girders

VII Diesel engine exhaust 

 Piping, piping components, and piping elements

V Drywell and suppression chamber spray system (internal surfaces): 

 Flow orifice 

 Spray nozzles

V Ducting

VII Ducting and components

VII Ducting and components external surfaces

V, VII Ducting and components internal surfaces

V, VII Ducting closure bolting

V Ducting, piping and components external surfaces
NUREG-1833 A-6 October 2005

A.1.1 Structures and/or Components: Listing and Location of Terms used in AMR Tables

Referring 

Chapters in 

GALL Rev. 1

Standardized Expression

III Earthen water-control structures: 

 Dams, 

 Embankments, 

 Reservoirs, 

 Channels, 

 Canals and ponds

VII Elastomer lining

V, VII Elastomer seals and components

VI Electrical equipment subject to 10 CFR 50.49 EQ requirements

V Encapsulation Components

IV, V, VII, VIII External surfaces

VII Fire barrier penetration seals

VII Fire rated doors

IV Flanges; nozzles; penetrations; pressure housings; safe ends; vessel shells, heads and 

welds

IV Flow distributor assembly 

 Flow distributor head and flange 

 Incore guide support plate 

 Clamping ring

IV Flow distributor assembly 

 Flow distributor head and flange 

 Shell forging-to-flow distributor bolts 

 Incore guide support plate 

 Clamping ring

IV Flow distributor assembly 

 Shell forging-to-flow distributor bolts

IV Fuel supports and control rod drive assemblies 

 Control rod drive housing

IV Fuel supports and control rod drive assemblies 

 Orificed fuel support

VI Fuse Holders (Not Part of a Larger Assembly); 

 Insulation

VI Fuse Holders (Not Part of a Larger Assembly); 

 Metallic Clamp

V, VII, VIII Heat exchanger components

III, V, VII, VIII Heat exchanger tubes

VIII

III High strength bolting for NSSS component supports

VI High voltage insulators

VII High-pressure pump 

 Casing

VII High-pressure pump 

 Closure bolting

IV Instrument penetrations and primary side nozzles, safe ends, and welds

IV Instrumentation 

 Intermediate range monitor (IRM) dry tubes 

 Source range monitor (SRM) dry tubes 

 Incore neutron flux monitor guide tubes
October 2005 A-7 NUREG-1833

A.1.1 Structures and/or Components: Listing and Location of Terms used in AMR Tables

Referring 

Chapters in 

GALL Rev. 1

Standardized Expression

IV Instrumentation support structures 

 Flux thimble guide tubes

IV Instrumentation support structures 

 Flux thimble tubes

IV Isolation condenser components

IV Jet pump assemblies 

 Castings

IV Jet pump assemblies 

 Jet pump sensing line

IV Jet pump assemblies 

 Thermal sleeve 

 Inlet header 

 Riser brace arm 

 Holddown beams 

 Inlet elbow 

 Mixing assembly 

 Diffuser 

 Castings

IV Lower grid assembly 

 Fuel assembly support pads Guide blocks

IV Lower grid assembly 

 Incore guide tube spider castings

IV Lower grid assembly 

 Lower grid rib section 

 Fuel assembly support pads 

 Lower grid flow dist. Plate 

 Orifice plugs 

 Lower grid and shell forgings 

 Guide blocks 

 Shock pads 

 Support post pipes 

 Incore guide tube spider castings

IV Lower grid assembly 

 Lower grid rib section 

 Fuel assembly support pads 

 Lower grid rib-to-shell forging screws 

 Lower grid flow dist. Plate 

 Orifice plugs 

 Lower grid and shell forgings 

 Lower internals assembly-to- thermal shield bolts 

 Guide blocks and bolts 

 Shock pads and bolts 

 Support post pipes 

 Incore guide tube spider castings
NUREG-1833 A-8 October 2005

A.1.1 Structures and/or Components: Listing and Location of Terms used in AMR Tables

Referring 

Chapters in 

GALL Rev. 1

Standardized Expression

IV Lower grid assembly 

 Lower grid rib section 

 Fuel assembly support pads 

 Lower grid rib-to-shell forging screws 

 Lower grid flow dist. Plate 

 Orifice plugs 

 Lower grid and shell forgings 

 Lower internals assembly-to-thermal shield bolts 

 Guide blocks and bolts 

 Shock pads and bolts 

 Support post pipes

IV Lower grid assembly 

 Lower grid rib-to-shell forging screws 

 Lower internals assembly-to- thermal shield bolts 

 Guide blocks bolts 

 Shock pads bolts

IV Lower grid assembly 

 Lower grid rib-to-shell forging screws 

 Lower internals assembly-to-thermal shield bolts

IV Lower internal assembly 

 Clevis insert bolts

IV Lower internal assembly 

 Core support column

IV Lower internal assembly 

 Core support plate 

 Fuel alignment pins 

 Lower support structure beam assemblies 

 Core support column bolts 

 Core support barrel snubber assemblies

IV Lower internal assembly 

 Core support plate 

 Lower support structure beam assemblies 

 Core support column 

 Core support barrel snubber assemblies

IV Lower internal assembly 

 Fuel alignment pins 

 Core support barrel snubber assemblies

IV Lower internal Assembly 

 Fuel alignment pins 

 Core support column bolts

IV Lower internal assembly 

 Fuel alignment pins 

 Lower support plate column bolts 

 Clevis insert bolts

IV Lower internal assembly 

 Lower core plate

IV Lower internal assembly 

 Lower core plate 

 Radial keys and clevis inserts
October 2005 A-9 NUREG-1833

A.1.1 Structures and/or Components: Listing and Location of Terms used in AMR Tables

Referring 

Chapters in 

GALL Rev. 1

Standardized Expression

IV Lower internal assembly 

 Lower support casting 

 Lower support plate columns

IV Lower internal assembly 

 Lower support forging 

 Lower support plate columns

IV Lower internal assembly 

 Lower support forging or casting 

 Lower support plate columns

IV Lower internal assembly 

 Lower support plate column bolts

IV Lower internal assembly 

 Radial keys and clevis Inserts

III Masonry walls: 

 All

III Metal components: 

 All structural members

VI Metal enclosed bus 

 Bus/connections

VI Metal enclosed bus 

 Enclosure assemblies

VI Metal enclosed bus 

 Insulation/insulators

V Motor Cooler

VII Non-regenerative heat exchanger components

IV Nozzle safe ends (and associated welds) 

 High pressure core spray 

 Low pressure core spray 

 Control rod drive return line 

 Recirculating water 

 Low pressure coolant injection or RHR injection mode

IV Nozzle safe ends and welds: 

 Inlet 

 Outlet 

 Safety injection

IV Nozzles 

 Control rod drive return line

IV Nozzles 

 Feedwater

IV Nozzles 

 Inlet 

 Outlet 

 Safety injection

IV Nozzles 

 Low pressure coolant injection or RHR injection mode

IV Once-through steam generator components: 

 Primary side nozzles 

 Safe ends and welds

V Orifice (miniflow recirculation)
NUREG-1833 A-10 October 2005

A.1.1 Structures and/or Components: Listing and Location of Terms used in AMR Tables

Referring 

Chapters in 

GALL Rev. 1

Standardized Expression

V Partially encased tanks with breached moisture barrier

II Penetration sleeves

II Penetration sleeves; 

 Penetration bellows

IV Penetrations 

 Control rod drive stub tubes Instrumentation 

 Jet pump instrument 

 Standby liquid control 

 Flux monitor 

 Drain line

IV Penetrations 

 Head vent pipe (top head)

 Instrument tubes (top head)

IV Penetrations 

 Instrument tubes (bottom head)

II Personnel airlock, equipment hatch, CRD hatch: 

 Locks, hinges, and closure mechanisms

II Personnel airlock, equipment hatch, CRD hatch

VII Piping and components external surfaces

IV Piping and components external surfaces and bolting

V Piping and components internal surfaces

V, VII, VIII Piping elements

IV, V, VII, VIII Piping, piping components, and piping elements

IV Piping, piping components, and piping elements greater than or equal to 4 NPS

V Piping, piping components, and piping elements internal surfaces

IV Piping, piping components, and piping elements; flanges; heater sheaths and sleeves; 

penetrations; thermal sleeves; vessel shell heads and welds

V Piping, piping components, piping elements internal surfaces, and tanks 

V, VII Piping, piping components, piping elements, and tanks

IV Plenum cover and plenum cylinder 

 Plenum cover assembly 

 Plenum cylinder 

 Reinforcing plates

IV Plenum cover and plenum cylinder 

 Plenum cover assembly Plenum cylinder 

 Reinforcing plates 

 Top flange-to-cover bolts Bottom flange-to-upper grid screws

IV Plenum cover and plenum cylinder 

 Top flange-to-cover bolts Bottom flange-to-upper grid screws

IV Pressure boundary and structural 

 Steam nozzle and safe end 

 FW nozzle and safe end

IV Pressure vessel support skirt and attachment welds

IV Pressurizer 

 Integral support

IV Pressurizer 

 Spray head

IV Pressurizer components

IV Pressurizer heater sheaths and sleeves, and heater bundle diaphragm plate
October 2005 A-11 NUREG-1833

A.1.1 Structures and/or Components: Listing and Location of Terms used in AMR Tables

Referring 

Chapters in 

GALL Rev. 1

Standardized Expression

IV Pressurizer instrumentation penetrations, heater sheaths and sleeves, heater bundle 

diaphragm plate, and manways and flanges

IV Pressurizer relief tank 

 Tank shell and heads 

 Flanges and nozzles

IV Pressurizer surge and steam space nozzles, and welds

II Prestressing system: 

 Tendons

II Prestressing system: 

 Tendons; anchorage components

IV Primary side 

 Divider Plate

IV Primary side components 

 Upper and lower heads 

 Tube sheets and tube-to-tube sheet welds

IV Pump and valve closure bolting

IV Pump and valve seal flange closure bolting

V Pump Casings

VIII PWR heat exchanger components

IV RCCA guide tube assemblies 

 RCCA guide tube bolts 

 RCCA guide tube support pins

IV RCCA guide tube assemblies 

 RCCA guide tubes

IV Reactor coolant pressure boundary components

IV Reactor coolant pressure boundary components: 

 Piping, piping components, and piping elements; 

 Flanges; 

 Nozzles and safe ends; 

 Pressurizer vessel shell heads and welds; 

 Heater sheaths and sleeves; 

 Penetrations; and 

 Thermal sleeves

IV Reactor coolant pressure boundary components: 

 Piping, piping components, and piping elements

VII Reactor coolant pump oil collection system 

 Piping, tubing, valve bodies

VII Reactor coolant pump oil collection system 

 Tank

IV Reactor coolant system piping and fittings 

 Cold leg 

 Hot leg 

 Surge line 

 Spray line
NUREG-1833 A-12 October 2005

A.1.1 Structures and/or Components: Listing and Location of Terms used in AMR Tables

Referring 

Chapters in 

GALL Rev. 1

Standardized Expression

IV Reactor vessel components: 

 Flanges; 

 Nozzles; 

 Penetrations; 

 Pressure housings; 

 Safe ends; 

 Thermal sleeves; 

 Vessel shells, heads and welds 

IV Reactor vessel components: 

 Flanges;

 Nozzles; 

 Penetrations; 

 Safe ends; 

 Thermal sleeves; 

 Vessel shells, heads and welds 

IV Reactor vessel internals components

IV Reactor Vessel: 

 Flanges, nozzles; penetrations; safe ends; vessel shells, heads and welds

IV Recirculating steam generator components: 

 Flanges; 

 Penetrations; 

 Nozzles; 

 Safe ends, lower heads and welds

VII Regenerative heat exchanger components

V Safety injection tank (accumulator)

II, III Seals, gaskets, and moisture barriers (caulking, flashing, and other sealants)

IV Secondary manways and handholes (cover only)

III Sliding support bearings and sliding support surfaces

VII Spent fuel storage racks 

 Neutron-absorbing sheets – BWR

VII Spent fuel storage racks 

 Neutron-absorbing sheets – PWR

VII Spent fuel storage racks 

 Storage racks – BWR

VII Spent fuel storage racks 

 Storage racks – PWR

IV Steam Dryers

IV Steam generator 

 Tube bundle wrapper

IV Steam generator closure bolting

IV Steam generator components 

 FW and AFW nozzles and safe ends 

 Steam nozzles and safe ends

IV Steam generator components 

 Shell assembly

IV Steam generator components 

 Such as secondary side nozzles (vent, drain, and instrumentation)
October 2005 A-13 NUREG-1833

A.1.1 Structures and/or Components: Listing and Location of Terms used in AMR Tables

Referring 

Chapters in 

GALL Rev. 1

Standardized Expression

IV Steam generator components 

 Top head; 

 Steam nozzle and safe end; 

 Upper and lower shell; 

 FW and AFW nozzle and safe end; 

 FW impingement plate and support

IV Steam generator components 

 Upper and lower shell, and transition cone

IV Steam generator feedwater impingement plate and support

IV Steam generator structural 

 Anti-vibration bars

IV Steam generator structural 

 Tube support lattice bars

IV Steam generator structural 

 Tube support plates

III Steel components: 

 All structural steel

III Steel components: 

 Fuel pool liner

III Steel components: 

 Radial beam seats in BWR drywell; 

 RPV support shoes for PWR with nozzle supports; 

 Other supports

III Steel components: 

 Radial beam seats in BWR drywell; 

 RPV support shoes for PWR with nozzle supports; 

 Steam generator supports

III Steel components: 

 Tank liner

II Steel elements: 

 Suppression chamber; drywell liner; drywell head; embedded shell; sand pocket 

region; support skirt; downcomer pipes; region shielded by diaphragm floor 

 Note: Inspection of containment supports is addressed by ASME Section XI, 

Subsection IWF (see III.B1.3)

II Steel elements: 

 Drywell head; 

 Downcomers

II Steel elements: 

Drywell; torus; drywell head; embedded shell and sand pocket regions; 

drywell support skirt; 

torus ring girder; 

downcomers; ECCS 

suction header 

 Note: Inspection of containment supports is addressed by ASME Section XI, 

Subsection IWF (see III.B1.3)

II Steel elements: 

 Liner; 

 Liner anchors; 

 Integral attachments
NUREG-1833 A-14 October 2005

A.1.1 Structures and/or Components: Listing and Location of Terms used in AMR Tables

Referring 

Chapters in 

GALL Rev. 1

Standardized Expression

II Steel elements: 

 Suppression chamber liner (interior surface)

II Steel elements: 

 Suppression chamber shell (interior surface)

II Steel elements: 

 Torus; 

 Vent line; 

 Vent header; 

 Vent line bellows; 

 Downcomers 

II Steel elements: 

 Vent header; 

 Downcomers 

II Steel elements: 

 Vent line bellows

VII Structural fire barriers: 

 Walls, ceilings and floors

VII Structural Steel

III Support members; welds; bolted connections; support anchorage to building structure

II Suppression pool shell; unbraced downcomers

VI Switchyard bus and connections

VII, VIII Tanks

IV Thermal shield

IV Top guide

IV Top head enclosure 

 Closure studs and nuts

IV Top head enclosure 

 Vessel flange leak detection line

IV Top head enclosure (without cladding) 

 Top head 

 Nozzles (vent, top head spray or RCIC, and spare)

VI Transmission conductors and connections

IV Tube plugs

IV Tubes

IV Tubes and sleeves

IV Tubes and sleeves (exposed to phosphate chemistry)

IV Upper assembly and separators 

 Feedwater inlet ring and support

IV Upper grid assembly 

 Fuel assembly support pads Plenum rib pads

IV Upper grid assembly 

 Rib- to-ring screws

IV Upper grid assembly 

 Upper grid rib section 

 Upper grid ring forging 

 Fuel assembly support pads 

 Plenum rib pads
October 2005 A-15 NUREG-1833

A.1.1 Structures and/or Components: Listing and Location of Terms used in AMR Tables

Referring 

Chapters in 

GALL Rev. 1

Standardized Expression

IV Upper grid assembly 

 Upper grid rib section 

 Upper grid ring forging 

 Fuel assembly support pads 

 Plenum rib pads 

 Rib-to-ring screws

IV Upper internals assembly 

 Fuel alignment plate 

 Fuel alignment plate guide lugs and their lugs 

 Hold-down ring

IV Upper internals assembly 

 Hold-down spring

IV Upper internals assembly 

 Upper core plate alignment pins

IV Upper internals assembly 

 Upper guide structure support plate 

 Fuel alignment plate 

 Fuel alignment plate guide lugs and guide lug inserts

IV Upper internals assembly 

 Upper support column

IV Upper internals assembly 

 Upper support column 

 (only cast austenitic stainless steel portions)

IV Upper internals assembly 

 Upper support column bolts

IV Upper internals assembly 

 Upper support column bolts Upper core plate alignment pins 

 Fuel alignment pins

IV Upper internals assembly 

 Upper support plate 

 Upper core plate 

 Hold-down spring

IV Vessel shell 

 Attachment welds

IV Vessel shell 

 Intermediate beltline shell 

 Beltline welds

IV Vessel shell 

 Upper shell 

 Intermediate and lower shell 

 (including beltline welds)

IV Vessel shell 

 Vessel flange

III Vibration isolation elements
NUREG-1833 A-16 October 2005

A.1.2 Definition of Selected Terminology for Structures and Components 

Table A.1.2 defines some of the structures and components referenced in the NUREG-1801, Rev. 1, 

AMR tables in Chapters II, III, IV, V, VI, VII, and VIII. Thus Table A.1.2 provides some illumination to the 

preceding Table A.1.1.

A.1.2 Definition of Selected Consolidated Structures and Components

Term Definition as used in this document

Bolting Bolting can refer to either structural bolting or closure 

bolting. Within the scope of license renewal, both Class 1 

and non-Class 1 systems and components contain bolted 

closures that are necessary for the pressure boundary of 

the components being joined/closed. Closure bolting in 

high-pressure or high-temperature systems is defined as 

that in which the pressure exceeds 275 psi or 200oF 

(93oC). Closure bolting is used to join pressure 

boundaries or where a mechanical seal is required; bolting 

includes closure bolting and all other bolting.

Ducting and components Ducting and components include heating, ventilation, and 

air-conditioning (HVAC) components. Examples include 

ductwork, ductwork fittings, access doors, closure bolts, 

equipment frames and housing, housing supports, 

including housings for valves, dampers (including louvers 

and gravity dampers), and ventilation fans (including 

exhaust fans, intake fans, and purge fans). In some 

cases, this also includes piping.

Encapsulation Components/

Valve Chambers

These are airtight enclosures that function as a secondary 

containment boundary to completely enclose containment 

sump lines and isolation valves. Encapsulation 

components and features (in systems such as emergency 

core cooling system, containment spray system, and 

containment isolation system, and refueling water storage 

tank) can include encapsulation vessels, piping, and 

valves. 

External surfaces In the context of structures and components, the term 

“external surfaces” is used to represent the external 

surfaces of structures and components such as tanks that 

are not specifically listed elsewhere.

Heat exchanger components A heat exchanger is a device that transfers heat from one 

fluid to another without the fluids coming in contact with 

each other. This includes air handling units and other 

devices that cool or heat fluids. Heat exchanger 

component examples may include, but are not limited to, 

air handling unit cooling and heating coils, piping/tubing, 

shell, tubesheets, tubes, valves, and bolting. Although 

tubes are the primary heat transfer component, heat 

exchanger internals including tubesheets and fins 

contribute to heat transfer and may be affected by 

reduction of heat transfer due to fouling [SAND 93-7070].

The inclusion of such components as tubesheets is 

dependent on manufacturer specifications.

High voltage insulators An insulator is an insulating material in a form designed to 

support a conductor physically and separate the 

conductor electrically from other conductors or objects. 
October 2005 A-17 NUREG-1833

A.1.2 Definition of Selected Consolidated Structures and Components

Term Definition as used in this document

The insulators evaluated for license renewal are those 

used to support and insulate high voltage electrical 

components in switchyards, switching stations and 

transmission lines.

Metal-enclosed bus MEB is the IEEE and ANSI term for electrical buses 

installed on electrically-insulated supports that are 

constructed with all phase conductors enclosed in a 

separate metal enclosure or a common metal enclosure. 

Piping, piping components, and piping 

elements 

This general category includes various features of the 

piping system that are within the scope of license renewal. 

Examples include piping, fittings, tubing, flow 

elements/indicators, demineralizer, nozzles, orifices, flex 

hoses, pump casing and bowl, safe ends, spray head, 

strainers, thermowells, and valve body and bonnet. For 

reactor coolant pressure boundary components in Chapter 

IV that are subject to cumulative fatigue damage, this can 

also include flanges, nozzles and safe ends, penetrations, 

vessel head, shell, welds, stub tubes and miscellaneous 

Class 1 components, such as pressure housings.

Piping elements This general category includes components made of 

glass, such as sight glasses and level indicators. This 

“piping elements” designation is used in the AMR tables 

only when the material is defined as glass.

Reactor Coolant Pressure Boundary 

Components

Reactor coolant pressure boundary components include, 

but are not limited to: piping, piping components, and 

piping elements; flanges; nozzles and safe ends; 

pressurizer vessel shell heads and welds; heater sheaths 

and sleeves; penetrations; and thermal sleeves.

Pressure housings The term “pressure housing” only refers to pressure 

housing for the control rod drive (CRD) head penetration 

(as indicated in GALL Rev. 0, it is only of concern in 

Section A2 for PWR reactor vessels).

Seals, gaskets, and moisture barriers 

(calking, flashing, and other sealants)

Elastomer components used as sealant, or as gaskets.

Steel elements: Liner; liner anchors; 

integral attachments

Steel liners used in suppression pool or spent fuel pool.

Switchyard bus Switchyard bus is uninsulated, unenclosed, rigid electrical 

conductor used in switchyards and switching stations to 

connect two or more elements of an electrical power 

circuit such as active disconnect switches and passive 

transmission conductors.

Tanks Steel tanks with bottoms in a soil or concrete environment 

have general corrosion as the aging effect for the interface 

between soil or concrete and the bottom of the tank. 

Degradation of the tank bottoms in these aboveground 

steel tanks can be managed by AMP XI.M29.

Transmission conductors Transmission conductors are uninsulated, stranded 

electrical cables used in switchyards, switching stations 

and transmission lines to connect two or more elements of 

an electrical power circuit such as active disconnect 
NUREG-1833 A-18 October 2005

A.1.2 Definition of Selected Consolidated Structures and Components

Term Definition as used in this document

switches, power circuit breakers, and transformers and 

passive switchyard bus.

Vibration isolation elements Non-steel supports used for supporting components prone 

to vibration
October 2005 A-19 NUREG-1833

A.2 Materials

Materials were listed in various ways in GALL Rev. 0. In most cases, general material types 

(e.g., stainless steel, carbon steel, nickel alloy) were used, while in others (e.g., reactor vessels 

and some vendor internals), specific types of steel are identified. For some results, multiple 

general material types were listed together. The material column entry was restated such that 

the combined information of the component, material, and environment columns supported the 

conclusions of the AMR results. The replacement of specific types with general types was done 

extensively for the reactor vessel and internals tables and for the cranes table in auxiliary 

systems. 

The general material types were determined on the basis of a common susceptibility to aging 

effects and mechanisms, shared with the specific material types replaced. For example, the 

specific material types listed in the first row of the reactor vessel table, A1, are SA302-Gr B, 

SA533-Gr B and SA336. Respectively, these materials are manganese-molybdenum alloy steel, 

carbon steel, and chromium-molybdenum alloy steel. The carbon steel and both the alloy steels 

are characterized as carbon steel because they are susceptible to general, pitting, and crevice 

corrosion in a wetted (reactor coolant) environment, a common aging susceptibility for carbon 

steel found throughout the GALL Report. Within the GALL Report, references to these specific 

material types refer to other aging susceptibilities consistent with carbon steel (e.g., loss of 

material due to boric acid corrosion, fatigue, neutron embrittlement, and wear). Therefore, these 

specific material types are considered carbon steel, and the description of carbon steel in the 

materials list in the attachments mentions alloy steels as a part of the general material type.

Composite materials (e.g., carbon steel clad with stainless steel) were not included unless the 

aging effect, such as fatigue, would apply to the composite material. Otherwise, each material of 

a composite was evaluated separately with its respective environment. For example, a carbon 

steel tank with stainless cladding containing borated water was evaluated as stainless steel in 

borated water, and carbon steel in air. The restatement of some GALL AMR results that 

included carbon (or low alloy) steel clad with stainless, addressed only the stainless portion 

since the environment and the aging management program were not applicable to the carbon 

steel portion. In these cases, the AMR results for exterior carbon steel surfaces (located 

elsewhere in the tables) address the balance of the component material.

The following tables define many of generalized materials utilized in the GALL AMR tables in 

Chapters II, III, IV, V, VI, VII, and VIII of NUREG-1801, Rev. 1. 

A.2.1 Listing, Location and Frequency of Terms 

Table A.2.1 provides a complete listing of the materials and their locations of usage in GALL 

Vol. 2. Table A.2.2 provides more information about how different materials are used in the 

context of nuclear power plant license renewal. 

The Roman numeral in the second column identifies the chapter in GALL Vol. 2 that the 

specified materials are associated with (i.e., “II” for Containment Structures, “III” for Structures 

and Component Supports, “IV” for Reactor Vessel, Internals, and Reactor Coolant Systems, “V” 

for Engineered Safety Features Systems, “VI” for Electrical Systems, “VII” for Auxiliary Systems, 

and “VIII” for Steam and Power Conversion Systems). The number of times the term is used in 

that given chapter is shown in the third column.
NUREG-1833 A-20 October 2005

A.2.1 Materials: Listing, Location, and Frequency of AMR Terms

Material Referring 

Chapters Total

Aluminum III 1

V 3

VII 7

VIII 2

Aluminum, copper, bronze, stainless steel, galvanized steel VI 1

Aluminum, steel VI 1

Aluminum/ Silver Plated Aluminum Copper/ Silver Plated Copper; 

Stainless steel, steel

VI 1

Boraflex VII 2

Boral, 

 boron steel

VII 2

Cast austenitic stainless steel IV 13

V 2

Chrome plated steel; stainless steel; Nickel alloy IV 2

Concrete II 24

Concrete block III 1

Concrete; porous concrete II 1

Concrete; steel II 4

Copper alloy IV 1

V 7

VI 1

VII 16

VIII 10

Copper alloy <15% Zn V 1

VII 1

Copper alloy >15% Zn IV 1

V 3

VII 6

VIII 3

Elastomers V 1

VI 1

VII 9

Elastomers 

 such as EPDM rubber

III 1
October 2005 A-21 NUREG-1833

A.2.1 Materials: Listing, Location, and Frequency of AMR Terms

Material Referring 

Chapters Total

Elastomers, rubber and other similar materials II 1

Galvanized steel III 1

V 1

VII 1

Galvanized steel, aluminum III 1

Galvanized steel, aluminum, stainless steel III 1

Glass V 5

VII 7

VIII 5

Gray cast iron V 3

VII 4

VIII 3

High-strength low alloy steel 

 Maximum tensile strength < 1172 MPa (<170 ksi)

IV 3

High-strength low-alloy steel, stainless steel IV 1

High-strength steel V 1

VII 2

VIII 1

Insulation material – bakelite, phenolic melamine or ceramic, molded 

polycarbonate and other

VI 2

Low alloy steel IV 1

Low alloy steel, yield strength >150 ksi III 2

Low-alloy steel SA 193 Gr. B7 IV 1

Low-alloy steel, stainless steel IV 1

Lubrite® III 3

Nickel alloy IV 21

V 1

VII 2

VIII 1

Nickel alloy or nickel alloy cladding IV 1

Nickel alloy; stainless steel IV 2

Nickel alloy; steel with nickel-alloy cladding IV 2

Nickel-based alloys VIII 1

Non-metallic 

 (e.g., Rubber)

III 1
NUREG-1833 A-22 October 2005

A.2.1 Materials: Listing, Location, and Frequency of AMR Terms

Material Referring 

Chapters Total

Porcelain, 

 Malleable iron, aluminum, galvanized steel, cement

VI 2

Porcelain, 

 xenoy, thermo-plastic organic polymers

VI 1

Reinforced concrete III 15

VII 4

Reinforced concrete; 

 Grout

III 1

Reinforced concrete; 

 Porous concrete

III 1

SA508-Cl 2 forgings clad with stainless steel using a high-heat-input 

welding process

IV 1

Stainless steel II 2

III 5

IV 81

V 26

VII 35

VIII 25

Stainless steel with or without chrome plating IV 1

Stainless steel; dissimilar metal welds II 1

Stainless steel; nickel alloy IV 49

Stainless steel; nickel alloy welds and/or buttering IV 1

Stainless steel; steel II 5

III 1

IV 6

VII 1

Stainless steel; steel with nickel-alloy or stainless steel cladding; nickelalloyIV 2

Stainless steel; steel with stainless steel cladding IV 6

VII 5

Steel II 8

III 5

IV 23

V 34

VII 43

VIII 35
October 2005 A-23 NUREG-1833

A.2.1 Materials: Listing, Location, and Frequency of AMR Terms

Material Referring 

Chapters Total

Steel (with or without coating or wrapping) V 1

VII 1

VIII 1

Steel (with or without lining/coating or with degraded lining/coating) VII 1

Steel (with or without stainless steel cladding) IV 4

Steel and non-steel materials (e.g., Lubrite® plates, vibration isolators, 

etc.)

III 1

Steel with elastomer lining VII 1

Steel with elastomer lining or stainless steel cladding VII 1

Steel with stainless steel cladding IV 5

V 2

VII 1

Steel with stainless steel or nickel alloy cladding IV 1

Steel with stainless steel or nickel alloy cladding; or stainless steel IV 2

Steel with stainless steel or nickel alloy cladding; stainless steel; nickel 

alloy

IV 2

Steel, Stainless steel VIII 1

Steel; copper alloys III 1

Steel; dissimilar metal welds II 1

Steel; galvanized steel VI 1

Steel; stainless steel; dissimilar metal welds II 4

Steel; stainless steel; steel with nickel-alloy or stainless steel cladding; 

nickel-alloy

IV 6

Various III 1

Various metals used for electrical contacts VI 2

Various organic polymers (e.g., EPR, SR, EPDM, XLPE) VI 3

Various polymeric and metallic materials VI 1

Grand Total 682
NUREG-1833 A-24 October 2005

A.2.2 Selected Descriptions of Materials

Table A.2.2 correlates what was referenced in GALL Rev. 0 to what is used in GALL Rev. 1

including reference to the nomenclature in the unified numbering system (UNS), when 

applicable.

References to materials have been simplified and streamlined. Where possible, different types 

of high-strength steel, for example, have been grouped together. The focus has been on 

grouping together categories where the dominant aging mechanisms will be similar. On this 

basis, copper alloys are separated between those containing under and more than 15% Zn.

A.2.2 Selected Descriptions of Materials

Standardized Expression Description and Technical Justification

Boraflex Boraflex is a material that is composed of 46% silica, 4% polydimethyl 

siloxane polymer and 50% boron carbide, by weight. It is a neutron 

absorbing material used as a neutron absorber in spent fuel storage racks; 

degradation of Boraflex panels under gamma radiation can lead to loss of 

the ability to absorb neutrons in spent fuel storage pools. The GALL AMP 

XI.M22 is used as a reference for Boraflex monitoring.

Boral, boron steel Boron steel is steel with boron content ranging from one to several percent. 

Boron steel absorbs neutrons and thus is often used as a control rod to 

help control the neutron flux. Boral is material consisting of boron carbide 

sandwiched between aluminum. Boral refers to patented Aluminum-Boron 

master alloys; these alloys can contain up to 10% boron as AlB12 

intermetallics.

Cast austenitic stainless 

steel (CASS)

CASS alloys, such as CF-3, CF-8, CF-3M, and CF-8M, have been widely 

used in LWRs. These CASS alloys are similar to wrought grades Type 

304L, Type 304, Type 316L, and Type 316, except CASS typically contains 

5 to 25% ferrite. CASS is susceptible to loss of fracture toughness due to 

thermal and neutron irradiation embrittlement.

Copper alloy <15% Zn The broad purpose of this material category is to collect those copper 

alloys whose critical alloying elements are less than certain thresholds that 

keep the alloy from being susceptible to aging effects. For example, 

copper, copper nickel, brass, bronze <15% zinc, and aluminum bronze 

<8% aluminum are resistant to stress corrosion cracking, selective leaching 

and pitting and crevice corrosion. They may be identified simply as copper 

alloy when these aging mechanisms are not at issue. 

Copper alloy >15% Zn The broad purpose of this material category is to collect those copper 

alloys whose critical alloying elements are above certain thresholds that 

make the alloy susceptible to aging effects. Copper-zinc alloys >15% zinc 

are susceptible to stress corrosion cracking, selective leaching (except for 

inhibited brass), and pitting and crevice corrosion. Additional copper alloys 

may be susceptible, such as aluminum bronze > 8% aluminum. The 

elements that are most commonly alloyed with copper are zinc (referred to 

as brass), tin (referred to as bronze), nickel, silicon, aluminum (referred to 

as aluminum-bronze), cadmium and beryllium. Additional copper alloys 

may be susceptible to these aging effects above the threshold for the 

critical alloying element.
October 2005 A-25 NUREG-1833

A.2.2 Selected Descriptions of Materials

Standardized Expression Description and Technical Justification

Elastomers Elastomers are materials such as rubber, EPT, EPDM, PTFE, ETFE, viton, 

vitril, neoprene, and silicone elastomer. Hardening and loss of strength of 

elastomers can be induced by elevated temperature (over about 95°F 

(35°C), and additional aging factors such as exposure to ozone, oxidation, 

and radiation. 

Galvanized steel Steel coated with zinc (usually by immersion or electrodeposition); the Zn 

coating is capable of protecting the steel from atmospheric corrosion even 

when the surface is scratched, since the Zn is preferentially attacked by 

carbonic acid, forming a protective coat of basic zinc carbonate. The zinc 

coating in galvanized steel protects the underlying steel and the corrosion 

rate of zinc (coating the steel) in dry clean air is very low.

Glass Any glass materials within the scope of license renewal. Glass is a hard, 

amorphous, brittle super-cooled liquid made by fusing together one or more 

of the oxides of silicon, boron, or phosphorous, with certain basic oxides 

(e.g., Na, Mg, Ca, K), and cooling the product rapidly to prevent 

crystallization or devitrification.

Gray cast iron This form of cast iron is an iron alloy used in nuclear plants. Cast iron is 

made by adding larger amounts of carbon to molten iron than would be 

used to make steel. Most steels will have less than about 1.2% by weight 

carbon, while cast irons typically have between 2.5 to 4% by weight carbon. 

Gray cast iron has flat graphite flakes, which reduce its strength and act as 

crack formers, initiating mechanical failures. They also cause the metal to 

behave in a nearly brittle fashion, rather than experiencing the elastic, 

ductile behavior of steel. Fractures in this type of metal tend to take place 

along the flakes, which give the fracture surface a gray color, hence the 

name of the metal. 

Cast iron is susceptible to selective leaching resulting in a significant 

reduction of the material’s strength due to the loss of iron from the 

microstructure, leaving a porous matrix of graphite.

Insulation materials (e.g. 

bakelite, phenolic 

melamine or ceramic, 

molded polycarbonate)

Electrical fuse holders are composed of insulation materials, e.g. bakelite, 

phenolic melamine or ceramic, and molded polycarbonate.

Low-alloy steel, yield 

strength >150 ksi

High-strength Fe-Cr-Ni-Mo low alloy steel bolting materials with maximum 

tensile strength <1172 MPa (<170 ksi) may be subject to stress corrosion 

cracking if the actual measured yield strength Sy= 150 ksi. Examples of 

high strength alloy steel designations that were earlier referenced in GALL 

Rev. 0 that comprise this category include SA540-Gr. B23/24, SA193-Gr. 

B8, and Grade L43 (AISI4340).

Low-alloy steel SA 193 Gr. B7 is a ferritic low-alloy steel bolting material for 

high-temperature service. 

Low-alloy steel includes AISI steels 4140, 4142, 4145, 4140H, 4142H, and 

4145H (UNS#: G41400, G41420, G41450, H41400, H41420, H41450). 

Bolting fabricated from high-strength (actual measured yield strength Sy= 

150 ksi) low-alloy steel SA 193 Gr. B7 is susceptible to stress corrosion 

cracking.
NUREG-1833 A-26 October 2005

A.2.2 Selected Descriptions of Materials

Standardized Expression Description and Technical Justification

Lubrite® Lubrite® refers to a patented technology in which the bearing substrate 

(bronze is commonly used, but, in unusual environments, other materials, 

ranging from stainless steel and nodular-iron to tool-steel, are used) is 

fastened to lubricant. Lubrite® is often defined as bronze attached to ASTM 

B22, alloy 905, with G10 lubricant.

Even though Lubrite® bearings are characterized as maintenance-free, 

because of the differences in installation, fineness of the surfaces, and 

lubricant characteristics, they can be subjected to mechanical wear and 

fretting.

Malleable iron Malleable iron usually means malleable cast iron, characterized by 

exhibiting some elongation and reduction in area in a tensile test. Malleable 

iron is one of the materials in the suite of “Porcelain, Malleable iron, 

aluminum, galvanized steel, cement” used to define the high voltage 

insulators subject to degradation of insulator quality/presence of any salt 

deposits or surface contamination (AMR line-item LP-07) or loss of 

material/mechanical wear due to wind blowing on transmission conductors 

(AMR line-item LP-11).

Nickel alloys Nickel alloys are used for a wide variety of applications, the majority of 

which involve corrosion resistance and/or heat resistance. Nickel and nickel 

alloys, like the stainless steels, offer a wide range of corrosion resistance. 

However, nickel can accommodate larger amounts of alloying elements, 

chiefly chromium, molybdenum, and tungsten, in solid solution than iron. 

Therefore, nickel-base alloys, in general, can be used in more severe 

environments than the stainless steels. 

Nickel-chromium-iron (molybdenum) alloys are those such as the Alloy 600 

and 690.

Examples of nickel alloy designations that were specifically referenced in 

GALL Rev. 0 that comprise this category include Alloy 182, Alloy 600, Alloy 

690, Gr. 688 (X-750), Inconel 182, Inconel 82, NiCrFe, SB-166, SB-167, 

SB-168, X-750.

PH stainless steel Precipitation hardened (PH) martensitic stainless steel. Combines excellent 

corrosion resistance, high strength and hardness, low temperature 

hardening and good fabricating characteristics, superior transverse ductility 

and toughness.

Examples of steel designations that were specifically referenced in GALL 

Rev.0 that comprise this category include Type 15-5PH.

Polymer (e.g., rubber) Vibration isolation elements in supports for the emergency diesel generator 

are fabricated from polymeric materials such as rubber and can be 

degraded by aging mechanisms such as radiation hardening, temperature, 

humidity, sustained vibratory loading. Polymers used in electrical 

applications include EPR, SR, EPDM, and XLPE. XLPE is cross linked 

polyethylene (XLPE) in the category of thermoplastic resins as 

polyethylene and polyethylene copolymers. EPR and EPDM are ethylenepropylene rubbers (EPR, EPDM) in the category of thermosetting

elastomers.
October 2005 A-27 NUREG-1833

A.2.2 Selected Descriptions of Materials

Standardized Expression Description and Technical Justification

Polymers used in electrical 

applications 

Polymers used in electrical applications include EPR, SR, EPDM, XLPE. 

XLPE is cross-linked polyethylene in the category of thermoplastic resins 

as polyethylene and polyethylene copolymers. EPR and EPDM are 

ethylene-propylene rubbers in the category of thermosetting elastomers. 

Porcelain Hard-quality porcelain is used as an insulator for supporting high-voltage 

electrical insulators. Porcelain is a hard, fine-grained ceramic that 

essentially consists of kaolin, quartz, and feldspar that is fired at high 

temperatures. Porcelain is one of the materials in the category of 

“Porcelain, Malleable iron, aluminum, galvanized steel, cement” used to 

define the high voltage insulators subject to degradation of insulator 

quality/presence of any salt deposits or surface contamination (AMR lineitem LP-07) or loss of material/mechanical wear due to wind blowing on 

transmission conductors (AMR line-item LP-11).

SA508-Cl 2 forgings clad 

with stainless steel using a 

high-heat-input welding 

process

Quenched and tempered vacuum treated carbon and alloy steel forgings 

for pressure vessels. Growth of intergranular separations (underclad 

cracks) in low-alloy steel forging heat affected zone under austenitic 

stainless steel cladding is a time-limited aging analysis (TLAA) to be 

evaluated for the period of extended operation for all the SA 508-Cl 2 

forgings where the cladding was deposited with a high heat input welding 

process. 

Stainless steel Wrought or forged austenitic, ferritic, martensitic, precipitation hardened 

(PH) martensitic, or duplex stainless steel (Cr content >11%) are grouped 

for AMRs under the term “stainless steel.” These materials are susceptible 

to a variety of aging effects and mechanisms, including loss of material due 

to pitting and crevice corrosion, and cracking due to stress corrosion 

cracking. In the context of license renewal, in some cases, when the 

recommended AMP is the same for PH stainless steel or cast austenitic 

stainless steel (CASS) as for stainless steel, PH stainless steel or CASS is 

included as a part of the stainless steel classification. However, CASS is 

susceptible to loss of fracture toughness due to thermal and neutron 

irradiation embrittlement. Therefore, when this aging effect is being 

considered, CASS is specifically designated in the AMR line-item. 

Steel with stainless steel cladding may also be considered stainless steel 

when the aging effect is associated with the stainless steel surface of the 

material, rather than the composite volume of the material.

Examples of stainless steel designations that were earlier referenced in 

GALL Rev. 0 that comprise this category include A-286, SA193-Gr. B8, 

SA193-Gr. B8M, Gr. 660 (A-286), SA193-6, SA193-Gr. B8 or B-8M, 

SA453, Type 304, Type 304NG, Type 308, Type 308L, Type 309, Type 

309L, Type 316, Type 347, Type 403, Type 15-5PH, and Type 416. 

Examples of CASS designations that were earlier referenced include CF-3, 

CF-8, CF-3M, and CF-8M. [ASME Section II: Part B]
NUREG-1833 A-28 October 2005

A.2.2 Selected Descriptions of Materials

Standardized Expression Description and Technical Justification

Steel For a given environment, carbon steel, alloy steel, cast iron, gray cast iron, 

malleable iron, and high strength low alloy steel are vulnerable to general, 

pitting, and crevice corrosion, even though the rates of aging may vary. 

Consequently, these metal types are generally grouped for AMRs under 

the broad term “steel.” Note that this does not include stainless steel. 

However, gray cast iron is also susceptible to selective leaching, and high 

strength low alloy steel is susceptible to stress corrosion cracking. 

Therefore, when these aging effects are being considered, these materials 

are specifically called out. Galvanized steel (zinc-coated carbon steel) is 

also included in this category of “steel” when exposed to moisture. 

Malleable iron is also specifically called out in the phrase “Porcelain, 

Malleable iron, aluminum, galvanized steel, cement” used to define the high 

voltage insulators in Chapter VI.

Examples of steel designations that were earlier referenced in GALL Rev. 0 

that comprise this category include ASTM A 36, ASTM A 285, ASTM A759, 

SA36, SA106-Gr. B, SA155-Gr. KCF70, SA193-Gr. B7, SA194 –Gr. 7, 

SA302-Gr B, SA320-Gr. L43 (AISI 4340), SA333-Gr. 6, SA336, SA508-64, 

class 2, SA508-Cl 2 or Cl 3, SA516-Gr. 70, SA533-Gr. B, SA540-Gr. 

B23/24, and SA582. [ASME Section II: Part A]
October 2005 A-29 NUREG-1833

A.2.3 Metals Background for the GALL Update

In Table A.2.3 the first column provides the term used in the GALL Report, Rev 0 followed by 

the equivalent designation according to the Unified Numbering System (UNS). The UNS 

provides a means of correlating many nationally used metal and alloy numbering systems 

currently administered by societies, trade associations, and those individual users and 

producers of metals and alloys. 

The second and third columns in the table below provide more information about the material 

and where it is referenced. The fourth column specifies the AMR line-item in GALL Rev. 0 that 

referenced the metal as found in column 1. The fifth column provides the term used in the GALL 

Rev. 1, Vol, 2 AMR line-items replacing the term in column 1. The last column below provides 

some explanation for the substitution, and is sometimes combined with the preceding column.

A.2.3 Metals Background for GALL Update

Metal 

Designation 

or Definition 

GALL Rev. 0

Metal 

Description

Designation/ 

Specification 

Ref.

GALL 

Rev.0 Ref, 

orig. use

Materials 

Consolidation 

Term in GALL 

Rev. 1

Explanation for 

Use of Revised 

Term

A7 ASTM Standard 

A7 

(“Specifications 

for Steel for 

Bridges and 

Buildings”) was 

withdrawn in 

1967 and 

replaced by 

ASTM 

A36/A36M. 

(see below).

ASM 

datasheet 

VII B1-a Steel- For a given environment, 

carbon steel, alloy steel, and cast 

iron exhibit the same aging effects, 

even though the rates of aging may 

vary. Consequently, these metal 

types may be considered the same 

for aging management reviews. 

Gray cast iron is also susceptible to 

selective leaching and high-strength 

low-alloy steel is also susceptible to 

stress corrosion cracking. 

Therefore, when these aging effects 

are being considered, these 

materials are specifically mentioned; 

otherwise they are considered part 

of the general category of steel, 

which does NOT include stainless 

steel. Galvanized steel – (zinc 

coated carbon steel) is also included 

in this category.

A36

UNS#: 

K02600

ASTM A36: 

Structural 

carbon steel. 

Covers carbon 

steel shapes, 

plates, and bars 

of structural 

quality for use 

in riveted, 

bolted, or 

welded 

construction

ASM 

datasheet 

VII B1 Steel As described for 

A7
NUREG-1833 A-30 October 2005

A.2.3 Metals Background for GALL Update

Metal 

Designation 

or Definition 

GALL Rev. 0

Metal 

Description

Designation/ 

Specification 

Ref.

GALL 

Rev.0 Ref, 

orig. use

Materials 

Consolidation 

Term in GALL 

Rev. 1

Explanation for 

Use of Revised 

Term

A285

UNS#: 

K02801

ASTM A285: 

Carburizing and 

general 

purpose steel 

(equivalent to 

SAE 1026)

ASM 

datasheet 

VII B1 Steel As described for 

A7

A-286

UNS#: 

S66286

Iron-nickel-base 

superalloy A286 has workhardening 

characteristics 

similar to those 

of type 304 

stainless steel 

and has slightly 

lower 

formability. 

Most other ironbase heatresistant alloys 

are somewhat 

less formable. 

Also referenced 

as austenitic 

wrought 

stainless steel. 

– Iron based 

high 

temperature, 

high strength 

alloy. A-286 

has 15% Cr, 

thus well above 

stainless steel 

threshold.

ASM 

datasheet 

(Note that 

Alloy A-286 is 

not to be 

confused with 

ASTM 

Standard 

A286 

(“Specification 

for HeatTreated AlloySteel Bars”), 

which was

withdrawn in 

1960. Alloy A286 is 

covered by 

ASTM 

Standards 

A453, Grade 

660 and 

A638, Grade 

660.) 

IVB4.4-d Stainless steel Wrought or forged 

austenitic, ferritic, 

martensitic, or 

duplex stainless 

steel (Cr content 

>11%) 

A759

UNS#: 

K07500

Nonresulfurized 

carbon steel, 

(ASTM A759)

ASM 

datasheet 

(added from 

Suppl. 

Database of 

GALL Rev. 

0)

Steel As described for 

A7
October 2005 A-31 NUREG-1833

A.2.3 Metals Background for GALL Update

Metal 

Designation 

or Definition 

GALL Rev. 0

Metal 

Description

Designation/ 

Specification 

Ref.

GALL 

Rev.0 Ref, 

orig. use

Materials 

Consolidation 

Term in GALL 

Rev. 1

Explanation for 

Use of Revised 

Term

Alloy 182

UNS#: 

W86182

Ni-base weld 

filler metal 

electrode used 

for gastungsten-arc, 

gas-metal-arc 

and 

submerged-arc 

welding of Nibase alloys. 

Inconel Alloy 82 

is the wire form 

of this same 

alloy. This alloy 

is also identified 

as AWS A5.14, 

ERNiCr-3 and 

ASME SFA5.14, ERNiCr-3

ASM 

datasheet 

Replace the 

term Inconel 

wherever it 

shows up in 

GALL with 

Alloy.

IVB1.1 - Nickel alloys are used for a wide 

variety of applications, the majority 

of which involve corrosion 

resistance and/or heat resistance. 

Nickel and nickel alloys, like the 

stainless steels, offer a wide range 

of corrosion resistance. However, 

nickel can accommodate larger 

amounts of alloying elements, 

chiefly chromium, molybdenum, and 

tungsten, in solid solution than iron. 

Therefore, nickel-base alloys, in 

general, can be used in more 

severe environments than the 

stainless steels. Nickel-chromiumiron (-molybdenum) alloys are those 

such as the Alloy 600 and 690.

Alloy 600

UNS#: 

N0660

(first A-182 

from list)

Inconel Alloy 

600: Corrosion 

and heatresistant alloy 

nickel-base 

superalloy 

ASM 

datasheet 

- replace the 

term Inconel 

wherever it 

shows up in 

GALL with 

Alloy.

IVA2.2 Nickel alloy As described for 

Alloy 182

Alloy 690

UNS#: 

N06690

Inconel Alloy 

690: Corrosionresistant high 

chromium 

nickel alloy, 

nickel with 

chromium 

and/or iron, 

molybdenum

ASM 

datasheet -

replace the 

term Inconel 

wherever it 

shows up in 

GALL with 

Alloy.

IVD1.2 Nickel alloy As described for 

Alloy 182

CF-3M

UNS#: 

J92800

Cast austenitic 

stainless steel 

(CASS), ASTM 

A 743 or A 744, 

Cr-Ni-Mo steel 

corresponding 

to wrought 

Type 316L SS

ASM 

datasheet 

IVB4.3 CASS Cast stainless 

steels containing 

ferrite in an 

austenitic matrix
NUREG-1833 A-32 October 2005

A.2.3 Metals Background for GALL Update

Metal 

Designation 

or Definition 

GALL Rev. 0

Metal 

Description

Designation/ 

Specification 

Ref.

GALL 

Rev.0 Ref, 

orig. use

Materials 

Consolidation 

Term in GALL 

Rev. 1

Explanation for 

Use of Revised 

Term

CF-8 and CF8M

UNS#: 

J92600 and 

J92900

Cast Austenitic 

Stainless Steel 

(CASS), ASTM 

A 743 or A 744. 

CF-8 is a Cr-Ni 

steel 

corresponding 

to wrought 

Type 304 SS 

and CF-8M is a 

Cr-Ni-Mo steel 

corresponding 

to wrought 

Type 316 SS.

ASM 

datasheet 

IVC2.3 CASS Cast stainless 

steels containing 

ferrite in an 

austenitic matrix

Gr. B8

UNS#: 

S30400

SA-193, Gr. B8 

austenitic steel, 

bolting material, 

comparable to 

AISI Type 304 

SS

Datasheet on 

ASTM, SAE, 

and ISO 

Grade for 

Steel 

Fasteners 

IVB4.1 Stainless steel Wrought or forged 

austenitic, ferritic, 

martensitic, or 

duplex stainless 

steel (Cr content 

>11%)

Gr. B8M

UNS#: 

S31600

SA-193, Gr. 

B8M austenitic 

steel, 

comparable to 

AISI Type 316 

SS

Datasheet on 

ASTM, SAE, 

and ISO 

Grade for 

Steel 

Fasteners 

IVB4.4 Stainless steel Wrought or forged 

austenitic, ferritic, 

martensitic, or 

duplex stainless 

steel (Cr content 

>11%)

Gr. 660 (A286)

UNS#: 

S66286

(See A-286) ASM 

datasheet 

IVB4.4 Stainless 

steel.

Wrought or forged 

austenitic, ferritic, 

martensitic, or 

duplex stainless 

steel (Cr content 

>11%)
October 2005 A-33 NUREG-1833

A.2.3 Metals Background for GALL Update

Metal 

Designation 

or Definition 

GALL Rev. 0

Metal 

Description

Designation/ 

Specification 

Ref.

GALL 

Rev.0 Ref, 

orig. use

Materials 

Consolidation 

Term in GALL 

Rev. 1

Explanation for 

Use of Revised 

Term

Gr. 688 

(Inconel Alloy 

X-750)

UNS#: 

N07750

Age-Hardening 

Nickel Alloy, 

Nickel with 

chromium 

and/or iron, 

molybdenum 

with good 

strength to 

649°C 

(1200°F). The 

alloy shows 

good oxidation 

resistance. 

(ASME SB-637, 

Inconel X-750; 

Grade 688 is 

old term)

ASM 

datasheet 

IVB4.4 Nickel alloy As described for 

Alloy 182

Inconel 182

UNS#: 

W86182

See Alloy 182 

above

Specialty 

Metals 

Manufacturing 

datasheet 

IVA1.1 -

replace the 

term Inconel 

wherever it 

shows up in 

GALL with 

Alloy.

Nickel alloy As described for 

Alloy 182

Inconel 82

UNS#: 

W86182

See Alloy 182 

above.

Specialty 

Metals 

Manufacturing 

datasheet 

IVA1.4 –

replace the 

term Inconel 

wherever it 

shows up in 

GALL with 

Alloy.

Nickel alloy As described for 

Alloy 182

NiCrFe Nickel alloy (for 

buttering, 

welds) –

generic term

ASM 

datasheet on 

Nickel alloys 

IV.A2.4 Nickel alloy As described for 

Alloy 182

SA-36

UNS#: 

K02600

(See A36 

above)

ASME BPVC 

Section IIA

IVA2.8 Steel As described for 

A7
NUREG-1833 A-34 October 2005

A.2.3 Metals Background for GALL Update

Metal 

Designation 

or Definition 

GALL Rev. 0

Metal 

Description

Designation/ 

Specification 

Ref.

GALL 

Rev.0 Ref, 

orig. use

Materials 

Consolidation 

Term in GALL 

Rev. 1

Explanation for 

Use of Revised 

Term

SA-106, Gr. 

B

UNS#: 

K03006

ASME SA106 

Seamless 

carbon steel 

pipe for hightemperature 

service, in NPS 

1/8 to NPS 48 

inclusive, with 

nominal 

(average) wall 

thickness as 

given is ANSI 

B36.10; Grade 

B has 0.30% C 

max.

E-Pipe 

manufacturer 

datasheet 

IVC1.1 Steel As described for 

A7

SA155-Gr 

KCF70

UNS#: 

unknown

Grade CF 70 

was 

apparently 

intended 

standard for 

GALL Rev. 0.

SA-155 is not 

listed in recent 

editions of the 

ASME Code 

Section II, and 

ASTM A 155 

(“Specification 

of electricfusion welded 

steel pipe for 

high-pressure 

service”) was 

withdrawn in 

1978 and 

replaced by 

ASTM A671 

(“Standard 

Specification for 

Electric-FusionWelded Steel 

Pipe for 

Atmospheric 

and Lower 

Temperatures”). 

Among the pipe 

grades listed in 

ASTM A671 is 

Grade CF 70. 

This is 

apparently the 

standard 

intended here.

Database 

from 

Independent 

Pipe and 

Supply Corp

IVC1.1 Steel As described for 

A7
October 2005 A-35 NUREG-1833

A.2.3 Metals Background for GALL Update

Metal 

Designation 

or Definition 

GALL Rev. 0

Metal 

Description

Designation/ 

Specification 

Ref.

GALL 

Rev.0 Ref, 

orig. use

Materials 

Consolidation 

Term in GALL 

Rev. 1

Explanation for 

Use of Revised 

Term

SA-182, 

F316 

UNS#: 

S31600

Type 316 

austenitic 

stainless steel 

pipe. 

Specification 

covers forged 

or rolled alloysteel pipe

flanges, forged 

fittings and 

valves and 

parts intended 

for hightemperature 

service

ASME 

Section II, 

CASTI 

Guidebook to 

ASME Sec II 

IVC2.4 Steel As described for 

A7

SA-193, Gr. 

B6

UNS#: 

S41000

AISI Type 410 

SS bolting 

material for 

hightemperature 

service.

ASME BPVC 

Section IIA

IVA2.1 Stainless Steel Wrought or forged 

austenitic, ferritic, 

martensitic, or 

duplex stainless 

steel (Cr content 

>11%)

SA-193, Gr. 

B7

UNS#: 

G41400, 

G41420, 

G41450, 

H41400, 

H41420, 

H41450

Ferritic lowalloy steel 

bolting material 

for hightemperature 

service. 

Includes AISI 

steels 4140, 

4142, 4145, 

4140H, 4142H, 

and 4145H.

ASME BPVC 

Section IIA

IVA1.1 Steel As described for 

A7

SA-193, Gr. 

B8 or B-8M

UNS#: 

30400 and 

31600

Austenitic 

Stainless Steel. 

Grade B8 is 

Type 304 SS 

and Grade B8M

is Type 316 SS.

ASME BPVC 

Section IIA

IVB4.1 Stainless steel Wrought or forged 

austenitic, ferritic, 

martensitic, or 

duplex stainless 

steel (Cr content 

>11%)
NUREG-1833 A-36 October 2005

A.2.3 Metals Background for GALL Update

Metal 

Designation 

or Definition 

GALL Rev. 0

Metal 

Description

Designation/ 

Specification 

Ref.

GALL 

Rev.0 Ref, 

orig. use

Materials 

Consolidation 

Term in GALL 

Rev. 1

Explanation for 

Use of Revised 

Term

SA-194, Gr. 7

UNS#: 

G41400, 

G41420, 

G41450, 

H41400, 

H41420, 

H41450

SA-194 is 

specification for

carbon and 

alloy steel nuts 

for bolts for 

high-pressure 

and hightemperature 

service; it also 

covers 

austenitic and 

martensitic 

stainless steel 

nuts. Thus it is 

imperative to 

specify the 

grade. Grade 7 

is equivalent to 

AISI 4140, 

4142, 4145, 

4140H, 4152H,

and 4145H 

high-strength 

low-alloy steels.

ASME BPVC 

Section IIA

IVA1.1 Steel As described for 

A7

SA-302, 

Gr. B

UNS#: 

K12022

Mn-Mo Alloy 

(Grade B) steel 

plates intended 

particularly for 

welded boilers 

and other 

pressure 

vessels (like 

early 533)

ASME BPVC 

Section IIA

IVA1.1 Steel As described for 

A7
October 2005 A-37 NUREG-1833

A.2.3 Metals Background for GALL Update

Metal 

Designation 

or Definition 

GALL Rev. 0

Metal 

Description

Designation/ 

Specification 

Ref.

GALL 

Rev.0 Ref, 

orig. use

Materials 

Consolidation 

Term in GALL 

Rev. 1

Explanation for 

Use of Revised 

Term

SA-320, Gr. 

L43 (AISI 

4340)

UNS#: 

G43400

Alloy steel 

bolting 

materials for 

lowtemperature 

service. Grade 

L43 (AISI 4340) 

is a highstrength lowalloy steel, FeNi-Cr-Mo alloy 

ferritic steel –

note that the B8 

grades are 

austenitic so 

that the grade 

must be 

specified.

ASME BPVC 

Section IIA

IVA1.1 Steel As described for 

A7

SA-333, Gr 6

UNS#: 

K03006

Nominal 

(average) wall 

seamless and 

welded carbon 

and alloy steel 

pipe intended 

for use at low 

temperatures. 

Several grades 

of ferritic steel 

are included, 

the Grade 6 

means that the 

tensile test 

results indicate 

min. yield pt 

and tensile 

strength of 240 

and 415MPa

(34.8 and 60.2 

ksi), 

respectively.

ASME BPVC 

Section IIA 

IVC1.1 Steel As described for 

A7
NUREG-1833 A-38 October 2005

A.2.3 Metals Background for GALL Update

Metal 

Designation 

or Definition 

GALL Rev. 0

Metal 

Description

Designation/ 

Specification 

Ref.

GALL 

Rev.0 Ref, 

orig. use

Materials 

Consolidation 

Term in GALL 

Rev. 1

Explanation for 

Use of Revised 

Term

SA-336

UNS#: 

(depends on 

class)

SA-336, 

Class F1 was 

apparently 

the intended 

GALL Rev. 0

designation

Alloy steel 

forgings for 

pressure and 

hightemperature 

parts, covers 

both Ferritic 

and austenitic 

steel forgings –

imperative to 

specify the 

class. Class F1 

is a carbon 

steel containing 

0.20-0.30wt%C. 

Thirteen other 

alloy steel 

classes exist for 

SA336.

HCWSS 332; 

ASME BPVC 

Section IIA

IVA1.1 –

nowhere 

was the SA336 grade 

specified in 

GALL, but 

throughout 

RCS 

systems in 

GALL, SA336 was 

referred to 

as carbon 

steel.

Steel As described for 

A7

SA-453

UNS#: 

(depends on 

grade)

Four grades of 

bolting material 

for use in hightemperature 

service such as 

fasteners for 

pressure 

vessels and 

valve flanges., 

Grade 651 is 

19Cr-9Ni-MoW, Since all 

four grades 

have >11% Cr, 

they classify as 

stainless steels.

ASME BPVC 

Section IIA

IVA2.2 Stainless steel Wrought or forged 

austenitic, ferritic, 

martensitic, or 

duplex stainless 

steel (Cr content 

>11%)

SA-508-64, 

Class 2

SA-508, 

Class 2 was 

the intended 

GALL Rev. 0

designation

UNS#: 

K12766

SA508, Class 2 

is a Cr-Mo lowalloy steel.

ASME BPVC 

Section IIA

IVA2.1-b Steel As described for 

A7
October 2005 A-39 NUREG-1833

A.2.3 Metals Background for GALL Update

Metal 

Designation 

or Definition 

GALL Rev. 0

Metal 

Description

Designation/ 

Specification 

Ref.

GALL 

Rev.0 Ref, 

orig. use

Materials 

Consolidation 

Term in GALL 

Rev. 1

Explanation for 

Use of Revised 

Term

SA-508, Cl 2 

and Cl 3 

UNS#: 

K12766

Quenched and 

tempered 

vacuum treated 

Carbon and 

alloy steel 

forgings for 

pressure 

vessels. 

Nomenclature 

changed in ’01; 

Class 2 is now 

called Grade 2 

class 1 and 

Class 3 is 

called Grade 3 

Class 1.

ASME BPVC 

Section IIA

IVA1.3 Steel As described for 

A7

SA-516, Gr70

UNS#: 

K02700

Carbon steel 

plates intended 

primarily for 

service in 

welded 

pressure 

vessels where 

improved notch 

toughness is 

important. Gr. 

70 has highest 

tensile strength 

of the four 

grades, 

ASME BPVC 

Section IIA

IVA2.8 Steel As described for 

A7

SA-533, Gr B

UNS#: 

12539

Mn-Mo-Ni Alloy 

steel plates for 

use in 

quenched and 

tempered 

condition for 

construction of 

welded 

pressure 

vessels

HCWSS 143; 

ASME BPVC 

Section IIA

IVA1.1 Steel As described for 

A7

SA-540, Gr. 

B23 and B24

UNS#: 

H43400

High-strength 

Cr-Ni-Mo lowalloy steel 

bolting 

materials

ASME BPVC 

Section IIA

IVA1.1 Steel As described for 

A7
NUREG-1833 A-40 October 2005

A.2.3 Metals Background for GALL Update

Metal 

Designation 

or Definition 

GALL Rev. 0

Metal 

Description

Designation/ 

Specification 

Ref.

GALL 

Rev.0 Ref, 

orig. use

Materials 

Consolidation 

Term in GALL 

Rev. 1

Explanation for 

Use of Revised 

Term

SA-540, Gr. 

B23

UNS#: 

H43400

High-strength 

Cr-Ni-Mo low 

alloy-steel 

bolting 

materials

ASME BPVC 

Section IIA

IV.C2.3 Steel As described for 

A7

SA-582 SA-582 is not 

listed in recent 

editions of the 

ASME Code 

Section II. 

ASTM 

Standards 

A582 and 

A582M are a 

current 

standard for 

free-machining 

stainless steel 

bars.

Apparently an 

inconsistency 

in GALL Rev. 

0.

IVC2.4 –a Steel As described for 

A7

SB-166

UNS#: 

N06600, 

N06690

Ni-Cr-Fe alloys 

and Ni-Cr-CoMo alloy in form 

of hot-finished 

and cold-work 

rod, bar, and 

wire. 

ASME BPVC 

Section IIB

IVA1.4 Nickel alloy As described for 

Alloy 182
October 2005 A-41 NUREG-1833

A.2.3 Metals Background for GALL Update

Metal 

Designation 

or Definition 

GALL Rev. 0

Metal 

Description

Designation/ 

Specification 

Ref.

GALL 

Rev.0 Ref, 

orig. use

Materials 

Consolidation 

Term in GALL 

Rev. 1

Explanation for 

Use of Revised 

Term

SB-167

UNS#: 

N06600,

N06690

nickelchromium-iron 

alloys (US 

N06600, UNS 

N06601, 

N06690, 

N06025, and 

N06045) in 

cold-worked 

annealed, hotworked 

annealed, hotfinished 

seamless pipe 

and tube 

intended for 

general 

corrosion 

resistant and 

heat resistant 

applications.

ASME BPVC 

Section IIB; 

E-Pipe 

manufacturer 

datasheet

IVA1.5 Nickel alloy As described for 

Alloy 182

SB-168

UNS#: 

N06600,

N06690

Nickel-Cr-Fe 

alloys and NiCr-Co-Mo alloy 

plate, sheet, 

and strip

ASME BPVC 

Section IIB

IVA2.6 Nickel alloy As described for 

Alloy 182

Type 15-5PH

UNS#: 

S15500

Precipitation 

hardened (PH) 

martensitic 

stainless steel, 

Combines 

excellent 

corrosion 

resistance, high 

strength and 

hardness, low 

temperature 

hardening and 

good fabricating 

characteristics. 

Superior 

transverse 

ductility and 

toughness

ASM 

datasheet

IVB4.4 PH stainless 

steel

Wrought or forged 

austenitic, ferritic, 

martensitic, or 

duplex stainless 

steel (Cr content 

>11%)
NUREG-1833 A-42 October 2005

A.2.3 Metals Background for GALL Update

Metal 

Designation 

or Definition 

GALL Rev. 0

Metal 

Description

Designation/ 

Specification 

Ref.

GALL 

Rev.0 Ref, 

orig. use

Materials 

Consolidation 

Term in GALL 

Rev. 1

Explanation for 

Use of Revised 

Term

Type 304

UNS#: 

S030400

Austenitic 

stainless steel 

(SS) – Low 

carbon 

chromium 

nickel SS, Low 

carbon variation 

of Type 302, 

minimizes 

carbide 

precipitation 

during welding.

ASM 

database

IV.A2.2 Stainless steel Wrought or forged 

austenitic, ferritic, 

martensitic, or 

duplex stainless 

steel (Cr content 

>11%)

Type 304 

forging

UNS#: 

S30400

Austenitic 

Stainless steel

IV.B4.1 Stainless steel Wrought or forged 

austenitic, ferritic, 

martensitic, or 

duplex stainless 

steel (Cr content 

>11%)
October 2005 A-43 NUREG-1833

A.2.3 Metals Background for GALL Update

Metal 

Designation 

or Definition 

GALL Rev. 0

Metal 

Description

Designation/ 

Specification 

Ref.

GALL 

Rev.0 Ref, 

orig. use

Materials 

Consolidation 

Term in GALL 

Rev. 1

Explanation for 

Use of Revised 

Term

Type 304NG

UNS#: 

S30451

(UNS for 

Type 304 N)

Austenitic 

Stainless steel. 

Instead of the 

nominal 0.03% 

C maximum of 

the L-grade 

stainless steels, 

the Nuclear 

Grades (NG) 

are 

characterized 

by a maximum 

carbon content 

of 0.020%. The 

second 

important 

composition 

characteristic of 

type 304NG is 

the 

specification of 

0.060 to 

0.100% N. This 

modification is 

designed to 

recover the 

decrease in 

alloy strength 

due to the 

reduction of the 

carbon content.

ASMI 

database

IVC1.1 Stainless steel Wrought or forged 

austenitic, ferritic, 

martensitic, or

duplex stainless 

steel (Cr content 

>11%)

Type 308

UNS#: 

S030800

Austenitic 

Stainless steel, 

AISI Type 308 

is an austenitic 

chromium 

nickel steel with 

corrosion and 

heat resistance 

superior to 

Type 304. The 

high Cr and Ni 

produce good 

heat/corrosion 

resistance. 

Used widely for 

welding rod.

ASMI 

database

IVA1.1 Stainless steel Wrought or forged 

austenitic, ferritic, 

martensitic, or 

duplex stainless 

steel (Cr content 

>11%) and the 

associated welding 

materials
NUREG-1833 A-44 October 2005

A.2.3 Metals Background for GALL Update

Metal 

Designation 

or Definition 

GALL Rev. 0

Metal 

Description

Designation/ 

Specification 

Ref.

GALL 

Rev.0 Ref, 

orig. use

Materials 

Consolidation 

Term in GALL 

Rev. 1

Explanation for 

Use of Revised 

Term

Type 308L

UNS#: 

S030883

Austenitic 

Stainless steel, 

This extra low 

carbon 

(reduced from 

0.08% max in 

308 to max of 

0.03% C) 

modification is 

highly resistant 

to sensitization 

and is therefore 

used widely 

where welded 

construction is 

required to 

fabricate 

vessels for 

service under 

highly corrosive 

conditions.

ASMI 

database

IVA1.2 Stainless steel Wrought or forged 

austenitic, ferritic, 

martensitic, or 

duplex stainless 

steel (Cr content 

>11%) and the 

associated welding 

materials

Type 309

UNS#: 

S30900

Austenitic SS –

AlSl Type 309 

is a chromiumnickel heat and 

corrosion 

resisting steel 

recommended 

for hightemperature 

applications in 

corrosive 

environments. It 

is intended 

primarily for 

high 

temperature 

applications at 

1500°F or 

higher where 

resistance to 

oxidation and/or 

corrosion is 

required.

ASMI 

database

IVA1.1 Stainless steel Wrought or forged 

austenitic, ferritic, 

martensitic, or 

duplex stainless 

steel (Cr content 

>11%) and the 

associated welding 

materials
October 2005 A-45 NUREG-1833

A.2.3 Metals Background for GALL Update

Metal 

Designation 

or Definition 

GALL Rev. 0

Metal 

Description

Designation/ 

Specification 

Ref.

GALL 

Rev.0 Ref, 

orig. use

Materials 

Consolidation 

Term in GALL 

Rev. 1

Explanation for 

Use of Revised 

Term

Type 309L

UNS#: 

S30983

Austenitic SS –

AlSl Type 309 

with Lowered 

carbon content 

(dropped from 

0.20% max in 

309 to nominal 

0.03%C 

maximum) 

ASMI 

database

IVA1.2 Stainless steel Wrought or forged 

austenitic, ferritic, 

martensitic, or 

duplex stainless 

steel (Cr content 

>11%) and the 

associated welding 

materials

Type 316

UNS#: 

S31600

Austenitic 

Stainless steel, 

AISI Type 316 

is a 

molybdenum 

type 18-12 

austenitic 

stainless steel 

having good 

resistance to 

acids. Mo 

improves 

general 

corrosion and 

pitting 

resistance and 

hightemperature 

strength.

ASMI 

database

IVA2.2 Stainless steel Wrought or forged 

austenitic, ferritic, 

martensitic, or 

duplex stainless 

steel (Cr content 

>11%) and the 

associated welding 

materials

Type 347

UNS#: 

S34700

Austenitic SS –

low-carbon 

niobiumstabilized type, 

Fe-18Cr-10NiNb Stabilized 

by the addition 

of niobium plus 

tantalum. This 

grade is nearly 

immune to 

intergranular 

precipitation of 

chromium 

carbide and its 

adverse effects 

on corrosion 

resistance. 

ASMI 

database

IVB2.4 Stainless steel Wrought or forged 

austenitic, ferritic, 

martensitic, or 

duplex stainless 

steel (Cr content 

>11%) and the 

associated welding 

materials
NUREG-1833 A-46 October 2005

A.2.3 Metals Background for GALL Update

Metal 

Designation 

or Definition 

GALL Rev. 0

Metal 

Description

Designation/ 

Specification 

Ref.

GALL 

Rev.0 Ref, 

orig. use

Materials 

Consolidation 

Term in GALL 

Rev. 1

Explanation for 

Use of Revised 

Term

Type 403

UNS#: 

S40300

Martensitic 

Stainless steel 

– AISI Type 

403 is a general 

purpose, heattreatable 

stainless steel 

of the straight 

Cr type. It is 

adaptable for 

general 

purpose 

corrosion and 

heat resisting 

applications.

ASMI 

database

IVA2.2 Stainless steel Wrought or forged 

austenitic, ferritic, 

martensitic, or 

duplex stainless 

steel (Cr content 

>11%)

Type 416

UNS#: 

S41600

Free-machining 

low-carbon 

chromium type 

stainless steel. 

(12-14% Cr)

ASMI 

database

IVC2.4 Stainless steel Wrought or forged 

austenitic, ferritic, 

martensitic, or 

duplex stainless 

steel (Cr content 

>11%)

X-750

UNS#: 

N07750

See Gr. 688 (X750) above.ASMI 

database

IVB1.4 Nickel alloy As described for 

A-182
October 2005 A-47 NUREG-1833

A.3 Environments

The environment column entry was restated such that the combined information of the 

component, material, and environment columns supported the conclusions of the AMR results. 

The environments were revised to identify the pertinent aspects of the environment that 

influence the aging effects applicable to the material. The restated environments identify the 

general chemical content (e.g., treated borated water) and if necessary, a temperature range 

that determines the applicability of aging effects. 

A.3.1 Listing, Location, and Frequency of Terms used in AMR Tables

The Roman numeral in the second column identifies the chapter in GALL Vol. 2 that the 

specified environments are associated with (i.e., “II” for Containment Structures, “III” for 

Structures and Component Supports, “IV” for Reactor Vessel, Internals, and Reactor Coolant 

Systems, “V” for Engineered Safety Features Systems, “VI” for Electrical Systems, “VII” for 

Auxiliary Systems, and “VIII” for Steam and Power Conversion Systems). The number of times 

the term is used in that given chapter is shown in the third column.

Table A.3.1 Environments: Listing, Location, and Frequency of AMR Terms

Environment Referring 

Chapters

Total # 

references

Adverse localized environment caused by exposure to moisture and 

voltage

VI 1

Adverse localized environment caused by heat, radiation, or moisture in 

the presence of oxygen

VI 2

Adverse localized environment caused by heat, radiation, or moisture in 

the presence of oxygen or > 60-year service limiting temperature

VI 1

Adverse localized environment caused by heat, radiation, oxygen, 

moisture, or voltage

VI 1

Air VII 1

VIII 1

Air – indoor VI 1

Air – indoor and outdoor VI 5

Air – indoor controlled (External) V 2

VII 2

VIII 1

Air – indoor uncontrolled II 7

III 7

IV 1

V 1

VII 6

Air – indoor uncontrolled 

or air outdoor

II 2

Air – indoor uncontrolled (External) III 2

IV 2

V 10
NUREG-1833 A-48 October 2005

Table A.3.1 Environments: Listing, Location, and Frequency of AMR Terms

Environment Referring 

Chapters

Total # 

references

VII 15

VIII 7

Air – indoor uncontrolled (Internal) V 4

VII 1

Air – indoor uncontrolled (Internal/ External) VII 1

Air – indoor uncontrolled (Internal/External) V 1

VI 1

Air – indoor uncontrolled or air – outdoor II 18

III 9

Air – indoor uncontrolled or air – outdoor; Water – flowing or water –

standing

III 1

Air – indoor uncontrolled or treated water (as applicable) II 4

Air – outdoor II 3

III 4

VI 4

VII 4

Air – outdoor (External) V 2

VII 5

VIII 3

Air – outdoor (Internal) VIII 1

Air with borated water leakage III 3

IV 2

V 6

VI 1

VII 6

VIII 2

Air with borated water leakage (Internal) V 1

Air with leaking secondary-side water and/or steam IV 1

Air with metal temperature up to 288°C (550°F) IV 1

Air with reactor coolant leakage IV 10

Air with reactor coolant leakage (Internal) 

or 

Reactor Coolant 

IV 2

Air with steam or water leakage V 2

VII 3

VIII 2
October 2005 A-49 NUREG-1833

Table A.3.1 Environments: Listing, Location, and Frequency of AMR Terms

Environment Referring 

Chapters

Total # 

references

Air-indoor uncontrolled or air-outdoor III 1

Any II 5

Any III 2

Closed cycle cooling water IV 3

V 11

VII 11

VIII 8

Closed cycle cooling water >60°C (>140°F) V 1

VII 2

VIII 1

Concrete IV 2

V 2

VII 2

VIII 2

Condensation VII 3

Condensation (External) V 2

VII 2

VIII 1

Condensation (Internal) V 3

VII 4

VIII 1

Diesel exhaust VII 2

Dried Air VII 3

Fuel oil VII 6

Gas IV 1

V 3

VII 4

VIII 4

Ground water/soil II 4

III 3

Lubricating oil III 1

V 7

VII 7

VIII 8

Moist air or condensation (Internal) VII 1

Raw water V 9

VII 22
NUREG-1833 A-50 October 2005

Table A.3.1 Environments: Listing, Location, and Frequency of AMR Terms

Environment Referring 

Chapters

Total # 

references

VIII 11

Reactor coolant IV 150

Reactor coolant >250°C (>482°F) IV 3

Reactor coolant >250°C (>482°F) and neutron flux IV 9

Reactor coolant and neutron flux IV 23

Reactor coolant and secondary feedwater/steam IV 1

Reactor coolant/ steam IV 2

Secondary feedwater IV 1

Secondary feedwater/ steam IV 18

Sodium pentaborate solution VII 1

Sodium pentaborate solution >60°C (>140°F) VII 1

Soil II 3

III 1

V 3

VII 3

VIII 3

Steam V 1

VIII 10

Steam or treated water VIII 1

System temperature up to 288°C (550°F) IV 4

System temperature up to 340°C (644°F) IV 2

Treated borated water IV 1

V 5

VII 9

Treated borated water >250°C (>482°F) V 1

Treated borated water >60°C (>140°F) IV 1

V 2

VII 5

Treated water V 10

VII 15

VIII 17

Treated Water < 60C (<140 F) III 1

Treated water >250°C (>482°F) V 1

Treated water >60°C (>140°F) V 1

VII 5

VIII 4
October 2005 A-51 NUREG-1833

Table A.3.1 Environments: Listing, Location, and Frequency of AMR Terms

Environment Referring 

Chapters

Total # 

references

Treated water or treated borated water III 1

Various III 1

Water – flowing II 5

III 3

Water – flowing 

Water – standing

III 1

Water – flowing under foundation III 1

Water – standing III 1

Grand Total 682
NUREG-1833 A-52 October 2005

A.3.2 Selected Descriptions of Environments

The following table defines many of the standardized environments utilized in the GALL AMR 

tables in Chapters II, III, IV, V, VI, VII, and VIII of NUREG-1801, Rev. 1. 

A.3.2 Selected Descriptions of Environments

Standardized 

Expression

Description and Technical Justification

Adverse localized 

environment caused 

by exposure to 

moisture and voltage

The conductor insulation used for electrical cables in instrumentation circuits 

can be subjected to an adverse localized environment caused by exposure to 

moisture and voltage.

Adverse localized 

environment caused 

by heat, radiation, or 

moisture in the 

presence of oxygen

The conductor insulation used for electrical cables in instrumentation circuits 

can be subjected to an adverse localized environment caused by heat, 

radiation, or moisture in the presence of oxygen.

Adverse localized 

environment caused 

by heat, radiation, or 

moisture in the 

presence of oxygen 

or > 60-year service 

limiting temperature

The conductor insulation used for electrical cables in instrumentation circuits 

can be subjected to an adverse localized environment caused by heat, 

radiation, or moisture in the presence of oxygen. The term “>60-year service 

limiting temperature” refers to that which exceeds the temperature below 

which the material has a 60-year or greater service lifetime. 

Adverse localized 

environment caused 

by heat, radiation, 

oxygen, moisture, or 

voltage

Electrical components subject to 10 CFR 50.49 EQ requirements can be 

subjected to an adverse localized environment caused by heat, radiation, 

oxygen, moisture, or voltage.

Aggressive 

environment

For steel in concrete. As described in NUREG-1557, this is defined as that 

occurring when concrete pH <11.5 or chlorides concentration >500 ppm). 

Examples of environment descriptors that were specifically referenced in 

GALL Rev. 0 that comprise this category include:

Inside or outside containment

Air – indoor Uniquely used for the new AMR line-item LP-01 in Chapter VI for electrical 

systems, air-indoor is synonymous with “Air – indoor uncontrolled 

(internal/external).” Indoor air on systems with temperatures higher than the 

dew point, i.e., condensation can occur but only rarely, equipment surfaces 

are normally dry. 

Air – indoor 

controlled

The environment to which the specified internal or external surface of the 

component or structure is exposed: indoor air in a humidity controlled (e.g., 

air conditioned) environment.
October 2005 A-53 NUREG-1833

A.3.2 Selected Descriptions of Environments

Standardized 

Expression

Description and Technical Justification

Air – indoor 

uncontrolled

Indoor air on systems with temperatures higher than the dew point –

Condensation can occur but only rarely – equipment surfaces are normally 

dry. 

Examples of environment descriptors that were specifically referenced in 

GALL Rev. 0 that comprise this category include:

Ambient temperature air

Ambient environment inside buildings

Inside or outside containment

Indoors: exposed to variable temperature and humidity inside the auxiliary 

building or fuel handling building

Air, moisture, and humidity < 100°C (212°F)

Air – indoor 

uncontrolled >35°C 

(>95°F) 

(Internal/External)

The environment to which the internal or external surface of the component or 

structure is exposed. This also applies to indoor air above thermal stress 

threshold for elastomers. If ambient is <95°F, then any resultant thermal 

aging of organic materials can be considered insignificant over the 60-yr 

period of interest [Gillen & Clough, 1981; Peckner & Bernstein, 1977]. 

Although 95°F is a recognized threshold, temperature is not the only factor for 

aging of elastomers. Elastomers are also subject to aging effects from other 

factors such as exposure to ozone, oxidation, and radiation.

Examples of environment descriptors that were specifically referenced in 

GALL Rev. 0 that comprise this category include:

Internal: occasional exposure to moist air; external: ambient plant air 

environment

Air – outdoor The outdoor environment consists of moist, possibly salt-laden atmospheric 

air, ambient temperatures and humidity, and exposure to weather, including 

precipitation and wind. The component is exposed to air and local weather 

conditions including salt spray where applicable. A component is considered 

susceptible to a wetted environment when it is submerged, has the potential 

to pool water, or is subject to external condensation.

Examples of environment descriptors that were specifically referenced in 

GALL Rev. 0 that comprise this category include:

Weather exposed

Outside containment
NUREG-1833 A-54 October 2005

A.3.2 Selected Descriptions of Environments

Standardized 

Expression

Description and Technical Justification

Air with borated 

water leakage

Air and untreated borated water leakage on indoor or outdoor systems with 

temperatures above or below the dew point. The water from leakage is 

considered to be untreated, due to the potential for water contamination at the 

surface. This is germane to PWRs.

Examples of environment descriptors that were specifically referenced in 

GALL Rev. 0 that comprise this category include:

Inside PWR containment

Air, leaking and dripping chemically treated borated water up to 340°C 

(644°F)

Air, leaking chemically treated borated water

Air with leaking 

secondary-side 

water and/or steam

Steel components in the pressure boundary and structural parts of the oncethrough steam generator may be exposed to an environment consisting of air 

with leaking secondary-side water and/or steam.

Air with metal 

temperature up to 

288°C (550°F)

Synonymous with system temperature up to 288°C (550°F). Used in GALL 

update to describe environment to which the steel and stainless steel 

pressurizer integral support in the PWR reactor coolant system are exposed.

Air with reactor 

coolant leakage

Air and reactor coolant or steam leakage on high temperature systems.

This is germane to BWRs

Examples of environment descriptors that were specifically referenced in 

GALL Rev. 0 that comprise this category include:

Air, leaking reactor coolant water and/or steam at 288°C (550°F)

Air with steam or 

water leakage

Air and untreated steam or water leakage on indoor or outdoor systems with 

temperatures above or below the dew point

Examples of environment descriptors that were specifically referenced in 

GALL Rev. 0 that comprise this category include:

Air, moisture, humidity, and leaking fluid

Air, dry Air that has been treated to reduce the dew point well below the system 

operating temperature

Air, moist Air with enough moisture to facilitate loss of material in steel caused by 

general, pitting, and crevice corrosion. Moist air in the absence of 

condensation is also potentially aggressive, e.g., under conditions where 

hygroscopic surface contaminants are present.

Any Could be any environment indoors or outdoors, aging effect not dependent on 

environment.

Examples of environment descriptors that were specifically referenced in 

GALL Rev. 0 that comprise this category include:

Inside or outside containment
October 2005 A-55 NUREG-1833

A.3.2 Selected Descriptions of Environments

Standardized 

Expression

Description and Technical Justification

Closed cycle cooling 

water

Treated water subject to the closed-cycle cooling water chemistry program. 

Closed cycle cooling water >60°C (>140°F) allows the possibility of stainless 

steel SCC. Examples of environment descriptors that comprise this category 

can include, but are not limited to

chemically treated borated water; and treated component cooling water

demineralized water on one side; closed-cycle cooling water (treated water) 

on the other side

chemically treated borated water on tube side and closed-cycle cooling water 

on shell side.

Concrete Components embedded in concrete

Condensation 

(Internal/External)

The environment to which the internal or external surface of the component or 

structure is exposed. Condensation on the surfaces of systems with 

temperatures below the dew point is considered raw water, due to potential 

for surface contamination. For the purposes of GALL Rev. 1, under certain 

circumstances, the GALL Rev. 0 terms “moist air” or “warm moist air” are 

enveloped by condensation to describe an environment where there is 

enough moisture for corrosion to occur.

Containment 

environment (inert) 

The drywell is made inert with hydrogen to render the primary containment 

atmosphere non-flammable by maintaining the oxygen content below 4% by 

volume during normal operation.

Diesel Exhaust Gases, fluids, particulates present in a diesel engine exhaust

Examples of environment descriptors that were specifically referenced in 

GALL Rev. 0 that comprise this category include:

Hot diesel engine exhaust gases containing moisture and particulates

Fuel oil Fuel oil used for combustion engines with possible water contamination

Gas Internal gas environments from dry air, inert or non-reactive gases. As used 

in GALL Rev. 1 AMR line-items, this generic term, standing on its own, is 

used only in “Common Miscellaneous Material/Environment” sections where 

aging effects are not expected to degrade the ability of the structure of 

component to perform its intended function for the extended period of 

operation. In such “none-none” AMR line-items, no AMPs are required. 

In the context of GALL Rev. 1, this term “gas” subsequently is not meant to 

envelope gases in the fire suppression system. The GALL AMP XI.M26 “Fire 

Protection” is used for the periodic inspection and test of the halon/carbon 

dioxide fire suppression system.

Groundwater/soil Groundwater is the water beneath the surface that can be collected with 

wells, tunnels, or drainage galleries, or that flows naturally to the earth’s 

surface via seeps or springs. Soil is a mixture of inorganic materials produced 

by the weathering of rocks and clays, and organic material produced by the 

decomposition of vegetation. Voids containing air and moisture occupy ~50% 

of the soil volume. Concrete subjected to a groundwater/soil environment can 

be vulnerable to Increase in porosity and permeability, cracking, loss of 

material (spalling, scaling)/ aggressive chemical attack.
NUREG-1833 A-56 October 2005

A.3.2 Selected Descriptions of Environments

Standardized 

Expression

Description and Technical Justification

Lubricating oil Lubricating oils within the scope of license renewal are low to medium 

viscosity hydrocarbons used for bearing, gear, and engine lubrication. This 

lubricating oil used for plant equipment has the possibility of water 

contamination. 

Examples of environment descriptors that were specifically referenced in 

GALL Rev. 0 that comprise this category include:

Lubricating oil (with contaminants and/or moisture)

Moist air In the emergency diesel generator system, the steel diesel engine starting air 

subsystem and the diesel engine combustion air intake subsystem can be 

exposed to moist air resulting in loss of material caused by general, pitting, 

and crevice corrosion. The description of condensation (internal/external) 

envelopes moist air.

Raw water Raw, untreated fresh, salt, or ground water. Floor drains and reactor buildings 

and auxiliary building sumps may be exposed to a variety of untreated water 

that is thus classified as raw water, for the determination of aging effects.

Raw water may contain contaminants, including oil and boric acid, depending 

on the location, as well as originally treated water that is not monitored by a 

chemistry program. 

Examples of environment descriptors that were specifically referenced in 

GALL Rev. 0 that comprise this category include:

Flowing water 

open-cycle cooling water (raw water)

Reactor coolant Water in the reactor coolant system and connected systems at or near full 

operating temperature – includes steam for BWRs. For aging effect of 

cumulative fatigue damage, no temperature threshold of concern. In context 

of PWR reactor vessel, reactor coolant was more appropriate description of 

environment. 

Examples of environment descriptors that were specifically referenced in 

GALL Rev. 0 that comprise this category include:

Chemically treated borated water or steam up to 340°C (644°F)

Up to 288°C (550°F), reactor coolant water

Reactor coolant 

>250°C (>482°F) 

and neutron flux

Water in the reactor coolant system and connected systems above thermal 

embrittlement threshold for CASS. Since CASS and the AMP XI.M13 are 

referenced, both environments are listed in single cell as well as the 

temperature threshold. Wherever there is thermal aging of CASS, 482°F 

applies. Wherever there is neutron irradiation, Neutron Flux applies. If 

components other than CASS are included, then the limitations do not apply 

for the other components.

Examples of environment descriptors that were specifically referenced in 

GALL Rev. 0 that comprise this category include:

Chemically treated borated water up to 340°C (644°F) fluence >1017 n/cm2 (E 

>1 MeV)
October 2005 A-57 NUREG-1833

A.3.2 Selected Descriptions of Environments

Standardized 

Expression

Description and Technical Justification

Reactor coolant 

>250°C (>482°F)

Treated water above thermal embrittlement threshold for CASS. Address 

environment specifications of concern for specific aging effect. Here thermal 

embrittlement of CASS is addressed.

Examples of environment descriptors that were specifically referenced in 

GALL Rev. 0 that comprise this category include:

25–288°C (77-550°F) demineralized water

Reactor coolant and 

high fluence 

(>1 x 10E21 n/cm2 

E >0.1 MeV)

The PWR reactor vessel internals (such as baffle/former assembly and 

associated baffle/former bolts) will be subjected to a reactor coolant 

environment and also a high fluence (>1 x 10E21 n/cm2 E >0.1 MeV). 

Subsequently, SCC and IASCC aging mechanisms can cause cracking.

Reactor coolant and 

neutron flux

Reactor core environment for ferritic materials that will result in a neutron 

fluence exceeding 1017 n/cm2 (E >1 MeV) at the end of the license renewal 

term. Since the material is steel and the aging effect/mechanism is loss of 

fracture toughness/ neutron irradiation embrittlement, the only environment of 

concern in this context is the neutron flux.

Examples of environment descriptors that were specifically referenced in 

GALL Rev. 0 that comprise this category include:

288°C (550°F) reactor coolant water 5x108– 5x109 n/cm2·s

Chemically treated borated water up to 340°C (644°F) neutron fluence 

greater than 1017 n/cm2 (E >1 MeV)

Reactor coolant and 

secondary 

feedwater/steam

For PWR systems, it is reasonable to combine these environments into one 

cell. Water in the reactor coolant system and connected systems at or near 

full operating temperature and the PWR feedwater or steam at or near full 

operating temperature subject to the secondary water chemistry program. 

Nickel-alloy tubes and sleeves are subject to cumulative fatigue damage and 

managed by TLAA.

Examples of environment descriptors that were specifically referenced in 

GALL Rev. 0 that comprise this category include:

ID chemically treated borated water up to 340°C (644°F); OD up to 300°C 

(572°F) secondary-side water chemistry

Secondary 

feedwater

Within the context of the recirculating steam generator, components such as 

steam generator feedwater impingement plate and support may be subjected 

to loss of material due to erosion in a secondary feedwater environment. 

More generally, the environment of concern is a secondary feedwater/steam 

combination.

Secondary 

feedwater/steam

PWR feedwater or steam at or near full operating temperature subject to the 

secondary water chemistry program. In IV, this is the descriptor for SCC of 

secondary side nozzles in pressure boundary and structural components of 

steam generator (once-through) constructed of Alloy 600

Examples of environment descriptors that were specifically referenced in 

GALL Rev. 0 that comprise this category include:

Up to 300°C (572°F) secondary-side water chemistry at 5.3-7.2 MPa
NUREG-1833 A-58 October 2005

A.3.2 Selected Descriptions of Environments

Standardized 

Expression

Description and Technical Justification

Sodium pentaborate 

solution

Treated water that contains a mixture of borax and boric acid. Although it has 

been referenced that sodium pentaborate approximates basic treated water in 

aggressivity, this is a fairly concentrated solution.

Examples of environment descriptors that were specifically referenced in 

GALL Rev. 0 that comprise this category include:

Sodium pentaborate solution at 21 – 32 °C (70 – 90°F) ( ̃24,500 ppm B)

Soil External environment for components buried in the soil, including 

groundwater in the soil. Environment where settlement could occur – includes 

changes in groundwater condition.

Examples of environment descriptors that were specifically referenced in 

GALL Rev. 0 that comprise this category include:

Soft soil; changes in groundwater conditions (III)

Soil (VII)

Soil and ground water (VIII)

Steam Steam, subject to BWR water chemistry program or PWR secondary plant 

water chemistry program. Defining temperature of steam is not considered 

necessary for analysis

Examples of environment descriptors that were specifically referenced in 

GALL Rev. 0 that comprise this category include:

288°C (550°F) steam

Up to 300°C (572°F) steam

System temperature 

up to 288°C (550°F)

Metal temperature outside the recirculation pump and valves associated with 

BWR reactor coolant pressure boundary

Examples of environment descriptors that were specifically referenced in 

GALL Rev. 0 that comprise this category include:

Air with metal temperature up to 288°C (550°F) 

System temperature 

up to 340°C (644°F)

Maximum metal temperature associated with reactor coolant pump, valves, 

and pressurizer integral support for PWR reactor coolant or PWR steam 

generators.

Examples of environment descriptors that were specifically referenced in 

GALL Rev. 0 that comprise this category include:

Air

Air with metal temperature up to 340°C (644°F)

Treated borated 

water

Borated (PWR) water. Since material of concern is Boraflex, no need to 

specify temperature threshold.

Examples of environment descriptors that were specifically referenced in 

GALL Rev. 0 that comprise this category include:

Chemically treated oxygenated (BWR) or borated (PWR) water
October 2005 A-59 NUREG-1833

A.3.2 Selected Descriptions of Environments

Standardized 

Expression

Description and Technical Justification

Treated borated 

water >60°C 

(>140°F)

Treated water with boric acid above SCC threshold for stainless steel. [2,3] 

borated (PWR) water, when dealing with SCC of stainless steel, then list > 

140°F

Examples of environment descriptors that were specifically referenced in 

GALL Rev. 0 that comprise this category include:

Chemically treated borated water at temperature <93°C (200°F)

Chemically treated oxygenated (BWR) or borated (PWR) water

Treated borated 

water >250°C 

(>482°F)

Treated water with boric acid above thermal embrittlement threshold for 

CASS. Only environmental temperature of concern is that above the 

embrittlement threshold – specifying full temp range is counterproductive.

Examples of environment descriptors that were specifically referenced in 

GALL Rev. 0 that comprise this category include:

Chemically treated borated water at temperature 25–340°C (77-644°F)

Treated water Treated water is demineralized water, which is the base water for all clean 

systems. Depending on the system, this demineralized water may require 

additional processing. Treated water could be deaerated and include 

corrosion inhibitors, biocides, or some combination of these treatments. 

Unlike the PWR reactor coolant environment (treated borated water), the 

BWR reactor coolant environment (i.e., treated water) does not contain boron, 

a recognized corrosion inhibitor.

Examples of environment descriptors that were specifically referenced in 

GALL Rev. 0 that comprise this category include:

<90°C (<194°F) treated water

25–288°C (77-550°F) demineralized water

Chemically treated oxygenated (BWR) or borated (PWR) water

Secondary side treated water

Treated water side (condensate side)

Treated water (BWRs: reactor coolant; PWRs: secondary side water)

Treated water side (other side of steam generator blowdown)

Treated water >60°C 

(>140°F)

Treated water above SCC threshold for stainless steel. This is Chemically 

treated oxygenated (BWR) water, when dealing with stress corrosion cracking 

(SCC) of stainless steel, then include temperature threshold > 140°F. Treated 

water in the reactor coolant system and connected systems above SCC 

threshold for stainless steel. [2,3] In context of SCC of SS components in 

PWR reactor vessel, then list >140°F

Examples of environment descriptors that were specifically referenced in 

GALL Rev. 0 that comprise this category include:

Chemically treated oxygenated (BWR) or borated (PWR) water

Chemically treated borated water up to 340°C (644°F)
NUREG-1833 A-60 October 2005

A.3.2 Selected Descriptions of Environments

Standardized 

Expression

Description and Technical Justification

Water – flowing Water that is refreshed, thus having larger impact on leaching – this can be 

raw water, groundwater, or flowing water under a foundation.

Examples of environment descriptors that were specifically referenced in 

GALL Rev. 0 that comprise this category include: include:

Flowing water under foundation

Water – standing Water that is stagnant and unrefreshed, thus possibly resulting in increased 

ionic strength of solution up to saturation.

Examples of environment descriptors that were specifically referenced in 

GALL Rev. 0 that comprise this category include:

Exposed to water
October 2005 A-61 NUREG-1833

A.3.3 Temperature Thresholds

The restructuring of the NUREG-1801 mechanical systems tables is not intended to alter the 

generic AMR results. The intent is to clarify those results and extend their applicability to a 

broader range of equipment to permit better comparisons to the results found in a typical plant 

AMR. New temperature thresholds for aging effects in common use by the industry, are 

presented in Table A.3.2 to further clarify applicability of the results.

A.3.3 Temperature Thresholds Expressed in Environmental Descriptors

Temperature Threshold Description and Technical Justification

95°F Thermal stresses for 

elastomers

In general, if the ambient temperature is less than about 

95°F, then thermal aging may be considered not 

significant for rubber, butyl rubber, neoprene, nitrile 

rubber, silicone elastomer, fluoroelastomer, EPR, and 

EPDM. [Gillen & Clough, 1981]

Although 95°F is a recognized threshold, temperature is 

not the only factor for aging of elastomers. Elastomers are 

also subject to aging effects from other factors such as 

exposure to ozone, oxidation, and radiation.

140°F SCC for stainless steel In general, SCC very rarely occurs in austenitic stainless 

steels below 140°F. Although SCC has been observed in 

stagnant, oxygenated borated water systems at lower 

temperatures than this 140°F threshold, all of these 

instances have identified a significant presence of 

contaminants (halogens, specifically chlorides) in the 

failed components. With a harsh enough environment 

(significant contamination), SCC can occur in austenitic 

stainless steel at ambient temperature. However, these 

conditions are considered event driven, resulting from a 

breakdown of chemistry controls. [Peckner & Bernstein, 

1977; Metals Handbook, 1988]

482°F Thermal embrittlement 

for CASS

CASS materials subjected to sustained temperatures 

below 250°C (482°F) will not result in a reduction of room 

temperature Charpy impact energy below 50 ft-lb for 

exposure times of approximately 300,000 hours (for CASS 

with ferrite content of 40%) and approximately 2,500,000 

hours for CASS with ferrite content of 14%) [Figure 2 in 

Chopra & Sather, 1990]. For a maximum exposure time of 

approximately 420,000 hours (48 EFPY), a screening 

temperature of 482°F is conservatively chosen because 

(1) the majority of nuclear grade materials are expected to 

contain a ferrite content well below 40%, and (2) the 50 ftlb limit is very conservative when applied to cast austenitic 

materials. It is typically applied to ferritic materials (e.g., 10 

CFR 50 Appendix G). For CASS components in the 

reactor coolant pressure boundary, this threshold is 

supported by NUREG-1801 XI.M12, with the exception of 

niobium-containing steels which require evaluation on a 

case-by-case basis.
NUREG-1833 A-62 October 2005

This Page Intentionally Left Blank
October 2005 A-63 NUREG-1833

A.4. Aging Effects and Aging Mechanisms

NUREG-1801 lists aging effects along with one or more aging mechanisms. The aging 

mechanisms, while useful to describe the considerations used in the generic aging management 

review, are generally not useful when comparing the plant AMR results to the NUREG-1801 

results. Although aging mechanisms are considered during the plant AMR, the results are 

reported in terms of aging effects. The suitability of an aging management program is 

determined primarily on its ability to detect or prevent the overall aging effect rather than the 

individual aging mechanism.

The following tables define many of the standardized aging effects and aging mechanisms 

descriptors utilized in the GALL AMR tables in Chapters II, III, IV, V, VI, VII, and VIII of NUREG1801, Rev. 1. 

A.4.1 Listing, Location, and Frequency of Aging Effect/ Aging Mechanism Terms

Table A.4.1 provides a complete listing, occurrence, and frequency of the aging effect/aging 

mechanisms found in NUREG-1801, Rev. 1. The Roman numeral in the second column 

identifies the chapter in GALL Vol. 2 that the structures and/or components are associated with 

(i.e., “II” for Containment Structures, “III” for Structures and Component Supports, “IV” for 

Reactor Vessel, Internals, and Reactor Coolant Systems, “V” for Engineered Safety Features 

Systems, “VI” for Electrical Systems, “VII” for Auxiliary Systems, and “VIII” for Steam and Power 

Conversion Systems).

A.4.1 Occurrence of Aging Effect/ Aging Mechanisms in GALL Report Vol. 2, Rev. 1

Aging Effect/ Aging Mechanism Referring 

Chapters

Total # 

references

Changes in dimensions/ void swelling IV 27

Concrete cracking and spalling/ aggressive chemical attack, and reaction 

with aggregates

VII 1

Concrete cracking and spalling/ freeze-thaw, aggressive chemical attack, 

and reaction with aggregates

VII 1

Corrosion of connector contact surfaces/ intrusion of borated water VI 1

Crack growth/ cyclic loading IV 1

Cracking due to expansion/ reaction with aggregates II 5

III 2

Cracking due to restraint shrinkage, creep, and aggressive environment III 1

Cracking, loss of bond, and loss of material (spalling, scaling)/ corrosion of II 4

embedded steel III 3

Cracking/ cyclic loading IV 7

Cracking/ cyclic loading 

(CLB fatigue analysis does not exist)

II 4

V 1

VII 2

Cracking/ cyclic loading, stress corrosion cracking

VIII 1

Cracking/ flow-induced vibration IV 1
NUREG-1833 A-64 October 2005

A.4.1 Occurrence of Aging Effect/ Aging Mechanisms in GALL Report Vol. 2, Rev. 1

Aging Effect/ Aging Mechanism Referring 

Chapters

Total # 

references

Cracking/ intergranular attack IV 1

Cracking/ outer diameter stress corrosion cracking IV 1

Cracking/ primary water stress corrosion cracking IV 11

II 3

III 1

IV 15

V 3

VII 11

Cracking/ stress corrosion cracking

VIII 7

Cracking/ stress corrosion cracking 

Loss of material/pitting and crevice corrosion

III 2

Cracking/ stress corrosion cracking and intergranular stress corrosion IV 7

cracking V 1

Cracking/ stress corrosion cracking, cyclic loading VII 3

Cracking/ stress corrosion cracking, intergranular stress corrosion cracking IV 1

VII 1

Cracking/ stress corrosion cracking, intergranular stress corrosion cracking 

(for stainless steel only), and thermal and mechanical loading

IV 1

Cracking/ stress corrosion cracking, intergranular stress corrosion cracking, 

cyclic loading

IV 1

Cracking/ stress corrosion cracking, intergranular stress corrosion cracking, 

irradiation-assisted stress corrosion cracking

IV 10

Cracking/ stress corrosion cracking, irradiation-assisted stress corrosion 

cracking

IV 24

Cracking/ stress corrosion cracking, primary water stress corrosion cracking IV 5

Cracking/ stress corrosion cracking, primary water stress corrosion 

cracking, irradiation-assisted stress corrosion cracking

IV 11

Cracking/ stress corrosion cracking, thermal and mechanical loading IV 1

Cracks and distortion due to increased stress levels from settlement II 3

III 1

IV 14

V 2

VII 5

Cumulative fatigue damage/ fatigue

VIII 2

Cumulative fatigue damage/ fatigue II 4

(Only if CLB fatigue analysis exists) III 1

Degradation of insulator quality/presence of any salt deposits or surface 

contamination

VI 1

Denting/ corrosion of carbon steel tube support plate IV 2
October 2005 A-65 NUREG-1833

A.4.1 Occurrence of Aging Effect/ Aging Mechanisms in GALL Report Vol. 2, Rev. 1

Aging Effect/ Aging Mechanism Referring 

Chapters

Total # 

references

Embrittlement, cracking, melting, discoloration, swelling, or loss of dielectric 

strength leading to reduced insulation resistance (IR); electrical failure/ 

degradation (Thermal/ thermoxidative) of organics/thermoplastics, 

radiation-induced oxidation, moisture intrusion and ohmic heating

VI 1

Embrittlement, cracking, melting, discoloration, swelling, or loss of dielectric 

strength leading to reduced insulation resistance (IR); electrical failure/ 

degradation of organics (Thermal/ thermoxidative), radiolysis and photolysis 

(UV sensitive materials only) of organics; radiation-induced oxidation, and 

moisture intrusion

VI 2

Embrittlement, cracking, melting, discoloration, swelling, or loss of dielectric 

strength leading to reduced insulation resistance (IR); electrical failure/ 

thermal/thermoxidative degradation of organics/thermoplastics, radiationinduced oxidation; moisture/debris intrusion, and ohmic heating

VI 1

Fatigue/ohmic heating, thermal cycling, electrical transients, frequent 

manipulation, vibration, chemical contamination, corrosion, and oxidation

VI 1

Fretting or lockup/ mechanical wear II 1

V 1

VI 1

Hardening and loss of strength/ elastomer degradation

VII 4

Increase in porosity and permeability, cracking, loss of material (spalling, II 4

scaling)/ aggressive chemical attack III 3

Increase in porosity and permeability, loss of strength/ leaching of calcium 

hydroxide

III 2

Increase in porosity, permeability/ leaching of calcium hydroxide II 4

Increased hardness, shrinkage and loss of strength/ weathering VII 2

Ligament cracking/ corrosion IV 1

Localized damage and breakdown of insulation leading to electrical failure/ 

moisture intrusion, water trees

VI 1

Lock-up/ wear III 1

Loosening of bolted connections due to thermal cycling, ohmic heating, 

electrical transients, vibration, chemical contamination, corrosion, and 

oxidation

VI 1

Loosening of bolted connections/ thermal cycling and ohmic heating VI 1

Loss of fracture toughness/ neutron irradiation embrittlement IV 7

Loss of fracture toughness/ neutron irradiation embrittlement, void swelling IV 16

Loss of fracture toughness/ thermal aging and neutron irradiation 

embrittlement

IV 9

Loss of fracture toughness/ thermal aging embrittlement IV 3

V 2

Loss of leak tightness/ mechanical wear of locks, hinges and closure 

mechanisms

II 1
NUREG-1833 A-66 October 2005

A.4.1 Occurrence of Aging Effect/ Aging Mechanisms in GALL Report Vol. 2, Rev. 1

Aging Effect/ Aging Mechanism Referring 

Chapters

Total # 

references

Loss of material (spalling, scaling) and cracking/ freeze-thaw II 3

III 2

Loss of material, loss of form/ erosion, settlement, sedimentation, frost 

action, waves, currents, surface runoff, seepage

III 1

Loss of material/ pitting and crevice corrosion (only for steel after lining 

degradation)

VII 1

Loss of material/ abrasion; cavitation III 1

Loss of material/ boric acid corrosion III 2

IV 1

V 4

VII 4

VIII 2

Loss of material/ cladding breach V 1

VII 1

Loss of material/ corrosion II 1

III 1

Loss of material/ corrosion of embedded steel VII 2

Loss of material/ crevice corrosion and fretting IV 1

Loss of material/ erosion IV 2

V 1

VII 1

Loss of material/ erosion, general, pitting, and crevice corrosion IV 1

Loss of material/ fretting and wear IV 1

Loss of material/ general (steel only), pitting and crevice corrosion III 1

IV 1

VII 1

VIII 1

Loss of material/ general and pitting corrosion III 2

VII 1

Loss of material/ general corrosion III 1

V 10

VI 1

VII 8

VIII 4

Loss of material/ general corrosion and fouling V 1
October 2005 A-67 NUREG-1833

A.4.1 Occurrence of Aging Effect/ Aging Mechanisms in GALL Report Vol. 2, Rev. 1

Aging Effect/ Aging Mechanism Referring 

Chapters

Total # 

references

Loss of material/ general, pitting, and crevice corrosion II 6

III 1

IV 4

V 8

VII 15

VIII 11

Loss of material/ general, pitting, crevice and boric acid corrosion V 1

Loss of material/ general, pitting, crevice, and (for drip pans and drain lines) 

microbiologically influenced corrosion

VII 1

Loss of material/ general, pitting, crevice, and galvanic corrosion V 1

VII 1

VIII 2

V 1

VII 1

Loss of material/ general, pitting, crevice, and microbiologically influenced 

corrosion

VIII 2

V 1

VII 3

Loss of material/ general, pitting, crevice, and microbiologically influenced 

corrosion, and fouling

VIII 1

Loss of material/ general, pitting, crevice, and microbiologically influenced 

corrosion, fouling, and lining/coating degradation

VII 1

V 1

VII 1

Loss of material/ general, pitting, crevice, galvanic, and microbiologically 

influenced corrosion, and fouling

VIII 1

Loss of material/ mechanical wear due to wind blowing on transmission 

conductors

VI 1

Loss of material/ microbiologically influenced corrosion VII 1

Loss of material/ pitting and crevice corrosion III 1

IV 6

V 12

VII 17

VIII 14

Loss of material/ pitting and crevice corrosion (only for steel after 

lining/cladding degradation)

VII 1

Loss of material/ pitting and crevice corrosion, and fouling VII 2

Loss of material/ pitting, crevice, and galvanic corrosion IV 1

V 2

VII 3

VIII 1
NUREG-1833 A-68 October 2005

A.4.1 Occurrence of Aging Effect/ Aging Mechanisms in GALL Report Vol. 2, Rev. 1

Aging Effect/ Aging Mechanism Referring 

Chapters

Total # 

references

Loss of material/ pitting, crevice, and microbiologically influenced corrosion V 1

VII 6

VIII 4

V 2

VII 2

Loss of material/ pitting, crevice, and microbiologically influenced corrosion, 

and fouling

VIII 1

Loss of material/ pitting, crevice, galvanic, and microbiologically influenced 

corrosion, and fouling

VII 1

Loss of material/ selective leaching IV 1

V 5

VII 9

VIII 6

Loss of material/ wastage and pitting corrosion IV 1

Loss of material/ wear IV 15

VII 5

Loss of material/ wind induced abrasion and fatigue 

Loss of conductor strength/ corrosion 

Increased resistance of connection/ oxidation or loss of pre-load

VI 2

Loss of mechanical function/ corrosion, distortion, dirt, ove rload, fatigue due 

to vibratory and cyclic thermal loads; elastomer hardening

III 3

Loss of preload/ stress relaxation IV 13

Loss of preload/ thermal effects, gasket creep, and self-loosening IV 3

Loss of preload/ thermal effects, gasket creep, and self-loosening IV 1

V 1

VII 1

VIII 1

Loss of prestress/ relaxation; shrinkage; creep; elevated temperature II 1

Loss of sealing/ deterioration of seals, gaskets, and moisture barriers 

(caulking, flashing, and other sealants)

III 1

Loss of sealing; Leakage through containment/ deterioration of seals, 

gaskets, and moisture barriers (caulking, flashing, and other sealants)

II 1

None III 4

IV 6

V 18

VI 1

VII 23

VIII 15

Reduction in concrete anchor capacity due to local concrete degradation/ 

service-induced cracking or other concrete aging mechanisms

III 1
October 2005 A-69 NUREG-1833

A.4.1 Occurrence of Aging Effect/ Aging Mechanisms in GALL Report Vol. 2, Rev. 1

Aging Effect/ Aging Mechanism Referring 

Chapters

Total # 

references

Reduction in foundation strength, cracking, differential settlement/ erosion II 1

of porous concrete subfoundation III 1

Reduction of heat transfer/ fouling III 1

Reduction of heat transfer/ fouling V 8

VII 6

VIII 10

Reduction of neutron-absorbing capacity and loss of material/ general 

corrosion

VII 2

Reduction of neutron-absorbing capacity/ boraflex degradation VII 2

Reduction of strength and modulus/ elevated temperature (>150°F general; II 5

>200°F local) III 1

Reduction or loss of isolation function/ radiation hardening, temperature, 

humidity, sustained vibratory loading

III 1

Various degradation/ various mechanisms VI 1

Wall thinning/ flow-accelerated corrosion IV 5

V 2

VIII 2

Grand Total 683
NUREG-1833 A-70 October 2005

A.4.2 Aging Effects

Table A.4.2 defines many of the standardized aging effects descriptors utilized in the GALL 

AMR tables in Chapters II, III, IV, V, VI, VII, and VIII of NUREG-1801, Rev. 1.

A.4.2 Aging Effects

Standardized 

Expression

Description and Technical Justification

Changes in dimensions Changes in dimension can result from void swelling

Concrete cracking and 

spalling

Concrete cracking and spalling can result from freeze-thaw, aggressive 

chemical attack, and reaction with aggregates.

Corrosion of connector 

contact surfaces

Corrosion of exposed connector contact surfaces can be caused by borated 

water intrusion.

Crack growth Increase in crack size, attributable to cyclic loading. For example, the vessel 

shell (including beltline welds) fabricated of SA508-Cl 2 forgings clad with 

stainless steel using a high-heat-input welding process when subjected to a 

reactor coolant environment can experience a crack growth aging effect 

caused by cyclic loading. 

Cracking This term is used in this document to be synonymous with the phrase “crack 

initiation and growth” where used in reference to metallic substrates. 

Nonductile failure of a component due to stress corrosion, fatigue, or 

embrittlement. 

Aging mechanisms that can result in cracking include:

• Cyclic loading

• Stress corrosion cracking

• Intergranular attack

• Outer diameter stress corrosion cracking

• Primary water stress corrosion cracking

• Intergranular stress corrosion cracking

• Irradiation-assisted stress corrosion cracking

• Thermal and mechanical loading

Examples of aging effect descriptors that were specifically referenced in 

GALL Rev. 0 that comprise this category include:

• Crack initiation and growth

Cracking in concrete can be caused by restraint shrinkage, creep, and 

aggressive environment.

Cracking, loss of bond, 

and loss of material 

(spalling, scaling)

Cracking, loss of bond, and loss of material (spalling, scaling) can be caused 

by corrosion of embedded steel in concrete.

Cracks; distortion; 

increase in component 

stress level

Within concrete structures, cracks, distortion, and increase in component 

stress level can be caused by settlement.

Cumulative fatigue 

damage

Cumulative fatigue damage is due to fatigue
October 2005 A-71 NUREG-1833

A.4.2 Aging Effects

Standardized 

Expression

Description and Technical Justification

Degradation of 

insulator quality

The decrease in insulating capacity can result from the presence of salt 

deposits or surface contamination. Although this derives from an aging 

mechanism (presence of salt deposits or surface contamination as noted in 

LP-07) that may be due to temporary, transient environmental conditions, the 

net result may be long-lasting and cumulative.

Denting Denting can result from corrosion of carbon steel tube support plates.

Embrittlement, 

cracking, melting, 

discoloration, swelling, 

or loss of dielectric 

strength leading to 

reduced insulation 

resistance (IR); 

electrical failure

Embrittlement, cracking, melting, discoloration, swelling, or loss of dielectric 

strength leading to reduced insulation resistance, electrical failure can result 

from mechanisms such as thermal or thermoxidative degradation of organics; 

radiation-induced oxidation, radiolysis and photolysis (UV sensitive materials 

only) of organics; moisture intrusion; and ohmic heating.

Expansion and 

cracking

Within concrete structures, expansion and cracking can result from reaction 

with aggregates

Fatigue Fatigue in copper fuse holder clamps can result from ohmic heating, thermal 

cycling, electrical transients, frequent manipulation, vibration, chemical 

contamination, corrosion, and oxidation.

Fretting or lockup Fretting is an aging effect due to accelerated deterioration at the interface 

between contacting surfaces as the result of corrosion and slight oscillatory 

movement between the two surfaces. In essence both fretting and lockup are 

due to mechanical wear.

Hardening and loss of 

strength 

Hardening and loss of strength can result from elastomer degradation of 

seals and other elastomeric components. Elastomers can experience 

increased hardness, shrinkage, and loss of strength, due to weathering.

Increase in porosity 

and permeability, 

cracking, loss of 

material (spalling, 

scaling)

Concrete can increase in porosity and permeability, cracking, loss of material 

(spalling, scaling) due to aggressive chemical attack. In concrete, loss of 

material (spalling, scaling) and cracking can result from freeze-thaw 

processes. 

Increase in porosity 

and permeability, loss 

of strength

Concrete can increase in porosity and permeability, with loss of strength due 

to leaching of calcium hydroxide

Increased resistance of 

connection

Increased resistance of connection in electrical transmission conductors and 

connections can be caused by oxidation or loss of preload. Loss of conductor 

strength in electrical transmission lines can result from corrosion.

Ligament cracking Steel tube support plates can experience ligament cracking due to corrosion.

Localized damage and 

breakdown of 

insulation leading to 

electrical failure 

Localized damage in polymeric electrical conductor insulation leading to 

electrical failure is due to moisture intrusion, and the formation of water trees.

Lock-up Lock-up of steel elements in the drywell head downcomers can be attributed 

to mechanical wear.
NUREG-1833 A-72 October 2005

A.4.2 Aging Effects

Standardized 

Expression

Description and Technical Justification

Loosening of bolted 

connections

The loosening of bolted bus duct connections due to thermal cycling can 

result from ohmic heating

Loss of fracture 

toughness

Loss of fracture toughness can result from various aging mechanisms 

including thermal aging, thermal aging embrittlement, and neutron irradiation 

embrittlement.

Loss of leak tightness Steel airlocks can experience loss of leak tightness in closed position 

resulting from mechanical wear of locks, hinges, and closure mechanisms.

Loss of material Loss of material may be due to general corrosion, boric acid corrosion, pitting 

corrosion, galvanic corrosion, crevice corrosion, erosion, fretting, flowaccelerated corrosion, MIC, selective leaching, wastage, wear, and 

aggressive chemical attack. In concrete structures, loss of material can also 

be caused by abrasion or cavitation or corrosion of embedded steel. For high 

voltage insulators, loss of material can be attributed to mechanical wear or 

wind-induced abrasion and fatigue due to wind blowing on transmission 

conductors.

Loss of material due to general corrosion is an aging effect requiring 

management for low alloy steel, carbon steel, and cast iron in outdoor 

environments.

Loss of material 

(spalling, scaling) and 

cracking

In concrete, loss of material (spalling, scaling) and cracking can result from 

freeze-thaw processes.

Loss of material, loss 

of form

In earthen water-control structures, the loss of material, and loss of form can 

result from erosion, settlement, sedimentation, frost action, waves, currents, 

surface runoff, and seepage.

Loss of mechanical 

function

Loss of mechanical function in ASME Class 1 piping and components (such 

as constant and variable load spring hangers, guides, stops, sliding surfaces, 

design clearances, vibration isolators) fabricated from steel or other materials 

such as Lubrite® can experience loss of mechanical function due to 

corrosion, distortion, dirt, overload, fatigue due to vibratory and cyclic thermal 

loads, or elastomer hardening.

Loss of preload Loss of preload due to gasket creep, thermal effects (including differential 

expansion and creep or stress relaxation), and self-loosening (which includes 

vibration, joint flexing, cyclic shear loads, thermal cycles) is an aging 

effect/mechanism accepted by industry as being within the scope of license 

renewal. 

Loss of prestress Loss of prestress in structural steel anchorage components can result from 

relaxation, shrinkage, creep, or elevated temperatures.

Loss of sealing; 

leakage through 

containment

Loss of sealing and leakage through containment in materials such as seals, 

elastomers, rubber and other similar materials can result from deterioration of 

seals, gaskets, and moisture barriers (caulking, flashing, and other sealants)

Loss of seal in elastomeric phase bus enclosure assemblies can result from 

moisture intrusion.

None Certain structures and components made of corrosion-resistant materials 

may in certain environments be subject to no aging mechanisms and thus 

there are also no relevant aging effects.
October 2005 A-73 NUREG-1833

A.4.2 Aging Effects

Standardized 

Expression

Description and Technical Justification

Reduction in concrete 

anchor capacity due to 

local concrete 

degradation

Reduction in concrete anchor capacity due to local concrete degradation can 

result from a service-induced cracking or other concrete aging mechanisms.

Reduction in 

foundation strength, 

cracking, differential 

settlement

Reduction in foundation strength, cracking, and differential settlement can 

result from erosion of porous concrete subfoundation.

Reduction of heat 

transfer

Reduction of heat transfer from fouling by the buildup, from whatever source, 

on the heat transfer surface. Although in heat exchangers, the tubes are the 

primary heat transfer component, heat exchanger internals including 

tubesheets and fins contribute to heat transfer and may be affected by the 

reduction of heat transfer due to fouling. Although GALL Rev. 1 does not 

include reduction of heat transfer for any heat exchanger surfaces other than 

tubes, reduction in heat transfer is of concern for other heat exchanger 

surfaces.

Reduction of neutronabsorbing capacityReduction of neutron-absorbing capacity can result from Boraflex 

degradation.

Reduction of neutronabsorbing capacity and 

loss of material

Reduction of neutron-absorbing capacity can result from Boraflex 

degradation.

Reduction of strength 

and modulus

In concrete, reduction of strength and modulus can be attributed to elevated 

temperatures (>150°F general; >200°F local).

Reduction or loss of 

isolation function 

Reduction or loss of isolation function in polymeric vibration isolation 

elements can result from Radiation hardening, temperature, humidity, 

sustained vibratory loading.

Various degradation 

effects

Electrical equipment subjected to adverse localized environment can be 

subject to various degradation effects due to various mechanisms (see L-05).

Wall thinning This is the term used throughout GALL Rev. 1 to describe the specific 

version of loss of material due to flow-accelerated corrosion.
NUREG-1833 A-74 October 2005

A.4.3 Aging Mechanisms

An aging mechanism is considered to be significant when it may result in aging effects that 

produce a loss of functionality of a component or structure during the current or license renewal 

period if allowed to continue without mitigation. Table A.4.3 presents the aging mechanisms 

identified in GALL.

A.4.3 Aging Mechanisms

Standardized 

Expression

Description and Technical Justification

Abrasion As water migrates over a concrete surface it may transport material that can 

abrade the concrete. The passage of water may also create a negative 

pressure at the water – air to concrete interface that can result in abrasion 

and cavitation degradation of the concrete. This may result in pitting or 

aggregate exposure due to loss of cement paste. [NUMARC Report 90-06]

Aggressive chemical 

attack

Concrete, being highly alkaline (pH> 12.5) is degraded by strong acids. 

Chlorides, and sulfates of potassium, sodium, and magnesium may attack 

concrete depending concentration in soil/ground water. Exposed surfaces of 

Class 1 structures may be subject to sulfur-based acid-rain degradation. 

Minimum degradation thresholds are 500 ppm chlorides and 1500 ppm 

sulphates. [NUMARC Report 90-06]

Boraflex Degradation Boraflex degradation may involve gamma radiation-induced shrinkage of 

Boraflex and the potential to develop tears or gaps in the material. A more 

significant potential degradation is the gradual release of silica and the 

depletion of boron carbide from Boraflex following gamma irradiation and 

long-term exposure to the wet pool environment. The loss of boron carbide 

from Boraflex is characterized by slow dissolution of the Boraflex matrix from 

the surface of the Boraflex and a gradual thinning of the material.

The boron carbide loss, of course, can result in a significant increase in the 

reactivity of the storage racks. An additional consideration is the potential for 

silica transfer through the fuel transfer canal into the reactor core during 

refueling operations and its effect on the fuel clad heat transfer capability. 

[NRC GL 96-04]

Borated Water Intrusion Influx of borated water.

Boric acid corrosion Corrosion by boric acid, which can occur where there is borated water 

leakage in an environment described as air with borated water leakage. See 

also Corrosion.

Cavitation Formation and instantaneous collapse of innumerable tiny voids or cavities 

within a liquid subjected to rapid and intense pressure changes. Cavitation 

caused by severe turbulent flow often leads to cavitation damage.

Chemical contamination Degradation due to presence of chemical constituents.
October 2005 A-75 NUREG-1833

A.4.3 Aging Mechanisms

Standardized 

Expression

Description and Technical Justification

Cladding breach This refers to the aging mechanisms comprising breach of the stainless steel 

cladding via any applicable process. Unique problems with stainless cladding 

have been identified for HHSI pumps as discussed in NRC Information 

Notice 94-63, “Boric Acid Corrosion of Charging Pump Casings Caused by 

Cladding Cracks.”

In GALL Rev. 1, it is only used in new AMR line-items in the Engineered 

Safety Features (EP-49) and Auxiliary System (VII AP-85) to describe the 

loss of material in PWR emergency core cooling system pump casing 

constructed of steel with stainless steel cladding (EP-49) and the PWR 

chemical and volume control system pump casing constructed of steel with 

stainless steel cladding (AP-85).

Cladding degradation This refers to the degradation of the stainless via any applicable degradation 

process. 

In GALL Rev. 1, it is only used in VII A-40 to describe the loss of material due 

to pitting and crevice corrosion (only for steel after lining/cladding 

degradation) of piping, piping components, and piping elements fabricated 

from steel, with elastomer lining or stainless steel cladding.

Corrosion Chemical or electrochemical reaction between a material, usually a metal, 

and its environment that produces a deterioration of the material and its 

properties.

Corrosion of carbon steel 

tube support plate

Corrosion (as defined above) of the carbon steel tube support plates which 

are plate-type component providing tube-tube mechanical support for the 

tubes in the tube bundle of the steam generator (recirculating) system of a 

PWR. The tubes pass through drill holes in the plate. The secondary coolant 

flows through the tube supports via flow holes between the tubes. [Shah & 

Macdonald, 1993; Gavrilas, et. Al., 2000]

Corrosion of embedded 

steel

If pH of the concrete in which steel is embedded is reduced (pH< 11.5) by 

intrusion of aggressive ions (e.g., chlorides > 500 ppm) in the presence of 

oxygen, embedded steel corrosion may occur. A reduction in pH may be 

caused by the leaching of alkaline products through cracks, entry of acidic 

materials, or carbonation. Chlorides may also be present in the constituents 

of the original concrete mix. The severity of the corrosion is affected by the 

properties and types of cement, aggregates, and moisture content. 

[NUMARC 90-01]

Creep Creep for metallic materials refers to a time-dependent continuous 

deformation process under constant stress. It is an elevated temperature 

process and is not a concern for low alloy steel below 700 0 F, for austenitic 

alloys below 1000 0 F, and Ni-based alloy below 1800 0 F. [NUMARC 90-07; 

ASTM Standards, 1976]

Creep in concrete is related to the loss of absorbed water from the hydrated 

cement paste. It is a function of modulus of elasticity of the aggregate. It may 

result in loss of prestress in the tendons used in prestressed concrete 

containment. [ Shah & Macdonald, 1993]
NUREG-1833 A-76 October 2005

A.4.3 Aging Mechanisms

Standardized 

Expression

Description and Technical Justification

Crevice Corrosion Localized corrosion of a metal surface at, or immediately adjacent to, an area 

that is shielded from full exposure to the environment because of close 

proximity between the metal and the surface of another material. Crevice 

corrosion occurs in a wetted or buried environment when a crevice or area of 

stagnant or low flow exists that allows a corrosive environment to develop in 

a component. It occurs most frequently in joints and connections, or points of 

contact between metals and non-metals, such as gasket surfaces, lap joints, 

and under bolt heads. Carbon steel, cast iron, low alloy steels, stainless 

steel, copper, and nickel base alloys are all susceptible to crevice corrosion.

Steel can be subject to crevice corrosion in some cases after lining/cladding 

degradation (e.g., A-40).

Cyclic loading One source of cyclic loading is due to periodic application of pressure loads 

and forces due to thermal movement of piping transmitted through 

penetrations and structures to which penetrations are connected. The typical 

results of cyclic loads on metal components is fatigue cracking and failure,

however the cyclic loads may also cause deformation that results in 

functional failure.

Deterioration of seals, 

gaskets, and moisture 

barriers (caulking, 

flashing, and other 

sealants)

Seals, gaskets, and moisture barriers (caulking, flashing, and other sealants) 

are subject to loss of sealing and leakage through containment caused by 

aging degradation of these components.

Distortion The aging mechanism of distortion can be caused by time-dependent strain, 

or gradual elastic and plastic deformation, of metal that is under constant 

stress at a value lower than its normal yield strength.

Elastomer degradation Elastomer materials are substances whose elastic properties similar to that 

of natural rubber. The term elastomer sometimes is used technically to 

distinguish synthetic rubbers and rubber-like plastics from natural rubber. 

Degradation may include cracking, crazing, fatigue breakdown, abrasion, 

chemical attacks, and weathering. [Davis, 2000; ASTM Standards, 2004] 

Electrical transients Electrical transients are one of the aging mechanisms that can cause fatigue 

in copper fuse holder clamps.

Elevated temperature In concrete, reduction of strength and modulus can be attributed to elevated 

temperatures (>150°F general; >200°F local)

Erosion Progressive loss of material from a solid surface due to mechanical 

interaction between that surface and a fluid, a multicomponent fluid, or solid 

particles carried with the fluid.

Examples include loss of material in components such as copper alloy heat 

exchanger tubes due to erosion. Erosion is an applicable aging mechanism 

for various components including heat exchanger tubes that are exposed to 

high velocity fluids containing particles such as raw water. Refer to SAND 93-

7070, AMP XI. M20, Open-Cycle Cooling Water System, and GL 89-13.

Erosion of porous 

concrete subfoundation

Erosion (as defined above) of the concrete subfoundation 
October 2005 A-77 NUREG-1833

A.4.3 Aging Mechanisms

Standardized 

Expression

Description and Technical Justification

Erosion settlement Erosion (as defined above). Settlement of containment structure may occur 

during the design life due to changes in the site conditions (e.g., due to 

erosion or changes in the water table). The amount of settlement depends on 

the foundation material and is generally determined by survey. 

Erosion, settlement, 

sedimentation, frost 

action, waves, currents, 

surface runoff, seepage

In earthen water-control structures, the loss of material and loss of form can 

result from erosion, settlement, sedimentation, frost action, waves, currents, 

surface runoff, and seepage.

Fatigue Phenomenon leading to fracture under repeated or fluctuating stresses 

having a maximum value less than the tensile strength of the material. 

Fatigue fractures are progressive and grow under the action of the fluctuating 

stress.

Fatigue due to vibratory 

and cyclic thermal loads

Structural degradation that can occur as a result of repeated stress/strain 

cycles caused by fluctuating loads (e.g., from vibratory loads) and 

temperatures (giving rise to thermal loads). After repeated cyclic loading of 

sufficient magnitude, microstructural damage may accumulate, leading to 

macroscopic crack initiation at the most vulnerable regions. Subsequent 

mechanical or thermal cyclic loading may lead to growth of the initiated 

crack.

Vibration may result in component cyclic fatigue, as well as in cutting, wear, 

and abrasion, if left unabated. Vibration is generally induced by external 

equipment operation. It may also result from flow resonance or movement of 

pumps or valves in fluid systems.

Crack initiation and growth resistance is governed by factors including stress 

range, mean stress, loading frequency, surface condition and the presence 

of deleterious chemical species. 

Flow-accelerated 

corrosion (FAC)

Also termed erosion-corrosion. A co-joint activity involving corrosion and 

erosion in the presence of a moving corrosive fluid, leading to the 

accelerated loss of material. Susceptibility may be determined using the 

review process outlined in Section 4.2 of NSAC-202L-R2 recommendations 

for an effective FAC program.

Fouling An accumulation of deposits. This term includes accumulation and growth of 

aquatic organisms on a submerged metal surface and also includes the 

accumulation of deposits, usually inorganic, on heat exchanger tubing. 

Biofouling, as a subset of fouling, can be caused by either macro-organisms 

(such as barnacles, Asian clams, zebra mussels, and others found in fresh 

and salt water) or micro-organisms (e.g., algae). 

Fouling can also be categorized as particulate fouling (sediment, silt, dust, 

and corrosion products), marine biofouling, or macrofouling, e.g., peeled 

coatings, debris, etc. Fouling in a raw water system can occur on the piping, 

valves, and heat exchangers. Fouling can result in a reduction of heat 

transfer, loss of material, or a reduction in the system flow rate (this last 

aging effect is considered active and thus is not in the purview of license 

renewal).
NUREG-1833 A-78 October 2005

A.4.3 Aging Mechanisms

Standardized 

Expression

Description and Technical Justification

Freeze-Thaw, Frost 

action

Repeated freezing and thawing is known to be capable of causing severe 

degradation to the concrete characterized by scaling, cracking, and spalling. 

The cause of this phenomenon is water freezing within the pores of the 

concrete, creating hydraulic pressure which if unrelieved will lead to freezethaw degradation.

Factors that enhance the resistance of concrete to freeze-thaw degradation 

are a) adequate air content (e. g., within ranges specified in ACI 301-84), b) 

low permeability, c) protection until adequate strength has developed, and 

surface coating applied to frequently wet-dry surfaces. 

Fretting Aging effect due to accelerated deterioration at the interface bet ween 

contacting surfaces as the result of corrosion and slight oscillatory movement 

between the two surfaces.

Galvanic Corrosion Accelerated corrosion of a metal because of an electrical contact with a more 

noble metal or nonmetallic conductor in a corrosive electrolyte. Also called 

bimetallic corrosion, contact corrosion, dissimilar metal corrosion, or twometal corrosion. Galvanic corrosion is an applicable aging mechanism for 

steel materials coupled to more noble metals in heat exchangers; galvanic 

corrosion of copper is of concern when coupled with the nobler stainless 

steel

General corrosion Also known as uniform corrosion, corrosion proceeds at approximately the 

same rate over a metal surface. Loss of material due to general corrosion is 

an aging effect requiring management for low alloy steel, carbon steel, and 

cast iron in outdoor environments. 

Some potential for pitting and crevice corrosion may exist even when pitting 

and crevice is not explicitly listed in the aging effects/aging mechanism 

column in GALL Rev. 1 AMR line-items and when the descriptor may only be 

loss of material due to general corrosion. For example, the new AMP XI.M36 

“External Surfaces Monitoring” inspects for general corrosion of steel and 

manages aging effects through visual inspection of external surfaces for 

evidence of material loss and leakage. It acts as a de facto screening for 

pitting and crevice corrosion, since the symptoms of general corrosion will be 

first noticed. Wastage is thinning of component walls due to general 

corrosion.

Intergranular attack (IGA) In austenitic stainless steels, the precipitation of chromium carbides, usually 

at grain boundaries, on exposure to temperatures of about 550-850°C, 

leaving the grain boundaries depleted of Cr and therefore susceptible to 

preferential attack (intergranular attack) by a corroding (oxidizing) medium.

Intergranular Stress 

Corrosion Cracking 

(IGSCC)

Stress corrosion cracking in which the cracking occurs along grain 

boundaries.

Irradiation-assisted stress 

corrosion cracking 

(IASCC)

Failure by intergranular cracking in aqueous environments of stressed 

materials exposed to ionizing radiation has been termed irradiation assisted 

stress corrosion cracking (IASCC). Irradiation by high-energy neutrons can

promote stress corrosion cracking by affecting material microchemistry (e.g., 

radiation-induced segregation of elements such as P, S, Si, and Ni to the 

grain boundaries), material composition and microstructure (e.g., radiation 

hardening), as well as water chemistry (e.g., radiolysis of the reactor water to 

make it more aggressive).
October 2005 A-79 NUREG-1833

A.4.3 Aging Mechanisms

Standardized 

Expression

Description and Technical Justification

Leaching of calcium 

hydroxide

Water passing through cracks, inadequately prepared construction joints, or 

areas that are not sufficiently consolidated during placing may dissolve some 

calcium-containing products, of which calcium hydroxide is the most-readily 

soluble, in concrete. Once the calcium hydroxide has been leached away, 

other cementatious constituents become vulnerable to chemical 

decomposition, finally leaving only the silica and alumina gels behind with 

little strength. The water’s aggressiveness in the leaching of calcium 

hydroxide depends on its salt content and temperature. This leaching action 

is effective only if the water passes through the concrete.

Mechanical loading Applied loads of mechanical origins rather than from other sources such as 

thermal. 

Mechanical wear Degradation of copper clamps in fuse holders can be partially attributed to 

frequent manipulation, which is a subset of mechanical wear, as referenced 

in LP-01. Other examples include mechanical wear of electrical lines due to 

wind blowing on transmission conductors as referenced in LP-11. Another 

example is the mechanical wear of locks, hinges, and closure mechanisms

Microbiologically 

influenced corrosion 

(MIC)

Any of the various forms of corrosion influenced by the presence and 

activities of such microorganisms as bacteria, fungi, and algae, and/or the 

products produced in their metabolism. Degradation of material that is 

accelerated due to conditions under a biofilm or microfouling tubercle, for 

example, anaerobic bacteria that can set up an electrochemical galvanic 

reaction or inactivate a passive protective film, or acid-producing bacterial 

that might produce corrosive metabolites.

Moisture Intrusion Influx of moisture through any viable process.

Neutron irradiation 

embrittlement

Irradiation by neutrons results in embrittlement of carbon and low alloy 

steels. It may produce changes in mechanical properties by increasing 

tensile and yield strengths with corresponding decrease in fracture 

toughness and ductility. The extent of embrittlement depends on neutron 

fluence, temperature, and trace material chemistry. 

Ohmic heating Ohmic heating is induced by current flow through a conductor and can be 

calculated using first principles of electricity and heat transfer. Ohmic heating 

is a thermal stressor and can be induced in situations, such as conductors 

passing through electrical penetrations. Ohmic heating is especially 

significant for power circuit penetrations. 

Outer Diameter Stress 

Corrosion Cracking 

(ODSCC)

Stress corrosion cracking initiating in the outer diameter (secondary side) 

surface of steam generator tubes. This differs from PWSCC which describes 

inner diameter (primary side) initiated cracking. 

Overload Overload is one of the aging mechanisms that can cause loss of mechanical 

function in ASME Class 1 piping and components (such as constant and 

variable load spring hangers, guides, stops, sliding surfaces, design 

clearances, vibration isolators) fabricated from steel or other materials such 

as Lubrite®

Oxidation Two types of reactions: a) reaction in which there is an increase in valence 

resulting from a loss of electrons, or b) a corrosion reaction in which the 

corroded metal forms an oxide. 

Photolysis Chemical reactions induced or assisted by light.
NUREG-1833 A-80 October 2005

A.4.3 Aging Mechanisms

Standardized 

Expression

Description and Technical Justification

Pitting corrosion Localized corrosion of a metal surface, confined to a point or small area, 

which takes the form of cavities called pits.

Plastic deformation Time-dependent strain, or gradual elastic and plastic deformation, of metal 

that is under constant stress at a value lower than its normal yield strength.

Presence of any salt 

deposits

The surface contamination resulting from the aggressive environment 

associated with the presence of any salt deposits can be an aging 

mechanism causing the aging effect of degradation of insulator quality. 

Although this aging mechanism may be due to temporary, transient 

environmental conditions, the net result may be long-lasting and cumulative.

Primary water stress 

corrosion cracking 

(PWSCC)

PWSCC is an intergranular cracking mechanism which requires the presence 

of high applied and/or residual stress, susceptible tubing microstructures (few 

intergranular carbides), and high temperature. For conditions of concern in 

context of license renewal, this aging mechanism is most likely for nickel 

alloys in PWR environment.

Radiation hardening, 

temperature, humidity, 

sustained vibratory 

loading.

Reduction or loss of isolation function in polymeric vibration isolation 

elements can result from a combination of radiation hardening, temperature, 

humidity, sustained vibratory loading.

Radiation-Induced 

oxidation

Two types of reactions that are affected by radiation: a) reaction in which 

there is an increase in valence resulting from a loss of electrons, or a 

corrosion reaction in which the corroded metal forms an oxide. This is a very 

limited form of oxidation and is referenced in LP-05 for MEB insulation. 

Radiolysis and photolysis 

(UV sensitive materials 

only) of organics

Chemical reactions induced or assisted by radiation. Radiolysis and 

photolysis aging mechanisms can occur in UV-sensitive organic materials.

Reaction With Aggregate For concrete reactions with aggregates are possible due to the presence in 

the concretes of alkalis. These alkalis are introduced mainly by cement, but 

also may come from admixtures, salt-contamination, seawater penetration, or 

solutions of deicing salts. These reactions include alkali-silica reactions, 

cement-aggregate reactions, and aggregate-carbonate reactions. These 

reactions may lead to expansion and cracking. 

Relaxation Relaxation in structural steel anchorage components can be an aging 

mechanism contributing to the aging effect of loss of prestress.

Restraint shrinkage Restraint shrinkage can cause cracking in concrete transverse to the 

longitudinal construction joint.

Selective leaching Also known as dealloying, (e.g., dezincification or graphitic corrosion). 

Selective corrosion of one or more components of a solid solution alloy. The 

selective leaching process involves the preferential removal of one of the 

alloying elements from the material, which leads to the enrichment of the 

remaining alloying elements. Dezincification (loss of zinc from brass greater 

than 15% zinc) and graphitization (removal of iron from cast iron) and 

removal of aluminum from aluminum-bronze (greater than 8% aluminum) are 

examples of such a process. Susceptible materials, high temperatures, 

stagnant-flow conditions, and corrosive environment such as acidic solutions, 

for example, for brasses with high zinc content, and dissolved oxygen, are 

conducive to selective leaching.
October 2005 A-81 NUREG-1833

A.4.3 Aging Mechanisms

Standardized 

Expression

Description and Technical Justification

Service-induced cracking 

or other concrete aging 

mechanisms

Cracking of concrete under load over time of service (e.g., from shrinkage or 

creep) or other concrete aging mechanisms which may include freeze-thaw, 

leaching, aggressive chemicals, reaction with aggregates, corrosion of 

embedded steels, elevated temperatures, irradiation, abrasion and 

cavitations. 

Settlement Settlement of containment structure may occur during the design life due to 

changes in the site conditions (e.g., the water table). The amount of 

settlement depends on the foundation material and is generally determined 

by survey. 

Stress corrosion cracking 

(SCC)

Cracking of a metal produced by the combined action of corrosion and 

tensile stress (applied or residual).

Stress relaxation Many of the bolts in reactor internals are stressed to a cold initial preload. 

When subject to high operating temperatures, over time, these bolts may 

loosen and the preload may be lost. Radiation can also cause stress 

relaxation, in highly stressed members such as bolts. 

Surface contamination Contamination of the surfaces by corrosive constituents.

Sustained vibratory 

loading

Vibratory loading over time.

Thermal Aging See Thermal aging embrittlement.

Thermal aging 

embrittlement

Also termed thermal aging or thermal embrittlement. At operating 

temperatures of 500 to 650°F, cast austenitic stainless steels (CASS) exhibit 

a spinoidal decomposition of the ferrite phase into ferrite-rich and chromiumrich phases. This may give rise to significant embrittlement, i.e., reduction in 

fracture toughness, depending on the amount, morphology, and distribution 

of the ferrite phase and the composition of the steel.

Thermal aging of materials other than CASS is a time- and temperaturedependent degradation mechanism that decreases material toughness. It 

includes temper embrittlement and strain aging embrittlement. Ferritic and 

low alloy steels are subject to both of these embrittlement, but wrought 

stainless steel is not affected by either of the processes. 

Thermal effects, gasket 

creep, and self-loosening

Loss of preload due to gasket creep, thermal effects (including differential 

expansion and creep or stress relaxation), and self-loosening (which includes 

vibration, joint flexing, cyclic shear loads, thermal cycles). 

Thermal and mechanical 

loading

Loads (stress) due to mechanical or thermal (temperature) sources.

Thermal cycling Cycling of the thermal (temperature) loads.

Thermal degradation of 

organic materials

This category includes both short-term thermal degradation and long-term 

thermal degradation. Thermal energy absorbed by polymers can result in 

cross linking and chain scission. Cross linking will generally result in 

increased tensile strength and hardening of material, with some loss of 

flexibility and eventual decrease in elongation-at-break (and increased 

compression set). Scission generally reduces tensile strength. Other 

reactions that may occur include crystallization and chain depolymerization.
NUREG-1833 A-82 October 2005

A.4.3 Aging Mechanisms

Standardized 

Expression

Description and Technical Justification

Thermal fatigue Thermal (temperature) fatigue can result from phenomena such as thermal 

loading, thermal cycling, where there is cycling of the thermal loads and 

thermal stratification and turbulent penetration. Thermal stratification is a 

thermo-hydraulic condition with definitive hot and cold water boundary 

inducing thermal fatigue of the piping. Turbulent penetration is a thermohydraulic condition where hot and cold water mix as a result of turbulent flow 

conditions, leading to thermal fatigue of the piping. The GALL AMP XI.M32 

“One-Time Inspection” inspects for cracking induced by thermal stratification, 

and for turbulent penetration via volumetric (RT or UT) techniques.

Thermoxidative 

degradation of 

organics/thermoplastics

Degradation of organics/thermoplastics via oxidation reactions (loss of 

electrons by a constituent of a chemical reaction) and thermal means. See 

Thermal degradation of organic materials. 

Vibration Vibration may result in component cyclic fatigue as well as cutting, wear, and 

abrasion if left unabated. Vibration is generally induced by external 

equipment operation. It may also result from flow resonance or movement of 

pumps or valves in fluid systems.

Void Swelling Vacancies created in reactor (metallic) materials as a result of irradiation may 

accumulate into voids which may, in turn lead to dimensional changes 

(swelling) of the material. Void swelling may occur after an extended 

incubation period.

Wastage and pitting 

corrosion

Wastage is thinning of component walls due to general corrosion. For pitting 

corrosion see pitting corrosion. 

Water trees Water trees occur when the insulating materials are exposed to long-term, 

continuous electrical stress and moisture; these trees eventually result in 

breakdown of the dielectric and ultimate failure. The growth and propagation 

of water trees is somewhat unpredictable. Water treeing is a degradation and 

long-term failure phenomenon.

Wear Wear is defined as the removal of surface layers due to relative motion 

between two surfaces or under the influence of hard abrasive particles. Wear 

occurs in parts that experience intermittent relative motion or in clamped 

joints where relative motion is not intended but may occur due to a loss of the 

clamping force. 

Weathering Degradation of external surfaces of materials when exposed to outside 

environment.

Wind induced abrasion See abrasion. Carrier of abrading particles is wind rather than water/liquids.
October 2005 A-83 NUREG-1833

A.5 Aging Management Programs

As shown in Chapter IV of NUREG-1833, a number of changes were made to AMPs to reflect 

decisions made through the ISG process. The following table explains how these AMPs are 

referenced in the GALL Rev. 1 AMR tables. 

A.5.1 Listing, Location, and Frequency of AMPs

Table A.5.1 presents a listing of the listing, location, and frequency of amps used in AMR tables. 

The Roman numeral in the second column identifies the chapter in GALL Vol. 2 that the 

structures and/or components are associated with (i.e., “II” for Containment Structures, “III” for 

Structures and Component Supports, “IV” for Reactor Vessel, Internals, and Reactor Coolant 

Systems, “V” for Engineered Safety Features Systems, “VI” for Electrical Systems, “VII” for 

Auxiliary Systems, and “VIII” for Steam and Power Conversion Systems).

A.5.1 Listing, Location, and Frequency of AMPs used in GALL Rev. 1 AMR Tables

Aging Management Program (AMP) Ref. 

Chpt.

Total 

Refs.

Chapter XI.E1, “Electrical Cables and Connections Not Subject to 10 CFR 50.49 

Environmental Qualification Requirements” 

VI 2

Chapter XI.E2, “Electrical Cables and Connections Not Subject to 10 CFR 50.49 

Environmental Qualification Requirements Used in Instrumentation Circuits”

VI 1

Chapter XI.E3, “Inaccessible Medium Voltage Cables Not Subject to 10 CFR 50.49 

Environmental Qualification Requirements”

VI 1

Chapter XI.E4, “Metal Enclosed Bus” VI 2

Chapter XI.E5, “Fuse Holders” VI 1

Chapter XI.E6, “Electrical Connections Not Subject to 10 CFR 50.49 Environmental 

Qualification Requirements”

VI 1

Chapter XI.M1, “ASME Section XI Inservice Inspection, Subsections IWB, IWC, and 

IWD,” for Class 1 components

IV 12

Chapter XI.M1, “ASME Section XI Inservice Inspection, Subsections IWB, IWC, and 

IWD,” for Class 2 components

IV 1

Chapter XI.M1, “ASME Section XI Inservice Inspection, Subsections IWB, IWC, and 

IWD,” for Class 1 components 

For pump casings and valve bodies, screening for susceptibility to thermal aging is not 

necessary. The ASME Section XI inspection requirements are sufficient for managing 

the effects of loss of fracture toughness due to thermal aging embrittlement of CASS 

pump casings and valve bodies. 

IV 1

Chapter XI.M1, “ASME Section XI Inservice Inspection, Subsections IWB, IWC, and 

IWD,” for Class 1 components and Chapter XI.M2, “Water Chemistry” for BWR water

IV 1

Chapter XI.M1, “ASME Section XI Inservice Inspection, Subsections IWB, IWC, and 

IWD,” for Class 1 components and 

Chapter XI.M2, “Water Chemistry,” for BWR water

IV 1

Chapter XI.M1, “ASME Section XI Inservice Inspection, Subsections IWB, IWC, and 

IWD,” for Class 1 components and 

Chapter XI.M2, “Water Chemistry,” for PWR primary water

IV 6
NUREG-1833 A-84 October 2005

A.5.1 Listing, Location, and Frequency of AMPs used in GALL Rev. 1 AMR Tables

Aging Management Program (AMP) Ref. 

Chpt.

Total 

Refs.

Chapter XI.M1, “ASME Section XI Inservice Inspection, Subsections IWB, IWC, and 

IWD” for Class 1 components, and 

Chapter XI.M2, “Water Chemistry,” for PWR primary water 

IV 1

Chapter XI.M1, “ASME Section XI Inservice Inspection, Subsections IWB, IWC, and 

IWD,” for Class 1 components and Chapter XI.M2, “Water Chemistry,” for BWR water 

Because cracking initiated in crevice regions is not amenable to visual inspection, for 

BWRs with a crevice in the access hole covers, an augmented inspection is to include 

ultrasonic testing (UT) or other demonstrated acceptable inspection of the access hole 

cover welds.

IV 1

Chapter XI.M1, “ASME Section XI Inservice Inspection, Subsections IWB, IWC, and 

IWD,” for Class 1 components and 

Chapter XI.M2, “Water Chemistry,” for PWR primary water 

Cracks in the pressurizer cladding could propagate from cyclic loading into the ferrite 

base metal and weld metal. However, because the weld metal between the surge 

nozzle and the vessel lower head is subjected to the maximum stress cycles and the 

area is periodically inspected as part of the ISI program, the existing AMP is adequate 

for managing the effect of pressurizer clad cracking.

IV 1

Chapter XI.M1, “ASME Section XI Inservice Inspection, Subsections IWB, IWC, and 

IWD,” for Class 2 components and 

Chapter XI.M2, “Water Chemistry,” for PWR secondary water. As noted in NRC IN 90-

04, if general and pitting corrosion of the shell is known to exist, the AMP guidelines in 

Chapter XI.M1 may not be sufficient to detect general and pitting corrosion (and the 

resulting corrosion-fatigue cracking), and additional inspection procedures are to be 

developed. This issue is limited to Westinghouse Model 44 and 51 Steam Generators 

where a high stress region exists at the shell to transition cone weld.

IV 1

Chapter XI.M1, “ASME Section XI Inservice Inspection, Subsections IWB, IWC, and 

IWD,” for Class 1 components 

and Chapter XI.M2, “Water Chemistry,” for BWR water. 

The AMP in Chapter XI.M1 is to be augmented to detect cracking due to stress 

corrosion cracking and verification of the program’s effectiveness is necessary to 

ensure that significant degradation is not occurring and the component intended 

function will be maintained during the extended period of operation. An acceptable 

verification program is to include temperature and radioactivity monitoring of the shell 

side water, and eddy current testing of tubes.

IV 1

Chapter XI.M1, “ASME Section XI Inservice Inspection, Subsections IWB, IWC, and 

IWD,” for Class 1 components, and 

Chapter XI.M2, “Water Chemistry,” for PWR primary water and 

For nickel alloy, comply with applicable NRC Orders and provide a commitment in the 

FSAR supplement to implement applicable (1) Bulletins and Generic Letters and (2) 

staff-accepted industry guidelines.

IV 3
October 2005 A-85 NUREG-1833

A.5.1 Listing, Location, and Frequency of AMPs used in GALL Rev. 1 AMR Tables

Aging Management Program (AMP) Ref. 

Chpt.

Total 

Refs.

Chapter XI.M1, “ASME Section XI Inservice Inspection, Subsections IWB, IWC, and 

IWD,” for Class 1 components, and 

Chapter XI.M2, “Water Chemistry,” for PWR primary water and 

Comply with applicable NRC Orders and provide a commitment in the FSAR 

supplement to implement applicable (1) Bulletins and Generic Letters and (2) staffaccepted industry guidelines.

IV 3

Chapter XI.M1, “ASME Section XI Inservice Inspection, Subsections IWB, IWC, and 

IWD,” for Class 1 components and Chapter XI.M2, “Water Chemistry,” for PWR 

primary water and Chapter XI.M11-A, “Nickel-Alloy Penetration Nozzles Welded to the 

Upper Reactor Vessel Closure Heads of Pressurized Water Reactors (PWRs Only)”

IV 2

Chapter XI.M1, “ASME Section XI Inservice Inspection, Subsections IWB, IWC, and 

IWD,” for Class 1 components, and 

Chapter XI.M2, “Water Chemistry,” for BWR water and

XI.M35, “One-Time Inspection of ASME Code Class 1 Small-bore Piping”

IV 1

Chapter XI.M1, “ASME Section XI Inservice Inspection, Subsections IWB, IWC, and 

IWD,” for Class 1 components, and 

Chapter XI.M2, “Water Chemistry,” for PWR water and 

XI.M35, “One-Time Inspection of ASME Code Class 1 Small-bore Piping”

IV 1

Chapter XI.M1, “ASME Section XI Inservice Inspection, Subsections IWB, IWC, and 

IWD,” for Class 1 components 

The AMP in Chapter XI.M1 is to be augmented to detect cracking due to cyclic loading 

and verification of the program’s effectiveness is necessary to ensure that significant 

degradation is not occurring and the component intended function will be maintained 

during the extended period of operation. An acceptable verification program is to 

include temperature and radioactivity monitoring of the shell side water, and eddy 

current testing of tubes.

IV 1

Chapter XI.M2, “Water Chemistry,” for BWR water VII 1

VIII 2

Chapter XI.M2, “Water Chemistry,” for PWR primary water IV 5

V 3

VII 4

Chapter XI.M2, “Water Chemistry,” for PWR secondary water VIII 4

Chapter XI.M2, “Water Chemistry,” for PWR primary water 

The AMP is to be augmented by verifying the absence of cracking due to stress 

corrosion cracking and cyclic loading. A plant specific aging management program is 

to be evaluated.

VII 2
NUREG-1833 A-86 October 2005

A.5.1 Listing, Location, and Frequency of AMPs used in GALL Rev. 1 AMR Tables

Aging Management Program (AMP) Ref. 

Chpt.

Total 

Refs.

Chapter XI.M2, “Water Chemistry,” for PWR primary water. 

The AMP is to be augmented by verifying the absence of cracking due to stress 

corrosion cracking and cyclic loading, or loss of material due to pitting and crevice 

corrosion. An acceptable verification program is to include temperature and 

radioactivity monitoring of the shell side water, and eddy current testing of tubes.

VII 1

Chapter XI.M2, “Water Chemistry” VII 1

The AMP is to be augmented by verifying the effectiveness of water chemistry control. 

See Chapter XI.M32, “One-Time Inspection,” for an acceptable verification program.

VIII 2

Chapter XI.M2, “Water Chemistry” 

The AMP is to be augmented by verifying the effectiveness of water chemistry control. 

See Chapter XI.M32, “One-Time Inspection,” for an acceptable verification program.

V 3

VII 1

VIII 5

Chapter XI.M2, “Water Chemistry” for BWR water 

The AMP is to be augmented by verifying the effectiveness of water chemistry control. 

See Chapter XI.M32, “One-Time Inspection,” for an acceptable verification program.

V 1

Chapter XI.M2, “Water Chemistry” for BWR water 

The AMP is to be augmented by verifying the effectiveness of water chemistry control. 

See Chapter XI.M32, “One-Time Inspection,” for an acceptable verification program.

V 1

IV 3

V 1

VII 7

Chapter XI.M2, “Water Chemistry,” for BWR water 

The AMP is to be augmented by verifying the effectiveness of water chemistry control. 

See Chapter XI.M32, “One-Time Inspection,” for an acceptable verification program.

VIII 6

Chapter XI.M2, “Water Chemistry,” for BWR water 

The AMP is to be augmented by verifying the effectiveness of water chemistry control. 

See Chapter XI.M32, “One-Time Inspection,” for an acceptable verification program.

IV 1

Chapter XI.M2, “Water Chemistry,” for PWR primary water VII 1

The AMP is to be augmented by verifying the effectiveness of water chemistry control. 

See Chapter XI.M32, “One-Time Inspection,” for an acceptable verification program.

VIII 1

Chapter XI.M2, “Water Chemistry,” for PWR secondary water IV 1

The AMP is to be augmented by verifying the effectiveness of water chemistry control. 

See Chapter XI.M32, “One-Time Inspection,” for an acceptable verification program.

VIII 5

Chapter XI.M2, “Water Chemistry,” and Chapter XI.M32 “One-Time Inspection” and 

For nickel alloy welded spray heads, provide a commitment in the FSAR supplement 

to submit a plant-specific AMP delineating commitments to Orders, Bulletins, or 

Generic Letters that inspect stipulated components for cracking of wetted surfaces. 

IV 1
October 2005 A-87 NUREG-1833

A.5.1 Listing, Location, and Frequency of AMPs used in GALL Rev. 1 AMR Tables

Aging Management Program (AMP) Ref. 

Chpt.

Total 

Refs.

Chapter XI.M2, “Water Chemistry,” and

Chapter XI.M1, “ASME Section XI Inservice Inspection, Subsections IWB, IWC, and 

IWD” and, 

For nickel alloy, comply with applicable NRC Orders and provide a commitment in the 

FSAR supplement to submit a plant-specific AMP to implement applicable (1) Bulletins 

and Generic Letters and (2) staff-accepted industry guidelines.

IV 1

Chapter XI.M2, “Water Chemistry,” and

Chapter XI.M1, “ASME Section XI Inservice Inspection, Subsections IWB, IWC, and 

IWD” and, 

Comply with applicable NRC Orders and provide a commitment in the FSAR 

supplement to submit a plant-specific AMP to implement applicable (1) Bulletins and 

Generic Letters and (2) staff-accepted industry guidelines.

IV 1

Chapter XI.M2, “Water Chemistry” and 

Chapter XI.M32 “One-Time Inspection” and, 

For nickel alloy, comply with applicable NRC Orders and provide a commitment in the 

FSAR supplement to submit a plant-specific AMP to implement applicable (1) Bulletins 

and Generic Letters and (2) staff-accepted industry guidelines.

IV 1

Chapter XI.M2, “Water Chemistry” and 

Chapter XI.M32 “One-Time Inspection” or Chapter XI.M1, “ASME Section XI Inservice 

Inspection, Subsections IWB, IWC, and IWD.” 

IV 1

Monitoring and control of primary water chemistry in accordance with the guidelines in 

EPRI TR-105714 (Rev. 3 or later) minimize the potential of SCC, and material 

selection according to NUREG-0313, Rev. 2 guidelines of =0.035% C and =7.5% 

ferrite reduces susceptibility to SCC. 

For CASS components that do not meet either one of the above guidelines, a plantspecific aging management program is to be evaluated. The program is to include 

(a) adequate inspection methods to ensure detection of cracks, and (b) flaw evaluation 

methodology for CASS components that are susceptible to thermal aging 

embrittlement.

IV 1

Chapter XI.M2, “Water Chemistry” for PWR primary water. No further aging 

management review is necessary if the applicant provides a commitment in the FSAR 

supplement to (1) participate in the industry programs for investigating and managing 

aging effects on reactor internals; (2) evaluate and implement the results of the 

industry programs as applicable to the reactor internals; and (3) upon completion of 

these programs, but not less than 24 months before entering the period of extended 

operation, submit an inspection plan for reactor internals to the NRC for review and 

approval.

IV 1
NUREG-1833 A-88 October 2005

A.5.1 Listing, Location, and Frequency of AMPs used in GALL Rev. 1 AMR Tables

Aging Management Program (AMP) Ref. 

Chpt.

Total 

Refs.

Chapter XI.M2, “Water Chemistry” for PWR primary water 

No further aging management review is necessary if the applicant provides a 

commitment in the FSAR supplement to (1) participate in the industry programs for 

investigating and managing aging effects on reactor internals; (2) evaluate and

implement the results of the industry programs as applicable to the reactor internals; 

and (3) upon completion of these programs, but not less than 24 months before 

entering the period of extended operation, submit an inspection plan for reactor 

internals to the NRC for review and approval.

IV 33

Chapter XI.M2, “Water Chemistry,” for PWR primary water 

No further aging management review is necessary if the applicant provides a 

commitment in the FSAR supplement to (1) participate in the industry programs for 

investigating and managing aging effects on reactor internals; (2) evaluate and 

implement the results of the industry programs as applicable to the reactor internals; 

and (3) upon completion of these programs, but not less than 24 months before 

entering the period of extended operation, submit an inspection plan for reactor 

internals to the NRC for review and approval.

IV 1

Chapter XI.M2, “Water Chemistry,” for BWR water, and 

Chapter XI.S3, “ASME Section XI, Subsection IWF”

III 1

Chapter XI.M2, “Water Chemistry” and, 

Monitoring of the spent fuel pool water level in accordance with technical 

specifications and leakage from the leak chase channels.

III 1

Chapter XI.M3, “Reactor Head Closure Studs” IV 3

Chapter XI.M4, “BWR Vessel ID Attachment Welds,” and 

Chapter XI.M2, “Water Chemistry,” for BWR water

IV 1

Chapter XI.M5, “BWR Feedwater Nozzle” IV 1

Chapter XI.M6, “BWR Control Rod Drive Return Line Nozzle” IV 1

IV 3

V 1

Chapter XI.M7, “BWR Stress Corrosion Cracking,” and 

Chapter XI.M2, “Water Chemistry,” for BWR water

VII 1

Chapter XI.M8, “BWR Penetrations,” and 

Chapter XI.M2, “Water Chemistry,” for BWR water

IV 1

Chapter XI.M9, “BWR Vessel Internals,” for core plate and 

Chapter XI.M2, “Water Chemistry” for BWR water

IV 1

Chapter XI.M9, “BWR Vessel Internals,” for core shroud and 

Chapter XI.M2, “Water Chemistry” for BWR water

IV 1
October 2005 A-89 NUREG-1833

A.5.1 Listing, Location, and Frequency of AMPs used in GALL Rev. 1 AMR Tables

Aging Management Program (AMP) Ref. 

Chpt.

Total 

Refs.

Chapter XI.M9, “BWR Vessel Internals,” for lower plenum and 

Chapter XI.M2, “Water Chemistry,” for BWR water

IV 2

Chapter XI.M9, “BWR Vessel Internals,” for shroud support and 

Chapter XI.M2, “Water Chemistry,” for BWR water

IV 1

Chapter XI.M9, “BWR Vessel Internals,” for jet pump assembly and 

Chapter XI.M2, “Water Chemistry,” for BWR water

IV 1

Chapter XI.M9, “BWR Vessel Internals,” for the LPCI coupling and 

Chapter XI.M2, “Water Chemistry,” for BWR water

IV 1

Chapter XI.M9, “BWR Vessel Internals,” for core spray internals and 

Chapter XI.M2, “Water Chemistry,” for BWR water

IV 1

Chapter XI.M9, “BWR Vessel Internals,” for top guide and Chapter XI.M2, “Water 

Chemistry,” for BWR water. For top guides with neutron fluence exceeding the IASCC 

threshold (5E20, E>1 MeV) inspect ten (10) percent of the top guide locations using 

enhanced visual inspection technique, EVT-1 within 12 years, one-half of the 

inspections (5% of locations) to be completed within 6 years. Locations selected for 

examination will be areas that have exceeded the neutron fluence threshold in the 

areas of highest projected neutron fluence. The extent and frequency of examination 

of the top guide is similar to the examination of the control rod drive housing guide 

tube in BWRVIP-47.

IV 1

Chapter XI.M10, “Boric Acid Corrosion” III 2

IV 1

Chapter XI.M10, “Boric Acid Corrosion” V 4

VI 1

VII 4

VIII 2

Chapter XI.M12, “Thermal Aging Embrittlement of Cast Austenitic Stainless Steel IV 2

(CASS)” V 2

Chapter XI.M13, “Thermal Aging and Neutron Irradiation Embrittlement of Cast 

Austenitic Stainless Steel (CASS)”

IV 9

Chapter XI.M17, “Flow-Accelerated Corrosion” IV 3

V 2

VIII 2

Chapter XI.M18, “Bolting Integrity” III 2

IV 10

V 5

VII 6
NUREG-1833 A-90 October 2005

A.5.1 Listing, Location, and Frequency of AMPs used in GALL Rev. 1 AMR Tables

Aging Management Program (AMP) Ref. 

Chpt.

Total 

Refs.

VIII 5

Chapter XI.M18, “Bolting Integrity.” 

The AMP is to be augmented by appropriate inspection to detect cracking if the bolts 

are not otherwise replaced during maintenance.

VII 1

Chapter XI.M19, “Steam Generator Tubing Integrity” and 

Chapter XI.M2, “Water Chemistry,” for PWR primary water

IV 2

Chapter XI.M19, “Steam Generator Tubing Integrity” and 

Chapter XI.M2, “Water Chemistry,” for PWR secondary water

IV 9

Chapter XI.M19, “Steam Generator Tubing Integrity” and 

Chapter XI.M2, “Water Chemistry,” for PWR secondary water. 

IV 1

Chapter XI.M19, “Steam Generator Tubing Integrity” and 

Chapter XI.M2, “Water Chemistry,” for PWR secondary water. 

For plants that could experience denting at the upper support plates, the applicant 

should evaluate potential for rapidly propagating cracks and then develop and take 

corrective actions consistent with Bulletin 88-02, “Rapidly Propagating Cracks in SG 

Tubes.”

IV 1

Chapter XI.M20, “Open-Cycle Cooling Water System” V 7

VII 14

VIII 7

Chapter XI.M21, “Closed-Cycle Cooling Water System” IV 2

V 9

VII 11

VIII 8

Chapter XI.M22, “Boraflex Monitoring” VII 2

Chapter XI.M23, “Inspection of Overhead Heavy Load and Light Load (Related to 

Refueling) Handling Systems”

VII 2

Chapter XI.M24, “Compressed Air Monitoring” VII 2

Chapter XI.M25, “BWR Reactor Water Cleanup System” VII 1

Chapter XI.M26, “Fire Protection” VII 5

Chapter XI.M26, “Fire Protection,” and Chapter XI.M30, “Fuel Oil Chemistry” VII 1

Chapter XI.M26, “Fire Protection” and Chapter XI.S6, “Structures Monitoring Program” VII 4

Chapter XI.M27, “Fire Water System” VII 3

V 1

VII 1

Chapter XI.M28, “Buried Piping and Tanks Surveillance,” or 

Chapter XI.M34, “Buried Piping and Tanks Inspection”

VIII 1
October 2005 A-91 NUREG-1833

A.5.1 Listing, Location, and Frequency of AMPs used in GALL Rev. 1 AMR Tables

Aging Management Program (AMP) Ref. 

Chpt.

Total 

Refs.

Chapter XI.M29, “Aboveground Steel Tanks” VII 1

VIII 1

Chapter XI.M30, “Fuel Oil Chemistry” 

The AMP is to be augmented by verifying the effectiveness of fuel oil chemistry 

control. See Chapter XI.M32, “One-Time Inspection,” for an acceptable verification 

program.

VII 4

Chapter XI.M31, “Reactor Vessel Surveillance” IV 3

Chapter XI.M33, “Selective Leaching of Materials” IV 1

V 5

VII 9

VIII 6

Chapter XI.M36, “External Surfaces Monitoring” V 7

VII 9

VIII 3

Chapter XI.M37, “Flux Thimble Tube Inspection” IV 1

Chapter XI.M38, “Inspection of Internal Surfaces in Miscellaneous Piping and Ducting 

Components”

V 5

VII 2

VIII 2

Chapter XI.M39, “Lubricating Oil Analysis”

The AMP is to be augmented to evaluate the thickness of the lower portion of the tank. 

See Chapter XI.M32, “One-Time Inspection,” for an acceptable verification program.

VII 1

III 1

V 6

VII 5

Chapter XI.M39, “Lubricating Oil Analysis”

The AMP is to be augmented by verifying the effectiveness of the lubricating oil 

analysis program. See Chapter XI.M32, “One-Time Inspection,” for an acceptable 

verification program. VIII 7

No further aging management review is necessary if the applicant provides a 

commitment in the FSAR supplement to (1) participate in the industry programs for 

investigating and managing aging effects on reactor internals; (2) evaluate and 

implement the results of the industry programs as applicable to the reactor internals; 

and (3) upon completion of these programs, but not less than 24 months before 

entering the period of extended operation, submit an inspection plan for reactor 

internals to the NRC for review and approval.

IV 56

A plant-specific aging management program is to be evaluated. III 1

IV 4

V 5

VI 3
NUREG-1833 A-92 October 2005

A.5.1 Listing, Location, and Frequency of AMPs used in GALL Rev. 1 AMR Tables

Aging Management Program (AMP) Ref. 

Chpt.

Total 

Refs.

VII 14

A plant-specific aging management program is to be evaluated. VIII 2

A plant-specific aging management program is to be evaluated. Reference NRC IN 

91-19, “Steam Generator Feedwater Distribution Piping Damage.”

IV 1

A plant-specific aging management program that determines and assesses the 

qualified life of the linings in the environment is to be evaluated.

VII 2

A plant-specific aging management program is to be evaluated. V 1

Reference NRC Information Notice 94-63, “Boric Acid Corrosion of Charging Pump 

Casings Caused by Cladding Cracks.”

VII 1

A plant-specific aging management program is to be evaluated for erosion of the 

orifice due to extended use of the centrifugal HPSI pump for normal charging. See 

LER 50-275/94-023 for evidence of erosion.

V 1

A plant-specific aging management program is to be evaluated because existing 

programs may not be capable of mitigating or detecting crack initiation and growth due 

to SCC in the vessel flange leak detection line.

IV 2

A plant-specific aging management program is to be evaluated for pitting and crevice 

corrosion of tank bottom because moisture and water can egress under the tank due 

to cracking of the perimeter seal from weathering.

V 1

A plant-specific aging management program is to be evaluated for plants located such 

that the potential exists for salt deposits or surface contamination (e.g., in the vicinity 

of salt water bodies or industrial pollution). 

VI 1

Inaccessible Areas: 

For plants with non-aggressive ground water/soil; i.e., pH > 5.5, chlorides < 500 ppm, 

or sulfates <1500 ppm, as a minimum, consider 

(1) Examination of the exposed portions of the below-grade concrete, when excavated 

for any reason, and 

(2) Periodic monitoring of below-grade water chemistry, including consideration of 

potential seasonal variations. 

For plants with aggressive groundwater/soil, and/or where the concrete structural 

elements have experienced degradation, a plant specific AMP accounting for the 

extent of the degradation experienced should be implemented to manage the concrete 

aging during the period of extended operation.

III 1

Plant-specific aging management program 

For any concrete elements that exceed specified temperature limits, further 

evaluations are warranted. Appendix A of ACI 349-85 specifies the concrete 

temperature limits for normal operation or any other long-term period. The 

temperatures shall not exceed 150°F except for local areas which are allowed to have 

increased temperatures not to exceed 200°F.

III 1
October 2005 A-93 NUREG-1833

A.5.1 Listing, Location, and Frequency of AMPs used in GALL Rev. 1 AMR Tables

Aging Management Program (AMP) Ref. 

Chpt.

Total 

Refs.

Plant-specific aging management program 

The implementation of 10 CFR 50.55a and ASME Section XI, Subsection IWL would 

not be able to identify the reduction of strength and modulus due to elevated 

temperature. Thus, for any portions of concrete containment that exceed specified 

temperature limits, further evaluations are warranted. Subsection CC-3400 of ASME 

Section III, Division 2, specifies the concrete temperature limits for normal operation or 

any other long-term period. The temperatures shall not exceed 150°F except for local 

areas, such as around penetrations, which are not allowed to exceed 200°F. If 

significant equipment loads are supported by concrete at temperatures exceeding 

150°F, an evaluation of the ability to withstand the postulated design loads is to be 

made. 

Higher temperatures than given above may be allowed in the concrete if tests and/or 

calculations are provided to evaluate the reduction in strength and this reduction is 

applied to the design allowables.

II 4

Plant-specific aging management program 

The implementation of 10 CFR 50.55a and ASME Section XI, Subsection IWL would 

not be able to identify the reduction of strength and modulus of elasticity due to 

elevated temperature. Thus, for any portions of concrete containment that exceed 

specified temperature limits, further evaluations are warranted. Subsection CC-3400 

of ASME Section III, Division 2, specifies the concrete temperature limits for normal 

operation or any other long-term period. The temperatures shall not exceed 150°F 

except for local areas, such as around penetrations, which are not allowed to exceed 

200°F. If significant equipment loads are supported by concrete at temperatures 

exceeding 150°F, an evaluation of the ability to withstand the postulated design loads 

is to be made. 

Higher temperatures than given above may be allowed in the concrete if tests and/or 

calculations are provided to evaluate the reduction in strength and this reduction is 

applied to the design allowables.

II 1

Chapter XI.S1, “ASME Section XI, Subsection IWE” II 1

Chapter XI.S1, “ASME Section XI, Subsection IWE“ and Chapter XI.S4, “10 CFR 

Part 50, Appendix J”

II 2

Chapter XI.S1, “ASME Section XI, Subsection IWE” 

Leak tightness will be monitored by 10 CFR Part 50, Appendix J Leak Rate Tests for 

pressure boundary, seals and gaskets (including O-rings).

II 1

Chapter XI.S1, “ASME Section XI, Subsection IWE,” 

(Note: IWE examination category E-F, surface examination of dissimilar metal welds, 

is recommended) 

Chapter XI.S4, “10 CFR Part 50, Appendix J” 

II 1
NUREG-1833 A-94 October 2005

A.5.1 Listing, Location, and Frequency of AMPs used in GALL Rev. 1 AMR Tables

Aging Management Program (AMP) Ref. 

Chpt.

Total 

Refs.

Chapter XI.S1, “ASME Section XI, Subsection IWE ” and Chapter XI.S4, “10 CFR 

Part 50, Appendix J” 

Evaluation of 10 CFR 50.55a/ASME Section XI, Subsection IWE is augmented as 

follows: 

(4) Detection of Aging Effects: VT-3 visual inspection may not detect fine cracks.

II 2

Chapter XI.S1, “ASME Section XI, Subsection IWE” and Chapter XI.S4, “10 CFR Part 

50, Appendix J” 

Evaluation of 10 CFR 50.55a/ASME Section XI, Subsection IWE is augmented as 

follows: 

(4) Detection of Aging Effects: 

Transgranular Stress corrosion cracking (TGSCC) is a concern for dissimilar metal 

welds. In the case of bellows assemblies, SCC may cause aging effects particularly if 

the material is not shielded from a corrosive environment. ASME Section XI, 

Subsection IWE covers inspection of these items under examination categories E-B, 

E-F, and E-P (10 CFR Part 50, Appendix J pressure tests). 10 CFR 50.55a identifies 

examination categories E-B and E-F as optional during the current term of operation. 

For the extended period of operation, Examination Categories E-B & E-F, and 

additional appropriate examinations to detect SCC in bellows assemblies and 

dissimilar metal welds are warranted to address this issue. 

(10) Operating Experience: 

IN 92-20 describes an instance of containment bellows cracking, resulting in loss of 

leak tightness.

II 1

Chapter XI.S1, “ASME Section XI, Subsection IWE” 

For inaccessible areas (embedded containment steel shell or liner), loss of material 

due to corrosion is not significant if the following conditions are satisfied: 

Concrete meeting the specifications of ACI 318 or 349 and the guidance of 201.2R 

was used for the containment concrete in contact with the embedded containment 

shell or liner. The concrete is monitored to ensure that it is free of penetrating cracks 

that provide a path for water seepage to the surface of the containment shell or liner. 

The moisture barrier, at the junction where the shell or liner becomes embedded, is 

subject to aging management activities in accordance with ASME Section XI, 

Subsection IWE requirements. Borated water spills and water ponding on the 

containment concrete floor are not common and when detected are cleaned up in a 

timely manner. 

If any of the above conditions cannot be satisfied, then a plant-specific aging 

management program for corrosion is necessary. 

Chapter XI.S4, “10 CFR Part 50, Appendix J”

II 2
October 2005 A-95 NUREG-1833

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Chpt.

Total 

Refs.

Chapter XI.S1, “ASME Section XI, Subsection IWE” 

For inaccessible areas (embedded containment steel shell or liner), loss of material 

due to corrosion is not significant if the following conditions are satisfied:

1. Concrete meeting the requirements of ACI 318 or 349 and the guidance of 201.2R 

was used for the containment concrete in contact with the embedded containment 

shell or liner.

2. The concrete is monitored to ensure that it is free of penetrating cracks that 

provide a path for water seepage to the surface of the containment shell or liner.

3. The moisture barrier, at the junction where the shell or liner becomes embedded, 

is subject to aging management activities in accordance with ASME Section XI, 

Subsection IWE requirements.

Borated water spills and water ponding on the containment concrete floor are not 

common and when detected are cleaned up in a timely manner.

If any of the above conditions cannot be satisfied, then a plant-specific aging 

management program for corrosion is necessary. 

Chapter XI.S4, “10 CFR Part 50, Appendix J”

II 1

Chapter XI.S1, “ASME Section XI, Subsection IWE “ and Chapter XI.S4, “10 CFR 

Part 50, Appendix J” 

Evaluation of 10 CFR 50.55a/ASME Section XI, Subsection IWE is augmented as 

follows: 

(4) Detection of Aging Effects: Stress corrosion cracking (SCC) is a concern for 

dissimilar metal welds. In the case of bellows assemblies, SCC may cause aging 

effects particularly if the material is not shielded from a corrosive environment. ASME 

Code 1995 edition, with addenda through 1996, ASME Section XI, Subsection IWE 

covers inspection of these items under Examination Categories E-B, E-F, and E-P 

(10 CFR Part 50, Appendix J pressure tests). 10 CFR 50.55a identifies examination 

categories E-B and E-F as optional during the current term of operation. For the 

extended period of operation, Examination Categories E-B and E-F, and additional 

appropriate examinations to detect SCC in bellows assemblies and dissimilar metal 

welds are warranted to address this issue. 

(10) Operating Experience: IN 92-20 describes an instance of containment bellows 

cracking, resulting in loss of leak tightness.

II 1

Chapter XI.S2, “ASME Section XI, Subsection IWL” II 1
NUREG-1833 A-96 October 2005

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Chpt.

Total 

Refs.

Chapter XI.S2, “ASME Section XI, Subsection IWL” 

Accessible areas: 

Inspections performed in accordance with IWL will indicate the presence of increase in 

porosity, and permeability due to leaching of calcium hydroxide. 

Inaccessible Areas: 

An aging management program is not necessary, even if reinforced concrete is 

exposed to flowing water, if there is documented evidence that confirms the in-place 

concrete was constructed in accordance with the recommendations in ACI 201.2R.

II 4

Chapter XI.S2, “ASME Section XI, Subsection IWL.” 

Accessible Areas: 

Inspections performed in accordance with IWL will indicate the presence of surface 

cracking due to reaction with aggregates. 

Inaccessible Areas: 

As described in NUREG-1557, investigations, tests, and petrographic examinations of 

aggregates performed in accordance with ASTM C295-54 or ASTM C227-50 can 

demonstrate that those aggregates do not react within reinforced concrete. For 

potentially reactive aggregates, aggregate-reinforced concrete reaction is not 

significant if the concrete was constructed in accordance with ACI 201.2R.Therefore, if 

these conditions are satisfied, aging management is not necessary.

II 5

Chapter XI.S2, “ASME Section XI, Subsection IWL” 

Accessible areas: 

Inspections performed in accordance with IWL will indicate the presence of loss of 

material (spalling, scaling) and surface cracking due to freeze-thaw. 

Inaccessible Areas: 

Evaluation is needed for plants that are located in moderate to severe weathering 

conditions (weathering index >100 day-inch/yr) (NUREG-1557). Documented 

evidence confirms that where the existing concrete had air content of 3% to 6%, 

subsequent inspection did not exhibit degradation related to freeze-thaw. Such 

inspections should be considered a part of the evaluation. 

The weathering index for the continental US is shown in ASTM C33-90, Fig. 1.

II 3
October 2005 A-97 NUREG-1833

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Aging Management Program (AMP) Ref. 

Chpt.

Total 

Refs.

Chapter XI.S2, “ASME Section XI, Subsection IWL.” 

Accessible Areas: 

Inspections performed in accordance with IWL will indicate the presence of surface 

cracking, loss of bond, and loss of material (spalling, scaling) due to corrosion of 

embedded steel. 

Inaccessible Areas: 

For plants with non-aggressive ground water/soil; i.e., pH > 5.5, chlorides < 500 ppm, 

or sulfates <1500 ppm, as a minimum, consider (1) Examination of the exposed 

portions of the below grade concrete, when excavated for any reason, and 

(2) Periodic monitoring of below-grade water chemistry, including consideration of 

potential seasonal variations. 

For plants with aggressive groundwater/soil, and/or where the concrete structural 

elements have experienced degradation, a plant specific AMP accounting for the 

extent of the degradation experienced should be implemented to manage the concrete 

aging during the period of extended operation.

II 3

Chapter XI.S2, “ASME Section XI, Subsection IWL.” 

Accessible Areas: 

Inspections performed in accordance with IWL will indicate the presence of surface 

cracking, loss of bond, and loss of material (spalling, scaling) due to corrosion of 

embedded steel. 

Inaccessible Areas: 

For plants with non-aggressive ground water/soil; i.e., pH > 5.5, chlorides < 500 ppm, 

or sulfates <1500 ppm, as a minimum, consider (1) Examination of the exposed 

portions of the below grade concrete, when excavated for any reason, and 

(2) Periodic monitoring of below-grade water chemistry, including consideration of 

potential seasonal variations. 

For plants with aggressive groundwater/soil, and/or where the concrete structural 

elements have experienced degradation, a plant specific AMP accounting for the 

extent of the degradation experienced should be implemented to manage the concrete 

aging during the period of extended operation.

II 1
NUREG-1833 A-98 October 2005

A.5.1 Listing, Location, and Frequency of AMPs used in GALL Rev. 1 AMR Tables

Aging Management Program (AMP) Ref. 

Chpt.

Total 

Refs.

Chapter XI.S2, “ASME Section XI, Subsection IWL.” 

Accessible Areas: 

Inspections performed in accordance with IWL will indicate the presence of increase in 

porosity and permeability, surface cracking, or loss of material (spalling, scaling) due 

to aggressive chemical attack. 

Inaccessible Areas: 

For plants with non-aggressive ground water/soil; i.e., pH > 5.5, chlorides < 500 ppm, 

or sulfates <1500 ppm, as a minimum, consider (1) Examination of the exposed 

portions of the below grade concrete, when excavated for any reason, and 

(2) Periodic monitoring of below-grade water chemistry, including consideration of 

potential seasonal variations. 

For plants with aggressive groundwater/soil, and/or where the concrete structural 

elements have experienced degradation, a plant specific AMP accounting for the 

extent of the degradation experienced should be implemented to manage the concrete 

aging during the period of extended operation.

II 4

Chapter XI.S3, “ASME Section XI, Subsection IWF” III 2

Chapter XI.S3, “ASME Section XI, Subsection IWF” or 

Chapter XI.S6, “Structures Monitoring Program”

III 1

Chapter XI.S4, “10 CFR Part 50, Appendix J” and 

Plant Technical Specifications

II 1

Chapter XI.S5, “Masonry Wall Program” III 1

Chapter XI.S6, “Structures Monitoring Program” III 7

VI 2

VII 1

Chapter XI.S6, “Structures Monitoring Program” II 3

If a de-watering system is relied upon for control of settlement, then the licensee is to 

ensure proper functioning of the de-watering system through the period of extended 

operation.

III 1

Chapter XI.S6, “Structures Monitoring Program” 

If protective coatings are relied upon to manage the effects of aging, the structures 

monitoring program is to include provisions to address protective coating monitoring 

and maintenance.

III 1

Chapter XI.S6, “Structures Monitoring Program” 

Accessible areas: 

Inspections performed in accordance with the Structures Monitoring Program will 

indicate the presence of cracking, loss of bond, and loss of material (spalling, scaling) 

due to corrosion of embedded steel. 

III 1
October 2005 A-99 NUREG-1833

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Aging Management Program (AMP) Ref. 

Chpt.

Total 

Refs.

Chapter XI.S6, “Structures Monitoring Program”

Accessible Areas: 

Inspections performed in accordance with Structures Monitoring Program will indicate 

the presence of increase in porosity and permeability, cracking, or loss of material

(spalling, scaling) due to aggressive chemical attack.

III 1

Chapter XI.S6, “Structures Monitoring Program” II 1

Erosion of cement from porous concrete subfoundations beneath containment 

basemats is described in NRC IN 97-11. IN 98-26 proposes Maintenance Rule 

Structures Monitoring for managing this aging effect, if applicable. If a de-watering 

system is relied upon for control of erosion of cement from porous concrete 

subfoundations, then the licensee is to ensure proper functioning of the de-watering 

system through the period of extended operation.

III 1

Chapter XI.S6, “Structures Monitoring Program”

Accessible areas: 

Inspections performed in accordance with the Structures Monitoring Program will 

indicate the presence of increase in porosity, and permeability due to leaching of 

calcium hydroxide. 

Inaccessible Areas: 

An aging management program is not necessary, even if reinforced concrete is 

exposed to flowing water, if there is documented evidence that confirms the in-place 

concrete was constructed in accordance with the recommendations in ACI 201.2R.

III 1

Chapter XI.S6, “Structures Monitoring Program” 

Accessible Areas: 

Inspections/evaluations performed in accordance with the Structures Monitoring 

Program will indicate the presence of expansion and cracking due to reaction with 

aggregates. 

Inaccessible Areas: 

As described in NUREG-1557, investigations, tests, and petrographic examinations of 

aggregates performed in accordance with ASTM C295-54 or ASTM C227-50 can 

demonstrate that those aggregates do not react within reinforced concrete. For 

potentially reactive aggregates, aggregate-reinforced concrete reaction is not 

significant if the concrete was constructed in accordance with ACI 201.2R. Therefore, 

if these conditions are satisfied, aging management is not necessary.

III 1
NUREG-1833 A-100 October 2005

A.5.1 Listing, Location, and Frequency of AMPs used in GALL Rev. 1 AMR Tables

Aging Management Program (AMP) Ref. 

Chpt.

Total 

Refs.

Chapter XI.S6, “Structures Monitoring Program” 

Accessible Areas: 

Inspections performed in accordance with the Structures Monitoring Program will 

indicate the presence of loss of material (spalling, scaling) and cracking due to freezethaw. 

Inaccessible Areas: 

Evaluation is needed for plants that are located in moderate to severe weathering 

conditions (weathering index > 100 day-inch/yr) (NUREG-1557). Documented 

evidence to confirm that existing concrete has air content of 3% to 6% and water-tocement ratio of 0.35-0.45, and subsequent inspections did not exhibit degradation 

related to freeze-thaw, should be considered a part of the evaluation. 

The weathering index for the continental US is shown in ASTM C33-90, Fig.1.

III 1

Chapter XI.S6, “Structures Monitoring Program”

Accessible Areas: 

Inspections performed in accordance with the Structures Monitoring Program will 

indicate the cracking, loss of bond, or loss of material (spalling, scaling) due to

corrosion of embedded steel. 

Inaccessible Areas: 

For plants with non-aggressive ground water/soil; i.e., pH > 5.5, chlorides < 500 ppm, 

or sulfates <1500 ppm, as a minimum, consider 

(1) Examination of the exposed portions of the below-grade concrete, when excavated 

for any reason, and 

(2) Periodic monitoring of below-grade water chemistry, including consideration of 

potential seasonal variations. 

For plants with aggressive groundwater/soil, and/or where the concrete structural 

elements have experienced degradation, a plant specific AMP accounting for the 

extent of the degradation experienced should be implemented to manage the concrete 

aging during the period of extended operation.

III 1

Chapter XI.S7, “Regulatory Guide 1.127, Inspection of Water-Control Structures 

Associated with Nuclear Power Plants” or the FERC / US Army Corp of Engineers 

dam inspections and maintenance programs.

III 2
October 2005 A-101 NUREG-1833

A.5.1 Listing, Location, and Frequency of AMPs used in GALL Rev. 1 AMR Tables

Aging Management Program (AMP) Ref. 

Chpt.

Total 

Refs.

Chapter XI.S7, “Regulatory Guide 1.127, Inspection of Water-Control Structures 

Associated with Nuclear Power Plants” or the FERC / US Army Corp of Engineers 

dam inspections and maintenance programs. 

Accessible Areas: 

Inspections/evaluations performed in accordance with “Regulatory Guide 1.127, 

Inspection of Water-Control Structures Associated with Nuclear Power Plants” or the 

FERC / US Army Corp of Engineers dam inspections and maintenance programs will 

indicate the presence of expansion and cracking due to reaction with aggregates. 

Inaccessible areas: 

As described in NUREG-1557, investigations, tests, and petrographic examinations of 

aggregates performed in accordance with ASTM C295-54 or ASTM C227-50 can 

demonstrate that those aggregates do not react within reinforced concrete. For 

potentially reactive aggregates, aggregate-reinforced concrete reaction is not 

significant if the concrete was constructed in accordance with ACI 201.2R. Therefore, 

if these conditions are satisfied, aging management is not necessary.

III 1

Chapter XI.S7, “Regulatory Guide 1.127, Inspection of Water-Control Structures 

Associated with Nuclear Power Plants” or the FERC / US Army Corp of Engineers 

dam inspections and maintenance programs

Accessible Areas: 

Inspections performed in accordance with Chapter XI.S7, “Regulatory Guide 1.127, 

Inspection of Water-Control Structures Associated with Nuclear Power Plants” or the 

FERC / US Army Corp of Engineers dam inspections and maintenance programs will 

indicate the presence of increase in porosity and permeability, loss of strength/ 

leaching of calcium hydroxide 

Inaccessible Areas: 

As described in NUREG-1557, leaching of calcium hydroxide from reinforced concrete 

becomes significant only if the concrete is exposed to flowing water. Even if reinforced 

concrete is exposed to flowing water, such leaching is not significant if the concrete is 

constructed to ensure that it is dense, well-cured, has low permeability, and that 

cracking is well controlled. Cracking is controlled through proper arrangement and 

distribution of reinforcing bars. All of the above characteristics are assured if the 

concrete was constructed with the guidance of ACI 201.2R. Therefore, if these 

conditions are satisfied, aging management is not necessary.

III 1
NUREG-1833 A-102 October 2005

A.5.1 Listing, Location, and Frequency of AMPs used in GALL Rev. 1 AMR Tables

Aging Management Program (AMP) Ref. 

Chpt.

Total 

Refs.

Chapter XI.S7, “Regulatory Guide 1.127, Inspection of Water-Control Structures 

Associated with Nuclear Power Plants” or the FERC / US Army Corp of Engineers 

dam inspections and maintenance programs. 

Accessible Areas: 

Inspections performed in accordance with “Regulatory Guide 1.127, Inspection of 

Water-Control Structures Associated with Nuclear Power Plants” or the FERC / US 

Army Corp of Engineers dam inspections and maintenance programs will indicate the 

presence of increase in porosity and permeability, cracking, or loss of material 

(spalling, scaling) due to aggressive chemical attack. 

Inaccessible areas: 

For plants with non-aggressive ground water/soil; i.e. pH > 5.5, chlorides < 500 ppm, 

or sulfates <1500 ppm, as a minimum, consider: 

(1) Examination of the exposed portions of the below grade concrete, when excavated 

for any reason, and 

(2) Periodic monitoring of below-grade water chemistry, including consideration of 

potential seasonal variations. 

For plants with aggressive groundwater/soil, and/or where the concrete structural 

elements have experienced degradation, a plant specific AMP accounting for the 

extent of the degradation experienced should be implemented to manage the concrete 

aging during the period of extended operation.

III 1

Chapter XI.S7, “Regulatory Guide 1.127, Inspection of Water-Control Structures 

Associated with Nuclear Power Plants” or the FERC / US Army Corp of Engineers 

dam inspections and maintenance programs.

Accessible Areas: 

Inspections performed in accordance with Chapter XI.S7, “Regulatory Guide 1.127, 

Inspection of Water-Control Structures Associated with Nuclear Power Plants” or the 

FERC / US Army Corp of Engineers dam inspections and maintenance programs will 

indicate the presence of loss of material (spalling, scaling) and cracking due to freezethaw. 

Inaccessible Areas: 

As described in NUREG-1557, freeze-thaw does not cause loss of material from 

reinforced concrete in foundations, or in above- and below-grade exterior concrete, for 

plants located in a geographic region of negligible weathering conditions (weathering 

index <100 day-inch/yr). Loss of material from such concrete is not significant at plants 

located in areas in which weathering conditions are severe (weathering index >500 

day-inch/yr) or moderate (100-500 day-inch/yr), provided that the concrete mix design 

meets the air content (entrained air 3-6%) and water-to-cement ratio (0.35-0.45) 

specified in ACI 318-63 or ACI 349-85. Therefore, if these conditions are satisfied, 

aging management is not necessary. 

The weathering index is defined in ASTM C33-90, Table 3, Footnote E. Fig. 1 of 

ASTM C33-90 illustrates the various weathering index regions throughout the U.S.

III 1
October 2005 A-103 NUREG-1833

A.5.1 Listing, Location, and Frequency of AMPs used in GALL Rev. 1 AMR Tables

Aging Management Program (AMP) Ref. 

Chpt.

Total 

Refs.

Chapter XI.S7, “Regulatory Guide 1.127, Inspection of Water-Control Structures 

Associated with Nuclear Power Plants” or the FERC / US Army Corp of Engineers 

dam inspections and maintenance programs. 

Accessible areas: 

As described in NUREG-1557, corrosion of exterior above-grade and interior 

embedded steel is not significant if the steel is not exposed to an aggressive 

environment (concrete pH <11.5 or chlorides >500 ppm). If such steel is exposed to 

an aggressive environment, corrosion is not significant if the concrete in which the 

steel is embedded has a low water-to-cement ratio (0.35-0.45), adequate air 

entrainment (3-6%), low permeability, and is designed in accordance with ACI 318-63 

or ACI 349-85. Therefore, if these conditions are satisfied, aging management is not 

necessary. 

Inaccessible areas: 

For plants with non-aggressive ground water/soil; i.e., pH > 5.5, chlorides < 500 ppm, 

or sulfates <1500 ppm, as a minimum, consider (1) Examination of the exposed 

portions of the below grade concrete, when excavated for any reason, and 

(2) Periodic monitoring of below-grade water chemistry, including consideration of 

potential seasonal variations. 

For plants with aggressive groundwater/soil, and/or where the concrete structural 

elements have experienced degradation, a plant specific AMP accounting for the 

extent of the degradation experienced should be implemented to manage the concrete 

aging during the period of extended operation.

III 1

Chapter XI.S7, “Regulatory Guide 1.127, Inspection of Water-Control Structures 

Associated with Nuclear Power Plants” or the FERC / US Army Corp of Engineers 

dam inspections and maintenance programs.

If protective coatings are relied upon to manage the effects of aging, this AMP is to 

include provisions to address protective coating monitoring and maintenance.

III 1

EQ is a time-limited aging analysis (TLAA) to be evaluated for the period of extended 

operation. See the Standard Review Plan, Section 4.4, “Environmental Qualification 

(EQ) of Electrical Equipment,” for acceptable methods for meeting the requirements of 

10 CFR 54.21I(1)(i) and (ii). 

See Chapter X.E1, “Environmental Qualification (EQ) of Electric Components,” of this 

report for meeting the requirements of 10 CFR 54.21(c)(1)(iii).

VI 1

Fatigue is a time-limited aging analysis (TLAA) to be evaluated for the period of 

extended operation. See the Standard Review Plan, Section 4.3 “Metal Fatigue,” for 

acceptable methods for meeting the requirements of 10 CFR 54.21(c)(1).

III 1

IV 7

V 2

VII 4

Fatigue is a time-limited aging analysis (TLAA) to be evaluated for the period of 

extended operation. See the Standard Review Plan, Section 4.3 “Metal Fatigue,” for 

acceptable methods for meeting the requirements of 10 CFR 54.21(c)(1).

VIII 2
NUREG-1833 A-104 October 2005

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Aging Management Program (AMP) Ref. 

Chpt.

Total 

Refs.

Fatigue is a time-limited aging analysis (TLAA) to be evaluated for the period of 

extended operation. See the Standard Review Plan, Section 4.6, “Containment Liner 

Plate and Penetration Fatigue Analysis” for acceptable methods for meeting the 

requirements of 10 CFR 54.21(c)(1).

II 4

Fatigue is a time-limited aging analysis (TLAA) to be performed for the period of 

extended operation, and, for Class 1 components, environmental effects on fatigue 

are to be addressed. See the Standard Review Plan, Section 4.3 “Metal Fatigue,” for 

acceptable methods for meeting the requirements of 10 CFR 54.21(c)(1).

IV 6

Fatigue is a time-limited aging analysis (TLAA) to be performed for the period of 

extended operation; check ASME Code limits for allowable cycles (less than 7000 

cycles) of thermal stress range. See the Standard Review Plan, Section 4.3 “Metal 

Fatigue,” for acceptable methods for meeting the requirements of 10 CFR 54.21(c)(1).

IV 1

Fatigue is a time-limited aging analysis (TLAA) to be evaluated for the period of 

extended operation for structural girders of cranes that fall within the scope of 10 CFR 

54. See the Standard Review Plan, Section 4.7, “Other Plant-Specific Time-Limited 

Aging Analyses,” for generic guidance for meeting the requirements of 10 CFR 

54.21(c)(1).

VII 1

Neutron irradiation embrittlement is a time-limited aging analysis (TLAA) to be 

evaluated for the period of extended operation for all ferritic materials that have a 

neutron fluence greater than 1E17 n/cm2 (E >1 MeV) at the end of the license renewal 

term. The TLAA is to evaluate the impact of neutron embrittlement on: (a) the RTPTS

value based on the requirements in 10 CFR 50.61, (b) the adjusted reference 

temperature values used for calculation of the plant’s pressure-temperature limits, and 

(c) the Charpy upper shelf energy or the equivalent margins analyses performed in 

accordance with 10 CFR Part 50, Appendix G requirements. See the Standard Review 

Plan, Section 4.2 “Reactor Vessel Neutron Embrittlement” for acceptable methods for 

meeting the requirements of 10 CFR 54.21(c).

IV 1

Neutron irradiation embrittlement is a time-limited aging analysis (TLAA) to be 

evaluated for the period of extended operation for all ferritic materials that have a 

neutron fluence greater than 1E17 n/cm2 (E >1 MeV) at the end of the license renewal 

term. The TLAA is to evaluate the impact of neutron embrittlement on: (a) the RTPTS

value based on the requirements in 10 CFR 50.61, (b) the adjusted reference 

temperature values used for calculation of the plant’s pressure-temperature limits, and 

(c) the Charpy upper shelf energy or the equivalent margins analyses performed in 

accordance with 10 CFR Part 50, Appendix G requirements. The applicant may 

choose to demonstrate that the materials in the inlet, outlet, and safety injection 

nozzles are not controlling for the TLAA evaluations.

IV 1
October 2005 A-105 NUREG-1833

A.5.1 Listing, Location, and Frequency of AMPs used in GALL Rev. 1 AMR Tables

Aging Management Program (AMP) Ref. 

Chpt.

Total 

Refs.

Neutron irradiation embrittlement is a time-limited aging analysis (TLAA) to be 

evaluated for the period of extended operation for all ferritic materials that have a 

neutron fluence greater than 1E17 n/cm2 (E >1 MeV) at the end of the license renewal 

term. In accordance with approved BWRVIP-74, the TLAA is to evaluate the impact of 

neutron embrittlement on: (a) the adjusted reference temperature values used for 

calculation of the plant’s pressure-temperature limits, and (b) the need for inservice 

inspection of circumferential welds, and (c) the Charpy upper shelf energy or the 

equivalent margins analyses performed in accordance with 10 CFR Part 50, Appendix 

G The applicant may choose to demonstrate that the materials of the nozzles are not 

controlling for the TLAA evaluations. See the Standard Review Plan, Section 4.2 

“Reactor Vessel Neutron Embrittlement” for acceptable methods for meeting the 

requirements of 10 CFR 54.21(c).

IV 1

Neutron irradiation embrittlement is a time dependent aging mechanism to be 

evaluated for the period of extended operation for all ferritic materials that have a 

neutron fluence greater than 1017 n/cm2 (E >1 MeV) at the end of the license renewal 

term. Aspects of this evaluation may involve a TLAA. In accordance with approved 

BWRVIP-74, the TLAA is to evaluate the impact of neutron embrittlement on: (a) the 

adjusted reference temperature values used for calculation of the plant’s pressuretemperature limits, (b) the need for inservice inspection of circumferential welds, and 

(c) the Charpy upper shelf energy or the equivalent margins analyses performed in 

accordance with 10 CFR Part 50, Appendix G. Additionally, the applicant is to monitor 

axial beltline weld embrittlement. One acceptable method is to determine that the 

mean RTNDT of the axial beltline welds at the end of the extended period of operation 

is less than the value specified by the Staff in its March 7, 2000 letter (ADAMS 

ML031430372). See the Standard Review Plan, Section 4.2 “Reactor Vessel Neutron 

Embrittlement” for acceptable methods for meeting the requirements of 10 CFR 

54.21(c).

IV 1

Loss of tendon prestress is a time-limited aging analysis (TLAA) to be evaluated for 

the period of extended operation. 

See the Standard Review Plan, Section 4.5, “Concrete Containment Tendon 

Prestress” for acceptable methods for meeting the requirements of 

10 CFR 54.21(c)(1)(i) and (ii). See Chapter X.S1 of this report for meeting the 

requirements of 10 CFR 54.21(c)(1)(iii). 

For periodic monitoring of prestress, see Chapter XI.S2. 

II 1

Growth of intergranular separations (underclad cracks) in low-alloy steel forging heat 

affected zone under austenitic stainless steel cladding is a time-limited aging analysis 

(TLAA) to be evaluated for the period of extended operation for all the SA 508-Cl 2 

forgings where the cladding was deposited with a high heat input welding process. 

The methodology for evaluating an underclad flaw is in accordance with the current 

well-established flaw evaluation procedure and criterion in the ASME Section XI Code. 

See the Standard Review Plan, Section 4.7, “Other Plant-Specific Time-Limited Aging 

Analysis,” for generic guidance for meeting the requirements of 10 CFR 54.21(c).

IV 1

None III 4

IV 6

V 18

VII 24
NUREG-1833 A-106 October 2005

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Chpt.

Total 

Refs.

VIII 15

Grand Total 681
October 2005

A-107 NUREG-1833

A.6. Summary of MEAP Combinations

Table A.6 presents a summary of MEAP combinations contained in the GALL Vol. 2 AMR tables. In column 6 of this table the SRPLR ID is a row identifier useful in matching the information presented in the corresponding table in the corresponding chapter of the 

SRP-LR. In column 7, the related item identifies the item number in Volume 2, Chapters II through VIII, presenting the detailed 

information summarized by this row. The new AMR line-items are identified by nomenclature such as AP-36. The first letter identifies 

the discipline(s) that the precedent is associated with (i.e., “A” for Auxiliary Systems, “C” for Containment Structures, “E” for 

Engineered Safety Features Systems, “L” for Electrical Systems, R” for Reactor Coolant Systems, “S” for Steam and Power 

Conversion Systems, and “T” for “Structures and Component Supports). When present, the second letter “P” identifies that there is a 

precedent for this new MEAP combination. Thus AP-36 is the 36th new AMR line-item that is applied for Auxiliary Systems in Chapter 

VII, Section J. Blank entries in a cell within a column represent a continuation of the same characteristic from the non-blank cell 

above it. For example, all of the rows in the table at the bottom of this page refer to Aluminum as the material.

A.6. Summary of MEAP Combinations in GALL Vol. 2 AMR Tables

Material Environment Aging Effect/ 

Mechanism Aging Management Programs

Referring 

GALL Rev.1

Chapters

SRPLR IDRelated 

Item

Location in 

AMR 

Chapters

Aluminum Air – indoor 

controlled 

(External)

None None VII 95 AP-36 J.

Air – indoor 

uncontrolled

None None III 56 TP-8 B1.1. B1.2. 

B1.3. B2. B3. 

B4. B5. 

Air – indoor 

uncontrolled 

(Internal/External)

None None V 50 EP-3 F.

Air with borated 

water leakage

Loss of material/ boric 

acid corrosion

Chapter XI.M10, “Boric Acid 

Corrosion”

V 45 EP-2 D2. 

VII 88 AP-1 A3. E1. 

Condensation Loss of material/ 

pitting and crevice 

corrosion

A plant-specific aging management 

program is to be evaluated.

VII 27 AP-74 F1. F2. F3. F4.
NUREG-1833

A-108 October 2005

A.6. Summary of MEAP Combinations in GALL Vol. 2 AMR Tables

Material Environment Aging Effect/ 

Mechanism Aging Management Programs

Referring 

GALL Rev.1

Chapters

SRPLR IDRelated 

Item

Location in 

AMR 

Chapters

Fuel oil Loss of material/ 

pitting, crevice, and 

microbiologically 

influenced corrosion

Chapter XI.M30, “Fuel Oil Chemistry” 

The AMP is to be augmented by 

verifying the effectiveness of fuel oil 

chemistry control. See Chapter 

XI.M32, “One-Time Inspection,” for 

an acceptable verification program.

VII 32 AP-35 H1. H2.

Gas None None VII 97 AP-37 J.

VIII 44 SP-23 I.

Raw water Loss of material/ 

pitting and crevice 

corrosion

Chapter XI.M26, “Fire Protection” VII 62 AP-83 G. 

Treated water Loss of material/ 

pitting and crevice 

corrosion

Chapter XI.M2, "Water Chemistry" 

The AMP is to be augmented by 

verifying the effectiveness of water 

chemistry control. See Chapter 

XI.M32, “One-Time Inspection,” for 

an acceptable verification program.

VII 24 AP-38 A4. E3. E4.

VIII 14 SP-24 D1. D2. E. F. 

G.

Chapter XI.M2, "Water Chemistry" 

for BWR water 

The AMP is to be augmented by 

verifying the effectiveness of water 

chemistry control. See Chapter 

XI.M32, “One-Time Inspection,” for 

an acceptable verification program.

V 5 EP-26 D2.
October 2005

A-109 NUREG-1833

A.6. Summary of MEAP Combinations in GALL Vol. 2 AMR Tables

Material Environment Aging Effect/ 

Mechanism Aging Management Programs

Referring 

GALL Rev.1

Chapters

SRPLR IDRelated 

Item

Location in 

AMR 

Chapters

Aluminum, 

copper, 

bronze, 

stainless 

steel, 

galvanized 

steel

Air – outdoor Loss of material/ wind 

induced abrasion and 

fatigue 

Loss of conductor 

strength/ corrosion 

Increased resistance 

of connection/ 

oxidation or loss of 

pre-load

A plant-specific aging management 

program is to be evaluated.

VI 12 LP-09 A.

Aluminum, 

steel

Air – outdoor Loss of material/ wind 

induced abrasion and 

fatigue 

Loss of conductor 

strength/ corrosion 

Increased resistance 

of connection/ 

oxidation or loss of 

pre-load

A plant-specific aging management 

program is to be evaluated.

VI 12 LP-08 A.

Aluminum/ 

Silver Plated 

Aluminum 

Copper/ Silver 

Plated 

Copper; 

Stainless 

steel, steel

Air – indoor and 

outdoor

Loosening of bolted 

connections/ thermal 

cycling and ohmic 

heating

Chapter XI.E4, "Metal Enclosed Bus" VI 7 LP-04 A.

Boraflex Treated borated 

water

Reduction of neutronabsorbing capacity/ 

boraflex degradation

Chapter XI.M22, “Boraflex 

Monitoring”

VII 87 A-86 A2.1-a 

Treated water Reduction of neutronabsorbing capacity/ 

boraflex degradation

Chapter XI.M22, “Boraflex 

Monitoring”

VII 36 A-87 A2.1-a 
NUREG-1833

A-110 October 2005

A.6. Summary of MEAP Combinations in GALL Vol. 2 AMR Tables

Material Environment Aging Effect/ 

Mechanism Aging Management Programs

Referring 

GALL Rev.1

Chapters

SRPLR IDRelated 

Item

Location in 

AMR 

Chapters

Boral, 

boron steel

Treated borated 

water

Reduction of neutronabsorbing capacity 

and loss of material/ 

general corrosion

A plant-specific aging management 

program is to be evaluated.

VII 13 A-88 A2.1-b 

Treated water Reduction of neutronabsorbing capacity 

and loss of material/ 

general corrosion

A plant-specific aging management 

program is to be evaluated.

VII 13 A-89 A2.1-b 

Cast 

austenitic 

stainless steel

Reactor coolant Cracking/ stress 

corrosion cracking

Monitoring and control of primary 

water chemistry in accordance with

the guidelines in EPRI TR-105714 

(Rev. 3 or later) minimize the 

potential of SCC, and material 

selection according to NUREG-0313, 

Rev. 2 guidelines of =0.035% C and 

=7.5% ferrite reduces susceptibility 

to SCC. 

For CASS components that do not 

meet either one of the above 

guidelines, a plant-specific aging 

management program is to be 

evaluated. The program is to include 

(a) adequate inspection methods to 

ensure detection of cracks, and 

(b) flaw evaluation methodology for 

CASS components that are 

susceptible to thermal aging 

embrittlement.

IV 24 R-05 C2.1-e C2.2-g 

C2.5-i 

Reactor coolant 

>250°C (>482°F)

Loss of fracture 

toughness/ thermal 

aging embrittlement

Chapter XI.M12, “Thermal Aging 

Embrittlement of Cast Austenitic 

Stainless Steel (CASS)”

IV 57 R-52 C1.1-g C2.1-f 

C2.2-e C2.5-l 

R A2.2-d
October 2005

A-111 NUREG-1833

A.6. Summary of MEAP Combinations in GALL Vol. 2 AMR Tables

Material Environment Aging Effect/ 

Mechanism Aging Management Programs

Referring 

GALL Rev.1

Chapters

SRPLR IDRelated 

Item

Location in 

AMR 

Chapters

Reactor coolant 

>250°C (>482°F)

Loss of fracture 

toughness/ thermal 

aging embrittlement

Chapter XI.M1, “ASME Section XI 

Inservice Inspection, Subsections 

IWB, IWC, and IWD,” for Class 1 

components 

For pump casings and valve bodies, 

screening for susceptibility to thermal 

aging is not necessary. The ASME 

Section XI inspection requirements 

are sufficient for managing the 

effects of loss of fracture toughness 

due to thermal aging embrittlement 

of CASS pump casings and valve 

bodies. Alternatively, the 

requirements of ASME Code Case 

N-481 for pump casings are 

sufficient for managing the effects of 

loss of fracture toughness due to 

thermal aging embrittlement of CASS 

pump casings.

IV 55 R-08 C1.2-c C1.3-b 

C2.3-c C2.4-c 

Reactor coolant 

>250°C (>482°F) 

and neutron flux

Loss of fracture 

toughness/ thermal 

aging and neutron 

irradiation 

embrittlement

Chapter XI.M13, “Thermal Aging and 

Neutron Irradiation Embrittlement of 

Cast Austenitic Stainless Steel 

(CASS)”

IV 51 R-101 B1.4-c

R-103 B1.5-a

80 R-111 B2.1-g

R-140 B2.5-m

R-153 B3.2-e

R-171 B3.5-f

R-183 B4.3-d
NUREG-1833

A-112 October 2005

A.6. Summary of MEAP Combinations in GALL Vol. 2 AMR Tables

Material Environment Aging Effect/ 

Mechanism Aging Management Programs

Referring 

GALL Rev.1

Chapters

SRPLR IDRelated 

Item

Location in 

AMR 

Chapters

R-191 B4.4-g

R-206 B4.6-e

Treated borated 

water >250°C 

(>482°F)

Loss of fracture 

toughness/ thermal 

aging embrittlement

Chapter XI.M12, “Thermal Aging 

Embrittlement of Cast Austenitic 

Stainless Steel (CASS)”

V 47 E-47 D1.1-b 

Treated water 

>250°C (>482°F)

Loss of fracture 

toughness/ thermal 

aging embrittlement

Chapter XI.M12, “Thermal Aging 

Embrittlement of Cast Austenitic 

Stainless Steel (CASS)”

V 20 E-11 D2.1-d 

Secondary 

feedwater/ steam

Cracking/ stress 

corrosion cracking

Chapter XI.M19, “Steam Generator 

Tubing Integrity” and 

Chapter XI.M2, “Water Chemistry,” 

for PWR secondary water

Chrome IV 74 RP-14 D1.

plated steel; 

stainless 

steel; Nickel 

alloy

Loss of material/ 

crevice corrosion and 

fretting

Chapter XI.M19, “Steam Generator 

Tubing Integrity” and 

Chapter XI.M2, “Water Chemistry,” 

for PWR secondary water

IV 74 RP-15 D1.
October 2005

A-113 NUREG-1833

A.6. Summary of MEAP Combinations in GALL Vol. 2 AMR Tables

Material Environment Aging Effect/ 

Mechanism Aging Management Programs

Referring 

GALL Rev.1

Chapters

SRPLR IDRelated 

Item

Location in 

AMR 

Chapters

II 4 C-33 B3.2.1-h

C-34 A2.2-h 

Air – indoor 

uncontrolled or air 

– outdoor

C-35 B2.2.1-g B1.2.

Reduction of strength 

and modulus/ 

elevated temperature 

(>150°F general; 

>200°F local) C-50 B3.1.2-g

Concrete Plant-specific aging management 

program 

The implementation of 

10 CFR 50.55a and ASME Section 

XI, Subsection IWL would not be 

able to identify the reduction of 

strength and modulus due to 

elevated temperature. Thus, for any 

portions of concrete containment that 

exceed specified temperature limits, 

further evaluations are warranted. 

Subsection CC-3400 of ASME 

Section III, Division 2, specifies the 

concrete temperature limits for 

normal operation or any other longterm period. The temperatures shall 

not exceed 150°F except for local 

areas, such as around penetrations, 

which are not allowed to exceed 

200°F. If significant equipment loads 

are supported by concrete at 

temperatures exceeding 150°F, an 

evaluation of the ability to withstand 

the postulated design loads is to be 

made. 

Higher temperatures than given 

above may be allowed in the 

concrete if tests and/or calculations 

are provided to evaluate the 

reduction in strength and this 

reduction is applied to the design 

allowables.

II 4 C-08 A1.1-h
NUREG-1833

A-114 October 2005

A.6. Summary of MEAP Combinations in GALL Vol. 2 AMR Tables

Material Environment Aging Effect/ 

Mechanism Aging Management Programs

Referring 

GALL Rev.1

Chapters

SRPLR IDRelated 

Item

Location in 

AMR 

Chapters

Air – outdoor Loss of material 

(spalling, scaling) and 

cracking/ freeze-thaw

II 14 C-01 A1.1-a 

C-28 A2.2-a

Chapter XI.S2, “ASME Section XI, 

Subsection IWL” 

Accessible areas: 

Inspections performed in accordance 

with IWL will indicate the presence of 

loss of material (spalling, scaling) 

and surface cracking due to freezethaw. 

Inaccessible Areas: 

Evaluation is needed for plants that 

are located in moderate to severe 

weathering conditions (weathering 

index >100 day-inch/yr) (NUREG1557). Documented evidence 

confirms that where the existing 

concrete had air content of 3% to 

6%, subsequent inspection did not 

exhibit degradation related to freezethaw. Such inspections should be 

considered a part of the evaluation. 

The weathering index for the 

continental US is shown in ASTM 

C33-90, Fig. 1.

C-29 B3.2.1-a 
October 2005

A-115 NUREG-1833

A.6. Summary of MEAP Combinations in GALL Vol. 2 AMR Tables

Material Environment Aging Effect/ 

Mechanism Aging Management Programs

Referring 

GALL Rev.1

Chapters

SRPLR IDRelated 

Item

Location in 

AMR 

Chapters

Concrete Any Cracking due to 

expansion/ reaction 

with aggregates

II 15 C-04 A1.1-d 

C-38 A2.2-d

C-39 B2.2.1-c B1.2.

C-40 B3.2.1-d

Chapter XI.S2, “ASME Section XI, 

Subsection IWL.” 

Accessible Areas: 

Inspections performed in accordance 

with IWL will indicate the presence of 

surface cracking due to reaction with 

aggregates. 

Inaccessible Areas: 

As described in NUREG-1557, 

investigations, tests, and 

petrographic examinations of 

aggregates performed in accordance 

with ASTM C295-54 or ASTM C227-

50 can demonstrate that those 

aggregates do not react within 

reinforced concrete. For potentially 

reactive aggregates, aggregatereinforced concrete reaction is not 

significant if the concrete was 

constructed in accordance with ACI 

201.2R.Therefore, if these conditions 

are satisfied, aging management is 

not necessary.

C-51 B3.1.2-c 
NUREG-1833

A-116 October 2005

A.6. Summary of MEAP Combinations in GALL Vol. 2 AMR Tables

Material Environment Aging Effect/ 

Mechanism Aging Management Programs

Referring 

GALL Rev.1

Chapters

SRPLR IDRelated 

Item

Location in 

AMR 

Chapters

Concrete Ground water/soil 

or air-indoor 

uncontrolled or airoutdoor

Increase in porosity 

and permeability, 

cracking, loss of 

material (spalling, 

scaling)/ aggressive 

chemical attack

II 1 C-03 A1.1-c 

C-26 B.2.2.1-b 

B.1.2. 

Chapter XI.S2, “ASME Section XI, 

Subsection IWL.” 

Accessible Areas: 

Inspections performed in accordance 

with IWL will indicate the presence of 

increase in porosity and permeability, 

surface cracking, or loss of material 

(spalling, scaling) due to aggressive 

chemical attack. 

Inaccessible Areas: 

For plants with non-aggressive 

ground water/soil; i.e., pH > 5.5, 

chlorides < 500 ppm, or sulfates 

<1500 ppm, as a minimum, consider 

(1) Examination of the exposed 

portions of the below grade concrete, 

when excavated for any reason, and 

(2) Periodic monitoring of belowgrade water chemistry, including 

consideration of potential seasonal 

variations. 

For plants with aggressive 

groundwater/soil, and/or where the 

concrete structural elements have 

experienced degradation, a plant 

specific AMP accounting for the 

extent of the degradation 

experienced should be implemented 

to manage the concrete aging during 

the period of extended operation.

C-27 B3.2.1-c
October 2005

A-117 NUREG-1833

A.6. Summary of MEAP Combinations in GALL Vol. 2 AMR Tables

Material Environment Aging Effect/ 

Mechanism Aging Management Programs

Referring 

GALL Rev.1

Chapters

SRPLR IDRelated 

Item

Location in 

AMR 

Chapters

Concrete Ground water/soil Increase in porosity 

and permeability, 

cracking, loss of 

material (spalling, 

scaling)/ aggressive 

chemical attack

Chapter XI.S2, “ASME Section XI, 

Subsection IWL.” 

Accessible Areas: 

Inspections performed in accordance 

with IWL will indicate the presence of 

increase in porosity and permeability, 

surface cracking, or loss of material 

(spalling, scaling) due to aggressive 

chemical attack. 

Inaccessible Areas: 

For plants with non-aggressive 

ground water/soil; i.e., pH > 5.5, 

chlorides < 500 ppm, or sulfates 

<1500 ppm, as a minimum, consider 

(1) Examination of the exposed 

portions of the below grade concrete, 

when excavated for any reason, and 

(2) Periodic monitoring of belowgrade water chemistry, including 

consideration of potential seasonal 

variations. 

For plants with aggressive 

groundwater/soil, and/or where the 

concrete structural elements have 

experienced degradation, a plant 

specific AMP accounting for the 

extent of the degradation 

experienced should be implemented 

to manage the concrete aging during 

the period of extended operation.

II 1 C-25 A2.2-c 

B.3.1.2-b
NUREG-1833

A-118 October 2005

A.6. Summary of MEAP Combinations in GALL Vol. 2 AMR Tables

Material Environment Aging Effect/ 

Mechanism Aging Management Programs

Referring 

GALL Rev.1

Chapters

SRPLR IDRelated 

Item

Location in 

AMR 

Chapters

Concrete Soil Cracks and distortion 

due to increased 

stress levels from 

settlement

II 2 C-06 B2.2.1-e 

B3.2.1-f B1.2. 

C-36 A2.2-f B3.1.2-

e 

Chapter XI.S6, “Structures 

Monitoring Program” 

If a de-watering system is relied 

upon for control of settlement, then 

the licensee is to ensure proper 

functioning of the de-watering 

system through the period of 

extended operation. 

C-37 A1.1-f 

Water – flowing Increase in porosity, 

permeability/ leaching 

of calcium hydroxide

II 15 C-02 A1.1-b 

C-32 B3.2.1-b

C-30 A2.2-b B3.1.2-

a

Chapter XI.S2, “ASME Section XI, 

Subsection IWL” 

Accessible areas: 

Inspections performed in accordance 

with IWL will indicate the presence of 

increase in porosity, and permeability 

due to leaching of calcium hydroxide. 

Inaccessible Areas: 

An aging management program is 

not necessary, even if reinforced 

concrete is exposed to flowing water, 

if there is documented evidence that 

confirms the in-place concrete was 

constructed in accordance with the 

recommendations in ACI 201.2R.

C-31 B2.2.1-a B1.2. 

Concrete 

block

Air – indoor 

uncontrolled or air 

– outdoor

Cracking due to 

restraint shrinkage, 

creep, and aggressive 

environment

Chapter XI.S5, “Masonry Wall 

Program”

III 43 T-12 A1.3-a A2.3-a 

A3.3-a A5.3-a 

A6.3-a
October 2005

A-119 NUREG-1833

A.6. Summary of MEAP Combinations in GALL Vol. 2 AMR Tables

Material Environment Aging Effect/ 

Mechanism Aging Management Programs

Referring 

GALL Rev.1

Chapters

SRPLR IDRelated 

Item

Location in 

AMR 

Chapters

Concrete; 

porous 

concrete

Water – flowing Reduction in 

foundation strength, 

cracking, differential 

settlement/ erosion of 

porous concrete 

subfoundation

Chapter XI.S6, “Structures 

Monitoring Program” 

Erosion of cement from porous 

concrete subfoundations beneath 

containment basemats is described 

in NRC IN 97-11. IN 98-26 proposes 

Maintenance Rule Structures 

Monitoring for managing this aging 

effect, if applicable. If a de-watering 

system is relied upon for control of 

erosion of cement from porous 

concrete subfoundations, then the 

licensee is to ensure proper 

functioning of the de-watering 

system through the period of 

extended operation.

II 3 C-07 A1.1-g A2.2-g 

B2.2.1-f 

B3.1.2-f 

B3.2.1-g B1.2.
NUREG-1833

A-120 October 2005

A.6. Summary of MEAP Combinations in GALL Vol. 2 AMR Tables

Material Environment Aging Effect/ 

Mechanism Aging Management Programs

Referring 

GALL Rev.1

Chapters

SRPLR IDRelated 

Item

Location in 

AMR 

Chapters

Concrete; 

steel

Air – indoor 

uncontrolled or air 

– outdoor

Cracking, loss of 

bond, and loss of 

material (spalling, 

scaling)/ corrosion of 

embedded steel

II 1 C-05 A1.1-e 

C-41 B2.2.1-d 

B1.2. 

C-42 B3.2.1-e

Chapter XI.S2, “ASME Section XI, 

Subsection IWL.” 

Accessible Areas: 

Inspections performed in accordance 

with IWL will indicate the presence of 

surface cracking, loss of bond, and 

loss of material (spalling, scaling) 

due to corrosion of embedded steel. 

Inaccessible Areas: 

For plants with non-aggressive 

ground water/soil; i.e., pH > 5.5, 

chlorides < 500 ppm, or sulfates 

<1500 ppm, as a minimum, consider 

(1) Examination of the exposed

portions of the below grade concrete, 

when excavated for any reason, and 

(2) Periodic monitoring of belowgrade water chemistry, including 

consideration of potential seasonal 

variations. 

For plants with aggressive 

groundwater/soil, and/or where the 

concrete structural elements have 

experienced degradation, a plant 

specific AMP accounting for the 

extent of the degradation 

experienced should be implemented 

to manage the concrete aging during 

the period of extended operation. 

II 1 C-43 A2.2-e B3.1.2-

d 
October 2005

A-121 NUREG-1833

A.6. Summary of MEAP Combinations in GALL Vol. 2 AMR Tables

Material Environment Aging Effect/ 

Mechanism Aging Management Programs

Referring 

GALL Rev.1

Chapters

SRPLR IDRelated 

Item

Location in 

AMR 

Chapters

Copper alloy Air – indoor Fatigue/ohmic 

heating, thermal 

cycling, electrical 

transients, frequent 

manipulation, 

vibration, chemical 

contamination, 

corrosion, and 

oxidation

Chapter XI.E5, "Fuse Holders" VI 6 LP-01 A.

Air – indoor 

uncontrolled 

(External)

None None V 53 EP-10 F.

VIII 41 SP-6 I.

Closed cycle 

cooling water

Loss of material/ 

pitting, crevice, and 

galvanic corrosion

Chapter XI.M21, “Closed-Cycle 

Cooling Water System”

IV 54 RP-11 C2.

V 29 EP-13 A. D1. D2.

EP-36 A. B. D1. D2.

VII 51 AP-12 A3. A4. C2. 

E1. E3. E4. 

F1. F2. F3. F4. 

H1. H2.

AP-34 E1. F1. F3. 

VIII 26 SP-8 E. F. G.

Reduction of heat 

transfer/ fouling

Chapter XI.M21, “Closed-Cycle 

Cooling Water System”

V 30 EP-39 A. 

VII 52 AP-80 C2. F1. F2. 

F3.

VIII 27 SP-57 E. 
NUREG-1833

A-122 October 2005

A.6. Summary of MEAP Combinations in GALL Vol. 2 AMR Tables

Material Environment Aging Effect/ 

Mechanism Aging Management Programs

Referring 

GALL Rev.1

Chapters

SRPLR IDRelated 

Item

Location in 

AMR 

Chapters

Condensation 

(External)

Loss of material/ 

pitting and crevice 

corrosion

A plant-specific aging management 

program is to be evaluated.

VII 25 A-46 F1.2-a F2.2-a 

F3.2-a F4.2-a 

Condensation 

(Internal)

Loss of material/ 

pitting and crevice 

corrosion

A plant-specific aging management 

program is to be evaluated.

VII 28 AP-78 G.

Dried Air None None VII 98 AP-8 J.

Fuel oil Loss of material/ 

pitting, crevice, and 

microbiologically 

influenced corrosion

Chapter XI.M30, “Fuel Oil Chemistry” 

The AMP is to be augmented by 

verifying the effectiveness of fuel oil 

chemistry control. See Chapter 

XI.M32, “One-Time Inspection,” for 

an acceptable verification program.

VII 32 AP-44 H1. H2. G.

Gas None None V 56 EP-9 F.

VII 97 AP-9 J.

VIII 44 SP-5 I.

Lubricating oil Loss of material/ 

pitting and crevice 

corrosion

Chapter XI.M39, "Lubricating Oil 

Analysis" 

The AMP is to be augmented by 

verifying the effectiveness of the 

lubricating oil analysis program. See 

Chapter XI.M32, “One-Time 

Inspection,” for an acceptable 

verification program.

V 6 EP-45 A. D1. D2. 

VII 26 AP-47 C1. C2. E1. 

E4. G. H2.

VIII 17 SP-32 A. D1. D2. E. 

G.
October 2005

A-123 NUREG-1833

A.6. Summary of MEAP Combinations in GALL Vol. 2 AMR Tables

Material Environment Aging Effect/ 

Mechanism Aging Management Programs

Referring 

GALL Rev.1

Chapters

SRPLR IDRelated 

Item

Location in 

AMR 

Chapters

Reduction of heat 

transfer/ fouling

Chapter XI.M39, "Lubricating Oil 

Analysis" 

The AMP is to be augmented by 

verifying the effectiveness of the 

lubricating oil analysis program. See 

Chapter XI.M32, “One-Time 

Inspection,” for an acceptable 

verification program.

V 9 EP-47 A. D1. D2. 

VIII 9 SP-53 G.

Raw water Loss of material/ 

pitting and crevice 

corrosion

Chapter XI.M20, “Open-Cycle 

Cooling Water System”

VII 78 A-43 C3.1-a C3.2-a 

Loss of material/ 

pitting, crevice, and 

microbiologically 

influenced corrosion

Chapter XI.M20, “Open-Cycle 

Cooling Water System”

VII 80 AP-45 H2. 

VIII 32 SP-31 A. E. F. G.

Loss of material/ 

pitting, crevice, and 

microbiologically 

influenced corrosion, 

and fouling

Chapter XI.M27, “Fire Water System” VII 70 A-45 G.6-b 

Chapter XI.M20, “Open-Cycle 

Cooling Water System”

VII 81 A-44 C1.1-a C1.2-a 

Loss of material/ 

pitting, crevice, 

galvanic, and 

microbiologically 

influenced corrosion, 

and fouling

Chapter XI.M20, “Open-Cycle 

Cooling Water System”

VII 82 A-65 C1.3-a
NUREG-1833

A-124 October 2005

A.6. Summary of MEAP Combinations in GALL Vol. 2 AMR Tables

Material Environment Aging Effect/ 

Mechanism Aging Management Programs

Referring 

GALL Rev.1

Chapters

SRPLR IDRelated 

Item

Location in 

AMR 

Chapters

Reduction of heat 

transfer/ fouling

Chapter XI.M20, “Open-Cycle 

Cooling Water System”

VII 83 A-72 C1.3-b 

VIII 34 SP-56 E. F. G.

Treated water Loss of material/ 

pitting and crevice 

corrosion

Chapter XI.M2, "Water Chemistry" 

The AMP is to be augmented by 

verifying the effectiveness of water 

chemistry control. See Chapter 

XI.M32, “One-Time Inspection,” for 

an acceptable verification program.

VIII 14 SP-61 A. F.

Loss of material/ 

pitting, crevice, and 

galvanic corrosion

Chapter XI.M2, “Water Chemistry,” 

for BWR water 

The AMP is to be augmented by 

verifying the effectiveness of water 

chemistry control. See Chapter 

XI.M32, “One-Time Inspection,” for 

an acceptable verification program.

VII 31 AP-64 A4. E3. E4.

Reduction of heat 

transfer/ fouling

Chapter XI.M2, “Water Chemistry” 

The AMP is to be augmented by 

verifying the effectiveness of water 

chemistry control. See Chapter 

XI.M32, “One-Time Inspection,” for 

an acceptable verification program.

VIII 8 SP-58 E. F. G. 

Copper alloy 

<15% Zn

Air with borated 

water leakage

None None V 57 EP-12 F.

VII 99 AP-11 J.

Loss of material/ boric 

acid corrosion

Chapter XI.M10, “Boric Acid 

Corrosion”

V 45 EP-38 E.

VII 88 AP-66 I.
October 2005

A-125 NUREG-1833

A.6. Summary of MEAP Combinations in GALL Vol. 2 AMR Tables

Material Environment Aging Effect/ 

Mechanism Aging Management Programs

Referring 

GALL Rev.1

Chapters

SRPLR IDRelated 

Item

Location in 

AMR 

Chapters

Closed cycle 

cooling water

Loss of material/ 

selective leaching

Chapter XI.M33, “Selective Leaching 

of Materials”

IV 56 RP-12 C2.

V 41 EP-27 A. B. D1. D2.

EP-37 A. B. D1. D2.

VII 84 AP-43 A3. A4. C2.E1. 

E3. E4. F1. 

F2. F3. F4. 

H1. H2.

VIII 35 SP-29 E. F. G.

Raw water Loss of material/ 

selective leaching

Chapter XI.M33, “Selective Leaching 

of Materials”

VII 84 A-47 C1.1-a C1.2-a 

C3.1-a C3.2-a 

G.6-b H2. 

A-66 C1.3-a

VIII 35 SP-30 A. E. F. G.

Treated water Loss of material/ 

selective leaching

Chapter XI.M33, “Selective Leaching 

of Materials”

VII 84 AP-32 A4. C2. E3. 

E4.

AP-65 E1. F1. F3. 

VIII 35 SP-55 E. F. G.

Elastomers Air – indoor and 

outdoor

Hardening and loss of 

strength/ elastomer 

degradation

Chapter XI.S6, “Structures 

Monitoring Program”

VI 10 LP-10 A.

Air – indoor 

uncontrolled

Hardening and loss of 

strength/ elastomer 

degradation

A plant-specific aging management 

program is to be evaluated.

V 11 E-06 B.1-b B.2-b 

Increased hardness, 

shrinkage and loss of 

strength/ weathering

Chapter XI.M26, “Fire Protection” VII 61 A-19 G.1-a G.2-a 

G.3-a G.4-a 
NUREG-1833

A-126 October 2005

A.6. Summary of MEAP Combinations in GALL Vol. 2 AMR Tables

Material Environment Aging Effect/ 

Mechanism Aging Management Programs

Referring 

GALL Rev.1

Chapters

SRPLR IDRelated 

Item

Location in 

AMR 

Chapters

Air – indoor 

uncontrolled 

(External)

Loss of material/ wear A plant-specific aging management 

program is to be evaluated.

VII 34 A-73 F1.1-c F2.1-c 

F3.1-c F4.1-c 

Air – indoor 

uncontrolled 

(Internal)

Loss of material/ wear A plant-specific aging management 

program is to be evaluated.

VII 34 A-18 F1.1-c F2.1-c 

F3.1-c F4.1-c 

Air – indoor 

uncontrolled 

(Internal/ External)

Hardening and loss of 

strength/ elastomer 

degradation

A plant-specific aging management 

program is to be evaluated.

VII 11 A-17 F1.1-b F1.4-b 

F2.1-b F2.4-b 

F3.1-b F3.4-b 

F4.1-b 

Air – outdoor Increased hardness, 

shrinkage and loss of 

strength/ weathering

Chapter XI.M26, “Fire Protection” VII 61 A-20 G.1-a G.2-a 

G.3-a G.4-a 

Raw water Hardening and loss of 

strength/ elastomer 

degradation

Chapter XI.M20, “Open-Cycle 

Cooling Water System”

VII 75 AP-75 C1.

Loss of material/ 

erosion

Chapter XI.M20, “Open-Cycle 

Cooling Water System”

VII 75 AP-76 C1.

Treated borated 

water

Hardening and loss of 

strength/ elastomer 

degradation

A plant-specific aging management 

program that determines and 

assesses the qualified life of the 

linings in the environment is to be 

evaluated.

VII 12 A-15 A3.2-a A3.2-d 

A3.3-a A3.3-d 

A3.5-a A3.5-c 

Treated water Hardening and loss of 

strength/ elastomer 

degradation

A plant-specific aging management 

program that determines and 

assesses the qualified life of the 

linings in the environment is to be 

evaluated.

VII 12 A-16 A4.2-a A4.2-b 

A4.3-a A4.3-b 

A4.5-a A4.5-b 
October 2005

A-127 NUREG-1833

A.6. Summary of MEAP Combinations in GALL Vol. 2 AMR Tables

Material Environment Aging Effect/ 

Mechanism Aging Management Programs

Referring 

GALL Rev.1

Chapters

SRPLR IDRelated 

Item

Location in 

AMR 

Chapters

Elastomers 

such as 

EPDM rubber

Various Loss of sealing/ 

deterioration of seals, 

gaskets, and moisture 

barriers (caulking, 

flashing, and other 

sealants)

Chapter XI.S6, “Structures 

Monitoring Program”

III 44 TP-7 A6.5. 

Elastomers, 

rubber and 

other similar 

materials

Air – indoor 

uncontrolled or air 

– outdoor

Loss of sealing; 

Leakage through 

containment/ 

deterioration of seals, 

gaskets, and moisture 

barriers (caulking, 

flashing, and other 

sealants)

Chapter XI.S1, “ASME Section XI, 

Subsection IWE” 

Leak tightness will be monitored by 

10 CFR Part 50, Appendix J Leak 

Rate Tests for pressure boundary, 

seals and gaskets (including Orings).

II 16 C-18 A3.3-a B4.3-a

Galvanized 

steel

Air – indoor 

controlled 

(External)

None None V 51 EP-14 F.

Air – indoor 

uncontrolled

None None III 56 TP-11 B1.1. B1.2. 

B1.3. B2. B3. 

B4. B5. 

VII 92 AP-13 J.

Galvanized 

steel, 

aluminum

Air with borated 

water leakage

Loss of material/ boric 

acid corrosion

Chapter XI.M10, “Boric Acid 

Corrosion”

III 55 TP-3 B1.1. B1.2. 

B1.3. B2. B3. 

B4. B5. 

Galvanized 

steel, 

aluminum, 

stainless steel

Air – outdoor Loss of material/ 

pitting and crevice 

corrosion

Chapter XI.S6, “Structures 

Monitoring Program”

III 50 TP-6 B2. B4.

Glass Air None None VII 93 AP-48 J.

VIII 40 SP-33 I.
NUREG-1833

A-128 October 2005

A.6. Summary of MEAP Combinations in GALL Vol. 2 AMR Tables

Material Environment Aging Effect/ 

Mechanism Aging Management Programs

Referring 

GALL Rev.1

Chapters

SRPLR IDRelated 

Item

Location in 

AMR 

Chapters

Air – indoor 

uncontrolled 

(External)

None None V 52 EP-15 F.

VII 93 AP-14 J.

VIII 40 SP-9 I.

Fuel oil None None VII 93 AP-49 J.

Lubricating oil None None V 52 EP-16 F.

VII 93 AP-15 J.

VIII 40 SP-10 I.

Raw water None None V 52 EP-28 F.

VII 93 AP-50 J.

VIII 40 SP-34 I.

Treated borated 

water

None None V 52 EP-30 F.

VII 93 AP-52 J.

Treated water None None V 52 EP-29 F.

VII 93 AP-51 J.

VIII 40 SP-35 I.

Gray cast iron Closed cycle 

cooling water

Loss of material/ 

selective leaching

Chapter XI.M33, “Selective Leaching 

of Materials”

V 42 EP-52 D1.

VII 85 A-50 C2.3-a F3. 

Raw water Loss of material/ 

selective leaching

Chapter XI.M33, “Selective Leaching 

of Materials”

VII 85 A-51 C1.5-a C3. G. 

H2. 

VIII 36 SP-28 A. G.

Soil Loss of material/

selective leaching

Chapter XI.M33, “Selective Leaching 

of Materials" 

V 43 EP-54 B. D1. D2. 
October 2005

A-129 NUREG-1833

A.6. Summary of MEAP Combinations in GALL Vol. 2 AMR Tables

Material Environment Aging Effect/ 

Mechanism Aging Management Programs

Referring 

GALL Rev.1

Chapters

SRPLR IDRelated 

Item

Location in 

AMR 

Chapters

VII 85 A-02 C1.1-c C3. G. 

H1. H2.

VIII 36 SP-26 E. G.

Treated water Loss of material/ 

selective leaching

Chapter XI.M33, “Selective Leaching 

of Materials”

V 44 E-43 A. D1. 

VII 85 AP-31 A3. A4. C2. 

E1. E3. E4. 

F1. F2. F4. G.

VIII 36 SP-27 A. E. F. G.

Air with reactor 

coolant leakage

Cracking/ stress 

corrosion cracking

Chapter XI.M3, “Reactor Head 

Closure Studs”

High-strength IV 71 R-71 A2.1-c

low alloy steel 

Maximum 

tensile 

strength < 

1172 MPa 

(<170 ksi)

Cracking/ stress 

corrosion cracking 

and intergranular 

stress corrosion 

cracking

Chapter XI.M3, “Reactor Head 

Closure Studs”

IV 50 R-60 A1.1-c
NUREG-1833

A-130 October 2005

A.6. Summary of MEAP Combinations in GALL Vol. 2 AMR Tables

Material Environment Aging Effect/ 

Mechanism Aging Management Programs

Referring 

GALL Rev.1

Chapters

SRPLR IDRelated 

Item

Location in 

AMR 

Chapters

Loss of material/ wear Chapter XI.M3, “Reactor Head 

Closure Studs”

IV 71 R-72 A2.1-d

High-strength 

low-alloy 

steel, 

stainless steel

Air with reactor 

coolant leakage

Cracking/ stress 

corrosion cracking

Chapter XI.M18, “Bolting Integrity” IV 52 R-11 C2.3-e C2.4-e 

C2.5-n 

High-strength 

steel

Air with steam or 

water leakage

Cracking/ cyclic 

loading, stress 

corrosion cracking

Chapter XI.M18, “Bolting Integrity” V 21 E-03 E.2-b 

VII 41 A-04 I.2-b 

VIII 21 S-03 H.2-b 

Chapter XI.M18, “Bolting Integrity.” 

The AMP is to be augmented by 

appropriate inspection to detect 

cracking if the bolts are not otherwise 

replaced during maintenance.

VII 10 A-104 E1.5-a 

Insulation 

material –

bakelite, 

phenolic 

melamine or 

ceramic, 

molded 

polycarbonate 

and other

Adverse localized 

environment 

caused by heat, 

radiation, or 

moisture in the 

presence of 

oxygen or > 60-

year service 

limiting 

temperature

Embrittlement, 

cracking, melting, 

discoloration, 

swelling, or loss of 

dielectric strength 

leading to reduced 

insulation resistance 

(IR); electrical failure/ 

degradation (Thermal/ 

thermoxidative) of 

organics/thermoplasti

cs, radiation-induced 

oxidation, moisture 

intrusion and ohmic 

heating

Chapter XI.E1, “Electrical Cables 

and Connections Not Subject to 10 

CFR 50.49 Environmental 

Qualification Requirements” 

VI 2 LP-03 A.
October 2005

A-131 NUREG-1833

A.6. Summary of MEAP Combinations in GALL Vol. 2 AMR Tables

Material Environment Aging Effect/ 

Mechanism Aging Management Programs

Referring 

GALL Rev.1

Chapters

SRPLR IDRelated 

Item

Location in 

AMR 

Chapters

Air – indoor 

uncontrolled 

(Internal/External)

None None VI 14 LP-02 A.

Low alloy 

steel

Air with reactor 

coolant leakage

Cumulative fatigue 

damage/ fatigue

Fatigue is a time-limited aging 

analysis (TLAA) to be evaluated for 

the period of extended operation. 

See the Standard Review Plan, 

Section 4.3 “Metal Fatigue,” for 

acceptable methods for meeting the 

requirements of 10 CFR 54.21(c)(1).

IV 7 R-73 A2.1-e

Low alloy 

steel, yield 

strength 

>150 ksi

Air – indoor 

uncontrolled 

(External)

Cracking/ stress 

corrosion cracking

Chapter XI.M18, “Bolting Integrity” III 51 T-27 B1.1.2-a

Loss of material/ 

general corrosion

Chapter XI.M18, “Bolting Integrity” III 51 TP-9 B1.1

Low-alloy 

steel SA 193 

Gr. B7

System 

temperature up to 

288°C (550°F)

Loss of preload/ 

thermal effects, 

gasket creep, and 

self-loosening

Chapter XI.M18, “Bolting Integrity” IV 52 R-27 C1.2-e C1.3-f 

Low-alloy 

steel, 

stainless steel

Air with reactor 

coolant leakage

Loss of preload/ 

thermal effects, 

gasket creep, and 

self-loosening

Chapter XI.M18, “Bolting Integrity” IV 52 R-12 C2.3-g C2.4-g 

C2.5-p 

Lubrite® Air – indoor 

uncontrolled

Lock-up/ wear Chapter XI.S3, “ASME Section XI, 

Subsection IWF” or 

Chapter XI.S6, “Structures 

Monitoring Program”

III 30 T-13 A4.2-b
NUREG-1833

A-132 October 2005

A.6. Summary of MEAP Combinations in GALL Vol. 2 AMR Tables

Material Environment Aging Effect/ 

Mechanism Aging Management Programs

Referring 

GALL Rev.1

Chapters

SRPLR IDRelated 

Item

Location in 

AMR 

Chapters

Loss of mechanical 

function/ corrosion, 

distortion, dirt, 

overload, fatigue due 

to vibratory and cyclic 

thermal loads

Chapter XI.S6, “Structures 

Monitoring Program”

III 52 TP-1 B2. B4.

Air – outdoor Loss of mechanical 

function/ corrosion, 

distortion, dirt, 

overload, fatigue due 

to vibratory and cyclic 

thermal loads

Chapter XI.S6, “Structures 

Monitoring Program”

III 52 TP-2 B2. B4.

Air–indoor 

uncontrolled or air–

outdoor

Loss of mechanical 

function/ corrosion, 

distortion, dirt, 

overload, fatigue due 

to vibratory and cyclic 

thermal loads

Chapter XI.S3, “ASME Section XI, 

Subsection IWF”

III 57 T-32 B1.1.3-a 

B1.2.2-a 

B1.3.2-a

Nickel alloy Air – indoor 

uncontrolled 

(External)

None None IV 85 RP-03 E.

V 53 EP-17 F.

VII 94 AP-16 J.

VIII 41 SP-11 I.

Raw water Loss of material/ 

pitting and crevice 

corrosion

Chapter XI.M20, “Open-Cycle 

Cooling Water System”

VII 78 AP-53 C1. C3. 
October 2005

A-133 NUREG-1833

A.6. Summary of MEAP Combinations in GALL Vol. 2 AMR Tables

Material Environment Aging Effect/ 

Mechanism Aging Management Programs

Referring 

GALL Rev.1

Chapters

SRPLR IDRelated 

Item

Location in 

AMR 

Chapters

Reactor coolant Cracking/ primary 

water stress corrosion 

cracking

Chapter XI.M1, “ASME Section XI 

Inservice Inspection, Subsections 

IWB, IWC, and IWD” for Class 1 

components, and 

Chapter XI.M2, “Water Chemistry,” 

for PWR primary water and 

Provide a commitment in the FSAR 

supplement to implement applicable 

(1) NRC Orders, Bulletins, and 

Generic Letters associated with 

nickel alloys and (2) staff-accepted 

industry guidelines.

IV 31 R-89 A2.7-a

Chapter XI.M2, “Water Chemistry,” 

and 

Chapter XI.M1, “ASME Section XI 

Inservice Inspection, Subsections 

IWB, IWC, and IWD" and, 

Provide a commitment in the FSAR 

supplement to submit a plant-specific 

AMP to implement applicable (1) 

NRC Orders, Bulletins, and Generic

Letters associated with nickel alloys 

and (2) staff-accepted industry 

guidelines.

IV 31 R-88 A2.6-a

Chapter XI.M19, “Steam Generator 

Tubing Integrity” and 

Chapter XI.M2, “Water Chemistry,” 

for PWR primary water

IV 73 R-40 D1.2-i D1.2-j 

D2.2-f D2.2-g 
NUREG-1833

A-134 October 2005

A.6. Summary of MEAP Combinations in GALL Vol. 2 AMR Tables

Material Environment Aging Effect/ 

Mechanism Aging Management Programs

Referring 

GALL Rev.1

Chapters

SRPLR IDRelated 

Item

Location in 

AMR 

Chapters

R-44 D1.2-a D2.2-a 

Chapter XI.M1, “ASME Section XI 

Inservice Inspection, Subsections 

IWB, IWC, and IWD,” for Class 1 

components and Chapter XI.M2, 

“Water Chemistry,” for PWR primary 

water and Chapter XI.M11-A, 

"Nickel-Alloy Penetration Nozzles 

Welded to the Upper Reactor Vessel 

Closure Heads of Pressurized Water 

Reactors (PWRs Only)"

IV 65 R-75 A2.2-a

R-90 A2.7-b

Cracking/ stress 

corrosion cracking 

and intergranular 

stress corrosion 

cracking

Chapter XI.M7, “BWR Stress 

Corrosion Cracking,” and 

Chapter XI.M2, “Water Chemistry,” 

for BWR water

IV 41 R-21 C1.1-f

Cracking/ stress 

corrosion cracking, 

intergranular stress 

corrosion cracking, 

irradiation-assisted

stress corrosion 

cracking

Chapter XI.M9, “BWR Vessel 

Internals,” for shroud support and 

Chapter XI.M2, “Water Chemistry,” 

for BWR water

IV 44 R-96 B1.1-f

Chapter XI.M1, “ASME Section XI 

Inservice Inspection, Subsections 

IWB, IWC, and IWD,” for Class 1 

components and 

Chapter XI.M2, “Water Chemistry,” 

for BWR water

IV 46 R-95 B1.1-e
October 2005

A-135 NUREG-1833

A.6. Summary of MEAP Combinations in GALL Vol. 2 AMR Tables

Material Environment Aging Effect/ 

Mechanism Aging Management Programs

Referring 

GALL Rev.1

Chapters

SRPLR IDRelated 

Item

Location in 

AMR 

Chapters

Chapter XI.M1, “ASME Section XI 

Inservice Inspection, Subsections 

IWB, IWC, and IWD,” for Class 1 

components and Chapter XI.M2, 

“Water Chemistry,” for BWR water 

Because cracking initiated in crevice 

regions is not amenable to visual 

inspection, for BWRs with a crevice 

in the access hole covers, an 

augmented inspection is to include 

ultrasonic testing (UT) or other 

demonstrated acceptable inspection 

of the access hole cover welds.

IV 49 R-94 B1.1-d

Reactor coolant 

and secondary 

feedwater/steam

Cumulative fatigue 

damage/ fatigue

Fatigue is a time-limited aging 

analysis (TLAA) to be evaluated for 

the period of extended operation. 

See the Standard Review Plan, 

Section 4.3 “Metal Fatigue,” for 

acceptable methods for meeting the 

requirements of 10 CFR 54.21(c)(1).

IV 6 R-46 D1.2-d D2.2-e 
NUREG-1833

A-136 October 2005

A.6. Summary of MEAP Combinations in GALL Vol. 2 AMR Tables

Material Environment Aging Effect/ 

Mechanism Aging Management Programs

Referring 

GALL Rev.1

Chapters

SRPLR IDRelated 

Item

Location in 

AMR 

Chapters

Reactor coolant/ 

steam

Cracking/ primary 

water stress corrosion 

cracking

Chapter XI.M1, “ASME Section XI 

Inservice Inspection, Subsections 

IWB, IWC, and IWD” for Class 1 

components, and 

Chapter XI.M2, “Water Chemistry,” 

for PWR primary water and 

Provide a commitment in the FSAR 

supplement to implement applicable 

(1) NRC Orders, Bulletins, and 

Generic Letters associated with 

nickel alloys and (2) staff-accepted 

industry guidelines.

IV 31 RP-22 C2. 

Chapter XI.M1, “ASME Section XI 

Inservice Inspection, Subsections 

IWB, IWC, and IWD” for Class 1 

components, and 

Chapter XI.M2, “Water Chemistry” 

for PWR primary water and 

Provide a commitment in the FSAR 

supplement to implement applicable 

(1) NRC Orders, Bulletins, and 

Generic Letters associated with 

nickel alloys and (2) staff-accepted 

industry guidelines.

IV 31 RP-31 C2. 

Secondary 

feedwater/ steam

Cracking/ 

intergranular attack

Chapter XI.M19, “Steam Generator 

Tubing Integrity” and 

Chapter XI.M2, “Water Chemistry,” 

for PWR secondary water

IV 72 R-48 D1.2-c D2.2-c 
October 2005

A-137 NUREG-1833

A.6. Summary of MEAP Combinations in GALL Vol. 2 AMR Tables

Material Environment Aging Effect/ 

Mechanism Aging Management Programs

Referring 

GALL Rev.1

Chapters

SRPLR IDRelated 

Item

Location in 

AMR 

Chapters

Cracking/ outer 

diameter stress 

corrosion cracking

Chapter XI.M19, “Steam Generator 

Tubing Integrity” and 

Chapter XI.M2, “Water Chemistry,” 

for PWR secondary water

IV 72 R-47 D1.2-b D2.2-b 

Cracking/ stress 

corrosion cracking

Chapter XI.M2, "Water Chemistry" 

and 

Chapter XI.M32 "One-Time 

Inspection" or Chapter XI.M1, 

“ASME Section XI Inservice 

Inspection, Subsections IWB, IWC, 

and IWD.” 

IV 84 R-36 D2.1-i 

Denting/ corrosion of 

carbon steel tube 

support plate

Chapter XI.M19, “Steam Generator 

Tubing Integrity” and 

Chapter XI.M2, “Water Chemistry,” 

for PWR secondary water. 

IV 75 R-226 D2. 

Chapter XI.M19, “Steam Generator 

Tubing Integrity” and 

Chapter XI.M2, “Water Chemistry,” 

for PWR secondary water. 

For plants that could experience 

denting at the upper support plates, 

the applicant should evaluate 

potential for rapidly propagating 

cracks and then develop and take 

corrective actions consistent with 

Bulletin 88-02, “Rapidly Propagating 

Cracks in SG Tubes."

IV 79 R-43 D1.2-g 
NUREG-1833

A-138 October 2005

A.6. Summary of MEAP Combinations in GALL Vol. 2 AMR Tables

Material Environment Aging Effect/ 

Mechanism Aging Management Programs

Referring 

GALL Rev.1

Chapters

SRPLR IDRelated 

Item

Location in 

AMR 

Chapters

Loss of material/ 

fretting and wear

Chapter XI.M19, “Steam Generator 

Tubing Integrity” and 

Chapter XI.M2, “Water Chemistry,” 

for PWR secondary water

IV 72 R-49 D1.2-e D2.2-d 

Loss of material/ 

wastage and pitting 

corrosion

Chapter XI.M19, “Steam Generator 

Tubing Integrity” and 

Chapter XI.M2, “Water Chemistry,” 

for PWR secondary water

IV 77 R-50 D1.2-f 

Nickel alloy or 

nickel alloy 

cladding

Reactor coolant Cracking/ primary 

water stress corrosion 

cracking

Chapter XI.M1, “ASME Section XI 

Inservice Inspection, Subsections 

IWB, IWC, and IWD” for Class 1 

components, and 

Chapter XI.M2, “Water Chemistry,” 

for PWR primary water and 

For nickel alloy, provide a 

commitment in the FSAR 

supplement to implement applicable 

(1) NRC Orders, Bulletins, and 

Generic Letters associated with 

nickel alloys and (2) staff-accepted 

industry guidelines.

IV 31 R-06 C2.5-k C2.5-s

C2.5-m 

Nickel alloy; 

stainless steel

Reactor coolant Cracking/ stress 

corrosion cracking, 

intergranular stress 

corrosion cracking, 

irradiation-assisted 

stress corrosion 

cracking

Chapter XI.M9, “BWR Vessel 

Internals,” for jet pump assembly and 

Chapter XI.M2, “Water Chemistry,” 

for BWR water

IV 44 R-100 B1.4-a
October 2005

A-139 NUREG-1833

A.6. Summary of MEAP Combinations in GALL Vol. 2 AMR Tables

Material Environment Aging Effect/ 

Mechanism Aging Management Programs

Referring 

GALL Rev.1

Chapters

SRPLR IDRelated 

Item

Location in 

AMR 

Chapters

Cracking/ stress 

corrosion cracking, 

primary water stress 

corrosion cracking

Chapter XI.M2, “Water Chemistry,” 

and Chapter XI.M32 "One-Time 

Inspection" and 

For nickel alloy welded spray heads, 

provide a commitment in the FSAR 

supplement to submit a plant-specific 

AMP delineating commitments to 

Orders, Bulletins, or Generic Letters 

that inspect stipulated components 

for cracking of wetted surfaces. 

IV 36 R-24 C2.5-j 

Nickel alloy; 

steel with

nickel-alloy 

cladding

Reactor coolant Cracking/ primary 

water stress corrosion 

cracking

Chapter XI.M2, “Water Chemistry,” 

for PWR primary water

IV 81 RP-21 D1.

Chapter XI.M1, “ASME Section XI 

Inservice Inspection, Subsections 

IWB, IWC, and IWD,” for Class 1 

components, and 

Chapter XI.M2, “Water Chemistry,” 

for PWR primary water and 

For nickel alloy, provide a 

commitment in the FSAR 

supplement to implement applicable 

(1) NRC Orders, Bulletins, and 

Generic Letters associated with 

nickel alloys and (2) staff-accepted 

industry guidelines.

IV 31 R-01 D1.1-i D1.1-j 

D2.1-h 

Nickel-based 

alloys

Steam Loss of material/ 

pitting and crevice 

corrosion

Chapter XI.M2, “Water Chemistry,” 

for PWR secondary water

VIII 37 SP-18 B1.
NUREG-1833

A-140 October 2005

A.6. Summary of MEAP Combinations in GALL Vol. 2 AMR Tables

Material Environment Aging Effect/ 

Mechanism Aging Management Programs

Referring 

GALL Rev.1

Chapters

SRPLR IDRelated 

Item

Location in 

AMR 

Chapters

Non-metallic 41 T-31 B4.2-a

(e.g., Rubber)

Air – indoor 

uncontrolled or air 

– outdoor

Reduction or loss of 

isolation function/ 

radiation hardening, 

temperature, humidity, 

sustained vibratory 

loading

Chapter XI.S6, “Structures 

Monitoring Program”

III

57 T-33 B1.1.3-a 

B1.2.2-a 

B1.3.2-a

Porcelain, 

Malleable iron, 

aluminum, 

galvanized 

steel, cement

Air – outdoor Degradation of 

insulator 

quality/presence of 

any salt deposits or 

surface contamination

A plant-specific aging management 

program is to be evaluated for plants 

located such that the potential exists 

for salt deposits or surface 

contamination (e.g., in the vicinity of 

salt water bodies or industrial 

pollution). 

VI 11 LP-07 A.

Loss of material/ 

mechanical wear due 

to wind blowing on 

transmission 

conductors

A plant-specific aging management 

program is to be evaluated.

VI 11 LP-11 A.
October 2005

A-141 NUREG-1833

A.6. Summary of MEAP Combinations in GALL Vol. 2 AMR Tables

Material Environment Aging Effect/ 

Mechanism Aging Management Programs

Referring 

GALL Rev.1

Chapters

SRPLR IDRelated 

Item

Location in 

AMR 

Chapters

Porcelain, 

xenoy, 

thermo-plastic 

organic 

polymers

Air – indoor and 

outdoor

Embrittlement, 

cracking, melting, 

discoloration, 

swelling, or loss of 

dielectric strength 

leading to reduced 

insulation resistance 

(IR); electrical failure/ 

thermal/thermoxidativ

e degradation of 

organics/thermoplasti

cs, radiation-induced 

oxidation; 

moisture/debris 

intrusion, and ohmic 

heating

Chapter XI.E4, "Metal Enclosed Bus" VI 8 LP-05 A.

Reinforced 

concrete

Air – indoor 

uncontrolled

Concrete cracking 

and spalling/ 

aggressive chemical 

attack, and reaction 

with aggregates

Chapter XI.M26, “Fire Protection” 

and Chapter XI.S6, “Structures 

Monitoring Program”

VII 65 A-90 G.1-b G.2-b 

G.3-b G.4-b 

G.5-a 

Loss of material/ 

corrosion of 

embedded steel

Chapter XI.M26, “Fire Protection” 

and Chapter XI.S6, “Structures 

Monitoring Program”

VII 67 A-91 G.1-c G.2-c 

G.3-c G.4-c 

G.5-b 
NUREG-1833

A-142 October 2005

A.6. Summary of MEAP Combinations in GALL Vol. 2 AMR Tables

Material Environment Aging Effect/ 

Mechanism Aging Management Programs

Referring 

GALL Rev.1

Chapters

SRPLR IDRelated 

Item

Location in 

AMR 

Chapters

Reduction of strength 

and modulus/ 

elevated temperature 

(>150°F general; 

>200°F local)

Plant-specific aging management 

program 

For any concrete elements that 

exceed specified temperature limits, 

further evaluations are warranted. 

Appendix A of ACI 349-85 specifies 

the concrete temperature limits for 

normal operation or any other longterm period. The temperatures shall 

not exceed 150°F except for local 

areas which are allowed to have 

increased temperatures not to 

exceed 200°F.

III 33 T-10 A1.1-j A2.1-j 

A3.1-j A4.1-c 

A5.1-j

Air – indoor 

uncontrolled or air 

– outdoor

Cracking, loss of 

bond, and loss of 

material (spalling, 

scaling)/ corrosion of 

embedded steel

Chapter XI.S6, “Structures 

Monitoring Program” 

Accessible areas: 

Inspections performed in accordance 

with the Structures Monitoring 

Program will indicate the presence of 

cracking, loss of bond, and loss of 

material (spalling, scaling) due to 

corrosion of embedded steel. 

III 23 T-04 A1.1-d A2.1-d 

A3.1-d A4.1-d 

A5.1-d A7.1-d 

A9.1-d
October 2005

A-143 NUREG-1833

A.6. Summary of MEAP Combinations in GALL Vol. 2 AMR Tables

Material Environment Aging Effect/ 

Mechanism Aging Management Programs

Referring 

GALL Rev.1

Chapters

SRPLR IDRelated 

Item

Location in 

AMR 

Chapters

Chapter XI.S7, “Regulatory Guide 

1.127, Inspection of Water-Control 

Structures Associated with Nuclear 

Power Plants” or the FERC / US 

Army Corp of Engineers dam 

inspections and maintenance 

programs. 

Accessible areas: 

As described in NUREG-1557, 

corrosion of exterior above-grade 

and interior embedded steel is not 

significant if the steel is not exposed 

to an aggressive environment 

(concrete pH <11.5 or chlorides >500 

ppm). If such steel is exposed to an 

aggressive environment, corrosion is 

not significant if the concrete in 

which the steel is embedded has a 

low water-to-cement ratio (0.35-

0.45), adequate air entrainment (3-

6%), low permeability, and is 

designed in accordance with ACI 

318-63 or ACI 349-85. Therefore, if 

these conditions are satisfied, aging 

management is not necessary. 

Inaccessible areas: 

For plants with non-aggressive 

ground water/soil; i.e., pH > 5.5, 

chlorides < 500 ppm, or sulfates 

<1500 ppm, as a minimum, consider 

(1) Examination of the exposed 

portions of the below grade concrete, 

when excavated for any reason, and 

III 34 T-18 A6.1-d
NUREG-1833

A-144 October 2005

A.6. Summary of MEAP Combinations in GALL Vol. 2 AMR Tables

Material Environment Aging Effect/ 

Mechanism Aging Management Programs

Referring 

GALL Rev.1

Chapters

SRPLR IDRelated 

Item

Location in 

AMR 

Chapters

2) Periodic monitoring of belowgrade water chemistry, including 

consideration of potential seasonal 

variations. For plants with aggressive 

groundwater/soil, and/or where the 

concrete structural elements have 

experienced degradation, a plant 

specific AMP accounting for the 

extent of the degradation 

experienced should be implemented 

to manage the concrete aging during 

the period of extended operation.

Air – outdoor Concrete cracking 

and spalling/ freezethaw, aggressive 

chemical attack, and 

reaction with 

aggregates

Chapter XI.M26, “Fire Protection” 

and Chapter XI.S6, “Structures 

Monitoring Program”

VII 66 A-92 G.1-b G.2-b 

G.3-b G.4-b 
October 2005

A-145 NUREG-1833

A.6. Summary of MEAP Combinations in GALL Vol. 2 AMR Tables

Material Environment Aging Effect/ 

Mechanism Aging Management Programs

Referring 

GALL Rev.1

Chapters

SRPLR IDRelated 

Item

Location in 

AMR 

Chapters

Loss of material 

(spalling, scaling) and 

cracking/ freeze-thaw

Chapter XI.S6, “Structures 

Monitoring Program” 

Accessible Areas: 

Inspections performed in accordance 

with the Structures Monitoring 

Program will indicate the presence of 

loss of material (spalling, scaling) 

and cracking due to freeze-thaw. 

Inaccessible Areas: 

Evaluation is needed for plants that 

are located in moderate to severe 

weathering conditions (weathering 

index > 100 day-inch/yr) (NUREG1557). Documented evidence to 

confirm that existing concrete has air 

content of 3% to 6% and water-tocement ratio of 0.35-0.45, and 

subsequent inspections did not 

exhibit degradation related to freezethaw, should be considered a part of 

the evaluation. 

The weathering index for the 

continental US is shown in ASTM 

C33-90, Fig.1.

III 26 T-01 A1.1-a A2.1-a 

A3.1-a A5.1-a 

A7.1-a A8.1-a 

A9.1-a
NUREG-1833

A-146 October 2005

A.6. Summary of MEAP Combinations in GALL Vol. 2 AMR Tables

Material Environment Aging Effect/ 

Mechanism Aging Management Programs

Referring 

GALL Rev.1

Chapters

SRPLR IDRelated 

Item

Location in 

AMR 

Chapters

Chapter XI.S7, “Regulatory Guide 

1.127, Inspection of Water-Control 

Structures Associated with Nuclear 

Power Plants” or the FERC / US 

Army Corp of Engineers dam 

inspections and maintenance 

programs.

Accessible Areas: 

Inspections performed in accordance 

with Chapter XI.S7, “Regulatory 

Guide 1.127, Inspection of WaterControl Structures Associated with 

Nuclear Power Plants” or the FERC / 

US Army Corp of Engineers dam 

inspections and maintenance 

programs will indicate the presence 

of loss of material (spalling, scaling) 

and cracking due to freeze-thaw. 

Inaccessible Areas: 

As described in NUREG-1557, 

freeze-thaw does not cause loss of 

material from reinforced concrete in 

foundations, or in above- and belowgrade exterior concrete, for plants 

located in a geographic region of 

negligible weathering conditions 

(weathering index <100 day-inch/yr). 

Loss of material from such concrete 

is not significant at plants located in 

areas in which weathering conditions 

are severe (weathering index >500 

day-inch/yr) or moderate (100-500 

day-inch/yr), provided that the 

III 35 T-15 A6.1-a
October 2005

A-147 NUREG-1833

A.6. Summary of MEAP Combinations in GALL Vol. 2 AMR Tables

Material Environment Aging Effect/ 

Mechanism Aging Management Programs

Referring 

GALL Rev.1

Chapters

SRPLR IDRelated 

Item

Location in 

AMR 

Chapters

concrete mix design meets the air 

content (entrained air 3-6%) and 

water-to-cement ratio (0.35-0.45) 

specified in ACI 318-63 or ACI 349-

85. Therefore, if these conditions are 

satisfied, aging management is not 

necessary. 

The weathering index is defined in 

ASTM C33-90, Table 3, Footnote E. 

Fig. 1 of ASTM C33-90 illustrates the 

various weathering index regions 

throughout the U.S.

Loss of material/ 

corrosion of 

embedded steel

Chapter XI.M26, “Fire Protection” 

and Chapter XI.S6, “Structures 

Monitoring Program”

VII 67 A-93 G.1-c G.2-c 

G.3-c G.4-c 

Air-indoor 

uncontrolled or airoutdoor

Increase in porosity 

and permeability, 

cracking, loss of 

material (spalling, 

scaling)/ aggressive 

chemical attack

Chapter XI.S6, "Structures 

Monitoring Program" 

Accessible Areas: 

Inspections performed in accordance 

with Structures Monitoring Program 

will indicate the presence of increase 

in porosity and permeability, 

cracking, or loss of material (spalling, 

scaling) due to aggressive chemical 

attack.

III 24 T-06 A1.1-f A2.1-f 

A3.1-f A4.1-a 

A5.1-f A7.1-f 

A9.1-f
NUREG-1833

A-148 October 2005

A.6. Summary of MEAP Combinations in GALL Vol. 2 AMR Tables

Material Environment Aging Effect/ 

Mechanism Aging Management Programs

Referring 

GALL Rev.1

Chapters

SRPLR IDRelated 

Item

Location in 

AMR 

Chapters

Any Cracking due to 

expansion/ reaction 

with aggregates

Chapter XI.S6, “Structures 

Monitoring Program” 

Accessible Areas: 

Inspections/evaluations performed in 

accordance with the Structures 

Monitoring Program will indicate the 

presence of expansion and cracking 

due to reaction with aggregates. 

Inaccessible Areas: 

As described in NUREG-1557, 

investigations, tests, and 

petrographic examinations of 

aggregates performed in accordance 

with ASTM C295-54 or ASTM C227-

50 can demonstrate that those 

aggregates do not react within 

reinforced concrete. For potentially 

reactive aggregates, aggregatereinforced concrete reaction is not 

significant if the concrete was 

constructed in accordance with ACI 

201.2R. Therefore, if these 

conditions are satisfied, aging 

management is not necessary.

III 27 T-03 A1.1-c A2.1-c 

A3.1-c A4.1-b 

A5.1-c A7.1-c 

A8.1-c A9.1-c
October 2005

A-149 NUREG-1833

A.6. Summary of MEAP Combinations in GALL Vol. 2 AMR Tables

Material Environment Aging Effect/ 

Mechanism Aging Management Programs

Referring 

GALL Rev.1

Chapters

SRPLR IDRelated 

Item

Location in 

AMR 

Chapters

Chapter XI.S7, “Regulatory Guide 

1.127, Inspection of Water-Control 

Structures Associated with Nuclear 

Power Plants” or the FERC / US 

Army Corp of Engineers dam 

inspections and maintenance 

programs. 

Accessible Areas: 

Inspections/evaluations performed in 

accordance with “Regulatory Guide 

1.127, Inspection of Water-Control 

Structures Associated with Nuclear 

Power Plants” or the FERC / US 

Army Corp of Engineers dam 

inspections and maintenance 

programs will indicate the presence 

of expansion and cracking due to 

reaction with aggregates. 

 Inaccessible areas: 

As described in NUREG-1557, 

investigations, tests, and 

petrographic examinations of 

aggregates performed in accordance 

with ASTM C295-54 or ASTM C227-

50 can demonstrate that those 

aggregates do not react within 

reinforced concrete. For potentially 

reactive aggregates, aggregatereinforced concrete reaction is not 

significant if the concrete was 

constructed in accordance with ACI 

201.2R. Therefore, if these 

conditions are satisfied, aging 

management is not necessary.

III 36 T-17 A6.1-c
NUREG-1833

A-150 October 2005

A.6. Summary of MEAP Combinations in GALL Vol. 2 AMR Tables

Material Environment Aging Effect/ 

Mechanism Aging Management Programs

Referring 

GALL Rev.1

Chapters

SRPLR IDRelated 

Item

Location in 

AMR 

Chapters

Ground water/soil Cracking, loss of 

bond, and loss of 

material (spalling, 

scaling)/ corrosion of 

embedded steel

Chapter XI.S6, "Structures 

Monitoring Program" 

Accessible Areas: 

Inspections performed in accordance 

with the Structures Monitoring 

Program will indicate the cracking, 

loss of bond, or loss of material 

(spalling, scaling) due to corrosion of 

embedded steel. 

Inaccessible Areas: 

For plants with non-aggressive 

ground water/soil; i.e., pH > 5.5, 

chlorides < 500 ppm, or sulfates 

<1500 ppm, as a minimum, consider 

(1) Examination of the exposed 

portions of the below-grade concrete, 

when excavated for any reason, and 

(2) Periodic monitoring of belowgrade water chemistry, including 

consideration of potential seasonal 

variations. 

For plants with aggressive 

groundwater/soil, and/or where the 

concrete structural elements have 

experienced degradation, a plant 

specific AMP accounting for the 

extent of the degradation 

experienced should be implemented 

to manage the concrete aging during 

the period of extended operation.

III 31 T-05 A1.1-e A2.1-e 

A3.1-e A5.1-e 

A7.1-e A8.1-d 

A9.1-e
October 2005

A-151 NUREG-1833

A.6. Summary of MEAP Combinations in GALL Vol. 2 AMR Tables

Material Environment Aging Effect/ 

Mechanism Aging Management Programs

Referring 

GALL Rev.1

Chapters

SRPLR IDRelated 

Item

Location in 

AMR 

Chapters

Increase in porosity 

and permeability, 

cracking, loss of 

material (spalling, 

scaling)/ aggressive 

chemical attack

Inaccessible Areas: 

For plants with non-aggressive 

ground water/soil; i.e., pH > 5.5, 

chlorides < 500 ppm, or sulfates 

<1500 ppm, as a minimum, consider 

(1) Examination of the exposed 

portions of the below-grade concrete, 

when excavated for any reason, and 

(2) Periodic monitoring of belowgrade water chemistry, including 

consideration of potential seasonal 

variations. 

For plants with aggressive 

groundwater/soil, and/or where the 

concrete structural elements have 

experienced degradation, a plant 

specific AMP accounting for the 

extent of the degradation 

experienced should be implemented 

to manage the concrete aging during 

the period of extended operation.

III 31 T-07 A1.1-g A2.1-g 

A3.1-g A5.1-g 

A7.1-g A8.1-e 

A9.1-g

Chapter XI.S7, “Regulatory Guide 

1.127, Inspection of Water-Control 

Structures Associated with Nuclear 

Power Plants” or the FERC / US 

Army Corp of Engineers dam 

inspections and maintenance 

programs. 

Accessible Areas: 

Inspections performed in accordance 

III 34 T-19 A6.1-e
NUREG-1833

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A.6. Summary of MEAP Combinations in GALL Vol. 2 AMR Tables

Material Environment Aging Effect/ 

Mechanism Aging Management Programs

Referring 

GALL Rev.1

Chapters

SRPLR IDRelated 

Item

Location in 

AMR 

Chapters

with “Regulatory Guide 1.127, 

Inspection of Water-Control 

Structures Associated with Nuclear 

Power Plants” or the FERC / US 

Army Corp of Engineers dam 

inspections and maintenance 

programs will indicate the presence 

of increase in porosity and 

permeability, cracking, or loss of 

material (spalling, scaling) due to 

aggressive chemical attack. 

Inaccessible areas: 

For plants with non-aggressive 

ground water/soil; i.e. pH > 5.5, 

chlorides < 500 ppm, or sulfates 

<1500 ppm, as a minimum, consider: 

(1) Examination of the exposed 

portions of the below grade concrete, 

when excavated for any reason, and 

(2) Periodic monitoring of belowgrade water chemistry, including 

consideration of potential seasonal 

variations. 

For plants with aggressive 

groundwater/soil, and/or where the 

concrete structural elements have 

experienced degradation, a plant 

specific AMP accounting for the 

extent of the degradation 

experienced should be implemented 

to manage the concrete aging during 

the period of extended operation.
October 2005

A-153 NUREG-1833

A.6. Summary of MEAP Combinations in GALL Vol. 2 AMR Tables

Material Environment Aging Effect/ 

Mechanism Aging Management Programs

Referring 

GALL Rev.1

Chapters

SRPLR IDRelated 

Item

Location in 

AMR 

Chapters

Soil Cracks and distortion 

due to increased 

stress levels from 

settlement

Chapter XI.S6, “Structures 

Monitoring Program” 

If a de-watering system is relied 

upon for control of settlement, then 

the licensee is to ensure proper 

functioning of the de-watering 

system through the period of 

extended operation. 

III 28 T-08 A1.1-h A2.1-h 

A3.1-h A5.1-h 

A6.1-f A7.1-h 

A8.1-f A9.1-h 

Water – flowing Increase in porosity 

and permeability, loss 

of strength/ leaching 

of calcium hydroxide

Chapter XI.S6, "Structures 

Monitoring Program" 

Accessible areas: 

Inspections performed in accordance 

with the Structures Monitoring 

Program will indicate the presence of 

increase in porosity, and permeability 

due to leaching of calcium hydroxide. 

Inaccessible Areas: 

An aging management program is 

not necessary, even if reinforced 

concrete is exposed to flowing water, 

if there is documented evidence that 

confirms the in-place concrete was 

constructed in accordance with the 

recommendations in ACI 201.2R.

III 32 T-02 A1.1-b A2.1-b 

A3.1-b A5.1-b 

A7.1-b A8.1-b 

A9.1-b
NUREG-1833

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A.6. Summary of MEAP Combinations in GALL Vol. 2 AMR Tables

Material Environment Aging Effect/ 

Mechanism Aging Management Programs

Referring 

GALL Rev.1

Chapters

SRPLR IDRelated 

Item

Location in 

AMR 

Chapters

Chapter XI.S7, “Regulatory Guide 

1.127, Inspection of Water-Control 

Structures Associated with Nuclear 

Power Plants” or the FERC / US 

Army Corp of Engineers dam 

inspections and maintenance 

programs

Accessible Areas: 

Inspections performed in accordance 

with Chapter XI.S7, “Regulatory 

Guide 1.127, Inspection of WaterControl Structures Associated with 

Nuclear Power Plants” or the FERC / 

US Army Corp of Engineers dam 

inspections and maintenance 

programs will indicate the presence 

of increase in porosity and 

permeability, loss of strength/ 

leaching of calcium hydroxide 

Inaccessible Areas: 

As described in NUREG-1557, 

leaching of calcium hydroxide from 

reinforced concrete becomes 

significant only if the concrete is 

exposed to flowing water. Even if 

reinforced concrete is exposed to 

flowing water, such leaching is not 

significant if the concrete is 

constructed to ensure that it is 

dense, well-cured, has low 

permeability, and that cracking is 

well controlled. Cracking is controlled 

through proper arrangement and 

III 37 T-16 A6.1-b
October 2005

A-155 NUREG-1833

A.6. Summary of MEAP Combinations in GALL Vol. 2 AMR Tables

Material Environment Aging Effect/ 

Mechanism Aging Management Programs

Referring 

GALL Rev.1

Chapters

SRPLR IDRelated 

Item

Location in 

AMR 

Chapters

distribution of reinforcing bars. All of 

the above characteristics are 

assured if the concrete was 

constructed with the guidance of ACI 

201.2R. Therefore, if these 

conditions are satisfied, aging 

management is not necessary.

Loss of material/ 

abrasion; cavitation

Chapter XI.S7, “Regulatory Guide 

1.127, Inspection of Water-Control 

Structures Associated with Nuclear 

Power Plants” or the FERC / US 

Army Corp of Engineers dam 

inspections and maintenance 

programs.

III 45 T-20 A6.1-h

Reinforced 

concrete; 

Grout

Air – indoor 

uncontrolled or air 

– outdoor

Reduction in concrete 

anchor capacity due 

to local concrete 

degradation/ serviceinduced cracking or 

other concrete aging 

mechanisms

Chapter XI.S6, “Structures 

Monitoring Program”

III 40 T-29 B1.1.4-a 

B1.2.3-a 

B1.3.3-a 

B2.2-a B3.2-a 

B4.3-a B5.2-a
NUREG-1833

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A.6. Summary of MEAP Combinations in GALL Vol. 2 AMR Tables

Material Environment Aging Effect/ 

Mechanism Aging Management Programs

Referring 

GALL Rev.1

Chapters

SRPLR IDRelated 

Item

Location in 

AMR 

Chapters

Reinforced 

concrete; 

Porous 

concrete

Water – flowing 

under foundation

Reduction in 

foundation strength, 

cracking, differential 

settlement/ erosion of 

porous concrete 

subfoundation

Chapter XI.S6, “Structures 

Monitoring Program” 

Erosion of cement from porous 

concrete subfoundations beneath 

containment basemats is described 

in NRC IN 97-11. NRC IN 98-26 

proposes Maintenance Rule 

Structures Monitoring for managing 

this aging effect, if applicable. If a dewatering system is relied upon for 

control of erosion of cement from 

porous concrete subfoundations, the 

licensee is to ensure proper 

functioning of the de-watering 

system through the period of 

extended operation.

III 29 T-09 A1.1-i A2.1-i 

A3.1-i A5.1-i 

A6.1-g A7.1-i 

A8.1-g A9.1-i
October 2005

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Material Environment Aging Effect/ 

Mechanism Aging Management Programs

Referring 

GALL Rev.1

Chapters

SRPLR IDRelated 

Item

Location in 

AMR 

Chapters

SA508-Cl 2 

forgings clad 

with stainless 

steel using a 

high-heatinput welding 

process

Reactor coolant Crack growth/ cyclic 

loading

Growth of intergranular separations 

(underclad cracks) in low-alloy steel 

forging heat affected zone under 

austenitic stainless steel cladding is 

a time-limited aging analysis (TLAA) 

to be evaluated for the period of 

extended operation for all the SA 

508-Cl 2 forgings where the cladding 

was deposited with a high heat input 

welding process. The methodology 

for evaluating an underclad flaw is in 

accordance with the current wellestablished flaw evaluation 

procedure and criterion in the ASME 

Section XI Code. See the Standard 

Review Plan, Section 4.7, “Other 

Plant-Specific Time-Limited Aging 

Analysis,” for generic guidance for 

meeting the requirements of 10 CFR 

54.21(c).

IV 21 R-85 A2.5-b

Stainless steel Air – indoor 

uncontrolled

Cracking/ stress 

corrosion cracking

Chapter XI.S1, “ASME Section XI, 

Subsection IWE” and Chapter XI.S4, 

“10 CFR Part 50, Appendix J”

II 19 C-24 B3.1.1-b 

B3.2.2-b
NUREG-1833

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A.6. Summary of MEAP Combinations in GALL Vol. 2 AMR Tables

Material Environment Aging Effect/ 

Mechanism Aging Management Programs

Referring 

GALL Rev.1

Chapters

SRPLR IDRelated 

Item

Location in 

AMR 

Chapters

Chapter XI.S1, “ASME Section XI, 

Subsection IWE “ and Chapter XI.S4, 

“10 CFR Part 50, Appendix J” 

Evaluation of 10 CFR 50.55a/ASME 

Section XI, Subsection IWE is 

augmented as follows: 

(4) Detection of Aging Effects: Stress 

corrosion cracking (SCC) is a 

concern for dissimilar metal welds. In 

the case of bellows assemblies, SCC 

may cause aging effects particularly 

if the material is not shielded from a 

corrosive environment. ASME Code 

1995 edition, with addenda through 

1996, ASME Section XI, Subsection 

IWE covers inspection of these items 

under Examination Categories E-B, 

E-F, and E-P (10 CFR Part 50, 

Appendix J pressure tests). 

10 CFR 50.55a identifies 

examination categories E-B and E-F 

as optional during the current term of 

operation. For the extended period of 

operation, Examination Categories 

E-B and E-F, and additional 

appropriate examinations to detect 

SCC in bellows assemblies and 

dissimilar metal welds are warranted 

to address this issue. 

(10) Operating Experience: IN 92-20 

describes an instance of containment 

bellows cracking, resulting in loss of 

leak tightness.

II 11 C-22 B1.1.1-d
October 2005

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Material Environment Aging Effect/ 

Mechanism Aging Management Programs

Referring 

GALL Rev.1

Chapters

SRPLR IDRelated 

Item

Location in 

AMR 

Chapters

None None III 57 TP-5 B1.1. B1.2. 

B1.3. B2. B3. 

B4. B5. 

Air – indoor 

uncontrolled 

(External)

None None IV 86 RP-04 E.

V 53 EP-18 F.

VII 94 AP-17 J.

VIII 41 SP-12 I.

Air with borated 

water leakage

None None IV 86 RP-05 E.

V 57 EP-19 F.

VII 99 AP-18 J.

None III 57 TP-4 B1.1. B1.2. 

B1.3. B2. B3. 

B4. B5. 

Air with reactor 

coolant leakage

Cracking/ stress 

corrosion cracking

Chapter XI.M18, “Bolting Integrity” IV 52 R-78 A2.2-e

Loss of material/ wear Chapter XI.M18, “Bolting Integrity” IV 52 R-79 A2.2-f

Loss of preload/ 

thermal effects, 

gasket creep, and 

self-loosening 

Chapter XI.M18, “Bolting Integrity” IV 52 R-80 A2.2-g

Air with reactor 

coolant leakage 

(Internal) 

or 

Reactor Coolant 

Cracking/ stress 

corrosion cracking

A plant-specific aging management 

program is to be evaluated because 

existing programs may not be 

capable of mitigating or detecting 

crack initiation and growth due to 

SCC in the vessel flange leak 

detection line.

IV 23 R-74 A2.1-f
NUREG-1833

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A.6. Summary of MEAP Combinations in GALL Vol. 2 AMR Tables

Material Environment Aging Effect/ 

Mechanism Aging Management Programs

Referring 

GALL Rev.1

Chapters

SRPLR IDRelated 

Item

Location in 

AMR 

Chapters

Closed cycle 

cooling water

Loss of material/ 

pitting and crevice 

corrosion

Chapter XI.M21, “Closed-Cycle 

Cooling Water System”

V 28 E-19 A.6-c D1.5-a 

D1.6-a D2.4-c 

EP-33 A. C. D1. D2.

VII 50 A-52 C2.2-a 

VIII 25 S-25 E.4-e F.4-e 

G.5-c 

SP-39 E. F. G.

Reduction of heat 

transfer/ fouling

Chapter XI.M21, “Closed-Cycle 

Cooling Water System”

V 30 EP-35 A. D1. D2.

VII 52 AP-63 C2. E3. E4. 

VIII 27 SP-41 E. F. G.

Closed cycle 

cooling water 

>60°C (>140°F)

Cracking/ stress 

corrosion cracking

Chapter XI.M21, “Closed-Cycle 

Cooling Water System”

V 25 EP-44 A. C. D1. D2.

VII 46 AP-60 C2. E3. E4.

VIII 23 SP-54 E. F. G.

Concrete None None IV 86 RP-06 E.

V 55 EP-20 F.

VII 96 AP-19 J.

VIII 43 SP-13 I.

Condensation Loss of material/ 

pitting and crevice 

corrosion

A plant-specific aging management 

program is to be evaluated.

VII 27 A-09 F1.4-a F2.4-a 

F3.4-a 

Condensation 

(Internal)

Loss of material/ 

pitting and crevice 

corrosion

A plant-specific aging management 

program is to be evaluated.

V 8 E-14 D2.1-e 
October 2005

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Material Environment Aging Effect/ 

Mechanism Aging Management Programs

Referring 

GALL Rev.1

Chapters

SRPLR IDRelated 

Item

Location in 

AMR 

Chapters

EP-53 A. D1. 

Chapter XI.M24, “Compressed Air 

Monitoring”

VII 54 AP-81 D. 

Diesel exhaust Cracking/ stress 

corrosion cracking

A plant-specific aging management 

program is to be evaluated.

VII 6 AP-33 H2.

Dried Air None None VII 98 AP-20 J.

Fuel oil Loss of material/ 

pitting, crevice, and 

microbiologically 

influenced corrosion

Chapter XI.M30, “Fuel Oil Chemistry” 

The AMP is to be augmented by 

verifying the effectiveness of fuel oil 

chemistry control. See Chapter 

XI.M32, “One-Time Inspection,” for 

an acceptable verification program.

VII 32 AP-54 G. H1. H2.

Gas None None IV 86 RP-07 E.

V 56 EP-22 F.

VII 97 AP-22 J.

VIII 44 SP-15 I.

Lubricating oil Loss of material/ 

pitting and crevice 

corrosion

Chapter XI.M39, "Lubricating Oil 

Analysis" 

The AMP is to be augmented by 

verifying the effectiveness of the 

lubricating oil analysis program. See 

Chapter XI.M32, “One-Time 

Inspection,” for an acceptable 

verification program.

V 6 EP-51 D1.
NUREG-1833

A-162 October 2005

A.6. Summary of MEAP Combinations in GALL Vol. 2 AMR Tables

Material Environment Aging Effect/ 

Mechanism Aging Management Programs

Referring 

GALL Rev.1

Chapters

SRPLR IDRelated 

Item

Location in 

AMR 

Chapters

Loss of material/ 

pitting, crevice, and 

microbiologically 

influenced corrosion

Chapter XI.M39, "Lubricating Oil 

Analysis" 

The AMP is to be augmented by 

verifying the effectiveness of the 

lubricating oil analysis program. See 

Chapter XI.M32, “One-Time 

Inspection,” for an acceptable 

verification program.

VII 33 AP-59 C1. C2. E1. 

E4. H2. G.

VIII 18 S-20 G.5-d 

SP-38 A. D1. D2. E. 

G.

Reduction of heat 

transfer/ fouling

Chapter XI.M39, "Lubricating Oil 

Analysis" 

The AMP is to be augmented by 

verifying the effectiveness of the 

lubricating oil analysis program. See 

Chapter XI.M32, “One-Time 

Inspection,” for an acceptable 

verification program.

III 9 SP-62 G.

V 9 EP-50 A. D1. D2. 

Raw water Loss of material/ 

pitting and crevice 

corrosion

A plant-specific aging management 

program is to be evaluated for pitting 

and crevice corrosion of tank bottom 

because moisture and water can 

egress under the tank due to 

cracking of the perimeter seal from 

weathering.

V 7 E-01 D1.8-c 

Chapter XI.M20, “Open-Cycle 

Cooling Water System”

VII 78 A-53 C3.2-a 
October 2005

A-163 NUREG-1833

A.6. Summary of MEAP Combinations in GALL Vol. 2 AMR Tables

Material Environment Aging Effect/ 

Mechanism Aging Management Programs

Referring 

GALL Rev.1

Chapters

SRPLR IDRelated 

Item

Location in 

AMR 

Chapters

Loss of material/ 

pitting and crevice 

corrosion, and fouling

Chapter XI.M27, “Fire Water System” VII 69 A-55 G.6-a G.6-b 

Chapter XI.M20, “Open-Cycle 

Cooling Water System”

VII 79 A-54 C1.1-a C1.2-a 

C1.4-a C1.6-a 

Loss of material/ 

pitting, crevice, and 

microbiologically 

influenced corrosion

Chapter XI.M20, “Open-Cycle 

Cooling Water System”

V 37 EP-55 D1.

VII 80 AP-55 H2.

VIII 32 SP-36 E. F. G.

Loss of material/ 

pitting, crevice, and 

microbiologically 

influenced corrosion, 

and fouling

Chapter XI.M20, “Open-Cycle 

Cooling Water System”

V 38 E-34 C.1-b

39 E-20 A.6-a D1.6-b 

D2.4-a 

VIII 33 S-26 E.4-b F.4-b 

G.5-a 

Reduction of heat 

transfer/ fouling

Chapter XI.M20, “Open-Cycle 

Cooling Water System”

V 40 E-21 A.6-b D1.6-c 

D2.4-b 

VII 83 AP-61 C1. C3. G. H2.

VIII 34 S-28 E.4-c F.4-c 

G.5-b 
NUREG-1833

A-164 October 2005

A.6. Summary of MEAP Combinations in GALL Vol. 2 AMR Tables

Material Environment Aging Effect/ 

Mechanism Aging Management Programs

Referring 

GALL Rev.1

Chapters

SRPLR IDRelated 

Item

Location in 

AMR 

Chapters

Reactor coolant Changes in 

dimensions/ void 

swelling

IV 33 R-107 B2.1-b

R-110 B2.1-f

R-117 B2.2-b

R-121 B2.3-b

R-124 B2.4-b

R-126 B2.4-d

R-139 B2.5-l

R-144 B2.6-b

R-147 B3.1-b

R-158 B3.3-b

No further aging management review 

is necessary if the applicant provides 

a commitment in the FSAR 

supplement to (1) participate in the 

industry programs for investigating 

and managing aging effects on 

reactor internals; (2) evaluate and 

implement the results of the industry 

programs as applicable to the reactor 

internals; and (3) upon completion of 

these programs, but not less than 24 

months before entering the period of 

extended operation, submit an 

inspection plan for reactor internals 

to the NRC for review and approval.

R-174 B4.1-c

R-177 B4.2-c

R-182 B4.3-c

R-199 B4.5-h

R-215 B4.8-b

Cracking/ cyclic 

loading

A plant-specific aging management 

program is to be evaluated.

IV 25 R-102 B1.4-d

Cracking/ flowinduced vibrationA plant-specific aging management 

program is to be evaluated.

IV 29 RP-18 B1.

Cracking/ stress 

corrosion cracking

A plant-specific aging management 

program is to be evaluated.

IV 23 RP-13 A2. 

Chapter XI.M2, “Water Chemistry,” 

for PWR primary water

IV 82 RP-17 D1.
October 2005

A-165 NUREG-1833

A.6. Summary of MEAP Combinations in GALL Vol. 2 AMR Tables

Material Environment Aging Effect/ 

Mechanism Aging Management Programs

Referring 

GALL Rev.1

Chapters

SRPLR IDRelated 

Item

Location in 

AMR 

Chapters

Chapter XI.M1, “ASME Section XI 

Inservice Inspection, Subsections 

IWB, IWC, and IWD,” for Class 1 

components and 

Chapter XI.M2, “Water Chemistry,” 

for PWR primary water

IV 68 R-217 C2.5-r 

Cracking/ stress 

corrosion cracking 

and intergranular 

stress corrosion 

cracking

Chapter XI.M7, “BWR Stress 

Corrosion Cracking,” and 

Chapter XI.M2, “Water Chemistry,” 

for BWR water

IV 41 R-20 C1.1-f C1.2-b 

C1.3-c 

Chapter XI.M9, “BWR Vessel

Internals,” for lower plenum and 

Chapter XI.M2, “Water Chemistry,” 

for BWR water

IV 43 R-104 B1.5-c
NUREG-1833

A-166 October 2005

A.6. Summary of MEAP Combinations in GALL Vol. 2 AMR Tables

Material Environment Aging Effect/ 

Mechanism Aging Management Programs

Referring 

GALL Rev.1

Chapters

SRPLR IDRelated 

Item

Location in 

AMR 

Chapters

Cracking/ stress 

corrosion cracking, 

intergranular stress 

corrosion cracking

Chapter XI.M1, “ASME Section XI 

Inservice Inspection, Subsections 

IWB, IWC, and IWD,” for Class 1 

components 

and Chapter XI.M2, “Water 

Chemistry,” for BWR water. 

The AMP in Chapter XI.M1 is to be 

augmented to detect cracking due to 

stress corrosion cracking and 

verification of the program's 

effectiveness is necessary to ensure 

that significant degradation is not 

occurring and the component 

intended function will be maintained 

during the extended period of 

operation. An acceptable verification 

program is to include temperature 

and radioactivity monitoring of the 

shell side water, and eddy current 

testing of tubes.

IV 20 R-15 C1.4-a

Chapter XI.M9, “BWR Vessel 

Internals,” for core plate and 

Chapter XI.M2, “Water Chemistry” 

for BWR water

Cracking/ stress IV 44 R-93 B1.1-b

corrosion cracking, 

intergranular stress 

corrosion cracking, 

irradiation-assisted 

stress corrosion 

cracking Chapter XI.M9, “BWR Vessel 

Internals,” for core shroud and 

Chapter XI.M2, “Water Chemistry” 

for BWR water

IV 44 R-92 B1.1-a
October 2005

A-167 NUREG-1833

A.6. Summary of MEAP Combinations in GALL Vol. 2 AMR Tables

Material Environment Aging Effect/ 

Mechanism Aging Management Programs

Referring 

GALL Rev.1

Chapters

SRPLR IDRelated 

Item

Location in 

AMR 

Chapters

Chapter XI.M9, “BWR Vessel 

Internals,” for core spray internals 

and 

Chapter XI.M2, “Water Chemistry,” 

for BWR water

IV 44 R-99 B1.3-a

Chapter XI.M9, “BWR Vessel 

Internals,” for lower plenum and 

Chapter XI.M2, “Water Chemistry,” 

for BWR water

IV 44 R-105 B1.6-a

Chapter XI.M9, “BWR Vessel 

Internals,” for the LPCI coupling and 

Chapter XI.M2, “Water Chemistry,” 

for BWR water

IV 44 R-97 B1.1-g

Chapter XI.M9, “BWR Vessel 

Internals,” for top guide and Chapter 

XI.M2, “Water Chemistry,” for BWR 

water. Additionally, for top guides 

with neutron fluence exceeding the 

IASCC threshold (5E20, E>lMeV) 

prior to the period of extended 

operation, inspect five percent (5%) 

of the top guide locations using 

enhanced visual inspection 

technique, EVT-1 within six years 

after entering the period of extended 

operation. An additional 5% of the 

top guide locations will be inspected 

within twelve years after entering the 

period of extended operation. 

IV 44 R-98 B1.2-a
NUREG-1833

A-168 October 2005

A.6. Summary of MEAP Combinations in GALL Vol. 2 AMR Tables

Material Environment Aging Effect/ 

Mechanism Aging Management Programs

Referring 

GALL Rev.1

Chapters

SRPLR IDRelated 

Item

Location in 

AMR 

Chapters

Alternatively, if the neutron fluence 

for the limiting top guide location is 

projected to exceed the threshold for 

IASCC after entering the period of 

extended operation, inspect 5% of 

the top guide locations (EVT-1) 

within six years after the date 

projected for exceeding the 

threshold. An additional 5% of the 

top guide locations will be inspected 

within twelve years after the date 

projected for exceeding the 

threshold.

The top guide inspection locations 

are those that have high neutron 

fluences exceeding the IASCC 

threshold. 

The extent and frequency of 

examination of the top guide is 

similar to the examination of the 

control rod drive housing guide tube 

in BWRVIP-47.
October 2005

A-169 NUREG-1833

A.6. Summary of MEAP Combinations in GALL Vol. 2 AMR Tables

Material Environment Aging Effect/ 

Mechanism Aging Management Programs

Referring 

GALL Rev.1

Chapters

SRPLR IDRelated 

Item

Location in 

AMR 

Chapters

IV 30 R-106 B2.1-a

R-109 B2.1-e

R-116 B2.2-a

R-120 B2.3-a

Cracking/ stress 

corrosion cracking, 

irradiation-assisted 

stress corrosion 

cracking

R-123 B2.4-a

R-138 B2.5-k

R-143 B2.6-a

R-146 B3.1-a

R-149 B3.2-a

R-155 B3.3-a

R-159 B3.4-a

R-166 B3.5-a

R-172 B4.1-a

Chapter XI.M2, "Water Chemistry" 

for PWR primary water 

No further aging management review 

is necessary if the applicant provides 

a commitment in the FSAR 

supplement to (1) participate in the 

industry programs for investigating 

and managing aging effects on 

reactor internals; (2) evaluate and 

implement the results of the industry 

programs as applicable to the reactor 

internals; and (3) upon completion of 

these programs, but not less than 24 

months before entering the period of 

extended operation, submit an 

inspection plan for reactor internals 

to the NRC for review and approval.

R-173 B4.1-b

R-175 B4.2-a

R-176 B4.2-b

R-180 B4.3-a

R-181 B4.3-b

R-185 B4.4-a

R-193 B4.5-a

R-202 B4.6-a

R-209 B4.7-a

R-214 B4.8-a
NUREG-1833

A-170 October 2005

A.6. Summary of MEAP Combinations in GALL Vol. 2 AMR Tables

Material Environment Aging Effect/ 

Mechanism Aging Management Programs

Referring 

GALL Rev.1

Chapters

SRPLR IDRelated 

Item

Location in 

AMR 

Chapters

Chapter XI.M2, "Water Chemistry," 

for PWR primary water 

No further aging management review 

is necessary if the applicant provides 

a commitment in the FSAR 

supplement to (1) participate in the 

industry programs for investigating 

and managing aging effects on 

reactor internals; (2) evaluate and 

implement the results of the industry 

programs as applicable to the reactor 

internals; and (3) upon completion of 

these programs, but not less than 24 

months before entering the period of 

extended operation, submit an 

inspection plan for reactor internals 

to the NRC for review and approval.

IV 30 R-125 B2.4-c, B4.5-g

Loss of material/ wear Chapter XI.M1, “ASME Section XI 

Inservice Inspection, Subsections 

IWB, IWC, and IWD,” for Class 1 

components

IV 63 R-142 B2.5-o

R-148 B3.1-c

R-152 B3.2-d

R-156 B3.3-b

R-179 B4.2-f

R-190 B4.4-f

R-208 B4.6-h
October 2005

A-171 NUREG-1833

A.6. Summary of MEAP Combinations in GALL Vol. 2 AMR Tables

Material Environment Aging Effect/ 

Mechanism Aging Management Programs

Referring 

GALL Rev.1

Chapters

SRPLR IDRelated 

Item

Location in 

AMR 

Chapters

Loss of preload/ 

stress relaxation

IV 27 R-108 B2.1-d

R-129 B2.4-h

R-184 B4.3-e

No further aging management review 

is necessary if the applicant provides 

a commitment in the FSAR 

supplement to (1) participate in the 

industry programs for investigating 

and managing aging effects on 

reactor internals; (2) evaluate and 

implement the results of the industry 

programs as applicable to the reactor 

internals; and (3) upon completion of 

these programs, but not less than 24 

months before entering the period of 

extended operation, submit an 

inspection plan for reactor internals 

to the NRC for review and approval.

R-201 B4.5-j

Reactor coolant 

and neutron flux

Loss of fracture 

toughness/ neutron 

irradiation 

embrittlement, void 

swelling

IV 22 R-122 B2.3-c

R-127 B2.4-e

R-128 B2.4-f B4.5-i

R-132 B2.5-c

R-141 B2.5-n

R-157 B3.3-a

R-161 B3.4-c

No further aging management review 

is necessary if the applicant provides 

a commitment in the FSAR 

supplement to (1) participate in the 

industry programs for investigating 

and managing aging effects on 

reactor internals; (2) evaluate and 

implement the results of the industry 

programs as applicable to the reactor 

internals; and (3) upon completion of 

these programs, but not less than 24 

months before entering the period of 

extended operation, submit an 

inspection plan for reactor internals 

to the NRC for review and approval. R-178 B4.2-e

R-216 B4.8-c
NUREG-1833

A-172 October 2005

A.6. Summary of MEAP Combinations in GALL Vol. 2 AMR Tables

Material Environment Aging Effect/ 

Mechanism Aging Management Programs

Referring 

GALL Rev.1

Chapters

SRPLR IDRelated 

Item

Location in 

AMR 

Chapters

Sodium 

pentaborate 

solution

Loss of material/ 

pitting and crevice 

corrosion

Chapter XI.M2, “Water Chemistry,” 

for BWR water 

The AMP is to be augmented by 

verifying the effectiveness of water 

chemistry control. See Chapter 

XI.M32, “One-Time Inspection,” for 

an acceptable verification program.

VII 30 AP-73 E2.

Sodium 

pentaborate 

solution >60°C 

(>140°F)

Cracking/ stress 

corrosion cracking

Chapter XI.M2, “Water Chemistry,” 

for BWR water 

The AMP is to be augmented by 

verifying the effectiveness of water 

chemistry control. See Chapter 

XI.M32, “One-Time Inspection,” for 

an acceptable verification program.

VII 4 A-59 E2.1-a E2.2-a 

E2.3-a E2.4-a 

Soil Loss of material/ 

pitting and crevice 

corrosion

A plant-specific aging management 

program is to be evaluated.

V 4 EP-31 D1. D2.

VII 29 AP-56 C1. C3. G. H1. 

H2.

A plant-specific aging management 

program is to be evaluated.

VIII 16 SP-37 E. G.

Steam Cracking/ stress 

corrosion cracking

Chapter XI.M2, “Water Chemistry,” 

for PWR secondary water

VIII 39 SP-44 A. B1.
October 2005

A-173 NUREG-1833

A.6. Summary of MEAP Combinations in GALL Vol. 2 AMR Tables

Material Environment Aging Effect/ 

Mechanism Aging Management Programs

Referring 

GALL Rev.1

Chapters

SRPLR IDRelated 

Item

Location in 

AMR 

Chapters

Chapter XI.M2, “Water Chemistry,” 

for BWR water 

The AMP is to be augmented by 

verifying the effectiveness of water 

chemistry control. See Chapter 

XI.M32, “One-Time Inspection,” for 

an acceptable verification program.

VIII 12 SP-45 A. B2.

Loss of material/ 

pitting and crevice 

corrosion

Chapter XI.M2, “Water Chemistry,” 

for BWR water

VIII 37 SP-46 A. B2.

Chapter XI.M2, “Water Chemistry,” 

for PWR secondary water

VIII 37 SP-43 A. B1.

Treated borated 

water

Cracking/ stress 

corrosion cracking, 

cyclic loading

Chapter XI.M2, “Water Chemistry,” 

for PWR primary water 

The AMP is to be augmented by 

verifying the absence of cracking due 

to stress corrosion cracking and 

cyclic loading. A plant specific aging 

management program is to be 

evaluated.

VII 9 A-76 E1.5-a 

Cumulative fatigue 

damage/ fatigue

Fatigue is a time-limited aging 

analysis (TLAA) to be evaluated for 

the period of extended operation. 

See the Standard Review Plan, 

Section 4.3 “Metal Fatigue,” for 

acceptable methods for meeting the 

requirements of 10 CFR 54.21(c)(1).

V 1 E-13 D1.1-c D1.4-a 

VII 2 A-100 E1.8-a

A-57 E1.1-a E1.3-a 

E1.7-a E1.8-a 
NUREG-1833

A-174 October 2005

A.6. Summary of MEAP Combinations in GALL Vol. 2 AMR Tables

Material Environment Aging Effect/ 

Mechanism Aging Management Programs

Referring 

GALL Rev.1

Chapters

SRPLR IDRelated 

Item

Location in 

AMR 

Chapters

Loss of material/ 

erosion

A plant-specific aging management 

program is to be evaluated for 

erosion of the orifice due to extended 

use of the centrifugal HPSI pump for 

normal charging. See LER 50-

275/94-023 for evidence of erosion.

V 12 E-24 D1.2-c 

Loss of material/ 

pitting and crevice 

corrosion

Chapter XI.M2, “Water Chemistry,” 

for PWR primary water

V 49 EP-41 A. D1. 

Treated borated 

water >60°C 

(>140°F)

Cracking/ stress 

corrosion cracking

Chapter XI.M2, “Water Chemistry,” 

for PWR primary water

V 48 E-12 A.1-a A.1-c 

A.3-a A.4-a 

D1.1-a D1.2-a 

D1.4-b D1.7-b 

D1.8-a 

VII 90 A-97 A2.1-c

AP-82 E1. 

Cracking/ stress 

corrosion cracking, 

cyclic loading

Chapter XI.M2, “Water Chemistry,” 

for PWR primary water. 

The AMP is to be augmented by 

verifying the absence of cracking due 

to stress corrosion cracking and 

cyclic loading, or loss of material due 

to pitting and crevice corrosion. An 

acceptable verification program is to 

include temperature and radioactivity 

monitoring of the shell side water, 

and eddy current testing of tubes.

VII 7 A-69 E1.8-b 
October 2005

A-175 NUREG-1833

A.6. Summary of MEAP Combinations in GALL Vol. 2 AMR Tables

Material Environment Aging Effect/ 

Mechanism Aging Management Programs

Referring 

GALL Rev.1

Chapters

SRPLR IDRelated 

Item

Location in 

AMR 

Chapters

Chapter XI.M2, “Water Chemistry,” 

for PWR primary water 

The AMP is to be augmented by 

verifying the absence of cracking due 

to stress corrosion cracking and 

cyclic loading. A plant specific aging 

management program is to be 

evaluated.

VII 8 A-84 E1.7-c 

Treated water Cumulative fatigue 

damage/ fatigue

Fatigue is a time-limited aging 

analysis (TLAA) to be evaluated for 

the period of extended operation. 

See the Standard Review Plan, 

Section 4.3 “Metal Fatigue,” for 

acceptable methods for meeting the 

requirements of 10 CFR 54.21(c)(1).

VII 2 A-62 E3.1-b E3.2-b 

E4.1-b 

Loss of material/ 

pitting and crevice 

corrosion

Chapter XI.M2, “Water Chemistry,” 

for BWR water 

The AMP is to be augmented by 

verifying the effectiveness of water 

chemistry control. See Chapter 

XI.M32, “One-Time Inspection,” for 

an acceptable verification program.

VII 24 A-58 A4.1-a A4.6-a 

E4.1-a E3. 

VIII 15 S-21 E.4-a E.4-d 

Chapter XI.M2, “Water Chemistry,” 

for PWR primary water 

The AMP is to be augmented by 

verifying the effectiveness of water 

chemistry control. See Chapter 

XI.M32, “One-Time Inspection,” for 

an acceptable verification program.

VIII 15 S-22 E.4-a E.4-d 

F.4-a F.4-d 
NUREG-1833

A-176 October 2005

A.6. Summary of MEAP Combinations in GALL Vol. 2 AMR Tables

Material Environment Aging Effect/ 

Mechanism Aging Management Programs

Referring 

GALL Rev.1

Chapters

SRPLR IDRelated 

Item

Location in 

AMR 

Chapters

Chapter XI.M2, “Water Chemistry” 

The AMP is to be augmented by 

verifying the effectiveness of water 

chemistry control. See Chapter 

XI.M32, “One-Time Inspection,” for 

an acceptable verification program.

V 3 E-33 C.1-b 

VIII 15 SP-16 B1. C. D1. F. 

G. E. D2. 

Chapter XI.M2, “Water Chemistry” 

for BWR water 

The AMP is to be augmented by 

verifying the effectiveness of water 

chemistry control. See Chapter 

XI.M32, “One-Time Inspection,” for 

an acceptable verification program.

V 5 EP-32 D2.

Reduction of heat 

transfer/ fouling

Chapter XI.M2, “Water Chemistry” 

The AMP is to be augmented by 

verifying the effectiveness of water 

chemistry control. See Chapter 

XI.M32, “One-Time Inspection,” for 

an acceptable verification program.

V 10 EP-34 A. D2.

VII 3 AP-62 A4. E3.

VIII 8 SP-40 E. F.

Treated water 

>60°C (>140°F)

Cracking/ stress 

corrosion cracking

Chapter XI.M7, “BWR Stress 

Corrosion Cracking,” and 

Chapter XI.M2, “Water Chemistry,” 

for BWR water

VII 38 A-61 E4.1-c E4.3-a 
October 2005

A-177 NUREG-1833

A.6. Summary of MEAP Combinations in GALL Vol. 2 AMR Tables

Material Environment Aging Effect/ 

Mechanism Aging Management Programs

Referring 

GALL Rev.1

Chapters

SRPLR IDRelated 

Item

Location in 

AMR 

Chapters

A plant-specific aging management 

program is to be evaluated.

VII 5 A-85 E3.3-d 

Chapter XI.M2, “Water Chemistry,” 

for BWR water

VII 39 A-96 A2.1-c

Chapter XI.M2, “Water Chemistry,” 

for BWR water 

The AMP is to be augmented by 

verifying the effectiveness of water 

chemistry control. See Chapter 

XI.M32, “One-Time Inspection,” for 

an acceptable verification program.

VIII 13 SP-19 E.

Chapter XI.M2, “Water Chemistry,” 

for PWR secondary water 

The AMP is to be augmented by 

verifying the effectiveness of water 

chemistry control. See Chapter 

XI.M32, “One-Time Inspection,” for 

an acceptable verification program.

VIII 13 S-39 F.4-a

SP-17 B1. C. E. D1. 

F. G. 

Chapter XI.M2, “Water Chemistry” 

The AMP is to be augmented by 

verifying the effectiveness of water 

chemistry control. See Chapter 

XI.M32, “One-Time Inspection,” for 

an acceptable verification program.

VIII 13 SP-42 E.
NUREG-1833

A-178 October 2005

A.6. Summary of MEAP Combinations in GALL Vol. 2 AMR Tables

Material Environment Aging Effect/ 

Mechanism Aging Management Programs

Referring 

GALL Rev.1

Chapters

SRPLR IDRelated 

Item

Location in 

AMR 

Chapters

Cracking/ stress 

corrosion cracking 

and intergranular 

stress corrosion 

cracking

Chapter XI.M7, “BWR Stress 

Corrosion Cracking,” and 

Chapter XI.M2, “Water Chemistry,” 

for BWR water

V 18 E-37 D2.1-c D2.3-c

Cracking/ stress 

corrosion cracking, 

intergranular stress 

corrosion cracking

Chapter XI.M25, “BWR Reactor 

Water Cleanup System”

VII 37 A-60 E3.1-a E3.2-a 

Treated water or 

treated borated 

water

Cracking/ stress 

corrosion cracking 

Loss of 

material/pitting and 

crevice corrosion

Chapter XI.M2, "Water Chemistry" 

and, 

Monitoring of the spent fuel pool 

water level in accordance with 

technical specifications and leakage 

from the leak chase channels.

III 46 T-14 A5.2-b

Water – standing Cracking/ stress 

corrosion cracking 

Loss of 

material/pitting and 

crevice corrosion

A plant-specific aging management 

program is to be evaluated.

III 38 T-23 A7.2-b A8.2-b

Stainless steel 

with or without 

chrome 

plating

Reactor coolant Loss of material/ wear Chapter XI.M37, “Flux Thimble Tube 

Inspection"

IV 60 R-145 B2.6-c

Stainless 

steel; 

dissimilar 

metal welds

Air – indoor 

uncontrolled or air 

– outdoor

Cracking/ stress 

corrosion cracking

Chapter XI.S1, “ASME Section XI, 

Subsection IWE” and Chapter XI.S4, 

“10 CFR Part 50, Appendix J” 

Evaluation of 10 CFR 50.55a/ASME 

Section XI, Subsection IWE is 

augmented as follows: 

II 10 C-15 A3.1-d B4.1-d
October 2005

A-179 NUREG-1833

A.6. Summary of MEAP Combinations in GALL Vol. 2 AMR Tables

Material Environment Aging Effect/ 

Mechanism Aging Management Programs

Referring 

GALL Rev.1

Chapters

SRPLR IDRelated 

Item

Location in 

AMR 

Chapters

(4) Detection of Aging Effects: 

Transgranular Stress corrosion 

cracking (TGSCC) is a concern for 

dissimilar metal welds. In the case of 

bellows assemblies, SCC may cause 

aging effects particularly if the 

material is not shielded from a 

corrosive environment. ASME 

Section XI, Subsection IWE covers 

inspection of these items under 

examination categories E-B, E-F, 

and E-P (10 CFR Part 50, 

Appendix J pressure tests). 

10 CFR 50.55a identifies 

examination categories E-B and E-F 

as optional during the current term of 

operation. For the extended period of 

operation, Examination Categories 

E-B & E-F, and additional 

appropriate examinations to detect 

SCC in bellows assemblies and 

dissimilar metal welds are warranted 

to address this issue. 

(10) Operating Experience: 

IN 92-20 describes an instance of 

containment bellows cracking, 

resulting in loss of leak tightness.
NUREG-1833

A-180 October 2005

A.6. Summary of MEAP Combinations in GALL Vol. 2 AMR Tables

Material Environment Aging Effect/ 

Mechanism Aging Management Programs

Referring 

GALL Rev.1

Chapters

SRPLR IDRelated 

Item

Location in 

AMR 

Chapters

Stainless 

steel; nickel 

alloy

Air with reactor 

coolant leakage 

(Internal) 

or 

Reactor Coolant 

Cracking/ stress 

corrosion cracking 

and intergranular 

stress corrosion 

cracking

A plant-specific aging management 

program is to be evaluated because 

existing programs may not be 

capable of mitigating or detecting 

crack initiation and growth due to 

SCC in the vessel flange leak 

detection line.

IV 19 R-61 A1.1-d

Reactor coolant Changes in IV 33 R-113 B2.1-j

dimensions/ void 

swelling R-119 B2.2-e

R-131 B2.5-b

R-134 B2.5-f

R-151 B3.2-c

R-160 B3.4-b

R-163 B3.4-f

R-168 B3.5-c

R-187 B4.4-c

No further aging management review 

is necessary if the applicant provides 

a commitment in the FSAR 

supplement to (1) participate in the 

industry programs for investigating 

and managing aging effects on 

reactor internals; (2) evaluate and 

implement the results of the industry 

programs as applicable to the reactor 

internals; and (3) upon completion of 

these programs, but not less than 24 

months before entering the period of 

extended operation, submit an 

inspection plan for reactor internals 

to the NRC for review and approval. R-195 B4.5-c

R-204 B4.6-c

R-211 B4.7-c

Cracking/ stress 

corrosion cracking 

and intergranular 

stress corrosion 

cracking

Chapter XI.M7, “BWR Stress 

Corrosion Cracking,” and 

Chapter XI.M2, “Water Chemistry,” 

for BWR water

IV 41 R-68 A1.4-a
October 2005

A-181 NUREG-1833

A.6. Summary of MEAP Combinations in GALL Vol. 2 AMR Tables

Material Environment Aging Effect/ 

Mechanism Aging Management Programs

Referring 

GALL Rev.1

Chapters

SRPLR IDRelated 

Item

Location in 

AMR 

Chapters

Chapter XI.M4, “BWR Vessel ID 

Attachment Welds,” and 

Chapter XI.M2, “Water Chemistry,” 

for BWR water

IV 42 R-64 A1.2-e 

Cracking/ stress 

corrosion cracking, 

intergranular stress 

corrosion cracking, 

cyclic loading

Chapter XI.M8, “BWR Penetrations,” 

and 

Chapter XI.M2, “Water Chemistry,” 

for BWR water

IV 40 R-69 A1.5-a

Cracking/ stress 

corrosion cracking, 

primary water stress 

corrosion cracking

Chapter XI.M2, “Water Chemistry,” 

and 

Chapter XI.M1, “ASME Section XI 

Inservice Inspection, Subsections 

IWB, IWC, and IWD" and, 

For nickel ally, comply with 

applicable NRC Orders and provide 

a commitment in the FSAR 

supplement to submit a plant-specific 

AMP to implement applicable (1) 

Bulletins and Generic Letters and (2) 

staff-accepted industry guidelines

IV 34 R-76 A2.2-b
NUREG-1833

A-182 October 2005

A.6. Summary of MEAP Combinations in GALL Vol. 2 AMR Tables

Material Environment Aging Effect/ 

Mechanism Aging Management Programs

Referring 

GALL Rev.1

Chapters

SRPLR IDRelated 

Item

Location in 

AMR 

Chapters

Cracking/ stress 

corrosion cracking, 

primary water stress 

corrosion cracking, 

irradiation-assisted 

stress corrosion 

cracking

Chapter XI.M2, "Water Chemistry" 

for PWR primary water 

No further aging management review 

is necessary if the applicant provides 

a commitment in the FSAR 

supplement to (1) participate in the 

industry programs for investigating 

and managing aging effects on 

reactor internals; (2) evaluate and 

implement the results of the industry 

programs as applicable to the reactor 

internals; and (3) upon completion of 

these programs, but not less than 24 

months before entering the period of 

extended operation, submit an 

inspection plan for reactor internals 

to the NRC for review and approval.

IV 37 R-112 B2.1-i

R-118 B2.2-d

R-130 B2.5-a

R-133 B2.5-e

R-162 B3.4-e

R-167 B3.5-b

R-186 B4.4-b

R-194 B4.5-b

R-203 B4.6-b

R-210 B4.7-b
October 2005

A-183 NUREG-1833

A.6. Summary of MEAP Combinations in GALL Vol. 2 AMR Tables

Material Environment Aging Effect/ 

Mechanism Aging Management Programs

Referring 

GALL Rev.1

Chapters

SRPLR IDRelated 

Item

Location in 

AMR 

Chapters

Chapter XI.M2, "Water Chemistry" 

for PWR primary water. No further 

aging management review is 

necessary if the applicant provides a 

commitment in the FSAR 

supplement to (1) participate in the 

industry programs for investigating 

and managing aging effects on 

reactor internals; (2) evaluate and 

implement the results of the industry 

programs as applicable to the reactor 

internals; and (3) upon completion of 

these programs, but not less than 24 

months before entering the period of 

extended operation, submit an 

inspection plan for reactor internals 

to the NRC for review and approval.

IV 37 R-150 B3.2-b

Cumulative fatigue 

damage/ fatigue

Fatigue is a time-limited aging 

analysis (TLAA) to be evaluated for 

the period of extended operation. 

See the Standard Review Plan, 

Section 4.3 “Metal Fatigue,” for 

acceptable methods for meeting the 

requirements of 10 CFR 54.21(c)(1).

IV 5 R-53 B1.1-c B1.2-b 

B1.3-b B1.4-b 

B1.5-b B1.6-b 

B2.1-c B2.1-h 

B2.1-m B2.2-c 

B2.2-f B2.3-d 

B2.4-g B2.5-d 

B2.5-j B2.5-p 

B3.2-f B3.4-d 

B3.5-g B4.1-d 

B4.2-d B4.3-f 

B4.4-e B4.5-f 

B4.6-f 

Loss of material/ 

pitting and crevice 

corrosion

Chapter XI.M2, “Water Chemistry,” 

for PWR primary water

IV 83 RP-24 B2. B3. B4.
NUREG-1833

A-184 October 2005

A.6. Summary of MEAP Combinations in GALL Vol. 2 AMR Tables

Material Environment Aging Effect/ 

Mechanism Aging Management Programs

Referring 

GALL Rev.1

Chapters

SRPLR IDRelated 

Item

Location in 

AMR 

Chapters

Chapter XI.M1, “ASME Section XI 

Inservice Inspection, Subsections 

IWB, IWC, and IWD,” for Class 1 

components and Chapter XI.M2, 

“Water Chemistry” for BWR water

IV 47 RP-26 B1.

Loss of material/ wear Chapter XI.M1, “ASME Section XI 

Inservice Inspection, Subsections 

IWB, IWC, and IWD,” for Class 1 

components

IV 63 R-115 B2.1-l

R-170 B3.5-e

Loss of preload/ 

stress relaxation

IV 27 R-114 B2.1-k

R-136 B2.5-h

R-137 B2.5-i

No further aging management review 

is necessary if the applicant provides 

a commitment in the FSAR 

supplement to (1) participate in the 

industry programs for investigating 

and managing aging effects on 

reactor internals; (2) evaluate and 

implement the results of the industry 

programs as applicable to the reactor 

internals; and (3) upon completion of 

these programs, but not less than 24 

months before entering the period of 

extended operation, submit an 

inspection plan for reactor internals 

to the NRC for review and approval.

R-154 B3.2-g

R-165 B3.4-h

R-192 B4.4-h

R-197 B4.5-e

R-207 B4.6-g

R-213 B4.7-e
October 2005

A-185 NUREG-1833

A.6. Summary of MEAP Combinations in GALL Vol. 2 AMR Tables

Material Environment Aging Effect/ 

Mechanism Aging Management Programs

Referring 

GALL Rev.1

Chapters

SRPLR IDRelated 

Item

Location in 

AMR 

Chapters

Reactor coolant 

and neutron flux

IV 22 R-135 B2.5-g

R-164 B3.4-g

Loss of fracture 

toughness/ neutron 

irradiation 

embrittlement, void 

swelling R-169 B3.5-d

R-188 B4.4-d

R-196 B4.5-d

R-205 B4.6-d

No further aging management review 

is necessary if the applicant provides 

a commitment in the FSAR 

supplement to (1) participate in the 

industry programs for investigating 

and managing aging effects on 

reactor internals; (2) evaluate and 

implement the results of the industry 

programs as applicable to the reactor 

internals; and (3) upon completion of 

these programs, but not less than 24 

months before entering the period of 

extended operation, submit an 

inspection plan for reactor internals 

to the NRC for review and approval.

R-212 B4.7-d

Stainless 

steel; nickel 

alloy welds 

and/or 

buttering

Reactor coolant Cracking/ stress 

corrosion cracking, 

primary water stress 

corrosion cracking

Chapter XI.M1, “ASME Section XI 

Inservice Inspection, Subsections 

IWB, IWC, and IWD,” for Class 1 

components and 

Chapter XI.M2, “Water Chemistry,” 

for PWR primary water

IV 69 R-83 A2.4-b

Stainless 

steel; steel

Air – indoor 

uncontrolled

Cracking/ cyclic 

loading 

(CLB fatigue analysis 

does not exist)

Chapter XI.S1, “ASME Section XI, 

Subsection IWE ” and Chapter XI.S4, 

“10 CFR Part 50, Appendix J” 

Evaluation of 10 CFR 50.55a/ ASME 

Section XI, Subsection IWE is 

augmented as follows: 

(4) Detection of Aging Effects: VT-3 

visual inspection may not detect fine 

cracks.

II 13 C-20 B1.1.1-b 
NUREG-1833

A-186 October 2005

A.6. Summary of MEAP Combinations in GALL Vol. 2 AMR Tables

Material Environment Aging Effect/ 

Mechanism Aging Management Programs

Referring 

GALL Rev.1

Chapters

SRPLR IDRelated 

Item

Location in 

AMR 

Chapters

Chapter XI.S1, “ASME Section XI, 

Subsection IWE ” and Chapter XI.S4, 

“10 CFR Part 50, Appendix J” 

Evaluation of 10 CFR 50.55a/ASME 

Section XI, Subsection IWE is 

augmented as follows: 

(4) Detection of Aging Effects: VT-3 

visual inspection may not detect fine 

cracks.

II 13 C-47 B2.2.2-c

Cumulative fatigue 

damage/ fatigue 

(Only if CLB fatigue 

analysis exists)

Fatigue is a time-limited aging 

analysis (TLAA) to be evaluated for 

the period of extended operation. 

See the Standard Review Plan, 

Section 4.6, “Containment Liner 

Plate and Penetration Fatigue 

Analysis” for acceptable methods for 

meeting the requirements of 

10 CFR 54.21(c)(1).

II 8 C-21 B1.1.1-c 

Air – indoor 

uncontrolled or 

treated water (as 

applicable)

Cumulative fatigue 

damage/ fatigue 

(Only if CLB fatigue 

analysis exists)

Fatigue is a time-limited aging 

analysis (TLAA) to be evaluated for 

the period of extended operation. 

See the Standard Review Plan, 

Section 4.6, “Containment Liner 

Plate and Penetration Fatigue 

Analysis” for acceptable methods for 

meeting the requirements of 

10 CFR 54.21(c)(1).

II 8 C-48 B2.2.2-d

Loss of material/ 

general, pitting, and 

crevice corrosion

Chapter XI.S1, “ASME Section XI, 

Subsection IWE“ and Chapter XI.S4, 

“10 CFR Part 50, Appendix J"

II 20 C-49 B2.2.2-b B1.2.
October 2005

A-187 NUREG-1833

A.6. Summary of MEAP Combinations in GALL Vol. 2 AMR Tables

Material Environment Aging Effect/ 

Mechanism Aging Management Programs

Referring 

GALL Rev.1

Chapters

SRPLR IDRelated 

Item

Location in 

AMR 

Chapters

Air with metal 

temperature up to 

288°C (550°F)

Cracking/ cyclic 

loading

Chapter XI.M1, “ASME Section XI 

Inservice Inspection, Subsections 

IWB, IWC, and IWD,” for Class 1 

components

IV 61 R-19 C2.5-v 

Diesel exhaust Loss of material/ 

general (steel only), 

pitting and crevice 

corrosion

A plant-specific aging management 

program is to be evaluated.

VII 18 A-27 H2.4-a 

Reactor coolant Cracking/ cyclic 

loading

Chapter XI.M1, “ASME Section XI 

Inservice Inspection, Subsections 

IWB, IWC, and IWD,” for Class 1 

components 

The AMP in Chapter XI.M1 is to be 

augmented to detect cracking due to 

cyclic loading and verification of the 

program's effectiveness is necessary 

to ensure that significant degradation 

is not occurring and the component 

intended function will be maintained 

during the extended period of 

operation. An acceptable verification 

program is to include temperature 

and radioactivity monitoring of the 

shell side water, and eddy current 

testing of tubes.

IV 26 R-225 C1.4-a 
NUREG-1833

A-188 October 2005

A.6. Summary of MEAP Combinations in GALL Vol. 2 AMR Tables

Material Environment Aging Effect/ 

Mechanism Aging Management Programs

Referring 

GALL Rev.1

Chapters

SRPLR IDRelated 

Item

Location in 

AMR 

Chapters

Cracking/ stress 

corrosion cracking, 

intergranular stress 

corrosion cracking (for 

stainless steel only), 

and thermal and 

mechanical loading

Chapter XI.M1, “ASME Section XI 

Inservice Inspection, Subsections 

IWB, IWC, and IWD,” for Class 1 

components, and 

Chapter XI.M2, “Water Chemistry,” 

for BWR water and 

XI.M35, "One-Time Inspection of 

ASME Code Class 1 Small-bore 

Piping"

IV 48 R-03 C1.1-i 

Loss of material/ 

general (steel only), 

pitting and crevice 

corrosion

Chapter XI.M2, “Water Chemistry,” 

for BWR water 

The AMP is to be augmented by 

verifying the effectiveness of water 

chemistry control. See Chapter 

XI.M32, “One-Time Inspection,” for 

an acceptable verification program.

IV 13 R-16 C1.4-b 

System 

temperature up to 

288°C (550°F)

Loss of material/ wear Chapter XI.M18, “Bolting Integrity” IV 52 R-29 C1.2-d C1.3-e 

System 

temperature up to 

340°C (644°F)

Cumulative fatigue 

damage/ fatigue

Fatigue is a time-limited aging 

analysis (TLAA) to be evaluated for 

the period of extended operation. 

See the Standard Review Plan, 

Section 4.3 “Metal Fatigue,” for 

acceptable methods for meeting the 

requirements of 10 CFR 54.21(c)(1).

IV 7 R-18 C2.3-d C2.4-d 

C2.5-t C2.5-w 
October 2005

A-189 NUREG-1833

A.6. Summary of MEAP Combinations in GALL Vol. 2 AMR Tables

Material Environment Aging Effect/ 

Mechanism Aging Management Programs

Referring 

GALL Rev.1

Chapters

SRPLR IDRelated 

Item

Location in 

AMR 

Chapters

Treated Water < 

60C (<140 F)

Loss of material/ 

general, pitting, and 

crevice corrosion

Chapter XI.M2, “Water Chemistry,” 

for BWR water, and 

Chapter XI.S3, “ASME Section XI, 

Subsection IWF”

III 49 TP-10 B1.1 

Reactor coolant Loss of material/ 

pitting and crevice 

corrosion

Chapter XI.M2, “Water Chemistry,” 

for PWR primary water

Stainless IV 83 RP-28 A2.

steel; steel 

with nickelalloy or 

stainless steel 

cladding; 

nickel-alloy

Chapter XI.M2, “Water Chemistry,” 

for BWR water 

The AMP is to be augmented by 

verifying the effectiveness of water 

chemistry control. See Chapter 

XI.M32, “One-Time Inspection,” for 

an acceptable verification program.

IV 14 RP-25 A1.

Stainless 

steel; steel 

with stainless 

steel cladding

Closed cycle 

cooling water

Loss of material/ 

microbiologically 

influenced corrosion

Chapter XI.M21, “Closed-Cycle 

Cooling Water System”

VII 49 A-67 E3.4-b E4.4-a 

Closed cycle 

cooling water 

>60°C (>140°F)

Cracking/ stress 

corrosion cracking

Chapter XI.M21, “Closed-Cycle 

Cooling Water System”

VII 46 A-68 E3.4-a 

Reactor coolant Cracking/ cyclic 

loading

Chapter XI.M1, “ASME Section XI 

Inservice Inspection, Subsections 

IWB, IWC, and IWD,” for Class 1 

components

IV 62 R-56 C2.1-c 
NUREG-1833

A-190 October 2005

A.6. Summary of MEAP Combinations in GALL Vol. 2 AMR Tables

Material Environment Aging Effect/ 

Mechanism Aging Management Programs

Referring 

GALL Rev.1

Chapters

SRPLR IDRelated 

Item

Location in 

AMR 

Chapters

Cracking/ stress 

corrosion cracking

Chapter XI.M1, “ASME Section XI 

Inservice Inspection, Subsections 

IWB, IWC, and IWD,” for Class 1 

components and 

Chapter XI.M2, “Water Chemistry,” 

for PWR primary water

IV 68 R-07 C2.2-f C2.5-h 

D1.1-i C2.5-m 

R-09 C2.3-b C2.4-b 

R-30 C2.1-c 

Cracking/ stress 

corrosion cracking, 

thermal and 

mechanical loading

Chapter XI.M1, “ASME Section XI 

Inservice Inspection, Subsections 

IWB, IWC, and IWD,” for Class 1 

components, and 

Chapter XI.M2, “Water Chemistry,” 

for PWR water and 

XI.M35, "One-Time Inspection of 

ASME Code Class 1 Small-bore 

Piping"

IV 70 R-02 C2.1-g C2.2-h 

Treated borated 

water

Loss of material/ 

pitting and crevice 

corrosion

Chapter XI.M2, “Water Chemistry,” 

for PWR primary water

VII 91 AP-79 E1. A2. A3. 

Treated borated 

water >60°C 

(>140°F)

Cracking/ stress 

corrosion cracking

Chapter XI.M1, “ASME Section XI 

Inservice Inspection, Subsections 

IWB, IWC, and IWD,” for Class 1 

components and 

Chapter XI.M2, “Water Chemistry,” 

for PWR primary water

IV 68 R-14 C2.6-c 
October 2005

A-191 NUREG-1833

A.6. Summary of MEAP Combinations in GALL Vol. 2 AMR Tables

Material Environment Aging Effect/ 

Mechanism Aging Management Programs

Referring 

GALL Rev.1

Chapters

SRPLR IDRelated 

Item

Location in 

AMR 

Chapters

Treated water Loss of material/ 

pitting and crevice 

corrosion

Chapter XI.M2, “Water Chemistry,” 

for BWR water 

The AMP is to be augmented by 

verifying the effectiveness of water 

chemistry control. See Chapter 

XI.M32, “One-Time Inspection,” for 

an acceptable verification program.

VII 23 A-70 A4.4-b 

Treated water 

>60°C (>140°F)

Cracking/ stress 

corrosion cracking

A plant-specific aging management 

program is to be evaluated.

VII 5 A-71 E3.4-a 

Steel Air – indoor None None V 54 EP-4 F.

controlled 

(External) VII 95 AP-2 J.

VIII 42 SP-1 I.

Air – indoor 

uncontrolled

Cumulative fatigue 

damage/ fatigue

Fatigue is a time-limited aging IV 1 R-70 A1.7-a A2.8-a

analysis (TLAA) to be evaluated for 

the period of extended operation. 

See the Standard Review Plan, 

Section 4.3 “Metal Fatigue,” for 

acceptable methods for meeting the 

requirements of 10 CFR 54.21(c)(1).

VII 2 A-34 E1.1-a E1.3-a 

E1.7-a E1.8-a 

E3.2-c 

Cumulative fatigue 

damage/ fatigue 

(Only if CLB fatigue 

analysis exists)

Fatigue is a time-limited aging 

analysis (TLAA) to be evaluated for 

the period of extended operation. 

See the Standard Review Plan, 

Section 4.3 “Metal Fatigue,” for 

acceptable methods for meeting the 

requirements of 10 CFR 54.21(c)(1).

III 42 T-26 B1.1.1-c 

B1.2.1-c 

B1.3.1-b

Fretting or lockup/ 

mechanical wear

Chapter XI.S1, “ASME Section XI, 

Subsection IWE”

II 21 C-23 B1.1.1-e 

B2.2.2-e 

B2.1.1-d B1.2.
NUREG-1833

A-192 October 2005

A.6. Summary of MEAP Combinations in GALL Vol. 2 AMR Tables

Material Environment Aging Effect/ 

Mechanism Aging Management Programs

Referring 

GALL Rev.1

Chapters

SRPLR IDRelated 

Item

Location in 

AMR 

Chapters

Loss of material/ 

general, pitting, and 

crevice corrosion

Chapter XI.S1, “ASME Section XI, 

Subsection IWE” 

For inaccessible areas (embedded 

containment steel shell or liner), loss 

of material due to corrosion is not 

significant if the following conditions 

are satisfied: 

1. Concrete meeting the 

requirements of ACI 318 or 349 and 

the guidance of 201.2R was used for 

the containment concrete in contact 

with the embedded containment shell 

or liner. 

2. The concrete is monitored to 

ensure that it is free of penetrating 

cracks that provide a path for water 

seepage to the surface of the 

containment shell or liner. 

3. The moisture barrier, at the 

junction where the shell or liner 

becomes embedded, is subject to 

aging management activities in 

accordance with ASME Section XI, 

Subsection IWE requirements. 

4. Borated water spills and water 

ponding on the containment concrete 

floor are not common and when 

detected are cleaned up in a timely 

manner. 

If any of the above conditions cannot 

be satisfied, then a plant-specific 

aging management program for 

II 6 C-09 A1.2-a A2.1-a 

B3.2.2-a
October 2005

A-193 NUREG-1833

A.6. Summary of MEAP Combinations in GALL Vol. 2 AMR Tables

Material Environment Aging Effect/ 

Mechanism Aging Management Programs

Referring 

GALL Rev.1

Chapters

SRPLR IDRelated 

Item

Location in 

AMR 

Chapters

corrosion is necessary. 

Chapter XI.S4, “10 CFR Part 50, 

Appendix J”

Loss of material/ wear Chapter XI.M26, “Fire Protection” VII 63 A-21 G.1-d G.2-d 

G.3-d G.4-d 

G.5-c 

Air – indoor 

uncontrolled 

or air outdoor

Loss of leak tightness/ 

mechanical wear of 

locks, hinges and 

closure mechanisms

Chapter XI.S4, “10 CFR Part 50, 

Appendix J” and 

Plant Technical Specifications

II 17 C-17 A3.2-b B4.2-b

Air – indoor 

uncontrolled 

(External)

Cumulative fatigue 

damage/ fatigue

Fatigue is a time-limited aging 

analysis (TLAA) to be evaluated for 

the period of extended operation for 

structural girders of cranes that fall 

within the scope of 10 CFR 54. See 

the Standard Review Plan, Section 

4.7, “Other Plant-Specific TimeLimited Aging Analyses,” for generic 

guidance for meeting the 

requirements of 10 CFR 54.21(c)(1).

VII 1 A-06 B.1-a 

Loss of material/ 

general corrosion

Chapter XI.M36, "External Surfaces 

Monitoring"

V 31 E-26 A.2-a A.5-a 

B.1-a B.2-a 

D2.1-e D2.5-a 

E-35 C.1-a

E-40 B.1-a

E-44 E. 

VII 55 A-105 F1.1-a F2.1-a 

F3.1-a F4.1-a 

I.
NUREG-1833

A-194 October 2005

A.6. Summary of MEAP Combinations in GALL Vol. 2 AMR Tables

Material Environment Aging Effect/ 

Mechanism Aging Management Programs

Referring 

GALL Rev.1

Chapters

SRPLR IDRelated 

Item

Location in 

AMR 

Chapters

56 A-10 F1.1-a F1.4-a 

F2.1-a F2.4-a 

F3.1-a F3.4-a 

F4.1-a 

57 A-80 D.1-a D.2-a 

D.3-a D.4-a 

D.5-a D.6-a 

58 A-77 I.1-b 

VIII 28 S-29 H.1-b 

Chapter XI.M23, “Inspection of 

Overhead Heavy Load and Light 

Load (Related to Refueling) Handling 

Systems”

VII 73 A-07 B.1-b 

Loss of material/ 

general, pitting, and 

crevice corrosion

Chapter XI.M18, “Bolting Integrity” V 23 EP-25 E.

VII 43 AP-27 I.

VIII 22 S-34 H.

Chapter XI.M36, "External Surfaces 

Monitoring"

VII 59 AP-41 F1. F2. F3. F4. 

G. H2.

Chapter XI.S6, “Structures 

Monitoring Program”

VII 86 A-94 A1.1-a 

Loss of material/ wear Chapter XI.M23, “Inspection of 

Overhead Heavy Load and Light 

Load (Related to Refueling) Handling 

Systems”

VII 74 A-05 B.2-a 

Loss of preload/ 

thermal effects, 

gasket creep, and 

self-loosening 

Chapter XI.M18, “Bolting Integrity” V 24 EP-24 E.
October 2005

A-195 NUREG-1833

A.6. Summary of MEAP Combinations in GALL Vol. 2 AMR Tables

Material Environment Aging Effect/ 

Mechanism Aging Management Programs

Referring 

GALL Rev.1

Chapters

SRPLR IDRelated 

Item

Location in 

AMR 

Chapters

VII 45 AP-26 I.

VIII 22 S-33 H.

Air – indoor 

uncontrolled 

(Internal)

Loss of material/ 

general corrosion

Chapter XI.M38, "Inspection of 

Internal Surfaces in Miscellaneous 

Piping and Ducting Components"

V 32 E-25 B.2-a 

E-29 A.2-a A.5-a 

D2.5-a 

Loss of material/ 

general corrosion and 

fouling

A plant-specific aging management 

program is to be evaluated.

V 13 E-04 D2.5-b 

Loss of material/ 

general, pitting, and 

crevice corrosion

Chapter XI.M38, "Inspection of 

Internal Surfaces in Miscellaneous 

Piping and Ducting Components"

V 33 EP-42 A.

Air – indoor 

uncontrolled or air 

– outdoor

Loss of material/ 

corrosion

Chapter XI.S6, “Structures 

Monitoring Program” 

If protective coatings are relied upon 

to manage the effects of aging, the 

structures monitoring program is to 

include provisions to address 

protective coating monitoring and 

maintenance.

III 25 T-11 A1.2-a A2.2-a 

A3.2-a A4.2-a 

A5.2-a A7.2-a 

A8.2-a

Chapter XI.S2, “ASME Section XI, 

Subsection IWL”

II 22 C-10 A1.3-a

B2.2.3-a

Loss of material/ 

general and pitting 

corrosion

Chapter XI.S6, “Structures 

Monitoring Program”

III 39 T-30 B2.1-a B3.1-a 

B4.1-a B5.1-a

Chapter XI.S3, “ASME Section XI, 

Subsection IWF”

III 53 T-24 B1.1.1-a 

B1.2.1-a 

B1.3.1-a
NUREG-1833

A-196 October 2005

A.6. Summary of MEAP Combinations in GALL Vol. 2 AMR Tables

Material Environment Aging Effect/ 

Mechanism Aging Management Programs

Referring 

GALL Rev.1

Chapters

SRPLR IDRelated 

Item

Location in 

AMR 

Chapters

Loss of material/ 

general, pitting, and 

crevice corrosion

Chapter XI.S1, “ASME Section XI, 

Subsection IWE,” 

Chapter XI.S4, “10 CFR Part 50, 

Appendix J”

II 18 C-16 A3.2-a B4.2-a

Loss of prestress/ 

relaxation; shrinkage; 

creep; elevated 

temperature

Loss of tendon prestress is a timelimited aging analysis (TLAA) to be 

evaluated for the period of extended 

operation. 

See the Standard Review Plan, 

Section 4.5, “Concrete Containment 

Tendon Prestress” for acceptable 

methods for meeting the 

requirements of 

10 CFR 54.21(c)(1)(i) and (ii). See 

Chapter X.S1 of this report for 

meeting the requirements of 

10 CFR 54.21(c)(1)(iii). 

For periodic monitoring of prestress, 

see Chapter XI.S2. 

II 7 C-11 A1.3-b

B2.2.3-b
October 2005

A-197 NUREG-1833

A.6. Summary of MEAP Combinations in GALL Vol. 2 AMR Tables

Material Environment Aging Effect/ 

Mechanism Aging Management Programs

Referring 

GALL Rev.1

Chapters

SRPLR IDRelated 

Item

Location in 

AMR 

Chapters

Air – indoor 

uncontrolled or 

treated water (as 

applicable)

Loss of material/ 

general, pitting, and 

crevice corrosion

Chapter XI.S1, “ASME Section XI, 

Subsection IWE” 

For inaccessible areas (embedded 

containment steel shell or liner), loss 

of material due to corrosion is not 

significant if the following conditions 

are satisfied: 

Concrete meeting the specifications 

of ACI 318 or 349 and the guidance 

of 201.2R was used for the 

containment concrete in contact with 

the embedded containment shell or 

liner. The concrete is monitored to 

ensure that it is free of penetrating 

cracks that provide a path for water 

seepage to the surface of the 

containment shell or liner. The 

moisture barrier, at the junction 

where the shell or liner becomes 

embedded, is subject to aging 

management activities in accordance 

with ASME Section XI, Subsection 

IWE requirements. Water ponding on 

the containment concrete floor are 

not common and when detected are 

cleaned up in a timely manner. 

If any of the above conditions cannot 

be satisfied, then a plant-specific 

aging management program for 

corrosion is necessary. 

Chapter XI.S4, “10 CFR Part 50, 

Appendix J”

II 5 C-46 B2.1.1-a 

B2.2.2-a B1.2.
NUREG-1833

A-198 October 2005

A.6. Summary of MEAP Combinations in GALL Vol. 2 AMR Tables

Material Environment Aging Effect/ 

Mechanism Aging Management Programs

Referring 

GALL Rev.1

Chapters

SRPLR IDRelated 

Item

Location in 

AMR 

Chapters

Chapter XI.S1, “ASME Section XI, 

Subsection IWE” 

For inaccessible areas (embedded 

containment steel shell or liner), loss 

of material due to corrosion is not 

significant if the following conditions 

are satisfied: 

Concrete meeting the specifications 

of ACI 318 or 349 and the guidance 

of 201.2R was used for the 

containment concrete in contact with 

the embedded containment shell or 

liner. The concrete is monitored to 

ensure that it is free of penetrating 

cracks that provide a path for water 

seepage to the surface of the 

containment shell or liner. The 

moisture barrier, at the junction 

where the shell or liner becomes 

embedded, is subject to aging 

management activities in accordance 

with ASME Section XI, Subsection 

IWE requirements. Water ponding on 

the containment concrete floor are 

not common and when detected are 

cleaned up in a timely manner. 

If any of the above conditions cannot 

be satisfied, then a plant-specific 

aging management program for 

corrosion is necessary. 

Chapter XI.S4, “10 CFR Part 50, 

Appendix J”

II 5 C-19 B1.1.1-a 

B3.1.1-a
October 2005

A-199 NUREG-1833

A.6. Summary of MEAP Combinations in GALL Vol. 2 AMR Tables

Material Environment Aging Effect/ 

Mechanism Aging Management Programs

Referring 

GALL Rev.1

Chapters

SRPLR IDRelated 

Item

Location in 

AMR 

Chapters

Air – outdoor Loss of material/ wear Chapter XI.M26, “Fire Protection” VII 63 A-22 G.1-d G.2-d 

G.3-d G.4-d 

Air – outdoor 

(External)

Loss of material/ 

general corrosion

Chapter XI.M36, "External Surfaces 

Monitoring"

V 31 E-45 E. 

VII 58 A-78 I.1-b 

VIII 28 S-41 H.1-b

Loss of material/ 

general, pitting, and 

crevice corrosion

Chapter XI.M29, “Aboveground Steel 

Tanks”

VII 40 A-95 H1.4-b 

VIII 20 S-31 E.5-c G.4-c 

Chapter XI.M18, “Bolting Integrity” V 23 EP-1 E.

VII 43 AP-28 I.

VIII 22 S-32 H.

Chapter XI.M36, "External Surfaces 

Monitoring"

VII 59 AP-40 G. H2.

60 A-24 H1.1-a H1.2-a 

H1.3-a 

Air – outdoor 

(Internal)

Loss of material/ 

general, pitting, and 

crevice corrosion

Chapter XI.M38, "Inspection of 

Internal Surfaces in Miscellaneous 

Piping and Ducting Components"

VIII 30 SP-59 B1.

Air with borated 

water leakage

Loss of material/ boric 

acid corrosion

Chapter XI.M10, “Boric Acid 

Corrosion”

III 55 T-25 B1.1.1-b 

B1.2.1-b

B2.1-b B3.1-b 

B4.1-b B5.1-b
NUREG-1833

A-200 October 2005

A.6. Summary of MEAP Combinations in GALL Vol. 2 AMR Tables

Material Environment Aging Effect/ 

Mechanism Aging Management Programs

Referring 

GALL Rev.1

Chapters

SRPLR IDRelated 

Item

Location in 

AMR 

Chapters

IV 58 R-17 A2.1-a A2.5-e 

A2.8-b C2.1-d 

C2.2-d C2.3-f 

C2.4-f C2.5-b 

C2.5-o C2.5-u 

C2.6-b D1.1-g 

D1.1-k D2.1-b 

D2.1-j 

V 45 E-28 A.1-b A.3-b 

A.4-b A.5-b 

A.6-d D1.1-d 

D1.2-b D1.3-a 

D1.4-c D1.5-b 

D1.6-d D1.7-a 

D1.8-b E.1-a 

E-41 E.

VII 89 A-102 I.

A-79 A3.1-a A3.2-b 

A3.2-c A3.3-c 

A3.4-b A3.5-b 

A3.6-a E1.1-b 

E1.2-a E1.3-b 

E1.4-a E1.5-b 

E1.6-a E1.7-b 

E1.8-d E1.9-a 

E1.10-a I.1-a 

VIII 38 S-30 H.1-a 

S-40 H.

Air with borated 

water leakage 

(Internal)

Loss of material/ 

general, pitting, 

crevice and boric acid 

corrosion

Chapter XI.M38, "Inspection of 

Internal Surfaces in Miscellaneous 

Piping and Ducting Components"

V 46 EP-43 A.
October 2005

A-201 NUREG-1833

A.6. Summary of MEAP Combinations in GALL Vol. 2 AMR Tables

Material Environment Aging Effect/ 

Mechanism Aging Management Programs

Referring 

GALL Rev.1

Chapters

SRPLR IDRelated 

Item

Location in 

AMR 

Chapters

Air with leaking 

secondary-side 

water and/or steam

Loss of material/ 

erosion

Chapter XI.M1, “ASME Section XI 

Inservice Inspection, Subsections 

IWB, IWC, and IWD,” for Class 2 

components

IV 66 R-31 D2.1-l 

Air with reactor 

coolant leakage

Cracking/ stress 

corrosion cracking

Chapter XI.M18, “Bolting Integrity” IV 52 R-10 D1.1-l 

Air with steam or 

water leakage

Loss of material/ 

general corrosion

Chapter XI.M18, “Bolting Integrity” V 22 E-02 E.2-a 

42 A-03 I.2-a 

VIII 22 S-02 H.2-a 

Closed cycle 

cooling water

Loss of material/ 

general, pitting, and 

crevice corrosion

Chapter XI.M21, “Closed-Cycle 

Cooling Water System”

IV 53 RP-10 C2.

V 26 EP-48 C.

VII 47 A-25 C2.1-a C2.2-a 

C2.3-a C2.4-a 

C2.5-a F1.3-a 

F2.3-a F3.3-a 

F4.3-a H2.1-a 

Loss of material/ 

general, pitting, 

crevice, and galvanic 

corrosion

Chapter XI.M21, “Closed-Cycle 

Cooling Water System”

V 27 E-17 A.6-c D1.5-a 

D1.6-a D2.4-c 

VII 48 A-63 A3.4-a A4.4-a 

E1.8-c E4.4-a 

C2. E3. F1. 

F2. F3. F4.

VIII 24 S-23 A. E.4-e F.4-e 

G.5-c 
NUREG-1833

A-202 October 2005

A.6. Summary of MEAP Combinations in GALL Vol. 2 AMR Tables

Material Environment Aging Effect/ 

Mechanism Aging Management Programs

Referring 

GALL Rev.1

Chapters

SRPLR IDRelated 

Item

Location in 

AMR 

Chapters

Reduction of heat 

transfer/ fouling

Chapter XI.M21, “Closed-Cycle 

Cooling Water System”

VII 52 AP-77 F1. F2. F3. F4.

VIII 27 SP-64 A. E.4-e F.4-e 

G.5-c 

Concrete None None IV 87 RP-01 E.

V 55 EP-5 F.

VII 96 AP-3 J.

VIII 43 SP-2 I.

Condensation Loss of material/ 

general, pitting, and 

crevice corrosion

Chapter XI.M18, “Bolting Integrity” VII 44 A-103 D.2-a

Condensation 

(External)

Loss of material/ 

general corrosion

Chapter XI.M36, "External Surfaces 

Monitoring"

V 31 E-30 C.1-a 

E-46 E. 

VII 58 A-81 I.1-b 

VIII 28 S-42 H.1-b

Condensation 

(Internal)

Loss of material/ 

general and pitting 

corrosion

Chapter XI.M24, “Compressed Air 

Monitoring”

VII 53 A-26 D.1-a D.2-a 

D.3-a D.4-a 

D.5-a D.6-a 

Loss of material/ 

general, pitting, and 

crevice corrosion

Chapter XI.M38, "Inspection of 

Internal Surfaces in Miscellaneous 

Piping and Ducting Components"

V 34 E-27 D2.1-e 

VIII 30 SP-60 B1. G.

Loss of material/ 

general, pitting, 

crevice, and (for drip 

pans and drain lines) 

microbiologically 

influenced corrosion

Chapter XI.M38, "Inspection of 

Internal Surfaces in Miscellaneous 

Piping and Ducting Components"

VII 72 A-08 F1.1-a F2.1-a 

F3.1-a F4.1-a 

F1.4-a F2.4-a 

F3.4-a 
October 2005

A-203 NUREG-1833

A.6. Summary of MEAP Combinations in GALL Vol. 2 AMR Tables

Material Environment Aging Effect/ 

Mechanism Aging Management Programs

Referring 

GALL Rev.1

Chapters

SRPLR IDRelated 

Item

Location in 

AMR 

Chapters

Dried Air None None VII 98 AP-4 J.

Fuel oil Loss of material/ 

general, pitting, and 

crevice corrosion

Chapter XI.M26, “Fire Protection,” 

and Chapter XI.M30, “Fuel Oil 

Chemistry” 

VII 64 A-28 G.8-a 

Loss of material/ 

general, pitting, 

crevice, and 

microbiologically 

influenced corrosion, 

and fouling

Chapter XI.M30, “Fuel Oil Chemistry” 

The AMP is to be augmented by 

verifying the effectiveness of fuel oil 

chemistry control. See Chapter 

XI.M32, “One-Time Inspection,” for 

an acceptable verification program.

VII 20 A-30 H1.4-a H2.5-a 

Gas None None V 56 EP-7 F.

VII 97 AP-6 J.

VIII 44 SP-4 I.

Lubricating oil Loss of material/ V 16 EP-46 A. D1. D2. 

general, pitting, and 

crevice corrosion VII 14 AP-30 C1. C2. E1. 

E4. F1. F2. 

F3. F4. G. H2. 

15 A-83 G.7-b 

Chapter XI.M39, "Lubricating Oil 

Analysis" 

The AMP is to be augmented by 

verifying the effectiveness of the 

lubricating oil analysis program. See 

Chapter XI.M32, “One-Time 

Inspection,” for an acceptable 

verification program.

VIII 6 SP-25 A. D1. D2. E. 

G.

Chapter XI.M39, "Lubricating Oil 

Analysis" 

The AMP is to be augmented to 

evaluate the thickness of the lower 

portion of the tank. See Chapter 

XI.M32, “One-Time Inspection,” for 

an acceptable verification program.

VII 16 A-82 G.7-a 
NUREG-1833

A-204 October 2005

A.6. Summary of MEAP Combinations in GALL Vol. 2 AMR Tables

Material Environment Aging Effect/ 

Mechanism Aging Management Programs

Referring 

GALL Rev.1

Chapters

SRPLR IDRelated 

Item

Location in 

AMR 

Chapters

Loss of material/ 

general, pitting, 

crevice, and 

microbiologically 

influenced corrosion

Chapter XI.M39, "Lubricating Oil 

Analysis" 

The AMP is to be augmented by 

verifying the effectiveness of the 

lubricating oil analysis program. See 

Chapter XI.M32, “One-Time 

Inspection,” for an acceptable 

verification program.

VIII 11 S-17 G.5-d 

Loss of material/ 

general, pitting, 

crevice, and 

microbiologically 

influenced corrosion, 

and fouling

Chapter XI.M39, "Lubricating Oil 

Analysis" 

The AMP is to be augmented by 

verifying the effectiveness of the 

lubricating oil analysis program. See 

Chapter XI.M32, “One-Time 

Inspection,” for an acceptable 

verification program.

VII 21 AP-39 H2.

Reduction of heat 

transfer/ fouling

Chapter XI.M39, "Lubricating Oil 

Analysis"

The AMP is to be augmented by 

verifying the effectiveness of the 

lubricating oil analysis program. See 

Chapter XI.M32, “One-Time 

Inspection,” for an acceptable 

verification program.

V 9 EP-40 A. D1. D2. 

VIII 9 SP-63 G.

Moist air or 

condensation

(Internal)

Loss of material/ 

general, pitting, and 

crevice corrosion

Chapter XI.M38, "Inspection of 

Internal Surfaces in Miscellaneous 

Piping and Ducting Components"

VII 71 A-23 H2.2-a H2.3-a 

G. 

Raw water Loss of material/ Chapter XI.M27, “Fire Water System” VII 68 A-33 G.6-a G.6-b 
October 2005

A-205 NUREG-1833

A.6. Summary of MEAP Combinations in GALL Vol. 2 AMR Tables

Material Environment Aging Effect/ 

Mechanism Aging Management Programs

Referring 

GALL Rev.1

Chapters

SRPLR IDRelated 

Item

Location in 

AMR 

Chapters

Chapter XI.M20, “Open-Cycle 

Cooling Water System”

general, pitting, V 35 E-22 C.1-a

crevice, and 

microbiologically 

influenced corrosion, 

and fouling

A plant-specific aging management 

program is to be evaluated.

VIII 7 S-12 G.1-d 

Chapter XI.M20, “Open-Cycle 

Cooling Water System”

V 36 E-18 A.6-a D1.6-b 

D2.4-a 

VII 77 A-64 C1.3-a

Loss of material/ 

general, pitting, 

crevice, galvanic, and 

microbiologically 

influenced corrosion, 

and fouling

VIII 31 S-24 E.4-b F.4-b 

G.5-a 

Reduction of heat 

transfer/ fouling

Chapter XI.M20, “Open-Cycle 

Cooling Water System”

V 40 E-23 D2.4-b 

VIII 34 S-27 G.5-b 

Reactor coolant Loss of material/ 

general, pitting, and 

crevice corrosion

Chapter XI.M2, “Water Chemistry,” 

for BWR water 

The AMP is to be augmented by 

verifying the effectiveness of water 

chemistry control. See Chapter 

XI.M32, “One-Time Inspection,” for 

an acceptable verification program.

IV 11 R-59 A1.1-a

Loss of material/ wear Chapter XI.M1, “ASME Section XI 

Inservice Inspection, Subsections 

IWB, IWC, and IWD,” for Class 1 

components

IV 63 R-87 A2.5-f

Wall thinning/ flowaccelerated corrosionChapter XI.M17, “Flow-Accelerated 

Corrosion”

IV 45 R-23 C1.1-a C1.1-c 

C1.3-a 
NUREG-1833

A-206 October 2005

A.6. Summary of MEAP Combinations in GALL Vol. 2 AMR Tables

Material Environment Aging Effect/ 

Mechanism Aging Management Programs

Referring 

GALL Rev.1

Chapters

SRPLR IDRelated 

Item

Location in 

AMR 

Chapters

Reactor coolant 

and neutron flux

Loss of fracture 

toughness/ neutron 

irradiation 

embrittlement

Neutron irradiation embrittlement is a 

time-limited aging analysis (TLAA) to 

be evaluated for the period of 

extended operation for all ferritic 

materials that have a neutron fluence 

greater than 1E17 n/cm2 (E >1 MeV) 

at the end of the license renewal 

term. In accordance with approved 

BWRVIP-74, the TLAA is to evaluate 

the impact of neutron embrittlement 

on: (a) the adjusted reference 

temperature values used for 

calculation of the plant’s pressuretemperature limits, and (b) the need 

for inservice inspection of 

circumferential welds, and (c) the 

Charpy upper shelf energy or the 

equivalent margins analyses 

performed in accordance with 10 

CFR Part 50, Appendix G The 

applicant may choose to 

demonstrate that the materials of the 

nozzles are not controlling for the 

TLAA evaluations. See the Standard 

Review Plan, Section 4.2 “Reactor 

Vessel Neutron Embrittlement” for 

acceptable methods for meeting the 

requirements of 10 CFR 54.21(c).

IV 17 R-67 A1.3-e

Secondary 

feedwater

Loss of material/ 

erosion

A plant-specific aging management 

program is to be evaluated.

IV 28 R-39 D1.1-e 
October 2005

A-207 NUREG-1833

A.6. Summary of MEAP Combinations in GALL Vol. 2 AMR Tables

Material Environment Aging Effect/ 

Mechanism Aging Management Programs

Referring 

GALL Rev.1

Chapters

SRPLR IDRelated 

Item

Location in 

AMR 

Chapters

Secondary 

feedwater/ steam

Cumulative fatigue 

damage/ fatigue

Fatigue is a time-limited aging 

analysis (TLAA) to be evaluated for 

the period of extended operation. 

See the Standard Review Plan, 

Section 4.3 “Metal Fatigue,” for 

acceptable methods for meeting the 

requirements of 10 CFR 54.21(c)(1).

IV 7 R-33 D1.1-a D1.1-b 

D2.1-d D2.1-g 

Ligament cracking/ 

corrosion

Chapter XI.M19, “Steam Generator 

Tubing Integrity” and 

Chapter XI.M2, “Water Chemistry,” 

for PWR secondary water

IV 76 R-42 D1.2-k D2. 

Loss of material/ 

erosion, general, 

pitting, and crevice 

corrosion

Chapter XI.M19, “Steam Generator 

Tubing Integrity” and 

Chapter XI.M2, “Water Chemistry,” 

for PWR secondary water

IV 76 RP-16 D1.

Loss of material/ 

general, pitting, and 

crevice corrosion

Chapter XI.M2, “Water Chemistry,” 

for PWR secondary water 

The AMP is to be augmented by 

verifying the effectiveness of water 

chemistry control. See Chapter 

XI.M32, “One-Time Inspection,” for 

an acceptable verification program.

IV 12 R-224 D2.1-e 
NUREG-1833

A-208 October 2005

A.6. Summary of MEAP Combinations in GALL Vol. 2 AMR Tables

Material Environment Aging Effect/ 

Mechanism Aging Management Programs

Referring 

GALL Rev.1

Chapters

SRPLR IDRelated 

Item

Location in 

AMR 

Chapters

Chapter XI.M1, “ASME Section XI 

Inservice Inspection, Subsections 

IWB, IWC, and IWD,” for Class 2 

components and 

Chapter XI.M2, “Water Chemistry,” 

for PWR secondary water. As noted 

in NRC IN 90-04, if general and 

pitting corrosion of the shell is known 

to exist, the AMP guidelines in 

Chapter XI.M1 may not be sufficient 

to detect general and pitting 

corrosion (and the resulting 

corrosion-fatigue cracking), and 

additional inspection procedures are 

to be developed. This issue is limited 

to Westinghouse Model 44 and 51 

Steam Generators where a high 

stress region exists at the shell to 

transition cone weld.

IV 16 R-34 D1.1-c 

Wall thinning/ flowaccelerated corrosionA plant-specific aging management 

program is to be evaluated. 

Reference NRC IN 91-19, "Steam 

Generator Feedwater Distribution 

Piping Damage." 

IV 32 R-51 D1.3-a 

Chapter XI.M17, “Flow-Accelerated 

Corrosion”

IV 59 R-37 D1.1-d 

R-38 D2.1-f 

Chapter XI.M19, “Steam Generator 

Tubing Integrity” and 

Chapter XI.M2, “Water Chemistry,” 

for PWR secondary water

IV 78 R-41 D1.2-h 
October 2005

A-209 NUREG-1833

A.6. Summary of MEAP Combinations in GALL Vol. 2 AMR Tables

Material Environment Aging Effect/ 

Mechanism Aging Management Programs

Referring 

GALL Rev.1

Chapters

SRPLR IDRelated 

Item

Location in 

AMR 

Chapters

Steam Loss of material/ 

general, pitting, and 

crevice corrosion

Chapter XI.M2, “Water Chemistry,” 

for BWR water 

The AMP is to be augmented by 

verifying the effectiveness of water 

chemistry control. See Chapter 

XI.M32, “One-Time Inspection,” for 

an acceptable verification program.

VIII 2 S-04 A.1-b A.2-b 

C.1-b C.2-b 

Chapter XI.M2, “Water Chemistry,” 

for PWR secondary water 

The AMP is to be augmented by 

verifying the effectiveness of water 

chemistry control. See Chapter 

XI.M32, “One-Time Inspection,” for 

an acceptable verification program.

VIII 2 S-06 A.1-b A.2-b 

C.1-b C.2-b

Loss of material/ 

pitting and crevice 

corrosion

Chapter XI.M2, “Water Chemistry,” 

for BWR water

VIII 37 S-05 B2.1-a B2.2-b 

Chapter XI.M2, “Water Chemistry,” 

for PWR secondary water

VIII 37 S-07 B1.1-a B1.2-a 

Wall thinning/ flowaccelerated corrosionChapter XI.M17, “Flow-Accelerated 

Corrosion”

V 19 E-07 D2.1-f 

VIII 29 S-15 A.1-a A.2-a 

B1.1-c B1.2-b 

B2.1-b B2.2-a 

C.1-a C.2-a 
NUREG-1833

A-210 October 2005

A.6. Summary of MEAP Combinations in GALL Vol. 2 AMR Tables

Material Environment Aging Effect/ 

Mechanism Aging Management Programs

Referring 

GALL Rev.1

Chapters

SRPLR IDRelated 

Item

Location in 

AMR 

Chapters

Steam or treated 

water

Cumulative fatigue 

damage/ fatigue

Fatigue is a time-limited aging 

analysis (TLAA) to be evaluated for 

the period of extended operation. 

See the Standard Review Plan, 

Section 4.3 “Metal Fatigue,” for 

acceptable methods for meeting the 

requirements of 10 CFR 54.21(c)(1).

VIII 1 S-08 B1.1-b B2.1-c 

System 

temperature up to 

288°C (550°F)

Cumulative fatigue 

damage/ fatigue

Fatigue is a time-limited aging 

analysis (TLAA) to be performed for 

the period of extended operation; 

check ASME Code limits for 

allowable cycles (less than 7000 

cycles) of thermal stress range. See 

the Standard Review Plan, Section 

4.3 “Metal Fatigue,” for acceptable 

methods for meeting the 

requirements of 10 CFR 54.21(c)(1).

IV 4 R-28 C1.2-f C1.3-g 

Loss of material/ wear Chapter XI.M18, “Bolting Integrity” IV 52 R-26 C1.2-d C1.3-e 

System 

temperature up to 

340°C (644°F)

Loss of preload/ 

thermal effects, 

gasket creep, and 

self-loosening

Chapter XI.M18, “Bolting Integrity” IV 52 R-32 D1.1-f D2.1-k 

Treated water Cumulative fatigue 

damage/ fatigue

Fatigue is a time-limited aging 

analysis (TLAA) to be evaluated for 

the period of extended operation. 

See the Standard Review Plan, 

Section 4.3 “Metal Fatigue,” for 

acceptable methods for meeting the 

requirements of 10 CFR 54.21(c)(1).

V 1 E-10 D2.1-b 

VIII 1 S-11 D1.1-b D2.1-c 

G.1-b 
October 2005

A-211 NUREG-1833

A.6. Summary of MEAP Combinations in GALL Vol. 2 AMR Tables

Material Environment Aging Effect/ 

Mechanism Aging Management Programs

Referring 

GALL Rev.1

Chapters

SRPLR IDRelated 

Item

Location in 

AMR 

Chapters

Loss of material/ 

general, pitting, and 

crevice corrosion

V 14 E-08 D2.1-a D2.2-a 

D2.3-b 

VII 17 A-35 E3. E4.1-a 

E4.2-a 

Chapter XI.M2, “Water Chemistry,” 

for BWR water 

The AMP is to be augmented by 

verifying the effectiveness of water 

chemistry control. See Chapter 

XI.M32, “One-Time Inspection,” for 

an acceptable verification program.

VIII 4 S-09 B2. C. D2.1-b 

D2.2-b D2.3-b 

E.1-b E.2-b 

E.3-a E.5-a 

E.6-a 

VIII 3 S-19 E.4-a E.4-d 

F.4-a F.4-d 

Chapter XI.M2, “Water Chemistry,” 

for PWR secondary water 

The AMP is to be augmented by 

verifying the effectiveness of water 

chemistry control. See Chapter 

XI.M32, “One-Time Inspection,” for 

an acceptable verification program.

4 S-10 B1. C. D1.1-c 

D1.2-b D1.3-a 

E.1-b E.2-b 

E.3-a E.5-a 

E.6-a F.1-b 

F.2-b F.3-a 

G.1-c G.2-a 

G.3-a G.4-a 

Chapter XI.M2, “Water Chemistry” 

The AMP is to be augmented by 

verifying the effectiveness of water 

chemistry control. See Chapter 

XI.M32, “One-Time Inspection,” for 

an acceptable verification program.

V 15 E-31 C.1-a 
NUREG-1833

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A.6. Summary of MEAP Combinations in GALL Vol. 2 AMR Tables

Material Environment Aging Effect/ 

Mechanism Aging Management Programs

Referring 

GALL Rev.1

Chapters

SRPLR IDRelated 

Item

Location in 

AMR 

Chapters

Loss of material/ 

general, pitting, 

crevice, and galvanic 

corrosion

Chapter XI.M2, “Water Chemistry,” 

for BWR water 

The AMP is to be augmented by 

verifying the effectiveness of water 

chemistry control. See Chapter 

XI.M32, “One-Time Inspection,” for 

an acceptable verification program.

VIII 19 S-18 E.4-a E.4-d 

Wall thinning/ flowaccelerated corrosionChapter XI.M17, “Flow-Accelerated 

Corrosion”

V 19 E-09 D2.3-a 

VIII 29 S-16 D1.1-a D1.2-a 

D1.3-b D2.1-a 

D2.2-a D2.3-a 

E.1-a E.2-a 

F.1-a F.2-a 

G.1-a 

Soil V 17 E-42 B.

VII 19 A-01 H1.1-b C1.1-b 

C3. G. 

Steel (with or 

without 

coating or 

wrapping)

Loss of material/ 

general, pitting, 

crevice, and 

microbiologically 

influenced corrosion

Chapter XI.M28, “Buried Piping and 

Tanks Surveillance,” or 

Chapter XI.M34, “Buried Piping and 

Tanks Inspection” VIII 10 S-01 E.5-d G.1-e 

G.4-d 

Steel (with or 

without 

lining/coating

or with 

degraded 

lining/coating)

Raw water Loss of material/ 

general, pitting, 

crevice, and 

microbiologically 

influenced corrosion, 

fouling, and 

lining/coating 

degradation

Chapter XI.M20, “Open-Cycle 

Cooling Water System”

VII 76 A-38 C1.1-a C1.2-a 

C1.5-a C1.6-a 

H2.1-b C3.1-a 

C3.2-a C3.3-a 
October 2005

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A.6. Summary of MEAP Combinations in GALL Vol. 2 AMR Tables

Material Environment Aging Effect/ 

Mechanism Aging Management Programs

Referring 

GALL Rev.1

Chapters

SRPLR IDRelated 

Item

Location in 

AMR 

Chapters

Steel (with or 

without 

stainless steel 

cladding)

Reactor coolant Cracking/ cyclic 

loading

Chapter XI.M5, “BWR Feedwater 

Nozzle”

IV 39 R-65 A1.3-b

Chapter XI.M6, “BWR Control Rod 

Drive Return Line Nozzle”

IV 38 R-66 A1.3-c

Reactor coolant 

and neutron flux

Chapter XI.M31, “Reactor Vessel 

Surveillance”

Loss of fracture IV 18 R-63 A1.2-d 

toughness/ neutron 

irradiation 

embrittlement Neutron irradiation embrittlement is a 

time dependent aging mechanism to 

be evaluated for the period of 

extended operation for all ferritic 

materials that have a neutron fluence 

greater than 1017 n/cm2 (E >1 MeV) 

at the end of the license renewal 

term. Aspects of this evaluation may 

involve a TLAA. In accordance with 

approved BWRVIP-74, the TLAA is 

to evaluate the impact of neutron 

embrittlement on: (a) the adjusted 

reference temperature values used 

for calculation of the plant’s 

pressure-temperature limits, (b) the 

need for inservice inspection of 

circumferential welds, and (c) the 

Charpy upper shelf energy or the 

equivalent margins analyses 

performed in accordance with 10 

CFR Part 50, Appendix G. 

Additionally, the applicant is to 

monitor axial beltline weld 

embrittlement. One acceptable 

method is to determine that the 

IV 17 R-62 A1.2-c
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A.6. Summary of MEAP Combinations in GALL Vol. 2 AMR Tables

Material Environment Aging Effect/ 

Mechanism Aging Management Programs

Referring 

GALL Rev.1

Chapters

SRPLR IDRelated 

Item

Location in 

AMR 

Chapters

mean RTNDT of the axial beltline 

welds at the end of the extended 

period of operation is less than the 

value specified by the Staff in its 

March 7, 2000 letter (ADAMS 

ML031430372). See the Standard 

Review Plan, Section 4.2 “Reactor 

Vessel Neutron Embrittlement” for 

acceptable methods for meeting the 

requirements of 10 CFR 54.21(c).

Steel and nonsteel materials 

(e.g., Lubrite®

plates, 

vibration 

isolators, etc.)

Air – indoor 

uncontrolled or air 

– outdoor

Loss of mechanical 

function/ corrosion, 

distortion, dirt, 

overload, fatigue due 

to vibratory and cyclic 

thermal loads; 

elastomer hardening

Chapter XI.S3, “ASME Section XI, 

Subsection IWF”

III 54 T-28 B1.1.3-a 

B1.2.2-a 

B1.3.2-a

Steel with 

elastomer 

lining

Treated borated 

water

Loss of material/ 

pitting and crevice 

corrosion (only for 

steel after lining 

degradation)

Chapter XI.M2, “Water Chemistry,” 

for PWR primary water 

The AMP is to be augmented by 

verifying the effectiveness of water 

chemistry control. See Chapter 

XI.M32, “One-Time Inspection,” for 

an acceptable verification program.

VII 22 A-39 A3.2-a A3.3-a 

A3.5-a 

Steel with 

elastomer 

lining or 

stainless steel 

cladding

Treated water Loss of material/ 

pitting and crevice 

corrosion (only for 

steel after 

lining/cladding 

degradation)

Chapter XI.M2, “Water Chemistry,” 

for BWR water 

The AMP is to be augmented by 

verifying the effectiveness of water 

chemistry control. See Chapter 

XI.M32, “One-Time Inspection,” for 

an acceptable verification program.

VII 22 A-40 A4.2-a A4.3-a 

A4.5-a 
October 2005

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A.6. Summary of MEAP Combinations in GALL Vol. 2 AMR Tables

Material Environment Aging Effect/ 

Mechanism Aging Management Programs

Referring 

GALL Rev.1

Chapters

SRPLR IDRelated 

Item

Location in 

AMR 

Chapters

Reactor coolant IV 18 R-82 A2.3-b

and neutron flux

Chapter XI.M31, “Reactor Vessel 

Surveillance” R-86 A2.5-c

Steel with 

stainless steel 

cladding

Loss of fracture 

toughness/ neutron 

irradiation 

embrittlement Neutron irradiation embrittlement is a 

time-limited aging analysis (TLAA) to 

be evaluated for the period of 

extended operation for all ferritic 

materials that have a neutron fluence 

greater than 1E17 n/cm2 (E >1 MeV) 

at the end of the license renewal 

term. The TLAA is to evaluate the 

impact of neutron embrittlement on: 

(a) the RTPTS value based on the 

requirements in 10 CFR 50.61, 

(b) the adjusted reference 

temperature values used for 

calculation of the plant’s pressuretemperature limits, and (c) the 

Charpy upper shelf energy or the 

equivalent margins analyses 

performed in accordance with 10 

CFR Part 50, Appendix G 

requirements. See the Standard 

Review Plan, Section 4.2 “Reactor 

Vessel Neutron Embrittlement” for 

acceptable methods for meeting the 

requirements of 10 CFR 54.21(c).

IV 17 R-84 A2.5-a
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A.6. Summary of MEAP Combinations in GALL Vol. 2 AMR Tables

Material Environment Aging Effect/ 

Mechanism Aging Management Programs

Referring 

GALL Rev.1

Chapters

SRPLR IDRelated 

Item

Location in 

AMR 

Chapters

Neutron irradiation embrittlement is a 

time-limited aging analysis (TLAA) to 

be evaluated for the period of 

extended operation for all ferritic 

materials that have a neutron fluence 

greater than 1E17 n/cm2 (E >1 MeV) 

at the end of the license renewal 

term. The TLAA is to evaluate the 

impact of neutron embrittlement on: 

(a) the RTPTS value based on the 

requirements in 10 CFR 50.61, 

(b) the adjusted reference 

temperature values used for 

calculation of the plant’s pressuretemperature limits, and (c) the 

Charpy upper shelf energy or the 

equivalent margins analyses 

performed in accordance with 10 

CFR Part 50, Appendix G 

requirements. The applicant may 

choose to demonstrate that the 

materials in the inlet, outlet, and 

safety injection nozzles are not 

controlling for the TLAA evaluations.

IV 17 R-81 A2.3-a

Treated borated 

water

Loss of 

material/cladding 

breach

A plant-specific aging management 

program is to be evaluated. 

Reference NRC Information Notice 

94-63, “Boric Acid Corrosion of 

Charging Pump Casings Caused by 

Cladding Cracks."

V 2 EP-49 D1.

VII 35 AP-85 E1.
October 2005

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A.6. Summary of MEAP Combinations in GALL Vol. 2 AMR Tables

Material Environment Aging Effect/ 

Mechanism Aging Management Programs

Referring 

GALL Rev.1

Chapters

SRPLR IDRelated 

Item

Location in 

AMR 

Chapters

Cumulative fatigue 

damage/ fatigue

Fatigue is a time-limited aging 

analysis (TLAA) to be evaluated for 

the period of extended operation. 

See the Standard Review Plan, 

Section 4.3 “Metal Fatigue,” for 

acceptable methods for meeting the 

requirements of 10 CFR 54.21(c)(1).

IV 7 R-13 C2.6-a 

Treated borated 

water >60°C 

(>140°F)

Cracking/ stress 

corrosion cracking

Chapter XI.M2, “Water Chemistry,” 

for PWR primary water

V 48 E-38 D1.7-b

VII 90 A-56 A3.3-b 

Steel with 

stainless steel 

or nickel alloy 

cladding

Reactor coolant Cracking/ stress 

corrosion cracking, 

primary water stress 

corrosion cracking

Chapter XI.M1, “ASME Section XI 

Inservice Inspection, Subsections 

IWB, IWC, and IWD,” for Class 1 

components, and 

Chapter XI.M2, “Water Chemistry,” 

for PWR primary water and 

For nickel alloy, provide a 

commitment in the FSAR 

supplement to implement applicable 

(1) NRC Orders, Bulletins, and 

Generic Letters associated with 

nickel alloys and (2) staff-accepted 

industry guidelines.

IV 35 R-35 D2.1-a 
NUREG-1833

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A.6. Summary of MEAP Combinations in GALL Vol. 2 AMR Tables

Material Environment Aging Effect/ 

Mechanism Aging Management Programs

Referring 

GALL Rev.1

Chapters

SRPLR IDRelated 

Item

Location in 

AMR 

Chapters

Steel with 

stainless steel 

or nickel alloy 

cladding; or 

stainless steel

Reactor coolant Cracking/ cyclic 

loading

Chapter XI.M1, “ASME Section XI 

Inservice Inspection, Subsections 

IWB, IWC, and IWD,” for Class 1 

components and 

Chapter XI.M2, “Water Chemistry,” 

for PWR primary water 

Cracks in the pressurizer cladding 

could propagate from cyclic loading 

into the ferrite base metal and weld 

metal. However, because the weld 

metal between the surge nozzle and 

the vessel lower head is subjected to 

the maximum stress cycles and the 

area is periodically inspected as part 

of the ISI program, the existing AMP 

is adequate for managing the effect 

of pressurizer clad cracking.

IV 67 R-58 C2.5-c C2.5-g 

Cracking/ stress 

corrosion cracking, 

primary water stress 

corrosion cracking

Chapter XI.M1, “ASME Section XI 

Inservice Inspection, Subsections 

IWB, IWC, and IWD” for Class 1 

components, and 

Chapter XI.M2, “Water Chemistry,” 

for PWR primary water 

IV 64 R-25 C2.5-c C2.5-g 

Steel with 

stainless steel 

or nickel alloy 

cladding; 

stainless 

steel; nickel 

alloy

Reactor coolant Loss of material/ 

pitting and crevice 

corrosion

Chapter XI.M2, “Water Chemistry,” 

for PWR primary water

IV 83 RP-23 C2.
October 2005

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A.6. Summary of MEAP Combinations in GALL Vol. 2 AMR Tables

Material Environment Aging Effect/ 

Mechanism Aging Management Programs

Referring 

GALL Rev.1

Chapters

SRPLR IDRelated 

Item

Location in 

AMR 

Chapters

Chapter XI.M2, “Water Chemistry,” 

for BWR water 

The AMP is to be augmented by 

verifying the effectiveness of water 

chemistry control. See Chapter 

XI.M32, “One-Time Inspection,” for 

an acceptable verification program.

IV 15 RP-27 C1.

Steel, 

Stainless steel

Treated water Loss of material/ 

general (steel only), 

pitting and crevice 

corrosion

Chapter XI.M2, “Water Chemistry” 

The AMP is to be augmented by 

verifying the effectiveness of water 

chemistry control. See Chapter 

XI.M32, “One-Time Inspection,” for 

an acceptable verification program.

VIII 5 S-13 E.5-a E.5-b 

G.4-a G.4-b 

Steel; copper 

alloys

Air – indoor 

uncontrolled or air -

outdoor; Water –

flowing or water –

standing

Loss of material/ 

general (steel only), 

pitting and crevice 

corrosion

Chapter XI.S7, “Regulatory Guide 

1.127, Inspection of Water-Control 

Structures Associated with Nuclear 

Power Plants” or the FERC / US 

Army Corp of Engineers dam 

inspections and maintenance 

programs.

If protective coatings are relied upon 

to manage the effects of aging, this 

AMP is to include provisions to 

address protective coating 

monitoring and maintenance.

III 47 T-21 A6.2-a
NUREG-1833

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A.6. Summary of MEAP Combinations in GALL Vol. 2 AMR Tables

Material Environment Aging Effect/ 

Mechanism Aging Management Programs

Referring 

GALL Rev.1

Chapters

SRPLR IDRelated 

Item

Location in 

AMR 

Chapters

Steel; 

dissimilar 

metal welds

Air – indoor 

uncontrolled 

or air outdoor

Loss of material/ 

general, pitting, and 

crevice corrosion

Chapter XI.S1, “ASME Section XI, 

Subsection IWE,” 

(Note: IWE examination category EF, surface examination of dissimilar 

metal welds, is recommended) 

Chapter XI.S4, “10 CFR Part 50, 

Appendix J” 

II 18 C-12 A3.1-a B4.1-a

Steel; 

galvanized 

steel

Air – indoor and 

outdoor

Loss of material/ 

general corrosion

Chapter XI.S6, “Structures 

Monitoring Program”

VI 9 LP-06 A.

Steel; 

stainless 

steel; 

dissimilar 

metal welds

Air – indoor 

uncontrolled or air 

– outdoor

Cracking/ cyclic 

loading 

(CLB fatigue analysis 

does not exist)

Chapter XI.S1, “ASME Section XI, 

Subsection IWE ” and Chapter XI.S4, 

“10 CFR Part 50, Appendix J” 

Evaluation of 10 CFR 50.55a/ASME 

Section XI, Subsection IWE is to be 

supplemented to consider the 

following: 

(4) Detection of Aging Effects: VT-3 

visual inspection may not detect fine 

cracks.

II 12 C-14 A3.1-c B4.1-c 

C-44 B2.1.1-b 

Cumulative fatigue 

damage/ fatigue 

(Only if CLB fatigue 

analysis exists)

Fatigue is a time-limited aging 

analysis (TLAA) to be evaluated for 

the period of extended operation. 

See the Standard Review Plan, 

Section 4.6, “Containment Liner 

Plate and Penetration Fatigue 

Analysis” for acceptable methods for 

meeting the requirements of 

10 CFR 54.21(c)(1).

II 9 C-13 A3.1-b B4.1-b 
October 2005

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A.6. Summary of MEAP Combinations in GALL Vol. 2 AMR Tables

Material Environment Aging Effect/ 

Mechanism Aging Management Programs

Referring 

GALL Rev.1

Chapters

SRPLR IDRelated 

Item

Location in 

AMR 

Chapters

Fatigue is a time-limited aging 

analysis (TLAA) to be evaluated for 

the period of extended operation. 

See the Standard Review Plan, 

Section 4.6, “Containment Liner 

Plate and Penetration Fatigue 

Analysis” for acceptable methods for 

meeting the requirements of 

10 CFR 54.21(c)(1).

II 9 C-45 B2.1.1-c 

Steel; 

stainless 

steel; steel 

with nickelalloy or 

stainless steel 

cladding; 

nickel-alloy

Reactor coolant Cumulative fatigue 

damage/ fatigue

Fatigue is a time-limited aging 

analysis (TLAA) to be performed for 

the period of extended operation, 

and, for Class 1 components, 

environmental effects on fatigue are 

to be addressed. See the Standard 

Review Plan, Section 4.3 “Metal 

Fatigue,” for acceptable methods for 

meeting the requirements of 10 CFR 

54.21(c)(1).

IV 2 R-04 A1.1-b A1.2-a 

A1.2-a A1.2-b 

A1.2-b A1.2-b 

A1.2-b A1.3-a 

A1.3-d A1.3-d 

A1.4-b A1.5-b 

A1.5-b A1.5-b 

A1.5-b A1.5-b 

A1.5-b A1.6-a

3 R-220 C1.1-b C1.1-d 

C1.1-e C1.1-e 

C1.1-h C1.1-h 

C1.1-h C1.1-h 

C1.1-h C1.1-h 

C1.1-h C1.2-a 

C1.2-a C1.2-a 

C1.3-d C1.3-d 

C1.3-d 
NUREG-1833

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A.6. Summary of MEAP Combinations in GALL Vol. 2 AMR Tables

Material Environment Aging Effect/ 

Mechanism Aging Management Programs

Referring 

GALL Rev.1

Chapters

SRPLR IDRelated 

Item

Location in 

AMR 

Chapters

8 R-223 C2.1-a C2.1-a 

C2.1-b C2.1-b 

C2.2-a C2.2-a 

C2.2-a C2.2-a 

C2.2-b C2.2-b 

C2.2-c C2.3-a 

C2.3-a C2.4-a 

C2.4-a C2.5-a 

C2.5-d C2.5-d 

C2.5-e C2.5-f 

C2.5-f C2.5-f 

C2.5-q 

9 R-219 A2.1-b A2.2-c 

A2.2-c A2.3-c 

A2.3-c A2.3-c 

A2.4-a A2.4-a 

A2.4-a A2.5-d 

A2.5-d A2.5-d 

A2.5-d 

10 R-221 D1.1-h 

R-222 D2.1-c

Various Water – flowing 

Water – standing

Loss of material, loss 

of form/ erosion, 

settlement, 

sedimentation, frost 

action, waves, 

currents, surface 

runoff, seepage

Chapter XI.S7, “Regulatory Guide 

1.127, Inspection of Water-Control 

Structures Associated with Nuclear 

Power Plants” or the FERC / US 

Army Corp of Engineers dam 

inspections and maintenance 

programs.

III 48 T-22 A6.4-a
October 2005

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A.6. Summary of MEAP Combinations in GALL Vol. 2 AMR Tables

Material Environment Aging Effect/ 

Mechanism Aging Management Programs

Referring 

GALL Rev.1

Chapters

SRPLR IDRelated 

Item

Location in 

AMR 

Chapters

Various 

metals used 

for electrical 

contacts

Air – indoor and 

outdoor

Loosening of bolted 

connections due to 

thermal cycling, ohmic 

heating, electrical 

transients, vibration, 

chemical 

contamination, 

corrosion, and 

oxidation

Chapter XI.E6, "Electrical 

Connections Not Subject to 10 CFR 

50.49 Environmental Qualification 

Requirements"

VI 13 LP-12 A.

Air with borated 

water leakage

Corrosion of 

connector contact 

surfaces/ intrusion of 

borated water

Chapter XI.M10, “Boric Acid 

Corrosion”

VI 5 L-04 A.2-a

Various 

organic 

polymers 

(e.g., EPR, 

SR, EPDM, 

XLPE)

Adverse localized 

environment 

caused by 

exposure to 

moisture and 

voltage

Localized damage 

and breakdown of 

insulation leading to 

electrical failure/ 

moisture intrusion, 

water trees

Chapter XI.E3, "Inaccessible 

Medium Voltage Cables Not Subject 

to 10 CFR 50.49 Environmental 

Qualification Requirements"

VI 4 L-03 A.1-c

Adverse localized 

environment 

caused by heat, 

radiation, or 

moisture in the 

presence of 

oxygen

Embrittlement, 

cracking, melting, 

discoloration, 

swelling, or loss of 

dielectric strength 

leading to reduced 

insulation resistance 

(IR); electrical failure/ 

degradation of 

organics (Thermal/ 

thermoxidative), 

radiolysis and 

photolysis 

(UV sensitive material

Chapter XI.E1, “Electrical Cables 

and Connections Not Subject to 10 

CFR 50.49 Environmental 

Qualification Requirements” 

VI 2 L-01 A.1-a
NUREG-1833

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A.6. Summary of MEAP Combinations in GALL Vol. 2 AMR Tables

Material Environment Aging Effect/ 

Mechanism Aging Management Programs

Referring 

GALL Rev.1

Chapters

SRPLR IDRelated 

Item

Location in 

AMR 

Chapters

Chapter XI.E2, "Electrical Cables 

and Connections Not Subject to 

10 CFR 50.49 Environmental 

Qualification Requirements Used in 

Instrumentation Circuits"

VI 3 L-02 A.1-b

Various 

polymeric and 

metallic 

materials

Adverse localized 

environment 

caused by heat, 

radiation, oxygen, 

moisture, or 

voltage

Various degradation/ 

various mechanisms

EQ is a time-limited aging analysis 

(TLAA) to be evaluated for the period 

of extended operation. See the 

Standard Review Plan, Section 4.4, 

"Environmental Qualification (EQ) of 

Electrical Equipment," for acceptable 

methods for meeting the 

requirements of 10 CFR 

54.21(c)(1)(i) and (ii). 

See Chapter X.E1, “Environmental 

Qualification (EQ) of Electric 

Components,” of this report for 

meeting the requirements of 10 CFR 

54.21(c)(1)(iii).

VI 1 L-05 B.1-a
October 2005 A-225 NUREG-1833

A.7. References:

NUREG/CR-2156 (SAND80-2149), R. L. Clough, K. T. Gillen, “Radiation-Thermal Degradation of PE and 

PVCL Mechanism of Synergism and Dose Rate Effects, June 1981.

Peckner, D., and I. M. Bernstein, Eds., “Handbook of Stainless Steels,” McGraw-Hill, New York, 1977, p. 

16-85.

Metals Handbook, Ninth Edition, Volume 13, Corrosion, American Society of Metals, 1987, p.326. 

O. K. Chopra and A. Sather, “Initial Assessment of the Mechanisms and Significance of Low-Temperature 

Embrittlement of Cast Stainless Steels in LWR Systems” NUREG/CR-5385 (ANL-89/17) Argonne 

National Laboratory, Argonne, IL (August 1990).

SAND96-0344, “Aging Management Guideline for Commercial Nuclear Power Plants – Electrical Cable 

and Terminations,” September 1996.

ASME Boiler & Pressure Vessel Code, SECTION II: Part A, Ferrous Material Specification.

ASME Boiler & Pressure Vessel Code, SECTION II: Part B, Nonferrous Material Specifications.

NUREG-1557, Summary of Technical Information and Agreements from Nuclear Management and 

Resources Council Industry Reports Addressing License Renewal, October 1996.

NUMARC Report 90-01, Revision 1, Sept 1991, "Pressurized Water Reactors Containment Structures 

License Renewal Industry Report,” NUMARC, Washington D.C.

ACI 301-84 Specification of Structural Concrete for Buildings, American Concrete Institute, Detroit, 

Michigan.

1976 Annual Book of ASTM Standards, Part 10, ASTM, Philadelphia, Pa., 1976.

NUMARC Report 90-07, May 1992, "PWR Reactor Coolant system License Renewal Industry Report,” 

NUMARC, Washington D.C.

Shah, V.N., and P.E. Macdonald (eds.) “Aging and Life Extension of Major Light Water Reactor 

Components," Elsevier, Amsterdam, 1993.

M. Gavrilas, P. Hejzlar, N.E. Todreas, and Y. Shatilla, "Safety Features of Operating Light Water 

Reactors of Western Designs", CANES, MIT, Cambridge, MA., 2000.

NUMARC Report 90-05, Revision 1, December 1992, "PWR Reactor Pressure Vessel Internals License 

Renewal Industry Report,” NUMARC, Washington D.C.

NUMARC Report 90-06, Revision 1, December 1991, "Class 1 Structures License Renewal Industry 

Report,” NUMARC, Washington D.C.

Davis, J.R., Ed., "Corrosion: Understanding the Basics," ASM International, Materials Park, Ohio, 2000

2004 Annual Book of ASTM Standards, Volume 09.01, ASTM International, 2004.

NRC GL 96-04: “Boraflex Degradation in Spent Fuel Pool Storage Racks,” NRC, Rockville, Md, 1996.

ASTM DS-56E, “Metals and Alloys in the Unified Numbering System,” SAE HS-1086 Feb 93.
NUREG-1833 A-226 October 2005

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October 2005 B-i NUREG-1833

APPENDIX B

SRP-LR Development Tools
NUREG-1833 B-ii October 2005

This Page Intentionally Left Blank
October 2005 B-1 NUREG-1833

Introduction

Certain tables in GALL Volume 1 (GV1) and the SRP-LR summarize the GALL Volume 2 (GV2) 

AMR table information. The SRP-LR development tools were prepared to support this 

summarization, or rollup process. These summary tables preserve some of the detailed AMR 

information; however, they do not preserve the material or environment information, both of 

which are often useful when organizing an LRA to align it with GV1. The SRP development tools 

presented in this appendix also facilitate that alignment. Figure 2 on pg. 10 in the introduction to 

this NUREG-1833 schematically clarifies the relationship between these documents.

To understand the organization of the SRP development tools, it is helpful to understand how 

the rollup presented in these tools was prepared. The objective for the rollup of the AMR items 

in the mechanical chapters of GV2 (RCS, ESF, AUX, and SPC) was to group sets of 

components together that were subject to the same aging management activities and the same 

further evaluation needs. (The items in the Components, Structures and Electrical chapters in 

GV2 (Chapters II, III and VI) were already grouped as commodities, and therefore, such SRP 

development tools were not considered necessary.) Therefore, components within a GV2 

mechanical chapter with the same aging effect/mechanism, further evaluation requirements, 

and aging management program are rolled up and grouped together in the SRP development 

tool. 

A common ID number for each grouping was also used as the identifier for the corresponding 

row in the SRP-LR and GV1 tables. For each ID number, summary descriptions of the aging 

management expectations were then developed for use in the SRP-LR and GV1 tables. These 

groupings were also used to develop the SRP-LR reference statements in the text sections of 

the SRP-LR. Additionally, the SRP-LR development tools also assisted the Staff in ensuring that 

the GV2 AMR tables were consistent, complete, and accurate.

The SRP development tools for the Reactor Coolant Systems, Engineered Safety Features 

Systems, Auxiliary Systems, and Steam and Power Conversion Systems are provided in Tables 

B1.1 through B1.4, respectively. These tables are organized as follows. The AMR item

groupings for which further evaluation is required are presented first, in the order in which they 

are addressed in the SRP-LR text. These are followed by items for which commitments are to 

be verified, if any. Next are the items for which no further evaluation is required. Finally, the 

items for which there are no aging effects that require management are presented. Other than 

the listing of items requiring further evaluation, the items within each grouping are presented in 

alphabetical order, based on the first character in the aging effect/mechanism field, then the 

next field to the right, and so forth.

It should be noted that the process used to develop these tables leaves the cell in a column 

blank if the entry would duplicate the entry in the row above. Therefore, to determine the value 

that applies when a cell is blank, the reader must look up the column to the previous non-blank 

cell.
NUREG-1833

B-2 October 2005

B.1 Reactor Coolant System SRP-LR Development Tool

Table B.1 presents the reactor coolant system SRP-LR development tool.

Table B.1 Reactor Coolant Systems

ID Aging Effect/ 

Mechanism

SRP-LR 

Ref

Type Further 

Evaluation

Aging Management 

Program (AMP)

Material Environment Related 

Item

Structure and/or 

Component

Related

1 Cumulative 

fatigue 

damage/ 

fatigue

3.1.2.2.1 BWR Yes, 

TLAA

Fatigue is a time-limited 

aging analysis (TLAA) to 

be evaluated for the 

period of extended 

operation. See the 

Standard Review Plan, 

Section 4.3 “Metal 

Fatigue,” for acceptable 

methods for meeting the 

requirements of 10 CFR 

54.21(c)(1).

Steel Air – indoor 

uncontrolled

R-70 Pressure vessel 

support skirt and 

attachment welds

A1.7-a 

A2.8-a

2 Cumulative 

fatigue 

damage/ 

fatigue

3.1.2.2.1 BWR Yes, 

TLAA

Fatigue is a time-limited 

aging analysis (TLAA) to 

be performed for the 

period of extended 

operation, and, for Class 1 

components, 

environmental effects on 

fatigue are to be 

addressed. See the 

Standard Review Plan, 

Section 4.3 “Metal 

Fatigue,” for acceptable 

methods for meeting the 

requirements of 10 CFR 

54.21(c)(1).

Steel; 

stainless 

steel; steel 

with nickelalloy or 

stainless steel 

cladding; 

nickel-alloy

Reactor 

coolant

R-04 Reactor vessel 

components: 

Flanges; 

Nozzles; 

Penetrations; 

Safe ends; 

Thermal sleeves; 

Vessel shells, heads 

and welds 

A1.1-b 

A1.2-a 

A1.2-a 

A1.2-b 

A1.2-b 

A1.2-b 

A1.2-b 

A1.3-a 

A1.3-d 

A1.3-d 

A1.4-b 

A1.5-b 

A1.5-b 

A1.5-b 

A1.5-b 

A1.5-b 

A1.5-b 

A1.6-a
October 2005

B-3 NUREG-1833

Table B.1 Reactor Coolant Systems

ID Aging Effect/ 

Mechanism

SRP-LR 

Ref

Type Further 

Evaluation

Aging Management 

Program (AMP)

Material Environment Related 

Item

Structure and/or 

Component

Related

3 Cumulative 

fatigue 

damage/ 

fatigue

3.1.2.2.1 BWR Yes, 

TLAA

Fatigue is a time-limited 

aging analysis (TLAA) to 

be performed for the 

period of extended 

operation, and, for Class 1 

components, 

environmental effects on 

fatigue are to be 

addressed. See the 

Standard Review Plan, 

Section 4.3 “Metal 

Fatigue,” for acceptable 

methods for meeting the 

requirem ents of 10 CFR 

54.21(c)(1).

Steel; 

stainless 

steel; steel 

with nickelalloy or 

stainless steel 

cladding; 

nickel-alloy

Reactor 

coolant

R-220 Reactor coolant 

pressure boundary 

components: 

Piping, piping 

components, and 

piping elements

C1.1-b 

C1.1-d 

C1.1-e 

C1.1-e 

C1.1-h 

C1.1-h 

C1.1-h 

C1.1-h 

C1.1-h 

C1.1-h 

C1.1-h 

C1.2-a 

C1.2-a 

C1.2-a 

C1.3-d 

C1.3-d 

C1.3-d 

4 Cumulative 

fatigue 

damage/ 

fatigue

3.1.2.2.1 BWR Yes, 

TLAA

Fatigue is a time-limited 

aging analysis (TLAA) to 

be performed for the 

period of extended 

operation; check ASME 

Code limits for allowable 

cycles (less than 7000 

cycles) of thermal stress 

range. See the Standard 

Review Plan, Section 4.3 

“Metal Fatigue,” for 

acceptable methods for 

meeting the requirements 

of 10 CFR 54.21(c)(1).

Steel System 

temperature 

up to 288°C 

(550°F)

R-28 Pump and valve 

closure bolting

C1.2-f 

C1.3-g 
NUREG-1833

B-4 October 2005

Table B.1 Reactor Coolant Systems

ID Aging Effect/ 

Mechanism

SRP-LR 

Ref

Type Further 

Evaluation

Aging Management 

Program (AMP)

Material Environment Related 

Item

Structure and/or 

Component

Related

5 Cumulative 

fatigue 

damage/ 

fatigue

3.1.2.2.1 BWR/ 

PWR

Yes, 

TLAA

Fatigue is a time-limited 

aging analysis (TLAA) to 

be evaluated for the 

period of extended 

operation. See the 

Standard Review Plan, 

Section 4.3 “Metal 

Fatigue,” for acceptable 

methods for meeting the 

requirements of 10 CFR 

54.21(c)(1).

Stainless 

steel; nickel 

alloy

Reactor 

coolant

R-53 Reactor vessel 

internals 

components

B1.1-c 

B1.2-b 

B1.3-b 

B1.4-b 

B1.5-b 

B1.6-b 

B2.1-c 

B2.1-h 

B2.1-m 

B2.2-c 

B2.2-f 

B2.3-d 

B2.4-g 

B2.5-d 

B2.5-j 

B2.5-p 

B3.2-f 

B3.4-d 

B3.5-g 

B4.1-d 

B4.2-d 

B4.3-f 

B4.4-e 

B4.5-f 

B4.6-f 

6 Cumulative 

fatigue 

damage/ 

fatigue

3.1.2.2.1 PWR Yes, 

TLAA

Fatigue is a time-limited 

aging analysis (TLAA) to 

be evaluated for the 

period of extended 

operation. See the 

Standard Review Plan, 

Section 4.3 “Metal 

Fatigue,” for acceptable 

methods for meeting the 

requirements of 10 CFR 

54.21(c)(1).

Nickel alloy Reactor 

coolant and 

secondary 

feedwater/ste

am

R-46 Tubes and sleeves D1.2-d 

D2.2-e 
October 2005

B-5 NUREG-1833

Table B.1 Reactor Coolant Systems

ID Aging Effect/ 

Mechanism

SRP-LR 

Ref

Type Further 

Evaluation

Aging Management 

Program (AMP)

Material Environment Related 

Item

Structure and/or 

Component

Related

7 Cumulative 

fatigue 

damage/ 

fatigue

3.1.2.2.1 PWR Yes, 

TLAA

Fatigue is a time-limited 

aging analysis (TLAA) to 

be evaluated for the 

period of extended 

operation. See the 

Standard Review Plan, 

Section 4.3 “Metal 

Fatigue,” for acceptable 

methods for meeting the 

requirements of 10 CFR 

54.21(c)(1).

Low alloy 

steel

Air with 

reactor 

coolant 

leakage

R-73 Closure head 

Stud assembly

A2.1-e

Stainless 

steel; steel

System 

temperature 

up to 340°C 

(644°F)

R-18 Piping and 

components external 

surfaces and bolting

C2.3-d 

C2.4-d 

C2.5-t 

C2.5-w 

Steel Secondary 

feedwater/ 

steam

R-33 Steam generator 

components 

Top head; 

Steam nozzle and 

safe end; 

Upper and lower 

shell; 

FW and AFW nozzle 

and safe end; 

FW impingement 

plate and support

D1.1-a 

D1.1-b 

D2.1-d 

D2.1-g 

Steel with 

stainless steel 

cladding

Treated 

borated water

R-13 Pressurizer relief 

tank 

Tank shell and 

heads 

Flanges and nozzles

C2.6-a 
NUREG-1833

B-6 October 2005

Table B.1 Reactor Coolant Systems

ID Aging Effect/ 

Mechanism

SRP-LR 

Ref

Type Further 

Evaluation

Aging Management 

Program (AMP)

Material Environment Related 

Item

Structure and/or 

Component

Related

8 Cumulative 

fatigue 

damage/ 

fatigue

3.1.2.2.1 PWR Yes, 

TLAA

Fatigue is a time-limited 

aging analysis (TLAA) to 

be performed for the 

period of extended 

operation, and, for Class 1 

components, 

environmental effects on 

fatigue are to be 

addressed. See the 

Standard Review Plan, 

Section 4.3 “Metal 

Fatigue,” for acceptable 

methods for meeting the 

requirements of 10 CFR 

54.21(c)(1).

Steel; 

stainless 

steel; steel 

with nickelalloy or 

stainless steel 

cladding; 

nickel-alloy

Reactor 

coolant

R-223 Reactor coolant 

pressure boundary 

components: 

Piping, piping 

components, and 

piping elements; 

Flanges; 

Nozzles and safe 

ends; 

Pressurizer vessel 

shell heads and 

welds; 

Heater sheaths and 

sleeves; 

Penetrations; and 

Thermal sleeves

C2.1-a 

C2.1-a 

C2.1-b 

C2.1-b 

C2.2-a 

C2.2-a 

C2.2-a 

C2.2-a 

C2.2-b 

C2.2-b 

C2.2-c 

C2.3-a 

C2.3-a 

C2.4-a 

C2.4-a 

C2.5-a 

C2.5-d 

C2.5-d 

C2.5-e 

C2.5-f 

C2.5-f 

C2.5-f 

C2.5-q 

9 Cumulative 

fatigue 

damage/ 

fatigue

3.1.2.2.1 PWR Yes, 

TLAA

Fatigue is a time-limited 

aging analysis (TLAA) to 

be performed for the 

period of extended 

operation, and, for Class 1 

components, 

environmental effects on 

fatigue are to be 

addressed. See the 

Standard Review Plan, 

Section 4.3 “Metal 

Fatigue,” for acceptable 

methods for meeting the 

requirements of 10 CFR 

54.21(c)(1).

Steel; 

stainless 

steel; steel 

with nickelalloy or 

stainless steel 

cladding; 

nickel-alloy

Reactor 

coolant

R-219 Reactor vessel 

components: 

Flanges; 

Nozzles; 

Penetrations; 

Pressure housings; 

Safe ends; 

Thermal sleeves; 

Vessel shells, heads 

and welds 

A2.1-b 

A2.2-c 

A2.2-c 

A2.3-c 

A2.3-c 

A2.3-c 

A2.4-a 

A2.4-a 

A2.4-a 

A2.5-d 

A2.5-d 

A2.5-d

A2.5-d 
October 2005

B-7 NUREG-1833

Table B.1 Reactor Coolant Systems

ID Aging Effect/ 

Mechanism

SRP-LR 

Ref

Type Further 

Evaluation

Aging Management 

Program (AMP)

Material Environment Related 

Item

Structure and/or 

Component

Related

10 Cumulative 

fatigue 

damage/ 

fatigue

3.1.2.2.1 PWR Yes, 

TLAA

Fatigue is a time-limited 

aging analysis (TLAA) to 

be performed for the 

period of extended 

operation, and, for Class 1 

components, 

environmental effects on 

fatigue are to be 

addressed. See the 

Standard Review Plan, 

Section 4.3 “Metal 

Fatigue,” for acceptable 

methods for meeting the 

requirements of 10 CFR 

54.21(c)(1).

Steel; 

stainless 

steel; steel 

with nickelalloy or 

stainless steel 

cladding; 

nickel-alloy

Reactor 

coolant

R-221 Recirculating steam 

generator 

components: 

Flanges; 

Penetrations; 

Nozzles; 

Safe ends, lower 

heads and welds

D1.1-h 

R-222 Once-through steam 

generator 

components: 

Primary side nozzles 

Safe ends and welds

D2.1-c

11 Loss of 

material/ 

general, 

pitting, and 

crevice 

corrosion

3.1.2.2.2.1 BWR Yes, detection 

of aging 

effects is to 

be evaluated

Chapter XI.M2, “Water 

Chemistry,” for BWR 

water 

The AMP is to be 

augmented by verifying 

the effectiveness of water 

chemistry control. See 

Chapter XI.M32, “OneTime Inspection,” for an 

acceptable verification 

program.

Steel Reactor 

coolant

R-59 Top head enclosure 

(without cladding) 

Top head 

Nozzles (vent, top 

head spray or RCIC, 

and spare)

A1.1-a
NUREG-1833

B-8 October 2005

Table B.1 Reactor Coolant Systems

ID Aging Effect/ 

Mechanism

SRP-LR 

Ref

Type Further 

Evaluation

Aging Management 

Program (AMP)

Material Environment Related 

Item

Structure and/or 

Component

Related

12 Loss of 

material/ 

general, 

pitting, and 

crevice 

corrosion

3.1.2.2.2.1 PWR Yes, detection 

of aging 

effects is to 

be evaluated

Chapter XI.M2, “Water 

Chemistry,” for PWR 

secondary water 

The AMP is to be 

augmented by verifying 

the effectiveness of water 

chemistry control. See 

Chapter XI.M32, “OneTime Inspection,” for an 

acceptable verification 

program.

Steel Secondary 

feedwater/ 

steam

R-224 Steam generator 

components 

Shell assembly

D2.1-e 

13 Loss of 

material/ 

general (steel 

only), pitting 

and crevice 

corrosion

3.1.2.2.2.2 BWR Yes, detection 

of aging 

effects is to 

be evaluated

Chapter XI.M2, “Water 

Chemistry,” for BWR 

water 

The AMP is to be 

augmented by verifying 

the effectiveness of water 

chemistry control. See 

Chapter XI.M32, “OneTime Inspection,” for an 

acceptable verification 

program.

Stainless 

steel; steel

Reactor 

coolant

R-16 Isolation condenser 

components

C1.4-b 

14 Loss of 

material/ 

pitting and 

crevice 

corrosion

3.1.2.2.2.3 BWR Yes, detection 

of aging 

effects is to 

be evaluated

Chapter XI.M2, “Water 

Chemistry,” for BWR 

water 

The AMP is to be 

augmented by verifying 

the effectiveness of water 

chemistry control. See 

Chapter XI.M32, “OneTime Inspection,” for an 

acceptable verification 

program.

Stainless 

steel; steel 

with nickelalloy or 

stainless steel 

cladding; 

nickel-alloy

Reactor 

coolant

RP-25 Reactor Vessel: 

Flanges, nozzles; 

penetrations; safe 

ends; vessel shells, 

heads and welds

A1.
October 2005

B-9 NUREG-1833

Table B.1 Reactor Coolant Systems

ID Aging Effect/ 

Mechanism

SRP-LR 

Ref

Type Further 

Evaluation

Aging Management 

Program (AMP)

Material Environment Related 

Item

Structure and/or 

Component

Related

15 Loss of 

material/ 

pitting and 

crevice 

corrosion

3.1.2.2.2.3 BWR Yes, detection 

of aging 

effects is to 

be evaluated

Chapter XI.M2, “Water 

Chemistry,” for BWR

water 

The AMP is to be 

augmented by verifying 

the effectiveness of water 

chemistry control. See 

Chapter XI.M32, “OneTime Inspection,” for an 

acceptable verification 

program.

Steel with 

stainless steel 

or nickel alloy 

cladding; 

stainless 

steel; nickel 

alloy

Reactor 

coolant

RP-27 Reactor coolant 

pressure boundary 

components

C1.
NUREG-1833

B-10 October 2005

Table B.1 Reactor Coolant Systems

ID Aging Effect/ 

Mechanism

SRP-LR 

Ref

Type Further 

Evaluation

Aging Management 

Program (AMP)

Material Environment Related 

Item

Structure and/or 

Component

Related

16 Loss of 

material/ 

general, 

pitting, and 

crevice 

corrosion

3.1.2.2.2.4 PWR Yes, detection 

of aging 

effects is to 

be evaluated

Chapter XI.M1, “ASME 

Section XI Inservice 

Inspection, Subsections 

IWB, IWC, and IWD,” for 

Class 2 components and 

Chapter XI.M2, “Water 

Chemistry,” for PWR 

secondary water. As 

noted in NRC IN 90-04, if 

general and pitting 

corrosion of the shell is 

known to exist, the AMP 

guidelines in Chapter 

XI.M1 may not be 

sufficient to detect general 

and pitting corrosion (and 

the resulting corrosionfatigue cracking), and 

additional inspection 

procedures are to be 

developed. This issue is 

limited to Westinghouse 

Model 44 and 51 Steam 

Generators where a high 

stress region exists at the 

shell to transition cone 

weld.

Steel Secondary 

feedwater/ 

steam

R-34 Steam generator 

components 

Upper and lower 

shell, and transition 

cone

D1.1-c 

17 Loss of 

fracture 

toughness/ 

neutron 

irradiation 

embrittlement

3.1.2.2.3.1 BWR/ 

PWR

Yes, 

TLAA

Neutron irradiation 

embrittlement is a time 

dependent aging 

mechanism to be 

evaluated for the period of 

extended operation for all 

ferritic materials that have 

a neutron fluence greater 

than 1017 n/cm2 (E 

>1 MeV) at the end of the 

Steel (with or 

without 

stainless steel 

cladding)

Reactor 

coolant and 

neutron flux

R-62 Vessel shell 

Intermediate beltline 

shell 

Beltline welds

A1.2-c
October 2005

B-11 NUREG-1833

Table B.1 Reactor Coolant Systems

ID Aging Effect/ 

Mechanism

SRP-LR 

Ref

Type Further 

Evaluation

Aging Management 

Program (AMP)

Material Environment Related 

Item

Structure and/or 

Component

Related

license renewal term. 

Aspects of this evaluation 

may involve a TLAA. In 

accordance with approved 

BWRVIP-74, the TLAA is 

to evaluate the impact of 

neutron embrittlement on: 

(a) the adjusted reference 

temperature values used 

for calculation of the 

plant’s pressuretemperature limits, (b) the 

need for inservice 

inspection of 

circumferential welds, and 

(c) the Charpy upper shelf 

energy or the equivalent 

margins analyses 

performed in accordance 

with 10 CFR Part 50, 

Appendix G. Additionally, 

the applicant is to monitor 

axial beltline weld 

embrittlement. One 

acceptable method is to 

determine that the mean 

RTNDT of the axial 

beltline welds at the end 

of the extended period of 

operation is less than the 

value specified by the 

Staff in its March 7, 2000 

letter (ADAMS 

ML031430372). See the 

Standard Review Plan, 

Section 4.2 “Reactor 

Vessel Neutron 

Embrittlement” for 

acceptable methods for 
NUREG-1833

B-12 October 2005

Table B.1 Reactor Coolant Systems

ID Aging Effect/ 

Mechanism

SRP-LR 

Ref

Type Further 

Evaluation

Aging Management 

Program (AMP)

Material Environment Related 

Item

Structure and/or 

Component

Related

meeting the requirements 

of 10 CFR 54.21(c).

Neutron irradiation 

embrittlement is a timelimited aging analysis 

(TLAA) to be evaluated for 

the period of extended 

operation for all ferritic 

materials that have a 

neutron fluence greater 

than 1E17 n/cm2 (E 

>1 MeV) at the end of the 

license renewal term. The 

TLAA is to evaluate the 

impact of neutron 

embrittlement on: (a) the 

RTPTS value based on the 

requirements in 10 CFR 

50.61, (b) the adjusted 

reference temperature 

values used for calculation 

of the plant’s pressuretemperature limits, and 

(c) the Charpy upper shelf 

energy or the equivalent 

margins analyses 

performed in accordance 

with 10 CFR Part 50, 

Appendix G requirements . 

See the Standard Review 

Plan, Section 4.2 “Reactor 

Vessel Neutron 

Embrittlement” for 

acceptable methods for 

meeting the requirements 

of 10 CFR 54.21(c).

Steel with 

stainless steel 

cladding

Reactor 

coolant and 

neutron flux

R-84 Vessel shell 

Upper shell 

Intermediate and 

lower shell 

(including beltline 

welds)

A2.5-a
October 2005

B-13 NUREG-1833

Table B.1 Reactor Coolant Systems

ID Aging Effect/ 

Mechanism

SRP-LR 

Ref

Type Further 

Evaluation

Aging Management 

Program (AMP)

Material Environment Related 

Item

Structure and/or 

Component

Related

Neutron irradiation 

embrittlement is a timelimited aging analysis 

(TLAA) to be evaluated for 

the period of extended 

operation for all ferritic 

materials that have a 

neutron fluence greater 

than 1E17 n/cm2 (E 

>1 MeV) at the end of the 

license renewal term. In 

accordance with approved 

BWRVIP-74, the TLAA is 

to evaluate the impact of 

neutron embrittlement on: 

(a) the adjusted reference 

temperature values used 

for calculation of the 

plant’s pressuretemperature limits, and (b) 

the need for inservice 

inspection of 

circumferential welds, and 

(c) the Charpy upper shelf 

energy or the equivalent 

margins analyses 

performed in accordance 

with 10 CFR Part 50, 

Appendix G The applicant 

may choose to 

demonstrate that the 

materials of the nozzles 

are not controlling for the

TLAA evaluations. See 

the Standard Review 

Plan, Section 4.2 “Reactor 

Vessel Neutron 

Embrittlement” for 

acceptable methods for 

meeting the requirements 

of 10 CFR 54.21(c).

Steel Reactor 

coolant and 

neutron flux

R-67 Nozzles 

Low pressure 

coolant injection or 

RHR injection mode

A1.3-e
NUREG-1833

B-14 October 2005

Table B.1 Reactor Coolant Systems

ID Aging Effect/ 

Mechanism

SRP-LR 

Ref

Type Further 

Evaluation

Aging Management 

Program (AMP)

Material Environment Related 

Item

Structure and/or 

Component

Related

Neutron irradiation 

embrittlement is a timelimited aging analysis 

(TLAA) to be evaluated for 

the period of extended 

operation for all ferritic 

materials that have a 

neutron fluence greater 

than 1E17 n/cm2 (E 

>1 MeV) at the end of the 

license renewal term. The 

TLAA is to evaluate the 

impact of neutron 

embrittlement on: (a) the 

RTPTS value based on the 

requirements in 10 CFR 

50.61, (b) the adjusted 

reference temperature 

values used for calculation 

of the plant’s pressuretemperature limits, and 

(c) the Charpy upper shelf 

energy or the equivalent 

margins analyses 

performed in accordance 

with 10 CFR Part 50, 

Appendix G requirements. 

The applicant may choose 

to demonstrate that the 

materials in the inlet, 

outlet, and safety injection 

nozzles are not controlling 

for the TLAA evaluations.

Steel with 

stainless steel 

cladding

Reactor 

coolant and 

neutron flux

R-81 Nozzles 

Inlet 

Outlet 

Safety injection

A2.3-a
October 2005

B-15 NUREG-1833

Table B.1 Reactor Coolant Systems

ID Aging Effect/ 

Mechanism

SRP-LR 

Ref

Type Further 

Evaluation

Aging Management 

Program (AMP)

Material Environment Related 

Item

Structure and/or 

Component

Related

18 Loss of 

fracture 

toughness/ 

neutron 

irradiation 

embrittlement

3.1.2.2.3.2 BWR/ 

PWR

No Chapter XI.M31, “Reactor 

Vessel Surveillance”

Steel (with or 

without 

stainless steel 

cladding)

Reactor 

coolant and 

neutron flux

R-63 Vessel shell 

Intermediate beltline 

shell 

Beltline welds

A1.2-d 

Steel with 

stainless steel 

cladding

Reactor 

coolant and 

neutron flux

R-82 Nozzles 

Inlet 

Outlet 

Safety injection

A2.3-b

R-86 Vessel shell 

Upper shell 

Intermediate and 

lower shell 

(including beltline 

welds)

A2.5-c

19 Cracking/ 

stress 

corrosion 

cracking and 

intergranular 

stress 

corrosion 

cracking

3.1.2.2.4.1 BWR Yes, plantspecificA plant-specific aging 

management program is 

to be evaluated because 

existing programs may not 

be capable of mitigating or 

detecting crack initiation 

and growth due to SCC in 

the vessel flange leak 

detection line.

Stainless 

steel; nickel 

alloy

Air with 

reactor 

coolant 

leakage 

(Internal) 

or 

Reactor 

Coolant 

R-61 Top head enclosure 

Vessel flange leak 

detection line

A1.1-d
NUREG-1833

B-16 October 2005

Table B.1 Reactor Coolant Systems

ID Aging Effect/ 

Mechanism

SRP-LR 

Ref

Type Further 

Evaluation

Aging Management 

Program (AMP)

Material Environment Related 

Item

Structure and/or 

Component

Related

20 Cracking/ 

stress 

corrosion 

cracking, 

intergranular 

stress 

corrosion 

cracking

3.1.2.2.4.2 BWR Yes, detection 

of aging 

effects is to 

be evaluated

Chapter XI.M1, “ASME 

Section XI Inservice 

Inspection, Subsections 

IWB, IWC, and IWD,” for 

Class 1 components 

and Chapter XI.M2, 

“Water Chemistry,” for 

BWR water. 

The AMP in Chapter 

XI.M1 is to be augmented 

to detect cracking due to 

stress corrosion cracking 

and verification of the 

program's effectiveness is 

necessary to ensure that 

significant degradation is 

not occurring and the 

component intended 

function will be m aintained 

during the extended 

period of operation. An 

acceptable verification 

program is to include 

temperature and 

radioactivity monitoring of 

the shell side water, and 

eddy current testing of 

tubes.

Stainless 

steel

Reactor 

coolant

R-15 Isolation condenser 

components

C1.4-a
October 2005

B-17 NUREG-1833

Table B.1 Reactor Coolant Systems

ID Aging Effect/ 

Mechanism

SRP-LR 

Ref

Type Further 

Evaluation

Aging Management 

Program (AMP)

Material Environment Related 

Item

Structure and/or 

Component

Related

21 Crack growth/ 

cyclic loading

3.1.2.2.5 PWR Yes, 

TLAA

Growth of intergranular 

separations (underclad 

cracks) in low-alloy steel 

forging heat affected zone 

under austenitic stainless 

steel cladding is a timelimited aging analysis 

(TLAA) to be evaluated for 

the period of extended 

operation for all the SA 

508-Cl 2 forgings where 

the cladding was 

deposited with a high heat 

input welding process. 

The methodology for 

evaluating an underclad 

flaw is in accordance with 

the current wellestablished flaw 

evaluation procedure and 

criterion in the ASME 

Section XI Code. See the 

Standard Review Plan, 

Section 4.7, “Other PlantSpecific Time-Limited 

Aging Analysis,” for 

generic guidance for 

meeting the requirements 

of 10 CFR 54.21(c).

SA508-Cl 2 

forgings clad 

with stainless 

steel using a 

high-heatinput welding 

process

Reactor 

coolant

R-85 Vessel shell 

Upper shell 

Intermediate and 

lower shell 

(including beltline 

welds)

A2.5-b
NUREG-1833

B-18 October 2005

Table B.1 Reactor Coolant Systems

ID Aging Effect/ 

Mechanism

SRP-LR 

Ref

Type Further 

Evaluation

Aging Management 

Program (AMP)

Material Environment Related 

Item

Structure and/or 

Component

Related

22 Loss of 

fracture 

toughness/ 

neutron 

irradiation 

embrittlement, 

void swelling

3.1.2.2.6 PWR No, but 

licensee 

commitment 

needs to be 

confirmed

No further aging 

management review is 

necessary if the applicant 

provides a commitment in 

the FSAR supplement to 

(1) participate in the 

industry programs for 

investigating and 

managing aging effects on 

reactor internals; (2) 

evaluate and implement 

the results of the industry 

programs as applicable to 

the reactor internals; and 

(3) upon completion of 

these programs, but not 

less than 24 months 

before entering the period 

of extended operation, 

submit an inspection plan 

for reactor internals to the 

NRC for review and 

approval.

Stainless 

steel

Reactor 

coolant and 

neutron flux

R-122 Core barrel 

Core barrel (CB) 

CB flange (upper) 

CB outlet nozzles 

Thermal shield

B2.3-c

R-127 Baffle/former 

assembly 

Baffle and former 

plates

B2.4-e

R-128 Baffle/former 

assembly 

Baffle/former bolts 

and screws

B2.4-f 

B4.5-i

R-132 Lower internal 

assembly 

Lower core plate

B2.5-c
October 2005

B-19 NUREG-1833

Table B.1 Reactor Coolant Systems

ID Aging Effect/ 

Mechanism

SRP-LR 

Ref

Type Further 

Evaluation

Aging Management 

Program (AMP)

Material Environment Related 

Item

Structure and/or 

Component

Related

R-141 Lower internal 

assembly 

Lower support 

forging 

Lower support plate 

columns

B2.5-n

R-157 Core support barrel 

Core support barrel 

upper flange

B3.3-a

R-161 Core shroud 

assembly 

Core shroud tie rods 

(core support plate 

attached by welds in 

later plants)

B3.4-c

R-178 Upper grid assembly 

Upper grid rib 

section 

Upper grid ring 

forging 

Fuel assembly 

support pads 

Plenum rib pads 

Rib-to-ring screws

B4.2-e

R-216 Thermal shield B4.8-c

Stainless 

steel; nickel 

alloy

Reactor 

coolant and 

neutron flux

R-135 Lower internal 

assembly 

Fuel alignment pins 

Lower support plate 

column bolts 

Clevis insert bolts

B2.5-g
NUREG-1833

B-20 October 2005

Table B.1 Reactor Coolant Systems

ID Aging Effect/ 

Mechanism

SRP-LR 

Ref

Type Further 

Evaluation

Aging Management 

Program (AMP)

Material Environment Related 

Item

Structure and/or 

Component

Related

R-164 Core shroud 

assembly 

Core shroud 

assembly bolts (later 

plants are welded)

B3.4-g

R-169 Lower internal 

assembly 

Core support plate 

Fuel alignment pins 

Lower support 

structure beam 

assemblies 

Core support column 

bolts 

 Core support barrel 

snubber assemblies

B3.5-d

R-188 Core support shield 

assembly 

Core support shield 

cylinder (top and 

bottom flange) 

Core support shieldto-core barrel bolts 

Outlet and vent 

valve (VV) nozzles 

 VV assembly 

locking device

B4.4-d
October 2005

B-21 NUREG-1833

Table B.1 Reactor Coolant Systems

ID Aging Effect/ 

Mechanism

SRP-LR 

Ref

Type Further 

Evaluation

Aging Management 

Program (AMP)

Material Environment Related 

Item

Structure and/or 

Component

Related

R-196 Core barrel 

assembly 

Core barrel cylinder 

(top and bottom 

flange) 

Lower internals 

assembly-to- core 

barrel bolts 

Core barrel-tothermal shield bolts 

Baffle plates and 

formers

B4.5-d

R-205 Lower grid assembly 

Lower grid rib 

section 

Fuel assembly 

support pads 

Lower grid rib-toshell forging screws 

Lower grid flow dist. 

plate 

Orifice plugs 

Lower grid and shell 

forgings 

Lower internals 

assembly-to-thermal 

shield bolts 

Guide blocks and 

bolts 

Shock pads and 

bolts 

Support post pipes

B4.6-d
NUREG-1833

B-22 October 2005

Table B.1 Reactor Coolant Systems

ID Aging Effect/ 

Mechanism

SRP-LR 

Ref

Type Further 

Evaluation

Aging Management 

Program (AMP)

Material Environment Related 

Item

Structure and/or 

Component

Related

R-212 Flow distributor 

assembly 

Flow distributor head 

and flange 

Shell forging-to-flow 

distributor bolts 

Incore guide support 

plate 

Clamping ring

B4.7-d

23 Cracking/ 

stress 

corrosion 

cracking

3.1.2.2.7.1 PWR Yes, plantspecificA plant-specific aging 

management program is 

to be evaluated because 

existing programs may not 

be capable of mitigating or 

detecting crack initiation 

and growth due to SCC in 

the vessel flange leak 

detection line.

Stainless 

steel

Air with 

reactor 

coolant 

leakage 

(Internal) 

or 

Reactor 

Coolant 

R-74 Closure head 

Vessel flange leak 

detection line

A2.1-f

A plant-specific aging 

management program is 

to be evaluated.

Stainless 

steel

Reactor 

coolant

RP-13 Bottom-mounted 

guide tube

A2. 
October 2005

B-23 NUREG-1833

Table B.1 Reactor Coolant Systems

ID Aging Effect/ 

Mechanism

SRP-LR 

Ref

Type Further 

Evaluation

Aging Management 

Program (AMP)

Material Environment Related 

Item

Structure and/or 

Component

Related

24 Cracking/ 

stress 

corrosion 

cracking

3.1.2.2.7.2 PWR Yes, plantspecificMonitoring and control of 

primary water chemistry in 

accordance with the 

guidelines in EPRI TR105714 (Rev. 3 or later) 

minimize the potential of 

SCC, and material 

selection according to 

NUREG-0313, Rev. 2 

guidelines of =0.035% C 

and =7.5% ferrite reduces 

susceptibility to SCC. 

For CASS components 

that do not meet either 

one of the above 

guidelines, a plant-specific 

aging management 

program is to be 

evaluated. The program is 

to include (a) adequate 

inspection methods to 

ensure detection of 

cracks, and (b) flaw 

evaluation methodology 

for CASS components 

that are susceptible to 

thermal aging 

embrittlement.

Cast 

austenitic 

stainless steel

Reactor 

coolant

R-05 Class 1 piping, 

piping components, 

and piping elements

C2.1-e 

C2.2-g 

C2.5-i 

25 Cracking/ 

cyclic loading

3.1.2.2.8.1 BWR Yes, plantspecificA plant-specific aging 

management program is 

to be evaluated.

Stainless 

steel

Reactor 

coolant

R-102 Jet pump 

assemblies 

Jet pump sensing 

line

B1.4-d
NUREG-1833

B-24 October 2005

Table B.1 Reactor Coolant Systems

ID Aging Effect/ 

Mechanism

SRP-LR 

Ref

Type Further 

Evaluation

Aging Management 

Program (AMP)

Material Environment Related 

Item

Structure and/or 

Component

Related

26 Cracking/ 

cyclic loading

3.1.2.2.8.2 BWR Yes, detection 

of aging 

effects is to 

be evaluated

Chapter XI.M1, “ASME 

Section XI Inservice 

Inspection, Subsections 

IWB, IWC, and IWD,” for 

Class 1 components 

The AMP in Chapter 

XI.M1 is to be augmented 

to detect cracking due to 

cyclic loading and 

verification of the 

program's effectiveness is 

necessary to ensure that 

significant degradation is 

not occurring and the 

component intended 

function will be maintained 

during the extended 

period of operation. An 

acceptable verification 

program is to include 

temperature and 

radioactivity monitoring of 

the shell side water, and 

eddy current testing of 

tubes.

Stainless 

steel; steel

Reactor 

coolant

R-225 Isolation condenser 

components

C1.4-a 
October 2005

B-25 NUREG-1833

Table B.1 Reactor Coolant Systems

ID Aging Effect/ 

Mechanism

SRP-LR 

Ref

Type Further 

Evaluation

Aging Management 

Program (AMP)

Material Environment Related 

Item

Structure and/or 

Component

Related

27 Loss of 

preload/ 

stress 

relaxation

3.1.2.2.9 PWR No, but 

licensee 

commitment 

needs to be 

confirmed

No further aging 

management review is 

necessary if the applicant 

provides a commitment in 

the FSAR supplement to 

(1) participate in the 

industry programs for 

investigating and 

managing aging effects on 

reactor internals; (2) 

evaluate and implement 

the results of the industry 

programs as applicable to 

the reactor internals; and 

(3) upon completion of 

these programs, but not 

less than 24 months 

before entering the period 

of extended operation, 

submit an inspection plan 

for reactor internals to the 

NRC for review and 

approval.

Stainless 

steel

Reactor 

coolant

R-108 Upper internals 

assembly

Hold-down spring

B2.1-d

R-129 Baffle/former 

assembly 

Baffle/former bolts

B2.4-h

R-184 Control rod guide 

tube (CRGT) 

assembly 

Flange-to-upper grid 

screws

B4.3-e
NUREG-1833

B-26 October 2005

Table B.1 Reactor Coolant Systems

ID Aging Effect/ 

Mechanism

SRP-LR 

Ref

Type Further 

Evaluation

Aging Management 

Program (AMP)

Material Environment Related 

Item

Structure and/or 

Component

Related

R-201 Core barrel 

assembly 

Baffle/former bolts 

and screws

B4.5-j

Stainless 

steel; nickel 

alloy

Reactor 

coolant

R-114 Upper internals 

assembly 

Upper support 

column bolts

B2.1-k

R-136 Lower internal 

assembly 

Lower support plate 

column bolts

B2.5-h

R-137 Lower internal 

assembly 

Clevis insert bolts

B2.5-i

R-154 CEA shroud 

assemblies 

CEA shrouds bolts

B3.2-g

R-165 Core shroud 

assembly 

Core shroud 

assembly bolts 

Core shroud tie rods

B3.4-h

R-192 Core support shield 

assembly 

Core support shieldto-core barrel bolts

B4.4-h
October 2005

B-27 NUREG-1833

Table B.1 Reactor Coolant Systems

ID Aging Effect/ 

Mechanism

SRP-LR 

Ref

Type Further 

Evaluation

Aging Management 

Program (AMP)

Material Environment Related 

Item

Structure and/or 

Component

Related

R-197 Core barrel 

assembly 

Lower internals 

assembly-to-core 

barrel bolts 

Core barrel-tothermal shield bolts

B4.5-e

R-207 Lower grid assembly 

Lower grid rib-toshell forging screws 

Lower internals 

assembly-to-thermal 

shield bolts

B4.6-g

R-213 Flow distributor 

assembly 

Shell forging-to-flow 

distributor bolts

B4.7-e

28 Loss of 

material/ 

erosion

3.1.2.2.10 PWR Yes, plantspecificA plant-specific aging 

management program is 

to be evaluated.

Steel Secondary 

feedwater

R-39 Steam generator 

feedwater 

impingement plate 

and support

D1.1-e 

29 Cracking/ 

flow-induced 

vibration

3.1.2.2.11 BWR Yes, plantspecificA plant-specific aging 

management program is 

to be evaluated.

Stainless 

steel

Reactor 

coolant

RP-18 Steam Dryers B1.
NUREG-1833

B-28 October 2005

Table B.1 Reactor Coolant Systems

ID Aging Effect/ 

Mechanism

SRP-LR 

Ref

Type Further 

Evaluation

Aging Management 

Program (AMP)

Material Environment Related 

Item

Structure and/or 

Component

Related

30 Cracking/ 

stress 

corrosion 

cracking, 

irradiationassisted 

stress 

corrosion 

cracking

3.1.2.2.12 PWR No, but 

licensee 

commitment 

needs to be 

confirmed

Chapter XI.M2, "Water 

Chemistry" for PWR 

primary water 

No further aging 

managem ent review is 

necessary if the applicant 

provides a commitment in 

the FSAR supplement to 

(1) participate in the 

industry programs for 

investigating and 

managing aging effects on 

reactor internals; (2) 

evaluate and implement 

the results of the industry 

programs as applicable to 

the reactor internals; and 

(3) upon completion of 

these programs, but not 

less than 24 months 

before entering the period 

of extended operation, 

submit an inspection plan 

for reactor internals to the 

NRC for review and 

approval.

Stainless 

steel

Reactor 

coolant

R-106 Upper internals 

assembly 

Upper support plate 

Upper core plate 

Hold-down spring

B2.1-a

R-109 Upper internals 

assembly 

Upper support 

column

B2.1-e

R-116 RCCA guide tube 

assemblies 

RCCA guide tubes

B2.2-a
October 2005

B-29 NUREG-1833

Table B.1 Reactor Coolant Systems

ID Aging Effect/ 

Mechanism

SRP-LR 

Ref

Type Further 

Evaluation

Aging Management 

Program (AMP)

Material Environment Related 

Item

Structure and/or 

Component

Related

R-120 Core barrel 

Core barrel (CB) 

CB flange (upper) 

CB outlet nozzles 

Thermal shield

B2.3-a

R-123 Baffle/former 

assembly 

Baffle and former 

plates

B2.4-a

R-138 Lower internal 

assembly 

Lower support 

forging or casting 

Lower support plate 

columns

B2.5-k

R-143 Instrumentation 

support structures 

Flux thimble guide 

tubes

B2.6-a

R-146 Upper internals 

assembly 

Upper guide 

structure support 

plate 

Fuel alignment plate 

Fuel alignment plate 

guide lugs and guide 

lug inserts

B3.1-a

R-149 CEA shroud 

assemblies

B3.2-a
NUREG-1833

B-30 October 2005

Table B.1 Reactor Coolant Systems

ID Aging Effect/ 

Mechanism

SRP-LR 

Ref

Type Further 

Evaluation

Aging Management 

Program (AMP)

Material Environment Related 

Item

Structure and/or 

Component

Related

R-155 Core support barrel 

Core support barrel 

upper flange

B3.3-a

R-159 Core shroud 

assembly 

Core shroud tie rods 

(core support plate 

attached by welds in 

later plants)

B3.4-a

R-166 Lower internal 

assembly 

Core support plate 

Lower support 

structure beam 

assemblies 

Core support column 

Core support barrel 

snubber assemblies

B3.5-a

R-172 Plenum cover and 

plenum cylinder 

Plenum cover

assembly 

Plenum cylinder 

Reinforcing plates

B4.1-a

R-173 Plenum cover and 

plenum cylinder 

Top flange-to-cover 

bolts Bottom flangeto-upper grid screws

B4.1-b
October 2005

B-31 NUREG-1833

Table B.1 Reactor Coolant Systems

ID Aging Effect/ 

Mechanism

SRP-LR 

Ref

Type Further 

Evaluation

Aging Management 

Program (AMP)

Material Environment Related 

Item

Structure and/or 

Component

Related

R-175 Upper grid assembly 

Upper grid rib 

section 

Upper grid ring 

forging 

Fuel assembly 

support pads 

Plenum rib pads

B4.2-a

R-176 Upper grid assembly 

Rib-to-ring screws

B4.2-b

R-180 Control rod guide 

tube (CRGT) 

assembly 

CRGT pipe and 

flange 

CRGT spacer 

casting 

CRGT rod guide 

tubes 

CRGT rod guide 

sectors

B4.3-a

R-181 Control rod guide 

tube (CRGT) 

assembly 

CRGT spacer 

screws 

Flange-to-upper grid 

screws

B4.3-b
NUREG-1833

B-32 October 2005

Table B.1 Reactor Coolant Systems

ID Aging Effect/ 

Mechanism

SRP-LR 

Ref

Type Further 

Evaluation

Aging Management 

Program (AMP)

Material Environment Related 

Item

Structure and/or 

Component

Related

R-185 Core support shield 

assembly 

Core support shield 

cylinder (top and 

bottom flange) 

Outlet and vent 

valve (VV) nozzles 

VV body and 

retaining ring

B4.4-a

R-193 Core barrel 

assembly 

Core barrel cylinder 

(top and bottom 

flange) 

Baffle plates and 

formers

B4.5-a

R-202 Lower grid assembly 

Lower grid rib 

section 

Fuel assembly 

support pads 

Lower grid flow dist. 

plate 

Orifice plugs 

Lower grid and shell 

forgings 

Guide blocks 

Shock pads 

Support post pipes 

Incore guide tube 

spider castings

B4.6-a
October 2005

B-33 NUREG-1833

Table B.1 Reactor Coolant Systems

ID Aging Effect/ 

Mechanism

SRP-LR 

Ref

Type Further 

Evaluation

Aging Management 

Program (AMP)

Material Environment Related 

Item

Structure and/or 

Component

Related

R-209 Flow distributor 

assembly 

Flow distributor head 

and flange 

Incore guide support 

plate 

Clamping ring

B4.7-a

R-214 Thermal shield B4.8-a

Chapter XI.M2, "Water 

Chemistry," for PWR 

primary water 

No further aging 

management review is 

necessary if the applicant 

provides a commitment in 

the FSAR supplement to 

(1) participate in the 

industry programs for 

investigating and 

managing aging effects on 

reactor internals; (2) 

evaluate and implement 

the results of the industry 

programs as applicable to 

the reactor internals; and 

(3) upon completion of 

these programs, but not 

less than 24 months 

before entering the period 

of extended operation, 

submit an inspection plan 

for reactor internals to the 

NRC for review and 

approval.

Stainless 

steel

Reactor 

coolant

R-125 Core barrel 

assembly 

Baffle/former 

assembly 

Baffle/former bolts 

and screws

B2.4-c, 

B4.5-g
NUREG-1833

B-34 October 2005

Table B.1 Reactor Coolant Systems

ID Aging Effect/ 

Mechanism

SRP-LR 

Ref

Type Further 

Evaluation

Aging Management 

Program (AMP)

Material Environment Related 

Item

Structure and/or 

Component

Related

31 Cracking/ 

primary water 

stress 

corrosion 

cracking

3.1.2.2.13 PWR No, but 

licensee 

commitment 

needs to be 

confirmed

Chapter XI.M1, “ASME 

Section XI Inservice 

Inspection, Subsections 

IWB, IWC, and IWD,” for 

Class 1 components, and 

Chapter XI.M2, “Water 

Chemistry,” for PWR 

primary water and for 

nickel alloy, comply 

with applicable NRC 

Orders and provide a 

commitment in the 

FSAR supplement to 

implement applicable 

(1) Bulletins and 

Generic Letters and (2) 

staff-accepted industry 

guidelines

Nickel alloy; 

steel with 

nickel-alloy 

cladding

Reactor 

coolant

R-01 Instrument 

penetrations and 

primary side 

nozzles, safe ends, 

and welds

D1.1-i 

D1.1-j 

D2.1-h 

Chapter XI.M1, “ASME 

Section XI Inservice 

Inspection, Subsections 

IWB, IWC, and IWD” for 

Class 1 components, and 

Chapter XI.M2, “Water 

Chemistry,” for PWR 

primary water and for 

nickel alloy, comply with 

applicable NRC Orders 

and provide a commitment 

in the FSAR supplement 

to implement applicable 

(1) Bulletins and Generic 

Letters and (2) staffaccepted industry 

guidelines.

Nickel alloy or 

nickel alloy 

cladding

Reactor 

coolant

R-06 Pressurizer 

instrumentation 

penetrations, heater 

sheaths and 

sleeves, heater 

bundle diaphragm

plate, and manways 

and flanges

C2.5-k 

C2.5-s 

C2.5-m 
October 2005

B-35 NUREG-1833

Table B.1 Reactor Coolant Systems

ID Aging Effect/ 

Mechanism

SRP-LR 

Ref

Type Further 

Evaluation

Aging Management 

Program (AMP)

Material Environment Related 

Item

Structure and/or 

Component

Related

Chapter XI.M1, “ASME 

Section XI Inservice 

Inspection, Subsections 

IWB, IWC, and IWD” for 

Class 1 components, and 

Chapter XI.M2, “Water 

Chemistry,” for PWR 

primary water and comply 

with applicable NRC 

Orders and provide a 

commitment in the FSAR 

supplement to submit a 

plant-specific AMP to 

implement applicable (1) 

Bulletins and Generic 

Letters and (2) staffaccepted industry 

guidelines.

Nickel alloy Reactor 

coolant

R-89 Penetrations 

Instrument tubes 

(bottom head)

A2.7-a

Reactor 

coolant/ 

steam

RP-22 Pressurizer surge 

and steam space 

nozzles, and welds

C2. 
NUREG-1833

B-36 October 2005

Table B.1 Reactor Coolant Systems

ID Aging Effect/ 

Mechanism

SRP-LR 

Ref

Type Further 

Evaluation

Aging Management 

Program (AMP)

Material Environment Related 

Item

Structure and/or 

Component

Related

Chapter XI.M1, “ASME 

Section XI Inservice 

Inspection, Subsections 

IWB, IWC, and IWD” for 

Class 1 components, and 

Chapter XI.M2, “Water 

Chemistry” for PWR 

primary water and comply 

with applicable NRC 

Orders and provide a 

commitment in the FSAR 

supplement to submit a 

plant-specific AMP to 

implement applicable (1) 

Bulletins and Generic 

Letters and (2) staffaccepted industry 

guidelines.

Nickel alloy Reactor 

coolant/ 

steam

RP-31 Piping, piping 

components, and 

piping elements

C2. 

Chapter XI.M2, “Water 

Chemistry,” and 

Chapter XI.M1, “ASME 

Section XI Inservice 

Inspection, Subsections 

IWB, IWC, and IWD" and, 

 for nickel alloy, comply 

with applicable NRC 

Orders and provide a 

commitment in the FSAR 

supplement to submit a 

plant-specific AMP to 

implement applicable (1) 

Bulletins and Generic 

Letters and (2) staffaccepted industry 

guidelines.

Nickel alloy Reactor 

coolant

R-88 Core support pads/ 

core guide lugs

A2.6-a
October 2005

B-37 NUREG-1833

Table B.1 Reactor Coolant Systems

ID Aging Effect/ 

Mechanism

SRP-LR 

Ref

Type Further 

Evaluation

Aging Management 

Program (AMP)

Material Environment Related 

Item

Structure and/or 

Component

Related

32 Wall thinning/ 

flowaccelerated 

corrosion

3.1.2.2.14.

1

PWR Yes, plantspecificA plant-specific aging 

management program is 

to be evaluated. 

Reference NRC IN 91-19, 

"Steam Generator 

Feedwater Distribution 

Piping Damage." 

Steel Secondary 

feedwater/ 

steam

R-51 Upper assembly and 

separators 

Feedwater inlet ring 

and support

D1.3-a 

33 Changes in 

dimensions/ 

void swelling

3.1.2.2.15 PWR No, but 

licensee 

commitment 

needs to be 

confirmed

No further aging 

management review is 

necessary if the applicant 

provides a commitment in 

the FSAR supplement to 

(1) participate in the 

industry programs for 

investigating and 

managing aging effects on 

reactor internals; (2) 

evaluate and implement 

the results of the industry 

programs as applicable to 

the reactor internals; and 

(3) upon completion of

these programs, but not 

less than 24 months 

before entering the period 

of extended operation, 

submit an inspection plan 

for reactor internals to the 

NRC for review and 

approval.

Stainless 

steel

Reactor 

coolant

R-107 Upper internals 

assembly 

Upper support plate 

Upper core plate 

Hold-down spring

B2.1-b

R-110 Upper internals 

assembly 

Upper support 

column

B2.1-f
NUREG-1833

B-38 October 2005

Table B.1 Reactor Coolant Systems

ID Aging Effect/ 

Mechanism

SRP-LR 

Ref

Type Further 

Evaluation

Aging Management 

Program (AMP)

Material Environment Related 

Item

Structure and/or 

Component

Related

R-117 RCCA guide tube 

assemblies 

RCCA guide tubes

B2.2-b

R-121 Core barrel 

Core barrel (CB) 

CB flange (upper) 

CB outlet nozzles 

Thermal shield

B2.3-b

R-124 Baffle/former 

assembly 

Baffle and former 

plates

B2.4-b

R-126 Baffle/former 

assembly 

Baffle/former bolts

B2.4-d

R-139 Lower internal 

assembly 

Lower support 

forging or casting 

Lower support plate 

columns

B2.5-l

R-144 Instrumentation 

support structures 

Flux thimble guide 

tubes

B2.6-b
October 2005

B-39 NUREG-1833

Table B.1 Reactor Coolant Systems

ID Aging Effect/ 

Mechanism

SRP-LR 

Ref

Type Further 

Evaluation

Aging Management 

Program (AMP)

Material Environment Related 

Item

Structure and/or 

Component

Related

R-147 Upper internals 

assembly 

Upper guide 

structure support 

plate 

Fuel alignment plate 

Fuel alignment plate 

guide lugs and guide 

lug inserts

B3.1-b

R-158 Core support barrel 

Core support barrel 

upper flange

B3.3-b

R-174 Plenum cover and 

plenum cylinder 

Plenum cover 

assembly Plenum 

cylinder 

Reinforcing plates 

Top flange-to-cover 

bolts Bottom flangeto-upper grid screws

B4.1-c

R-177 Upper grid assembly 

Upper grid rib 

section 

Upper grid ring 

forging 

Fuel assembly 

support pads 

Plenum rib pads 

Rib-to-ring screws

B4.2-c
NUREG-1833

B-40 October 2005

Table B.1 Reactor Coolant Systems

ID Aging Effect/ 

Mechanism

SRP-LR 

Ref

Type Further 

Evaluation

Aging Management 

Program (AMP)

Material Environment Related 

Item

Structure and/or 

Component

Related

R-182 Control rod guide 

tube (CRGT) 

assembly 

CRGT pipe and 

flange 

CRGT spacer 

casting 

CRGT spacer 

screws 

Flange-to-upper grid 

screws 

CRGT rod guide 

tubes 

CRGT rod guide 

sectors

B4.3-c

R-199 Core barrel 

assembly 

Baffle/former bolts 

and screws

B4.5-h

R-215 Thermal shield B4.8-b

Stainless 

steel; nickel 

alloy

Reactor 

coolant

R-113 Upper internals 

assembly 

Upper support 

column bolts Upper 

core plate alignment 

pins 

Fuel alignment pins

B2.1-j

R-119 RCCA guide tube 

assemblies 

RCCA guide tube 

bolts 

RCCA guide tube 

support pins

B2.2-e
October 2005

B-41 NUREG-1833

Table B.1 Reactor Coolant Systems

ID Aging Effect/ 

Mechanism

SRP-LR 

Ref

Type Further 

Evaluation

Aging Management 

Program (AMP)

Material Environment Related 

Item

Structure and/or 

Component

Related

R-131 Lower internal 

assembly 

Lower core plate 

Radial keys and 

clevis inserts

B2.5-b

R-134 Lower internal 

assembly 

Fuel alignment pins 

Lower support plate 

column bolts 

Clevis insert bolts

B2.5-f

R-151 CEA shroud 

assemblies 

CEA shrouds bolts

B3.2-c

R-160 Core shroud 

assembly 

Core shroud tie rods 

(core support plate 

attached by welds in 

later plants)

B3.4-b

R-163 Core shroud 

assembly 

Core shroud 

assembly bolts (later 

plants are welded)

B3.4-f
NUREG-1833

B-42 October 2005

Table B.1 Reactor Coolant Systems

ID Aging Effect/ 

Mechanism

SRP-LR 

Ref

Type Further 

Evaluation

Aging Management 

Program (AMP)

Material Environment Related 

Item

Structure and/or 

Component

Related

R-168 Lower internal 

assembly 

Core support plate 

Fuel alignment pins 

Lower support 

structure beam 

assemblies 

Core support column 

bolts 

 Core support barrel 

snubber assemblies

B3.5-c

R-187 Core support shield 

assembly 

Core support shield 

cylinder (top and 

bottom flange) 

Core support shieldto-core barrel bolts 

VV retaining ring 

VV assembly locking 

device

B4.4-c

R-195 Core barrel 

assembly 

Core barrel cylinder 

(top and bottom 

flange) 

Lower internals 

assembly-to- core 

barrel bolts 

Core barrel-tothermal shield bolts 

Baffle plates and 

formers

B4.5-c
October 2005

B-43 NUREG-1833

Table B.1 Reactor Coolant Systems

ID Aging Effect/ 

Mechanism

SRP-LR 

Ref

Type Further 

Evaluation

Aging Management 

Program (AMP)

Material Environment Related 

Item

Structure and/or 

Component

Related

R-204 Lower grid assembly 

Lower grid rib 

section 

Fuel assembly 

support pads 

Lower grid rib-toshell forging screws 

Lower grid flow dist. 

plate 

Orifice plugs 

Lower grid and shell 

forgings 

Lower internals 

assembly-to- thermal 

shield bolts 

Guide blocks and 

bolts 

Shock pads and 

bolts 

Support post pipes 

Incore guide tube 

spider castings

B4.6-c

R-211 Flow distributor 

assembly 

Flow distributor head 

and flange 

Shell forging-to-flow 

distributor bolts 

Incore guide support 

plate 

Clamping ring

B4.7-c
NUREG-1833

B-44 October 2005

Table B.1 Reactor Coolant Systems

ID Aging Effect/ 

Mechanism

SRP-LR 

Ref

Type Further 

Evaluation

Aging Management 

Program (AMP)

Material Environment Related 

Item

Structure and/or 

Component

Related

34 Cracking/ 

stress 

corrosion 

cracking, 

primary water 

stress 

corrosion 

cracking

3.1.2.2.16.

1

PWR No, but 

licensee 

commitment 

needs to be 

confirmed

Chapter XI.M2, “Water 

Chemistry,” and 

Chapter XI.M1, “ASME 

Section XI Inservice 

Inspection, Subsections 

IWB, IWC, and IWD" and, 

 for nickel alloy, comply 

with applicable NRC 

Orders and provide a 

commitment in the FSAR 

supplement to implement 

applicable (1) Bulletins 

and Generic Letters and 

(2) staff-accepted industry 

guidelines.

Stainless 

steel; nickel 

alloy

Reactor 

coolant

R-76 Control rod drive 

head penetration 

Pressure housing

A2.2-b

35 Cracking/ 

stress 

corrosion 

cracking, 

primary water 

stress 

corrosion 

cracking

3.1.2.2.16.

1

PWR No, but 

licensee 

commitment 

needs to be 

confirmed

Chapter XI.M1, “ASME 

Section XI Inservice 

Inspection, Subsections 

IWB, IWC, and IWD,” for 

Class 1 components, and 

Chapter XI.M2, “Water 

Chemistry,” for PWR 

primary water and for 

nickel alloy, comply with 

applicable NRC Orders 

and provide a commitment 

in the FSAR supplement 

to implement applicable 

(1) Bulletins and Generic 

Letters and (2) staffaccepted industry 

guidelines.

Steel with 

stainless steel 

or nickel alloy

cladding

Reactor 

coolant

R-35 Primary side 

components 

Upper and lower 

heads 

Tube sheets and 

tube-to-tube sheet 

welds

D2.1-a 
October 2005

B-45 NUREG-1833

Table B.1 Reactor Coolant Systems

ID Aging Effect/ 

Mechanism

SRP-LR 

Ref

Type Further 

Evaluation

Aging Management 

Program (AMP)

Material Environment Related 

Item

Structure and/or 

Component

Related

36 Cracking/ 

stress 

corrosion 

cracking, 

primary water 

stress 

corrosion 

cracking

3.1.2.2.16.

2

PWR No, unless 

licensee 

commitment 

needs to be 

confirmed

Chapter XI.M2, “Water 

Chemistry,” and Chapter 

XI.M32 "One-Time 

Inspection" and for nickel 

alloy welded spray heads, 

comply with applicable 

NRC Orders and provide 

a commitment in the 

FSAR supplement to 

implement applicable (1) 

Bulletins and Generic 

Letters and (2) staffaccepted industry 

guidelines.

Nickel alloy; 

stainless steel

Reactor 

coolant

R-24 Pressurizer 

Spray head

C2.5-j 
NUREG-1833

B-46 October 2005

Table B.1 Reactor Coolant Systems

ID Aging Effect/ 

Mechanism

SRP-LR 

Ref

Type Further 

Evaluation

Aging Management 

Program (AMP)

Material Environment Related 

Item

Structure and/or 

Component

Related

37 Cracking/ 

stress 

corrosion 

cracking, 

primary water 

stress 

corrosion 

cracking, 

irradiationassisted 

stress 

corrosion 

cracking

3.1.2.2.17 PWR No, but 

licensee 

commitment 

needs to be 

confirmed

Chapter XI.M2, "Water 

Chemistry" for PWR 

primary water 

No further aging 

management review is 

necessary if the applicant 

provides a commitment in 

the FSAR supplement to 

(1) participate in the 

industry programs for 

investigating and 

managing aging effects on 

reactor internals; (2) 

evaluate and implement 

the results of the industry 

programs as applicable to 

the reactor internals; and 

(3) upon completion of 

these programs, but not 

less than 24 months 

before entering the period 

of extended operation, 

submit an inspection plan 

for reactor internals to the 

NRC for review and 

approval.

Stainless 

steel; nickel 

alloy

Reactor 

coolant

R-112 Upper internals 

assembly 

Upper s upport 

column bolts Upper 

core plate alignment 

pins 

Fuel alignment pins

B2.1-i

R-118 RCCA guide tube 

assemblies 

RCCA guide tube 

bolts 

RCCA guide tube 

support pins

B2.2-d
October 2005

B-47 NUREG-1833

Table B.1 Reactor Coolant Systems

ID Aging Effect/ 

Mechanism

SRP-LR 

Ref

Type Further 

Evaluation

Aging Management 

Program (AMP)

Material Environment Related 

Item

Structure and/or 

Component

Related

R-130 Lower internal 

assembly 

Lower core plate 

Radial keys and 

clevis inserts

B2.5-a

R-133 Lower internal 

assembly 

Fuel alignment pins 

Lower support plate 

column bolts 

Clevis insert bolts

B2.5-e

R-162 Core shroud 

assembly 

Core shroud 

assembly bolts (later 

plants are welded)

B3.4-e

R-167 Lower internal 

Assembly 

Fuel alignment pins 

Core support column 

bolts

B3.5-b

R-186 Core support shield 

assembly 

Core support shieldto-core barrel bolts 

VV assembly locking 

device

B4.4-b
NUREG-1833

B-48 October 2005

Table B.1 Reactor Coolant Systems

ID Aging Effect/ 

Mechanism

SRP-LR 

Ref

Type Further 

Evaluation

Aging Management 

Program (AMP)

Material Environment Related 

Item

Structure and/or 

Component

Related

R-194 Core barrel 

assembly 

Lower internals 

assembly-to-core 

barrel bolts 

Core barrel-tothermal shield bolts

B4.5-b

R-203 Lower grid assembly 

Lower grid rib-toshell forging screws 

Lower internals 

assembly-to- thermal 

shield bolts 

Guide blocks bolts 

Shock pads bolts

B4.6-b

R-210 Flow distributor 

assembly 

Shell forging-to-flow 

distributor bolts

B4.7-b
October 2005

B-49 NUREG-1833

Table B.1 Reactor Coolant Systems

ID Aging Effect/ 

Mechanism

SRP-LR 

Ref

Type Further 

Evaluation

Aging Management 

Program (AMP)

Material Environment Related 

Item

Structure and/or 

Component

Related

Chapter XI.M2, "Water 

Chemistry" for PWR 

primary water. No further 

aging management review 

is necessary if the 

applicant provides a 

commitment in the FSAR 

supplement to (1) 

participate in the industry 

programs for investigating 

and managing aging 

effects on reactor 

internals; (2) evaluate and 

implement the results of 

the industry programs as 

applicable to the reactor 

internals; and (3) upon 

completion of these

programs, but not less 

than 24 months before 

entering the period of 

extended operation, 

submit an inspection plan 

for reactor internals to the 

NRC for review and 

approval.

Stainless 

steel; nickel 

alloy

Reactor 

coolant

R-150 CEA shroud 

assemblies 

CEA shrouds bolts

B3.2-b

38 Cracking/ 

cyclic loading

NA BWR No Chapter XI.M6, “BWR 

Control Rod Drive Return 

Line Nozzle”

Steel (with or 

without 

stainless steel 

cladding)

Reactor 

coolant

R-66 Nozzles 

Control rod drive 

return line

A1.3-c

39 Cracking/ 

cyclic loading

NA BWR No Chapter XI.M5, “BWR 

Feedwater Nozzle”

Steel (with or 

without 

stainless steel 

cladding)

Reactor 

coolant

R-65 Nozzles 

Feedwater

A1.3-b
NUREG-1833

B-50 October 2005

Table B.1 Reactor Coolant Systems

ID Aging Effect/ 

Mechanism

SRP-LR 

Ref

Type Further 

Evaluation

Aging Management 

Program (AMP)

Material Environment Related 

Item

Structure and/or 

Component

Related

40 Cracking/ 

stress 

corrosion 

cracking, 

intergranular 

stress 

corrosion 

cracking, 

cyclic loading

NA BWR No Chapter XI.M8, “BWR 

Penetrations,” and 

Chapter XI.M2, “Water 

Chemistry,” for BWR 

water

Stainless 

steel; nickel 

alloy

Reactor 

coolant

R-69 Penetrations 

Control rod drive 

stub tubes 

Instrumentation 

Jet pump instrument 

Standby liquid 

control 

Flux monitor 

Drain line

A1.5-a

41 Cracking/ 

stress 

corrosion 

cracking and 

intergranular 

stress 

corrosion 

cracking

NA BWR No Chapter XI.M7, “BWR 

Stress Corrosion 

Cracking,” and 

Chapter XI.M2, “Water 

Chemistry,” for BWR 

water

Nickel alloy Reactor 

coolant

R-21 Piping, piping 

components, and 

piping elements 

greater than or equal 

to 4 NPS

C1.1-f

Stainless 

steel

Reactor 

coolant

R-20 Piping, piping 

components, and 

piping elements 

greater than or equal 

to 4 NPS

C1.1-f 

C1.2-b 

C1.3-c 

Stainless 

steel; nickel 

alloy

Reactor 

coolant

R-68 Nozzle safe ends 

(and associated 

welds) 

High pressure core 

spray 

Low pressure core 

spray 

Control rod drive 

return line 

Recirculating water 

Low pressure 

coolant injection or 

RHR injection mode

A1.4-a
October 2005

B-51 NUREG-1833

Table B.1 Reactor Coolant Systems

ID Aging Effect/ 

Mechanism

SRP-LR 

Ref

Type Further 

Evaluation

Aging Management 

Program (AMP)

Material Environment Related 

Item

Structure and/or 

Component

Related

42 Cracking/ 

stress 

corrosion 

cracking and 

intergranular 

stress 

corrosion 

cracking

NA BWR No Chapter XI.M4, “BWR 

Vessel ID Attachment 

Welds,” and 

Chapter XI.M2, “Water 

Chemistry,” for BWR 

water

Stainless 

steel; nickel 

alloy

Reactor 

coolant

R-64 Vessel shell 

Attachment welds

A1.2-e 

43 Cracking/ 

stress 

corrosion 

cracking and 

intergranular 

stress 

corrosion 

cracking

NA BWR No Chapter XI.M9, “BWR 

Vessel Internals,” for 

lower plenum and 

Chapter XI.M2, “Water 

Chemistry,” for BWR 

water

Stainless 

steel

Reactor 

coolant

R-104 Fuel supports and 

control rod drive 

assemblies 

Control rod drive 

housing

B1.5-c

44 Cracking/ 

stress 

corrosion 

cracking, 

intergranular 

stress 

corrosion 

cracking, 

irradiationassisted 

stress 

corrosion 

cracking

NA BWR No Chapter XI.M9, “BWR 

Vessel Internals,” for core 

plate and 

Chapter XI.M2, “Water 

Chemistry” for BWR water

Stainless 

steel

Reactor 

coolant

R-93 Core shroud and 

core plate 

Core plate 

Core plate bolts 

(used in early 

BWRs)

B1.1-b

Chapter XI.M9, “BWR 

Vessel Internals,” for core

shroud and 

Chapter XI.M2, “Water 

Chemistry” for BWR water

Stainless 

steel

Reactor 

coolant

R-92 Core shroud 

(including repairs) 

and core plate 

Core shroud (upper, 

central, lower)

B1.1-a
NUREG-1833

B-52 October 2005

Table B.1 Reactor Coolant Systems

ID Aging Effect/ 

Mechanism

SRP-LR 

Ref

Type Further 

Evaluation

Aging Management 

Program (AMP)

Material Environment Related 

Item

Structure and/or 

Component

Related

Chapter XI.M9, “BWR 

Vessel Internals,” for core 

spray internals and 

Chapter XI.M2, “Water 

Chemistry,” for BWR 

water

Stainless 

steel

Reactor 

coolant

R-99 Core spray lines and 

spargers 

Core spray lines 

(headers) 

Spray rings 

Spray nozzles 

Thermal sleeves

B1.3-a

Chapter XI.M9, “BWR 

Vessel Internals,” for jet 

pump assembly and 

Chapter XI.M2, “Water 

Chemistry,” for BWR 

water

Nickel alloy; 

stainless steel

Reactor 

coolant

R-100 Jet pump 

assemblies 

Thermal sleeve 

Inlet header 

Riser brace arm 

Holddown beams 

Inlet elbow 

Mixing assembly 

Diffuser 

Castings

B1.4-a

Chapter XI.M9, “BWR 

Vessel Internals,” for 

lower plenum and 

Chapter XI.M2, “Water 

Chemistry,” for BWR 

water

Stainless 

steel

Reactor 

coolant

R-105 Instrumentation 

Intermediate range 

monitor (IRM) dry 

tubes 

Source range 

monitor (SRM) dry 

tubes 

Incore neutron flux 

monitor guide tubes

B1.6-a
October 2005

B-53 NUREG-1833

Table B.1 Reactor Coolant Systems

ID Aging Effect/ 

Mechanism

SRP-LR 

Ref

Type Further 

Evaluation

Aging Management 

Program (AMP)

Material Environment Related 

Item

Structure and/or 

Component

Related

Chapter XI.M9, “BWR 

Vessel Internals,” for 

shroud support and 

Chapter XI.M2, “Water 

Chemistry,” for BWR 

water

Nickel alloy Reactor 

coolant

R-96 Core shroud 

(including repairs) 

and core plate 

Shroud support 

structure (shroud 

support cylinder, 

shroud support 

plate, shroud 

support legs)

B1.1-f

Chapter XI.M9, “BWR 

Vessel Internals,” for the 

LPCI coupling and 

Chapter XI.M2, “Water 

Chemistry,” for BWR 

water

Stainless 

steel

Reactor

coolant

R-97 Core shroud and 

core plate 

 LPCI coupling

B1.1-g

Chapter XI.M9, “BWR 

Vessel Internals,” for top 

guide and Chapter XI.M2, 

“Water Chemistry,” for 

BWR water. Additionally, 

for top guides with 

neutron fluence 

exceeding the IASCC 

threshold (5E20, 

E>lMeV) prior to the 

period of extended 

operation, inspect five 

percent (5%) of the top 

guide locations using 

enhanced visual 

inspection technique, 

EVT-1 within six years 

after entering the period 

of extended operation. 

Stainless 

steel

Reactor 

coolant

R-98 Top guide B1.2-a
NUREG-1833

B-54 October 2005

Table B.1 Reactor Coolant Systems

ID Aging Effect/ 

Mechanism

SRP-LR 

Ref

Type Further 

Evaluation

Aging Management 

Program (AMP)

Material Environment Related 

Item

Structure and/or 

Component

Related

An additional 5% of the 

top guide locations will 

be inspected within 

twelve years after 

entering the period of 

extended operation. 

Alternatively, if the 

neutron fluence for the 

limiting top guide 

location is projected to 

exceed the threshold 

for IASCC after 

entering the period of 

extended operation, 

inspect 5% of the top 

guide locations (EVT-1) 

within six years after 

the date projected for 

exceeding the 

threshold. An additional 

5% of the top guide 

locations will be 

inspected within twelve 

years after the date 

projected for exceeding 

the threshold.

The top guide 

inspection locations are 

those that have high 

neutron fluences 

exceeding the IASCC 

threshold. 
October 2005

B-55 NUREG-1833

Table B.1 Reactor Coolant Systems

ID Aging Effect/ 

Mechanism

SRP-LR 

Ref

Type Further 

Evaluation

Aging Management 

Program (AMP)

Material Environment Related 

Item

Structure and/or 

Component

Related

The extent and 

frequency of 

examination of the top 

guide is similar to the 

examination of the 

control rod drive 

housing guide tube in 

BWRVIP-47.

45 Wall thinning/ 

flowaccelerated 

corrosion

NA BWR No Chapter XI.M17, “FlowAccelerated Corrosion”Steel Reactor 

coolant

R-23 Piping, piping 

components, and 

piping elements

C1.1-a 

C1.1-c 

C1.3-a 

46 Cracking/ 

stress 

corrosion 

cracking, 

intergranular 

stress 

corrosion 

cracking, 

irradiationassisted 

stress 

corrosion 

cracking

NA BWR No Chapter XI.M1, “ASME 

Section XI Inservice 

Inspection, Subsections 

IWB, IWC, and IWD,” for 

Class 1 components and 

Chapter XI.M2, “Water 

Chemistry,” for BWR 

water

Nickel alloy Reactor 

coolant

R-95 Core shroud and 

core plate 

Access hole cover 

(mechanical covers)

B1.1-e

47 Loss of 

material/ 

pitting and 

crevice 

corrosion

NA BWR No Chapter XI.M1, “ASME 

Section XI Inservice 

Inspection, Subsections 

IWB, IWC, and IWD,” for 

Class 1 components and 

Chapter XI.M2, “Water 

Chemistry” for BWR water

Stainless 

steel; nickel 

alloy

Reactor 

coolant

RP-26 Reactor vessel 

internals 

components

B1.
NUREG-1833

B-56 October 2005

Table B.1 Reactor Coolant Systems

ID Aging Effect/ 

Mechanism

SRP-LR 

Ref

Type Further 

Evaluation

Aging Management 

Program (AMP)

Material Environment Related 

Item

Structure and/or 

Component

Related

48 Cracking/ 

stress 

corrosion 

cracking, 

intergranular 

stress 

corrosion 

cracking (for 

stainless steel 

only), and 

thermal and 

mechanical 

loading

NA BWR No Chapter XI.M1, “ASME 

Section XI Inservice 

Inspection, Subsections 

IWB, IWC, and IWD,” for 

Class 1 components, and 

Chapter XI.M2, “Water 

Chemistry,” for BWR 

water and 

XI.M35, "One-Time 

Inspection of ASME Code 

Class 1 Small-bore 

Piping"

Stainless 

steel; steel

Reactor 

coolant

R-03 Class 1 piping, 

fittings and branch 

connections < NPS 

4

C1.1-i 

49 Cracking/ 

stress 

corrosion 

cracking, 

intergranular 

stress 

corrosion 

cracking, 

irradiationassisted 

stress 

corrosion 

cracking

NA BWR No Chapter XI.M1, “ASME 

Section XI Inservice 

Inspection, Subsections 

IWB, IWC, and IWD,” for 

Class 1 components and 

Chapter XI.M2, “Water 

Chemistry,” for BWR 

water 

Because cracking initiated 

in crevice regions is not 

amenable to visual 

inspection, for BWRs with 

a crevice in the access 

hole covers, an 

augmented inspection is 

to include ultrasonic 

testing (UT) or other 

demonstrated acceptable 

inspection of the access 

hole cover welds.

Nickel alloy Reactor 

coolant

R-94 Core shroud and 

core plate 

Access hole cover 

(welded covers)

B1.1-d
October 2005

B-57 NUREG-1833

Table B.1 Reactor Coolant Systems

ID Aging Effect/ 

Mechanism

SRP-LR 

Ref

Type Further 

Evaluation

Aging Management 

Program (AMP)

Material Environment Related 

Item

Structure and/or 

Component

Related

50 Cracking/ 

stress 

corrosion 

cracking and 

intergranular 

stress 

corrosion 

cracking

NA BWR No Chapter XI.M3, “Reactor 

Head Closure Studs”

High-strength 

low alloy steel 

Maximum 

tensile 

strength < 

1172 MPa 

(<170 ksi)

Air with 

reactor 

coolant 

leakage

R-60 Top head enclosure 

Closure studs and 

nuts

A1.1-c

51 Loss of 

fracture 

toughness/ 

thermal aging 

and neutron 

irradiation 

embrittlement

NA BWR No Chapter XI.M13, “Thermal 

Aging and Neutron 

Irradiation Embrittlement 

of Cast Austenitic 

Stainless Steel (CASS)”

Cast 

austenitic 

stainless steel

Reactor 

coolant 

>250°C 

(>482°F) and 

neutron flux

R-101 Jet pump 

assemblies 

Castings

B1.4-c

R-103 Fuel supports and 

control rod drive 

assemblies 

Orificed fuel support

B1.5-a

52 Cracking/ 

stress 

corrosion 

cracking

NA BWR/ 

PWR

No Chapter XI.M18, “Bolting 

Integrity”

High-strength 

low-alloy 

steel, 

stainless steel

Air with 

reactor 

coolant 

leakage

R-11 Closure bolting C2.3-e 

C2.4-e 

C2.5-n 

Stainless 

steel

Air with 

reactor 

coolant 

leakage

R-78 Control rod drive 

head penetration 

Flange bolting

A2.2-e

Steel Air with 

reactor 

coolant 

leakage

R-10 Closure bolting D1.1-l 

Loss of 

material/ wear

NA BWR/ 

PWR

No Chapter XI.M18, “Bolting 

Integrity”

Stainless 

steel

Air with 

reactor 

coolant 

leakage

R-79 Control rod drive 

head penetration 

Flange bolting

A2.2-f
NUREG-1833

B-58 October 2005

Table B.1 Reactor Coolant Systems

ID Aging Effect/ 

Mechanism

SRP-LR 

Ref

Type Further 

Evaluation

Aging Management 

Program (AMP)

Material Environment Related 

Item

Structure and/or 

Component

Related

Stainless 

steel; steel

System 

temperature 

up to 288°C 

(550°F)

R-29 Pump and valve seal 

flange closure 

bolting

C1.2-d 

C1.3-e 

Steel System 

temperature 

up to 288°C 

(550°F)

R-26 Pump and valve 

closure bolting

C1.2-d 

C1.3-e 

Loss of 

preload/ 

thermal 

effects, 

gasket creep, 

and selfloosening 

NA BWR/ 

PWR

No Chapter XI.M18, “Bolting 

Integrity”

Stainless 

steel

Air with 

reactor 

coolant 

leakage

R-80 Control rod drive 

head penetration 

Flange bolting

A2.2-g

Loss of 

preload/ 

thermal 

effects, 

gasket creep, 

and selfloosening

NA BWR/ 

PWR

No Chapter XI.M18, “Bolting 

Integrity”

Low-alloy 

steel SA 193 

Gr. B7

System 

temperature 

up to 288°C 

(550°F)

R-27 Pump and valve 

closure bolting

C1.2-e 

C1.3-f 

Low-alloy 

steel, 

stainless steel

Air with 

reactor 

coolant 

leakage

R-12 Closure bolting C2.3-g 

C2.4-g 

C2.5-p 

Steel System 

temperature 

up to 340°C 

(644°F)

R-32 Steam generator 

closure bolting

D1.1-f 

D2.1-k 

53 Loss of 

material/ 

general, 

pitting, and 

crevice 

corrosion

NA BWR/ 

PWR

No Chapter XI.M21, “ClosedCycle Cooling Water 

System”

Steel Closed cycle 

cooling water

RP-10 Piping, piping 

components, and 

piping elements

C2.
October 2005

B-59 NUREG-1833

Table B.1 Reactor Coolant Systems

ID Aging Effect/ 

Mechanism

SRP-LR 

Ref

Type Further 

Evaluation

Aging Management 

Program (AMP)

Material Environment Related 

Item

Structure and/or 

Component

Related

54 Loss of 

material/ 

pitting, 

crevice, and 

galvanic 

corrosion

NA BWR/ 

PWR

No Chapter XI.M21, “ClosedCycle Cooling Water 

System”

Copper alloy Closed cycle 

cooling water

RP-11 Piping, piping 

components , and 

piping elements

C2.

55 Loss of 

fracture 

toughness/ 

thermal aging 

embrittlement

NA BWR/ 

PWR

No Chapter XI.M1, “ASME 

Section XI Inservice 

Inspection, Subsections 

IWB, IWC, and IWD,” for 

Class 1 components 

For pump casings and 

valve bodies, screening 

for susceptibility to 

thermal aging is not 

necessary. The ASME 

Section XI inspection 

requirements are sufficient 

for managing the effects 

of loss of fracture 

toughness due to thermal 

aging embrittlement of 

CASS pump casings and 

valve bodies. 

Alternatively, the 

requirements of ASME 

Code Case N-481 for 

pump casings are 

sufficient for managing the 

effects of loss of fracture 

toughness due to thermal 

aging embrittlement of 

CASS pump casings.

Cast 

austenitic 

stainless steel

Reactor 

coolant 

>250°C 

(>482°F)

R-08 Class 1 pump 

casings, and valve 

bodies and bonnets

C1.2-c 

C1.3-b 

C2.3-c 

C2.4-c 

56 Loss of 

material/ 

selective 

leaching

NA BWR/ 

PWR

No Chapter XI.M33, 

“Selective Leaching of 

Materials”

Copper alloy 

>15% Zn

Closed cycle 

cooling water

RP-12 Piping, piping 

components, and 

piping elements

C2.
NUREG-1833

B-60 October 2005

Table B.1 Reactor Coolant Systems

ID Aging Effect/ 

Mechanism

SRP-LR 

Ref

Type Further 

Evaluation

Aging Management 

Program (AMP)

Material Environment Related 

Item

Structure and/or 

Component

Related

57 Loss of 

fracture 

toughness/ 

thermal aging 

embrittlement

NA BWR/ 

PWR

No Chapter XI.M12, “Thermal 

Aging Embrittlement of 

Cast Austenitic Stainless 

Steel (CASS)”

Cast 

austenitic 

stainless steel

Reactor 

coolant 

>250°C 

(>482°F)

R-52 Class 1 piping, 

piping components, 

and piping elements

C1.1-g 

C2.1-f 

C2.2-e 

C2.5-l 

R Control rod drive 

head penetration 

Pressure housing

A2.2-d

58 Loss of 

material/ boric 

acid corrosion

NA PWR No Chapter XI.M10, “Boric 

Acid Corrosion”

Steel Air with 

borated water 

leakage

R-17 External surfaces A2.1-a 

A2.5-e 

A2.8-b 

C2.1-d 

C2.2-d 

C2.3-f 

C2.4-f 

C2.5-b 

C2.5-o 

C2.5-u 

C2.6-b 

D1.1-g 

D1.1-k 

D2.1-b 

D2.1-j 

59 Wall thinning/ 

flowaccelerated 

corrosion

NA PWR No Chapter XI.M17, “FlowAccelerated Corrosion”Steel Secondary 

feedwater/ 

steam

R-37 Pressure boundary 

and structural 

Steam nozzle and 

safe end 

FW nozzle and safe 

end

D1.1-d 
October 2005

B-61 NUREG-1833

Table B.1 Reactor Coolant Systems

ID Aging Effect/ 

Mechanism

SRP-LR 

Ref

Type Further 

Evaluation

Aging Management 

Program (AMP)

Material Environment Related 

Item

Structure and/or 

Component

Related

R-38 Steam generator 

components 

FW and AFW 

nozzles and safe 

ends 

Steam nozzles and 

safe ends

D2.1-f 

60 Loss of 

material/ wear

NA PWR No Chapter XI.M37, “Flux 

Thimble Tube Inspection"

Stainless 

steel with or 

without 

chrome 

plating

Reactor 

coolant

R-145 Instrumentation 

support structures 

Flux thimble tubes

B2.6-c

61 Cracking/ 

cyclic loading

NA PWR No Chapter XI.M1, “ASME 

Section XI Inservice 

Inspection, Subsections 

IWB, IWC, and IWD,” for 

Class 1 components

Stainless 

steel; steel

Air with metal 

temperature 

up to 288°C 

(550°F)

R-19 Pressurizer 

Integral support

C2.5-v 

62 Cracking/ 

cyclic loading

NA PWR No Chapter XI.M1, “ASME 

Section XI Inservice 

Inspection, Subsections 

IWB, IWC, and IWD,” for 

Class 1 components

Stainless 

steel; steel 

with stainless 

steel cladding

Reactor 

coolant

R-56 Reactor coolant 

system piping and 

fittings 

Cold leg 

Hot leg 

Surge line 

Spray line

C2.1-c 

63 Loss of 

material/ wear

NA PWR No Chapter XI.M1, “ASME 

Section XI Inservice 

Inspection, Subsections 

IWB, IWC, and IWD,” for 

Class 1 components

Stainless 

steel

Reactor 

coolant

R-142 Lower internal 

assembly 

Radial keys and 

clevis Inserts

B2.5-o
NUREG-1833

B-62 October 2005

Table B.1 Reactor Coolant Systems

ID Aging Effect/ 

Mechanism

SRP-LR 

Ref

Type Further 

Evaluation

Aging Management 

Program (AMP)

Material Environment Related 

Item

Structure and/or 

Component

Related

R-148 Upper internals 

assembly 

Fuel alignment plate 

Fuel alignment plate 

guide lugs and their 

lugs 

Hold-down ring

B3.1-c

R-152 CEA shroud 

assemblies 

CEA shroud 

extension shaft 

guides

B3.2-d

R-156 Core support barrel 

Core support barrel 

upper flange 

Core support barrel 

alignment keys

B3.3-b

R-179 Upper grid assembly 

Fuel assembly 

support pads 

Plenum rib pads

B4.2-f

R-190 Core support shield 

assembly 

Core support shield 

cylinder 

(top flange) 

VV assembly locking 

device

B4.4-f
October 2005

B-63 NUREG-1833

Table B.1 Reactor Coolant Systems

ID Aging Effect/ 

Mechanism

SRP-LR 

Ref

Type Further 

Evaluation

Aging Management 

Program (AMP)

Material Environment Related 

Item

Structure and/or 

Component

Related

R-208 Lower grid assembly 

Fuel assembly 

support pads Guide 

blocks

B4.6-h

Stainless 

steel; nickel 

alloy

Reactor 

coolant

R-115 Upper internals 

assembly 

Upper core plate 

alignment pins

B2.1-l

R-170 Lower internal 

assembly 

Fuel alignment pins 

Core support barrel 

snubber assemblies

B3.5-e

Steel Reactor 

coolant

R-87 Vessel shell 

Vessel flange

A2.5-f

64 Cracking/ 

stress 

corrosion 

cracking, 

primary water 

stress

corrosion 

cracking

NA PWR No Chapter XI.M1, “ASME 

Section XI Inservice 

Inspection, Subsections 

IWB, IWC, and IWD” for 

Class 1 components, and 

Chapter XI.M2, “Water 

Chemistry,” for PWR 

primary water 

Steel with 

stainless steel 

or nickel alloy 

cladding; or 

stainless steel

Reactor 

coolant

R-25 Pressurizer 

components

C2.5-c 

C2.5-g 
NUREG-1833

B-64 October 2005

Table B.1 Reactor Coolant Systems

ID Aging Effect/ 

Mechanism

SRP-LR 

Ref

Type Further 

Evaluation

Aging Management 

Program (AMP)

Material Environment Related 

Item

Structure and/or 

Component

Related

65 Cracking/ 

primary water 

stress 

corrosion 

cracking

NA PWR No Chapter XI.M1, “ASME 

Section XI Inservice 

Inspection, Subsections 

IWB, IWC, and IWD,” for 

Class 1 components and 

Chapter XI.M2, “Water 

Chemistry,” for PWR 

primary water and 

Chapter XI.M11-A, 

"Nickel-Alloy Penetration 

Nozzles Welded to the 

Upper Reactor Vessel 

Closure Heads of 

Pressurized Water 

Reactors (PWRs Only)"

Nickel alloy Reactor 

coolant

R-75 Control rod drive 

head penetration 

Nozzle and welds

A2.2-a

R-90 Penetrations 

Head vent pipe (top 

head) 

Instrument tubes 

(top head)

A2.7-b

66 Loss of 

material/ 

erosion

NA PWR No Chapter XI.M1, “ASME 

Section XI Inservice 

Inspection, Subsections 

IWB, IWC, and IWD,” for 

Class 2 components

Steel Air with 

leaking 

secondaryside water 

and/or steam

R-31 Secondary manways 

and handholes 

(cover only)

D2.1-l 
October 2005

B-65 NUREG-1833

Table B.1 Reactor Coolant Systems

ID Aging Effect/ 

Mechanism

SRP-LR 

Ref

Type Further 

Evaluation

Aging Management 

Program (AMP)

Material Environment Related 

Item

Structure and/or 

Component

Related

67 Cracking/ 

cyclic loading

NA PWR No Chapter XI.M1, “ASME 

Section XI Inservice 

Inspection, Subsections 

IWB, IWC, and IWD,” for 

Class 1 components and 

Chapter XI.M2, “Water 

Chemistry,” for PWR 

primary water 

Cracks in the pressurizer 

cladding could propagate 

from cyclic loading into the 

ferrite base metal and 

weld metal. However, 

because the weld metal 

between the surge nozzle 

and the vessel lower head 

is subjected to the 

maximum stress cycles 

and the area is 

periodically inspected as 

part of the ISI program, 

the existing AMP is 

adequate for managing 

the effect of pressurizer 

clad cracking.

Steel with 

stainless steel 

or nickel alloy 

cladding; or 

stainless steel

Reactor 

coolant

R-58 Pressurizer 

components

C2.5-c 

C2.5-g 

68 Cracking/ 

stress 

corrosion 

cracking

NA PWR No Chapter XI.M1, “ASME 

Section XI Inservice 

Inspection, Subsections 

IWB, IWC, and IWD,” for 

Class 1 components and 

Chapter XI.M2, “Water 

Chemistry,” for PWR 

primary water

Stainless 

steel

Reactor 

coolant

R-217 Pressurizer heater 

sheaths and 

sleeves, and heater 

bundle diaphragm 

plate

C2.5-r 
NUREG-1833

B-66 October 2005

Table B.1 Reactor Coolant Systems

ID Aging Effect/ 

Mechanism

SRP-LR 

Ref

Type Further 

Evaluation

Aging Management 

Program (AMP)

Material Environment Related 

Item

Structure and/or 

Component

Related

Stainless 

steel; steel 

with stainless 

steel cladding

Reactor 

coolant

R-07 Class 1 piping, 

fittings, primary 

nozzles, safe ends, 

manways, and 

flanges

C2.2-f 

C2.5-h 

D1.1-i 

C2.5-m 

R-09 Class 1 pump 

casings and valve 

bodies

C2.3-b 

C2.4-b 

R-30 Reactor coolant 

system piping and 

fittings 

Cold leg 

Hot leg 

Surge line 

Spray line

C2.1-c 

Treated 

borated water 

>60°C 

(>140°F)

R-14 Pressurizer relief 

tank 

Tank shell and 

heads 

Flanges and nozzles

C2.6-c 

69 Cracking/ 

stress 

corrosion 

cracking, 

primary water 

stress 

corrosion 

cracking

NA PWR No Chapter XI.M1, “ASME 

Section XI Inservice 

Inspection, Subsections 

IWB, IWC, and IWD,” for 

Class 1 components and 

Chapter XI.M2, “Water 

Chemistry,” for PWR 

primary water

Stainless 

steel; nickel 

alloy welds 

and/or 

buttering

Reactor 

coolant

R-83 Nozzle safe ends 

and welds: 

Inlet 

Outlet 

Safety injection

A2.4-b
October 2005

B-67 NUREG-1833

Table B.1 Reactor Coolant Systems

ID Aging Effect/ 

Mechanism

SRP-LR 

Ref

Type Further 

Evaluation

Aging Management 

Program (AMP)

Material Environment Related 

Item

Structure and/or 

Component

Related

70 Cracking/ 

stress 

corrosion 

cracking, 

thermal and 

mechanical 

loading

NA PWR No Chapter XI.M1, “ASME 

Section XI Inservice 

Inspection, Subsections 

IWB, IWC, and IWD,” for 

Class 1 components, and 

Chapter XI.M2, “Water 

Chemistry,” for PWR 

water and 

XI.M35, "One-Time 

Inspection of ASME Code 

Class 1 Small-bore 

Piping"

Stainless 

steel; steel 

with stainless 

steel cladding

Reactor 

coolant

R-02 Class 1 piping, 

fittings and branch 

connections < NPS 

4

C2.1-g 

C2.2-h 

71 Cracking/ 

stress 

corrosion 

cracking

NA PWR No Chapter XI.M3, “Reactor 

Head Closure Studs”

High-strength 

low alloy steel 

Maximum 

tensile 

strength < 

1172 MPa 

(<170 ksi)

Air with 

reactor 

coolant 

leakage

R-71 Closure head 

Stud assembly

A2.1-c

Loss of 

material/ wear

NA PWR No Chapter XI.M3, “Reactor 

Head Closure Studs”

High-strength 

low alloy steel 

Maximum 

tensile 

strength < 

1172 MPa 

(<170 ksi)

Air with 

reactor 

coolant 

leakage

R-72 Closure head 

Stud assembly

A2.1-d

72 Cracking/ 

intergranular 

attack

NA PWR No Chapter XI.M19, “Steam 

Generator Tubing 

Integrity” and 

Chapter XI.M2, “Water 

Chemistry,” for PWR 

secondary water

Nickel alloy Secondary 

feedwater/ 

steam

R-48 Tubes and sleeves D1.2-c 

D2.2-c 
NUREG-1833

B-68 October 2005

Table B.1 Reactor Coolant Systems

ID Aging Effect/ 

Mechanism

SRP-LR 

Ref

Type Further 

Evaluation

Aging Management 

Program (AMP)

Material Environment Related 

Item

Structure and/or 

Component

Related

Cracking/ 

outer 

diameter 

stress 

corrosion 

cracking

NA PWR No Chapter XI.M19, “Steam 

Generator Tubing 

Integrity” and 

Chapter XI.M2, “Water 

Chemistry,” for PWR 

secondary water

Nickel alloy Secondary 

feedwater/ 

steam

R-47 Tubes and sleeves D1.2-b 

D2.2-b 

Loss of 

material/ 

fretting and 

wear

NA PWR No Chapter XI.M19, “Steam 

Generator Tubing 

Integrity” and 

Chapter XI.M2, “Water 

Chemistry,” for PWR 

secondary water

Nickel alloy Secondary 

feedwater/ 

steam

R-49 Tubes and sleeves D1.2-e 

D2.2-d 

73 Cracking/ 

primary water 

stress

corrosion 

cracking

NA PWR No Chapter XI.M19, “Steam 

Generator Tubing 

Integrity” and 

Chapter XI.M2, “Water 

Chemistry,” for PWR 

primary water

Nickel alloy Reactor 

coolant

R-40 Tube plugs D1.2-i 

D1.2-j 

D2.2-f 

D2.2-g 

R-44 Tubes and sleeves D1.2-a

D2.2-a 

74 Cracking/ 

stress 

corrosion 

cracking

NA PWR No Chapter XI.M19, “Steam 

Generator Tubing 

Integrity” and 

Chapter XI.M2, “Water 

Chemistry,” for PWR 

secondary water

Chrome 

plated steel; 

stainless 

steel; Nickel 

alloy

Secondary 

feedwater/ 

steam

RP-14 Steam generator 

structural 

Anti-vibration bars

D1.
October 2005

B-69 NUREG-1833

Table B.1 Reactor Coolant Systems

ID Aging Effect/ 

Mechanism

SRP-LR 

Ref

Type Further 

Evaluation

Aging Management 

Program (AMP)

Material Environment Related 

Item

Structure and/or 

Component

Related

Loss of 

material/ 

crevice 

corrosion and 

fretting

NA PWR No Chapter XI.M19, “Steam 

Generator Tubing 

Integrity” and 

Chapter XI.M2, “Water 

Chemistry,” for PWR 

secondary water

Chrome 

plated steel; 

stainless 

steel; Nickel 

alloy

Secondary 

feedwater/ 

steam

RP-15 Steam generator 

structural 

Anti-vibration bars

D1.

75 Denting/ 

corrosion of 

carbon steel 

tube support 

plate

NA PWR No Chapter XI.M19, “Steam 

Generator Tubing 

Integrity” and 

Chapter XI.M2, “Water 

Chemistry,” for PWR 

secondary water. 

Nickel alloy Secondary 

feedwater/ 

steam

R-226 Tubes D2. 

76 Ligament 

cracking/ 

corrosion

NA PWR No Chapter XI.M19, “Steam 

Generator Tubing 

Integrity” and 

Chapter XI.M2, “Water 

Chemistry,” for PWR 

secondary water

Steel Secondary 

feedwater/ 

steam

R-42 Steam generator 

structural 

Tube support plates

D1.2-k 

D2. 

Loss of 

material/ 

erosion, 

general, 

pitting, and 

crevice 

corrosion

NA PWR No Chapter XI.M19, “Steam 

Generator Tubing 

Integrity” and 

Chapter XI.M2, “Water 

Chemistry,” for PWR 

secondary water

Steel Secondary 

feedwater/ 

steam

RP-16 Steam generator 

Tube bundle 

wrapper

D1.

77 Loss of 

material/ 

wastage and 

pitting 

corrosion

NA PWR No Chapter XI.M19, “Steam 

Generator Tubing 

Integrity” and 

Chapter XI.M2, “Water 

Chemistry,” for PWR 

secondary water

Nickel alloy Secondary 

feedwater/ 

steam

R-50 Tubes and sleeves 

(exposed to 

phosphate 

chemistry)

D1.2-f 
NUREG-1833

B-70 October 2005

Table B.1 Reactor Coolant Systems

ID Aging Effect/ 

Mechanism

SRP-LR 

Ref

Type Further 

Evaluation

Aging Management 

Program (AMP)

Material Environment Related 

Item

Structure and/or 

Component

Related

78 Wall thinning/ 

flowaccelerated 

corrosion

NA PWR No Chapter XI.M19, “Steam 

Generator Tubing 

Integrity” and 

Chapter XI.M2, “Water 

Chemistry,” for PWR 

secondary water

Steel Secondary 

feedwater/ 

steam

R-41 Steam generator 

structural 

Tube support lattice 

bars

D1.2-h 

79 Denting/ 

corrosion of 

carbon steel 

tube support 

plate

NA PWR No Chapter XI.M19, “Steam 

Generator Tubing 

Integrity” and 

Chapter XI.M2, “Water 

Chemistry,” for PWR 

secondary water. 

For plants that could 

experience denting at the 

upper support plates, the 

applicant should evaluate 

potential for rapidly 

propagating cracks and 

then develop and take 

corrective actions 

consistent with Bulletin 

88-02, “Rapidly 

Propagating Cracks in SG 

Tubes."

Nickel alloy Secondary 

feedwater/ 

steam

R-43 Tubes D1.2-g 

80 Loss of 

fracture 

toughness/ 

thermal aging 

and neutron 

irradiation 

embrittlement

NA PWR No Chapter XI.M13, “Thermal 

Aging and Neutron 

Irradiation Embrittlement 

of Cast Austenitic 

Stainless Steel (CASS)”

Cast 

austenitic 

stainless steel

Reactor 

coolant 

>250°C 

(>482°F) and 

neutron flux

R-111 Upper internals 

assembly 

Upper support 

column 

(only cast austenitic 

stainless steel 

portions)

B2.1-g
October 2005

B-71 NUREG-1833

Table B.1 Reactor Coolant Systems

ID Aging Effect/ 

Mechanism

SRP-LR 

Ref

Type Further 

Evaluation

Aging Management 

Program (AMP)

Material Environment Related 

Item

Structure and/or 

Component

Related

R-140 Lower internal 

assembly 

Lower support 

casting 

Lower support plate 

columns

B2.5-m

R-153 CEA shroud 

assemblies

B3.2-e

R-171 Lower internal 

assembly 

Core support column

B3.5-f

R-183 Control rod guide 

tube (CRGT) 

assembly 

CRGT spacer 

casting

B4.3-d

R-191 Core support shield 

assembly 

Outlet and vent 

valve nozzles 

VV body and 

retaining ring

B4.4-g

R-206 Lower grid assembly 

Incore guide tube 

spider castings

B4.6-e

81 Cracking/ 

primary water 

stress 

corrosion 

cracking

NA PWR No Chapter XI.M2, “Water 

Chemistry,” for PWR 

primary water

Nickel alloy; 

steel with 

nickel-alloy 

cladding

Reactor 

coolant

RP-21 Primary side 

Divider Plate

D1.
NUREG-1833

B-72 October 2005

Table B.1 Reactor Coolant Systems

ID Aging Effect/ 

Mechanism

SRP-LR 

Ref

Type Further 

Evaluation

Aging Management 

Program (AMP)

Material Environment Related 

Item

Structure and/or 

Component

Related

82 Cracking/ 

stress 

corrosion 

cracking

NA PWR No Chapter XI.M2, “Water 

Chemistry,” for PWR 

primary water

Stainless 

steel

Reactor 

coolant

RP-17 Primary side 

Divider Plate

D1.

83 Loss of 

material/ 

pitting and 

crevice 

corrosion

NA PWR No Chapter XI.M2, “Water 

Chemistry,” for PWR 

primary water

Stainless 

steel; nickel 

alloy

Reactor 

coolant

RP-24 Reactor vessel 

internals 

components

B2. B3. 

B4.

Stainless 

steel; steel 

with nickelalloy or 

stainless steel 

cladding; 

nickel-alloy

Reactor 

coolant

RP-28 Flanges ; nozzles; 

penetrations; 

pressure housings; 

safe ends; vessel 

shells, heads and 

welds

A2.

Steel with 

stainless steel 

or nickel alloy 

cladding; 

stainless 

steel; nickel 

alloy

Reactor 

coolant

RP-23 Piping, piping 

components, and 

piping elements; 

flanges; heater 

sheaths and 

sleeves; 

penetrations; 

thermal sleeves; 

vessel shell heads 

and welds

C2.

84 Cracking/ 

stress 

corrosion 

cracking

NA PWR No Chapter XI.M2, "Water 

Chemistry" and 

Chapter XI.M32 "OneTime Inspection" or 

Chapter XI.M1, “ASME 

Section XI Inservice 

Inspection, Subsections 

IWB, IWC, and IWD.” 

Nickel alloy Secondary 

feedwater/ 

steam

R-36 Steam generator 

components 

Such as secondary 

side nozzles (vent, 

drain, and 

instrumentation)

D2.1-i 
October 2005

B-73 NUREG-1833

Table B.1 Reactor Coolant Systems

ID Aging Effect/ 

Mechanism

SRP-LR 

Ref

Type Further 

Evaluation

Aging Management 

Program (AMP)

Material Environment Related 

Item

Structure and/or 

Component

Related

85 None NA BWR/ 

PWR

No None Nickel alloy Air – indoor 

uncontrolled 

(External)

RP-03 Piping, piping 

components, and 

piping elements

E.

86 None NA BWR/ 

PWR

No None Stainless 

steel

Air – indoor 

uncontrolled 

(External)

RP-04 Piping, piping 

components, and 

piping elements

E.

Air with 

borated water 

leakage

RP-05 Piping, piping 

components, and 

piping elements

E.

Concrete RP-06 Piping, piping 

components, and 

piping elements

E.

Gas RP-07 Piping, piping 

components, and 

piping elements

E.

87 None NA BWR/ 

PWR

No None Steel Concrete RP-01 Piping, piping 

components, and 

piping elements

E.
NUREG-1833 B-74 October 2005

This Page Intentionally Left Blank
October 2005

B-75 NUREG-1833

B.2 Engineered Safety Features SRP-LR Development Tool

Table B.2 presents the engineered safety features SRP-LR development tool.

Table B.2 Engineered Safety Features

ID Aging Effect/ 

Mechanism

SRP-LR 

Ref

Type Further 

Evaluation

Aging Management 

Program (AMP)

Material Environment Related 

Item

Structure and/or 

Component

Related

1 Cumulative 

fatigue 

damage/ 

fatigue

3.2.2.2.1 BWR/ 

PWR

Yes, 

TLAA

Fatigue is a time-limited 

aging analysis (TLAA) to 

be evaluated for the 

period of extended 

operation. See the 

Standard Review Plan, 

Section 4.3 “Metal 

Fatigue,” for acceptable 

methods for meeting the 

requirements of 10 CFR 

54.21(c)(1).

Stainless 

steel

Treated 

borated water

E-13 Piping, piping 

components, and 

piping elements

D1.1-c 

D1.4-a 

Steel Treated water E-10 Piping, piping 

components, and 

piping elements

D2.1-b 

2 Loss of 

material/claddi

ng breach

3.2.2.2.2 PWR Yes, verify 

that plantspecific 

program 

addresses 

cladding 

breach

A plant-specific aging 

management program is 

to be evaluated. 

Reference NRC 

Information Notice 94-63, 

“Boric Acid Corrosion of 

Charging Pump Casings 

Caused by Cladding 

Cracks."

Steel with 

stainless steel 

cladding

Treated 

borated water

EP-49 Pump Casings D1.
NUREG-1833

B-76 October 2005

Table B.2 Engineered Safety Features

ID Aging Effect/ 

Mechanism

SRP-LR 

Ref

Type Further 

Evaluation

Aging Management 

Program (AMP)

Material Environment Related 

Item

Structure and/or 

Component

Related

3 Loss of 

material/ 

pitting and 

crevice 

corrosion

3.2.2.2.3.1 BWR/ 

PWR

Yes, 

detection of 

aging 

effects is to 

be 

evaluated

Chapter XI.M2, “Water 

Chemistry” 

The AMP is to be 

augmented by verifying 

the effectiveness of water 

chemistry control. See 

Chapter XI.M32, “OneTime Inspection,” for an 

acceptable verification 

program.

Stainless 

steel

Treated water E-33 Containment 

isolation piping and 

components internal 

surfaces

C.1-b 

4 Loss of 

material/ 

pitting and 

crevice 

corrosion

3.2.2.2.3.2 BWR/ 

PWR

Yes, plantspecificA plant-specific aging 

management program is 

to be evaluated.

Stainless 

steel

Soil EP-31 Piping, piping 

components, and 

piping elements

D1. D2.

5 Loss of 

material/ 

pitting and 

crevice 

corrosion

3.2.2.2.3.3 BWR Yes, 

detection of 

aging 

effects is to 

be 

evaluated

Chapter XI.M2, "Water 

Chemistry" for BWR water 

The AMP is to be 

augmented by verifying 

the effectiveness of water 

chemistry control. See 

Chapter XI.M32, “OneTime Inspection,” for an 

acceptable verification 

program.

Aluminum Treated water EP-26 Piping, piping 

components, and 

piping elements

D2.
October 2005

B-77 NUREG-1833

Table B.2 Engineered Safety Features

ID Aging Effect/ 

Mechanism

SRP-LR 

Ref

Type Further 

Evaluation

Aging Management 

Program (AMP)

Material Environment Related 

Item

Structure and/or 

Component

Related

Chapter XI.M2, “Water 

Chemistry” for BWR water 

The AMP is to be 

augmented by verifying 

the effectiveness of water 

chemistry control. See 

Chapter XI.M32, “OneTime Inspection,” for an 

acceptable verification 

program.

Stainless 

steel

Treated water EP-32 Piping, piping 

components, and 

piping elements

D2.

6 Loss of 

material/ 

pitting and 

crevice 

corrosion

3.2.2.2.3.4 BWR/ 

PWR

Yes, 

detection of 

aging 

effects is to 

be 

evaluated

Chapter XI.M39, 

"Lubricating Oil Analys is" 

The AMP is to be 

augmented by verifying 

the effectiveness of the 

lubricating oil analysis 

program . See Chapter 

XI.M32, “One-Time 

Inspection,” for an 

acceptable verification 

program.

Copper alloy Lubricating oil EP-45 Piping, piping 

components, and 

piping elements

A. D1. 

D2. 

Stainless 

steel

Lubricating oil EP-51 Piping, piping 

components, and 

piping elements

D1.

7 Loss of 

material/ 

pitting and 

crevice 

corrosion

3.2.2.2.3.5 BWR/ 

PWR

Yes, plantspecificA plant-specific aging 

management program is 

to be evaluated for pitting 

and crevice corrosion of 

tank bottom because 

moisture and water can 

egress under the tank due 

to cracking of the 

perimeter seal from 

weathering.

Stainless 

steel

Raw water E-01 Partially encased 

tanks with breached 

moisture barrier

D1.8-c 
NUREG-1833

B-78 October 2005

Table B.2 Engineered Safety Features

ID Aging Effect/ 

Mechanism

SRP-LR 

Ref

Type Further 

Evaluation

Aging Management 

Program (AMP)

Material Environment Related 

Item

Structure and/or 

Component

Related

8 Loss of 

material/ 

pitting and 

crevice 

corrosion

3.2.2.2.3.6 BWR/ 

PWR

Yes, plantspecificA plant-specific aging 

management program is 

to be evaluated.

Stainless 

steel

Condensation 

(Internal)

E-14 Piping, piping 

components, and 

piping elem ents 

internal surfaces

D2.1-e 

EP-53 Piping, piping 

components, piping 

elements internal 

surfaces, and tanks 

A. D1. 

9 Reduction of 

heat transfer/ 

fouling

3.2.2.2.4.1 BWR/ 

PWR

Yes, 

detection of 

aging 

effects is to 

be 

evaluated

Chapter XI.M39, 

"Lubricating Oil Analysis" 

The AMP is to be 

augmented by verifying 

the effectiveness of the 

lubricating oil analysis 

program . See Chapter 

XI.M32, “One-Time 

Inspection,” for an 

acceptable verification 

program.

Copper alloy Lubricating oil EP-47 Heat exchanger 

tubes

A. D1. 

D2. 

Stainless 

steel

Lubricating oil EP-50 Heat exchanger 

tubes

A. D1. 

D2. 

Steel Lubricating oil EP-40 Heat exchanger 

tubes

A. D1. 

D2. 

10 Reduction of 

heat transfer/ 

fouling

3.2.2.2.4.2 BWR/ 

PWR

Yes, 

detection of 

aging 

effects is to 

be 

evaluated

Chapter XI.M2, “Water 

Chemistry” 

The AMP is to be 

augmented by verifying 

the effectiveness of water 

chemistry control. See 

Chapter XI.M32, “OneTime Inspection,” for an 

acceptable verification 

program.

Stainless 

steel

Treated water EP-34 Heat exchanger 

tubes

A. D2.
October 2005

B-79 NUREG-1833

Table B.2 Engineered Safety Features

ID Aging Effect/ 

Mechanism

SRP-LR 

Ref

Type Further 

Evaluation

Aging Management 

Program (AMP)

Material Environment Related 

Item

Structure and/or 

Component

Related

11 Hardening 

and loss of 

strength/ 

elastomer 

degradation

3.2.2.2.5 BWR Yes, plantspecificA plant-specific aging 

management program is 

to be evaluated.

Elastomers Air – indoor 

uncontrolled

E-06 Elastomer seals and 

components

B.1-b 

B.2-b 

12 Loss of 

material/ 

erosion

3.2.2.2.6 PWR Yes, plantspecificA plant-specific aging 

management program is 

to be evaluated for 

erosion of the orifice due 

to extended use of the 

centrifugal HPSI pump for 

normal charging. See LER 

50-275/94-023 for 

evidence of erosion.

Stainless 

steel

Treated 

borated water

E-24 Orifice (miniflow 

recirculation)

D1.2-c 

13 Loss of 

material/ 

general 

corrosion and 

fouling

3.2.2.2.7 BWR Yes, plantspecificA plant-specific aging 

management program is 

to be evaluated.

Steel Air – indoor 

uncontrolled 

(Internal)

E-04 Drywell and 

suppression 

chamber spray 

system (internal 

surfaces): 

Flow orifice 

 Spray nozzles

D2.5-b 

14 Loss of 

material/ 

general, 

pitting, and 

crevice 

corrosion

3.2.2.2.8.1 BWR Yes, 

detection of 

aging 

effects is to 

be 

evaluated

Chapter XI.M2, “Water 

Chemistry,” for BWR 

water 

The AMP is to be 

augmented by verifying 

the effectiveness of water 

chemistry control. See 

Chapter XI.M32, “OneTime Inspection,” for an 

acceptable verification 

program.

Steel Treated water E-08 Piping, piping 

components, and 

piping elements

D2.1-a 

D2.2-a 

D2.3-b 
NUREG-1833

B-80 October 2005

Table B.2 Engineered Safety Features

ID Aging Effect/ 

Mechanism

SRP-LR 

Ref

Type Further 

Evaluation

Aging Management 

Program (AMP)

Material Environment Related 

Item

Structure and/or 

Component

Related

15 Loss of 

material/ 

general, 

pitting, and 

crevice 

corrosion

3.2.2.2.8.2 BWR/ 

PWR

Yes, 

detection of 

aging 

effects is to 

be 

evaluated

Chapter XI.M2, “Water 

Chemistry” 

The AMP is to be 

augmented by verifying 

the effectiveness of water 

chemistry control. See 

Chapter XI.M32, “OneTime Inspection,” for an 

acceptable verification 

program.

Steel Treated water E-31 Containment 

isolation piping and 

components internal 

surfaces

C.1-a 

16 Loss of 

material/ 

general, 

pitting, and 

crevice 

corrosion

3.2.2.2.8.3 BWR/ 

PWR

Yes, 

detection of 

aging 

effects is to 

be 

evaluated

Chapter XI.M39, 

"Lubricating Oil Analysis" 

The AMP is to be 

augmented by verifying 

the effectiveness of the 

lubricating oil analysis 

program . See Chapter 

XI.M32, “One-Time 

Inspection,” for an 

acceptable verification 

program.

Steel Lubricating oil EP-46 Piping, piping 

components, and 

piping elements

A. D1. 

D2. 

17 Loss of 

material/ 

general, 

pitting, 

crevice, and 

microbiologically 

influenced 

corrosion

3.2.2.2.9 BWR/ 

PWR

No 

Yes, 

detection of 

aging 

effects and 

operating 

experience 

are to be 

further 

evaluated

Chapter XI.M28, “Buried 

Piping and Tanks 

Surveillance,” or 

Chapter XI.M34, “Buried 

Piping and Tanks 

Inspection”

Steel (with or 

without 

coating or 

wrapping)

Soil E-42 Piping, piping 

components, and 

piping elements

B.
October 2005

B-81 NUREG-1833

Table B.2 Engineered Safety Features

ID Aging Effect/ 

Mechanism

SRP-LR 

Ref

Type Further 

Evaluation

Aging Management 

Program (AMP)

Material Environment Related 

Item

Structure and/or 

Component

Related

18 Cracking/ 

stress 

corrosion 

cracking and 

intergranular 

stress 

corrosion 

cracking

NA BWR No Chapter XI.M7, “BWR 

Stress Corrosion 

Cracking,” and 

Chapter XI.M2, “Water 

Chemistry,” for BWR 

water

Stainless 

steel

Treated water 

>60°C 

(>140°F)

E-37 Piping, piping 

components, and 

piping elements

D2.1-c 

D2.3-c

19 Wall thinning/ 

flowaccelerated 

corrosion

NA BWR No Chapter XI.M17, “FlowAccelerated Corrosion”Steel Steam E-07 Piping, piping 

components, and 

piping elements

D2.1-f 

Treated water E-09 Piping, piping 

components, and 

piping elements

D2.3-a 

20 Loss of 

fracture 

toughness/ 

thermal aging 

embrittlement

NA BWR No Chapter XI.M12, “Thermal 

Aging Embrittlement of 

Cast Austenitic Stainless 

Steel (CASS)”

Cast 

austenitic 

stainless steel

Treated water 

>250°C 

(>482°F)

E-11 Piping, piping 

components, and 

piping elements

D2.1-d 

21 Cracking/ 

cyclic loading, 

stress 

corrosion 

cracking

NA BWR/ 

PWR

No Chapter XI.M18, “Bolting 

Integrity”

High-strength 

steel

Air with steam 

or water 

leakage

E-03 Closure bolting E.2-b 

22 Loss of 

material/ 

general 

corrosion

NA BWR/ 

PWR

No Chapter XI.M18, “Bolting 

Integrity”

Steel Air with steam 

or water 

leakage

E-02 Closure bolting E.2-a 

23 Loss of 

material/ 

general, 

pitting, and 

crevice 

corrosion

NA BWR/ 

PWR

No Chapter XI.M18, “Bolting 

Integrity”

Steel Air – indoor 

uncontrolled 

(External)

EP-25 Closure bolting E.
NUREG-1833

B-82 October 2005

Table B.2 Engineered Safety Features

ID Aging Effect/ 

Mechanism

SRP-LR 

Ref

Type Further 

Evaluation

Aging Management 

Program (AMP)

Material Environment Related 

Item

Structure and/or 

Component

Related

Air – outdoor 

(External)

EP-1 Bolting E.

24 Loss of 

preload/ 

thermal 

effects, gasket 

creep, and 

self-loosening 

NA BWR/ 

PWR

No Chapter XI.M18, “Bolting 

Integrity”

Steel Air – indoor 

uncontrolled 

(External)

EP-24 Closure bolting E.

25 Cracking/ 

stress 

corrosion 

cracking

NA BWR/ 

PWR

No Chapter XI.M21, “ClosedCycle Cooling Water 

System”

Stainless 

steel

Closed cycle 

cooling water 

>60°C 

(>140°F)

EP-44 Piping, piping 

components, and 

piping elements

A. C. D1. 

D2.

26 Loss of 

material/ 

general, 

pitting, and 

crevice 

corrosion

NA BWR/ 

PWR

No Chapter XI.M21, “ClosedCycle Cooling Water 

System”

Steel Closed cycle 

cooling water

EP-48 Piping, piping 

components, and 

piping elements

C.

27 Loss of 

material/ 

general, 

pitting, 

crevice, and 

galvanic 

corrosion

NA BWR/ 

PWR

No Chapter XI.M21, “ClosedCycle Cooling Water 

System”

Steel Closed cycle 

cooling water

E-17 Heat exchanger 

components

A.6-c 

D1.5-a 

D1.6-a 

D2.4-c 

28 Loss of 

material/ 

pitting and 

crevice 

corrosion

NA BWR/ 

PWR

No Chapter XI.M21, “ClosedCycle Cooling Water 

System”

Stainless 

steel

Closed cycle 

cooling water

E-19 Heat exchanger 

components

A.6-c 

D1.5-a 

D1.6-a 

D2.4-c 

EP-33 Piping, piping 

components, and 

piping elements

A. C. D1. 

D2.
October 2005

B-83 NUREG-1833

Table B.2 Engineered Safety Features

ID Aging Effect/ 

Mechanism

SRP-LR 

Ref

Type Further 

Evaluation

Aging Management 

Program (AMP)

Material Environment Related 

Item

Structure and/or 

Component

Related

29 Loss of 

material/ 

pitting, 

crevice, and 

galvanic 

corrosion

NA BWR/ 

PWR

No Chapter XI.M21, “ClosedCycle Cooling Water 

System”

Copper alloy Closed cycle 

cooling water

EP-13 Heat exchanger 

components

A. D1. 

D2.

EP-36 Piping, piping 

components, and 

piping elements

A. B. D1. 

D2.

30 Reduction of 

heat transfer/ 

fouling

NA BWR/ 

PWR

No Chapter XI.M21, “ClosedCycle Cooling Water 

System”

Copper alloy Closed cycle 

cooling water

EP-39 Heat exchanger 

tubes

A. 

Stainless 

steel

Closed cycle 

cooling water

EP-35 Heat exchanger 

tubes

A. D1. 

D2.

31 Loss of 

material/ 

general 

corrosion

NA BWR/ 

PWR

No Chapter XI.M36, "External 

Surfaces Monitoring"

Steel Air – indoor 

uncontrolled 

(External)

E-26 Ducting, piping and 

components external 

surfaces

A.2-a 

A.5-a 

B.1-a 

B.2-a 

D2.1-e 

D2.5-a 

E-35 Containment 

isolation piping and 

components external 

surfaces

C.1-a

E-40 Ducting closure 

bolting

B.1-a

E-44 External surfaces E. 

Air – outdoor 

(External)

E-45 External surfaces E. 

Condensation 

(External)

E-30 Containment 

isolation piping and 

components external 

surfaces

C.1-a 

E-46 External surfaces E. 
NUREG-1833

B-84 October 2005

Table B.2 Engineered Safety Features

ID Aging Effect/ 

Mechanism

SRP-LR 

Ref

Type Further 

Evaluation

Aging Management 

Program (AMP)

Material Environment Related 

Item

Structure and/or 

Component

Related

32 Loss of 

material/ 

general 

corrosion

NA BWR/ 

PWR

No Chapter XI.M38, 

"Inspection of Internal 

Surfaces in Miscellaneous 

Piping and Ducting 

Components"

Steel Air – indoor 

uncontrolled 

(Internal)

E-25 Ducting and 

components internal

surfaces

B.2-a 

E-29 Piping and 

components internal 

surfaces

A.2-a 

A.5-a 

D2.5-a 

33 Loss of 

material/ 

general, 

pitting, and 

crevice 

corrosion

NA BWR/ 

PWR

No Chapter XI.M38, 

"Inspection of Internal 

Surfaces in Miscellaneous 

Piping and Ducting 

Components"

Steel Air – indoor 

uncontrolled 

(Internal)

EP-42 Encapsulation 

Components

A.

34 Loss of 

material/ 

general, 

pitting, and 

crevice 

corrosion

NA BWR/ 

PWR

No Chapter XI.M38, 

"Inspection of Internal 

Surfaces in Miscellaneous 

Piping and Ducting 

Components"

Steel Condensation 

(Internal)

E-27 Piping and 

components internal 

surfaces

D2.1-e 

35 Loss of 

material/ 

general, 

pitting, 

crevice, and 

microbiologically 

influenced 

corrosion, and 

fouling

NA BWR/ 

PWR

No Chapter XI.M20, “OpenCycle Cooling Water 

System”

Steel Raw water E-22 Containment 

isolation piping and 

components internal 

surfaces

C.1-a
October 2005

B-85 NUREG-1833

Table B.2 Engineered Safety Features

ID Aging Effect/ 

Mechanism

SRP-LR 

Ref

Type Further 

Evaluation

Aging Management 

Program (AMP)

Material Environment Related 

Item

Structure and/or 

Component

Related

36 Loss of 

material/ 

general, 

pitting, 

crevice, 

galvanic, and 

microbiologically 

influenced 

corrosion, and 

fouling

NA BWR/ 

PWR

No Chapter XI.M20, “OpenCycle Cooling Water 

System”

Steel Raw water E-18 Heat exchanger 

components

A.6-a 

D1.6-b 

D2.4-a 

37 Loss of 

material/ 

pitting, 

crevice, and 

microbiologically 

influenced 

corrosion

NA BWR/ 

PWR

No Chapter XI.M20, “OpenCycle Cooling Water 

System”

Stainless 

steel

Raw water EP-55 Piping, piping 

components, and 

piping elements

D1.

38 Loss of 

material/ 

pitting, 

crevice, and 

microbiologically 

influenced 

corrosion, and 

fouling

NA BWR/ 

PWR

No Chapter XI.M20, “OpenCycle Cooling Water 

System”

Stainless 

steel

Raw water E-34 Containment 

isolation piping and 

components internal 

surfaces

C.1-b

39 Loss of 

material/ 

pitting, 

crevice, and 

microbiologically 

influenced 

corrosion, and 

fouling

NA BWR/ 

PWR

No Chapter XI.M20, “OpenCycle Cooling Water 

System”

Stainless 

steel

Raw water E-20 Heat exchanger 

components

A.6-a 

D1.6-b 

D2.4-a 
NUREG-1833

B-86 October 2005

Table B.2 Engineered Safety Features

ID Aging Effect/ 

Mechanism

SRP-LR 

Ref

Type Further 

Evaluation

Aging Management 

Program (AMP)

Material Environment Related 

Item

Structure and/or 

Component

Related

40 Reduction of 

heat transfer/ 

fouling

NA BWR/ 

PWR

No Chapter XI.M20, “OpenCycle Cooling Water 

System”

Stainless 

steel

Raw water E-21 Heat exchanger 

tubes

A.6-b 

D1.6-c 

D2.4-b 

Steel Raw water E-23 Heat exchanger 

tubes

D2.4-b 

41 Loss of 

material/ 

selective 

leaching

NA BWR/ 

PWR

No Chapter XI.M33, 

“Selective Leaching of 

Materials”

Copper alloy 

>15% Zn

Closed cycle 

cooling water

EP-27 Piping, piping 

components, and 

piping elements

A. B. D1. 

D2.

EP-37 Heat exchanger 

components

A. B. D1. 

D2.

42 Loss of 

material/ 

selective 

leaching

NA BWR/ 

PWR

No Chapter XI.M33, 

“Selective Leaching of 

Materials”

Gray cast iron Closed cycle 

cooling water

EP-52 Piping, piping 

components, and 

piping elements

D1.

43 Loss of 

material/ 

selective 

leaching

NA BWR/ 

PWR

No Chapter XI.M33, 

“Selective Leaching of 

Materials" 

Gray cast iron Soil EP-54 Piping, piping 

components, and 

piping elements

B. D1. 

D2. 

44 Loss of 

material/ 

selective 

leaching

NA BWR/ 

PWR

No Chapter XI.M33, 

“Selective Leaching of 

Materials”

Gray cast iron Treated water E-43 Motor Cooler A. D1. 

45 Loss of 

material/ boric 

acid corrosion

NA PWR No Chapter XI.M10, “Boric 

Acid Corrosion”

Aluminum Air with 

borated water 

leakage

EP-2 Piping, piping 

components , and 

piping elements

D2. 

Copper alloy 

>15% Zn

Air with 

borated water 

leakage

EP-38 Piping, piping 

components, and 

piping elements

E.
October 2005

B-87 NUREG-1833

Table B.2 Engineered Safety Features

ID Aging Effect/ 

Mechanism

SRP-LR 

Ref

Type Further 

Evaluation

Aging Management 

Program (AMP)

Material Environment Related 

Item

Structure and/or 

Component

Related

Steel Air with 

borated water 

leakage

E-28 External surfaces A.1-b 

A.3-b 

A.4-b 

A.5-b 

A.6-d 

D1.1-d 

D1.2-b 

D1.3-a 

D1.4-c 

D1.5-b 

D1.6-d 

D1.7-a 

D1.8-b 

E.1-a 

E-41 Bolting E.

46 Loss of 

material/ 

general, 

pitting, crevice 

and boric acid 

corrosion

NA PWR No Chapter XI.M38, 

"Inspection of Internal 

Surfaces in Miscellaneous 

Piping and Ducting 

Components"

Steel Air with 

borated water 

leakage 

(Internal)

EP-43 Encapsulation 

Components

A.

47 Loss of 

fracture 

toughness/ 

thermal aging 

embrittlement

NA PWR No Chapter XI.M12, “Thermal 

Aging Embrittlement of 

Cast Austenitic Stainless 

Steel (CASS)”

Cast 

austenitic 

stainless steel

Treated 

borated water 

>250°C 

(>482°F)

E-47 Piping, piping 

components, and 

piping elements

D1.1-b 

48 Cracking/ 

stress 

corrosion 

cracking

NA PWR No Chapter XI.M2, “Water 

Chemistry,” for PWR 

primary water

Stainless 

steel

Treated 

borated water 

>60°C 

(>140°F)

E-12 Piping, piping 

components, piping 

elements, and tanks

A.1-a 

A.1-c 

A.3-a 

A.4-a 

D1.1-a 

D1.2-a 

D1.4-b 

D1.7-b 

D1.8-a 
NUREG-1833

B-88 October 2005

Table B.2 Engineered Safety Features

ID Aging Effect/ 

Mechanism

SRP-LR 

Ref

Type Further 

Evaluation

Aging Management 

Program (AMP)

Material Environment Related 

Item

Structure and/or 

Component

Related

Steel with 

stainless steel 

cladding

Treated 

borated water 

>60°C 

(>140°F)

E-38 Safety injection tank 

(accumulator)

D1.7-b

49 Loss of 

material/ 

pitting and 

crevice 

corrosion

NA PWR No Chapter XI.M2, “Water 

Chemistry,” for PWR 

primary water

Stainless 

steel

Treated 

borated water

EP-41 Piping, piping 

components, piping 

elements, and tanks

A. D1. 

50 None NA BWR/ 

PWR

No None Aluminum Air – indoor 

uncontrolled 

(Internal/Exter

nal)

EP-3 Piping, piping 

components, and 

piping elements

F.

51 None NA BWR/ 

PWR

No None Galvanized 

steel

Air – indoor 

controlled 

(External)

EP-14 Ducting F.

52 None NA BWR/ 

PWR

No None Glass Air – indoor 

uncontrolled 

(External)

EP-15 Piping elements F.

Lubricating oil EP-16 Piping elements F.

Raw water EP-28 Piping elements F.

Treated 

borated water

EP-30 Piping elements F.

Treated water EP-29 Piping elements F.

53 None NA BWR/ 

PWR

No None Copper alloy Air – indoor 

uncontrolled 

(External)

EP-10 Piping, piping 

components, and 

piping elements

F.

Nickel alloy Air – indoor 

uncontrolled 

(External)

EP-17 Piping, piping 

components, and 

piping elements

F.

Stainless 

steel

Air – indoor 

uncontrolled 

(External)

EP-18 Piping, piping 

components, and 

piping elements

F.
October 2005

B-89 NUREG-1833

Table B.2 Engineered Safety Features

ID Aging Effect/ 

Mechanism

SRP-LR 

Ref

Type Further 

Evaluation

Aging Management 

Program (AMP)

Material Environment Related 

Item

Structure and/or 

Component

Related

54 None NA BWR/ 

PWR

No None Steel Air – indoor 

controlled 

(External)

EP-4 Piping, piping 

components, and 

piping elements

F.

55 None NA BWR/ 

PWR

No None Stainless 

steel

Concrete EP-20 Piping, piping 

components, and 

piping elements

F.

Steel Concrete EP-5 Piping, piping 

components, and 

piping elements

F.

56 None NA BWR/ 

PWR

No None Copper alloy Gas EP-9 Piping, piping 

components, and 

piping elements

F.

Stainless 

steel

Gas EP-22 Piping, piping 

components, and 

piping elements

F.

Steel Gas EP-7 Piping, piping 

components, and 

piping elements

F.

57 None NA PWR No None Copper alloy 

<15% Zn

Air with 

borated water 

leakage

EP-12 Piping, piping 

components, and 

piping elements

F.

Stainless 

steel

Air with 

borated water 

leakage

EP-19 Piping, piping 

components, and 

piping elements

F.
NUREG-1833 B-90 October 2005

This Page Intentionally Left Blank
October 2005

B-91 NUREG-1833

B.3 Auxiliary Systems SRP-LR Development Tool

Table B.3 presents the auxiliary systems SRP-LR development tool.

Table B.3 Auxiliary Systems

ID Aging Effect/ 

Mechanism

SRP-LR Ref Type Further 

Evaluation

Aging Management 

Program (AMP)

Material Environment Related 

Item

Structure and/or 

Component

Related

1 Cumulative 

fatigue 

damage/ 

fatigue

3.3.2.2.1 BWR/ 

PWR

Yes, 

TLAA

Fatigue is a time-limited 

aging analysis (TLAA) to 

be evaluated for the 

period of extended 

operation for structural 

girders of cranes that fall 

within the scope of 10 

CFR 54. See the Standard 

Review Plan, Section 4.7, 

“Other Plant-Specific 

Time-Limited Aging 

Analyses,” for generic 

guidance for meeting the 

requirements of 10 CFR 

54.21(c)(1).

Steel Air – indoor 

uncontrolled 

(External)

A-06 Cranes - Structural 

girders

B.1-a 

2 Cumulative 

fatigue 

damage/ 

fatigue

3.3.2.2.1 BWR/ 

PWR

Yes, 

TLAA

Fatigue is a time-limited 

aging analysis (TLAA) to 

be evaluated for the 

period of extended 

operation. See the 

Standard Review Plan, 

Section 4.3 “Metal 

Fatigue,” for acceptable 

methods for meeting the 

requirements of 10 CFR 

54.21(c)(1).

Stainless 

steel

Treated 

borated water

A-100 Heat exchanger 

components

E1.8-a

A-57 Piping, piping 

components, and 

piping elements

E1.1-a 

E1.3-a 

E1.7-a 

E1.8-a 

Treated water A-62 Piping, piping 

components, and 

piping elements

E3.1-b 

E3.2-b 

E4.1-b 
NUREG-1833

B-92 October 2005

Table B.3 Auxiliary Systems

ID Aging Effect/ 

Mechanism

SRP-LR Ref Type Further 

Evaluation

Aging Management 

Program (AMP)

Material Environment Related 

Item

Structure and/or 

Component

Related

Steel Air – indoor 

uncontrolled

A-34 Piping, piping 

components, and 

piping elements

E1.1-a 

E1.3-a 

E1.7-a 

E1.8-a 

E3.2-c 

3 Reduction of 

heat transfer/ 

fouling

3.3.2.2.2 BWR/ 

PWR

Yes, 

detection of 

aging 

effects is to 

be 

evaluated

Chapter XI.M2, “Water 

Chemistry” 

The AMP is to be 

augmented by verifying 

the effectiveness of water 

chemistry control. See 

Chapter XI.M32, “OneTime Inspection,” for an 

acceptable verification 

program.

Stainless 

steel

Treated water AP-62 Heat exchanger 

tubes

A4. E3.

4 Cracking/ 

stress 

corrosion 

cracking

3.3.2.2.3.1 BWR Yes, 

detection of 

aging 

effects is to 

be 

evaluated

Chapter XI.M2, “Water 

Chemistry,” for BWR 

water 

The AMP is to be 

augmented by verifying 

the effectiveness of water 

chemistry control. See 

Chapter XI.M32, “OneTime Inspection,” for an 

acceptable verification 

program.

Stainless 

steel

Sodium 

pentaborate 

solution 

>60°C 

(>140°F)

A-59 Piping, piping 

components, and 

piping elements

E2.1-a 

E2.2-a 

E2.3-a 

E2.4-a 

5 Cracking/ 

stress 

corrosion 

cracking

3.3.2.2.3.2 BWR/ 

PWR

Yes, plantspecificA plant-specific aging 

management program is 

to be evaluated.

Stainless 

steel

Treated water 

>60°C 

(>140°F)

A-85 Regenerative heat 

exchanger 

components

E3.3-d 

Stainless 

steel; steel 

with stainless 

steel cladding

Treated water 

>60°C 

(>140°F)

A-71 Heat exchanger 

components

E3.4-a 
October 2005

B-93 NUREG-1833

Table B.3 Auxiliary Systems

ID Aging Effect/ 

Mechanism

SRP-LR Ref Type Further 

Evaluation

Aging Management 

Program (AMP)

Material Environment Related 

Item

Structure and/or 

Component

Related

6 Cracking/ 

stress 

corrosion 

cracking

3.3.2.2.3.3 BWR/ 

PWR

Yes, plantspecificA plant-specific aging 

management program is 

to be evaluated.

Stainless 

steel

Diesel 

exhaust

AP-33 Diesel engine 

exhaust 

Piping, piping 

components, and 

piping elements

H2.

7 Cracking/ 

stress 

corrosion 

cracking, 

cyclic loading

3.3.2.2.4.1 PWR Yes, plantspecificChapter XI.M2, “Water 

Chemistry,” for PWR 

primary water. 

The AMP is to be 

augmented by verifying 

the absence of cracking 

due to stress corrosion 

cracking and cyclic 

loading, or loss of material 

due to pitting and crevice 

corrosion. An acceptable 

verification program is to 

include temperature and 

radioactivity monitoring of 

the shell side water, and 

eddy current testing of 

tubes.

Stainless 

steel

Treated 

borated water 

>60°C 

(>140°F)

A-69 Non-regenerative 

heat exchanger 

components

E1.8-b 

8 Cracking/ 

stress 

corrosion 

cracking, 

cyclic loading

3.3.2.2.4.2 PWR Yes, plantspecificChapter XI.M2, “Water 

Chemistry,” for PWR 

primary water 

The AMP is to be 

augmented by verifying 

the absence of cracking 

due to stress corrosion 

cracking and cyclic 

loading. A plant specific 

aging management 

program is to be 

evaluated.

Stainless 

steel

Treated 

borated water 

>60°C 

(>140°F)

A-84 Heat exchanger 

components

E1.7-c 
NUREG-1833

B-94 October 2005

Table B.3 Auxiliary Systems

ID Aging Effect/ 

Mechanism

SRP-LR Ref Type Further 

Evaluation

Aging Management 

Program (AMP)

Material Environment Related 

Item

Structure and/or 

Component

Related

9 Cracking/ 

stress 

corrosion 

cracking, 

cyclic loading

3.3.2.2.4.3 PWR Yes, plantspecificChapter XI.M2, “Water 

Chemistry,” for PWR 

primary water 

The AMP is to be 

augmented by verifying 

the absence of cracking 

due to stress corrosion 

cracking and cyclic 

loading. A plant specific 

aging management 

program is to be 

evaluated.

Stainless 

steel

Treated 

borated water

A-76 High-pressure pump 

Casing

E1.5-a 

10 Cracking/ 

cyclic loading, 

stress 

corrosion 

cracking

3.3.2.2.4.4 BWR/ 

PWR

Yes, if the 

bolts are 

not 

replaced 

during 

maintenanc

e

Chapter XI.M18, “Bolting 

Integrity.” 

The AMP is to be 

augmented by appropriate 

inspection to detect 

cracking if the bolts are 

not otherwise replaced 

during maintenance.

High-strength 

steel

Air with steam 

or water 

leakage

A-104 High-pressure pump 

Closure bolting

E1.5-a 

11 Hardening 

and loss of 

strength/ 

elastomer 

degradation

3.3.2.2.5.1 BWR/ 

PWR

Yes, plantspecificA plant-specific aging 

management program is 

to be evaluated.

Elastomers Air – indoor 

uncontrolled 

(Internal/ 

External)

A-17 Elastomer seals and 

components

F1.1-b 

F1.4-b 

F2.1-b 

F2.4-b 

F3.1-b 

F3.4-b 

F4.1-b 

12 Hardening 

and loss of 

strength/ 

elastomer 

degradation

3.3.2.2.5.2 BWR/ 

PWR

Yes, plantspecificA plant-specific aging 

management program that 

determines and assesses 

the qualified life of the 

linings in the environment 

is to be evaluated.

Elastomers Treated 

borated water

A-15 Elastomer lining A3.2-a 

A3.2-d 

A3.3-a 

A3.3-d 

A3.5-a 

A3.5-c 
October 2005

B-95 NUREG-1833

Table B.3 Auxiliary Systems

ID Aging Effect/ 

Mechanism

SRP-LR Ref Type Further 

Evaluation

Aging Management 

Program (AMP)

Material Environment Related 

Item

Structure and/or 

Component

Related

Treated water A-16 Elastomer lining A4.2-a 

A4.2-b 

A4.3-a 

A4.3-b 

A4.5-a 

A4.5-b 

13 Reduction of 

neutronabsorbing 

capacity and 

loss of 

material/ 

general 

corrosion

3.3.2.2.6 BWR/ 

PWR

Yes, plantspecificA plant-specific aging 

management program is 

to be evaluated.

Boral, 

boron steel

Treated 

borated water

A-88 Spent fuel storage 

racks 

Neutron-absorbing 

sheets - PWR

A2.1-b 

Treated water A-89 Spent fuel storage 

racks 

Neutron-absorbing 

sheets - BWR

A2.1-b 

14 Loss of 

material/ 

general, 

pitting, and 

crevice 

corrosion

3.3.2.2.7.1 BWR/ 

PWR

Yes, 

detection of 

aging 

effects is to 

be 

evaluated

Chapter XI.M39, 

"Lubricating Oil Analysis" 

The AMP is to be 

augmented by verifying 

the effectiveness of the 

lubricating oil analysis 

program . See Chapter 

XI.M32, “One-Time 

Inspection,” for an 

acceptable verification 

program.

Steel Lubricating oil AP-30 Piping, piping 

components, and 

piping elements

C1. C2. 

E1. E4. 

F1. F2. 

F3. F4. 

G. H2. 
NUREG-1833

B-96 October 2005

Table B.3 Auxiliary Systems

ID Aging Effect/ 

Mechanism

SRP-LR Ref Type Further 

Evaluation

Aging Management 

Program (AMP)

Material Environment Related 

Item

Structure and/or 

Component

Related

15 Loss of 

material/ 

general, 

pitting, and 

crevice 

corrosion

3.3.2.2.7.1 BWR/ 

PWR

Yes, 

detection of 

aging 

effects is to 

be 

evaluated

Chapter XI.M39, 

"Lubricating Oil Analysis" 

The AMP is to be 

augmented by verifying 

the effectiveness of the 

lubricating oil analysis 

program . See Chapter 

XI.M32, “One-Time 

Inspection,” for an 

acceptable verification 

program.

Steel Lubricating oil A-83 Reactor coolant 

pump oil collection 

system 

Piping, tubing, valve 

bodies

G.7-b 

16 Loss of 

material/ 

general, 

pitting, and 

crevice 

corrosion

3.3.2.2.7.1 BWR/ 

PWR

Yes, 

detection of 

aging 

effects is to 

be 

evaluated

Chapter XI.M39, 

"Lubricating Oil Analysis" 

The AMP is to be 

augmented to evaluate 

the thickness of the lower 

portion of the tank. See 

Chapter XI.M32, “OneTime Inspection,” for an 

acceptable verification 

program.

Steel Lubricating oil A-82 Reactor coolant 

pump oil collection 

system 

Tank

G.7-a 

17 Loss of 

material/ 

general, 

pitting, and 

crevice 

corrosion

3.3.2.2.7.2 BWR/ 

PWR

Yes, 

detection of 

aging 

effects is to 

be 

evaluated

Chapter XI.M2, “Water 

Chemistry,” for BWR 

water 

The AMP is to be 

augmented by verifying 

the effectiveness of water 

chemistry control. See 

Chapter XI.M32, “OneTime Inspection,” for an 

acceptable verification 

program.

Steel Treated water A-35 Piping, piping 

components, and 

piping elements

E3. E4.1-

a E4.2-a 
October 2005

B-97 NUREG-1833

Table B.3 Auxiliary Systems

ID Aging Effect/ 

Mechanism

SRP-LR Ref Type Further 

Evaluation

Aging Management 

Program (AMP)

Material Environment Related 

Item

Structure and/or 

Component

Related

18 Loss of 

material/ 

general (steel 

only), pitting 

and crevice 

corrosion

3.3.2.2.7.3 BWR/ 

PWR

Yes, plantspecificA plant-specific aging 

management program is 

to be evaluated.

Stainless 

steel; steel

Diesel 

exhaust

A-27 Diesel engine 

exhaust 

Piping, piping 

components, and 

piping elements

H2.4-a 

19 Loss of 

material/ 

general, 

pitting, 

crevice, and 

microbiologically 

influenced 

corrosion

3.3.2.2.8 BWR/ 

PWR

No 

Yes, 

detection of 

aging 

effects and 

operating 

experience 

are to be 

further 

evaluated

Chapter XI.M28, “Buried 

Piping and Tanks 

Surveillance,” or 

Chapter XI.M34, “Buried 

Piping and Tanks 

Inspection”

Steel (with or 

without 

coating or 

wrapping)

Soil A-01 Piping, piping 

components, and 

piping elements

H1.1-b 

C1.1-b 

C3. G. 

20 Loss of 

material/ 

general, 

pitting, 

crevice, and 

microbiologically 

influenced

corrosion, and 

fouling

3.3.2.2.9.1 BWR/ 

PWR

Yes, 

detection of 

aging 

effects is to 

be 

evaluated

Chapter XI.M30, “Fuel Oil 

Chemistry” 

The AMP is to be 

augmented by verifying 

the effectiveness of fuel oil 

chemistry control. See 

Chapter XI.M32, “OneTime Inspection,” for an 

acceptable verification 

program.

Steel Fuel oil A-30 Piping, piping 

components, piping 

elements, and tanks

H1.4-a 

H2.5-a 
NUREG-1833

B-98 October 2005

Table B.3 Auxiliary Systems

ID Aging Effect/ 

Mechanism

SRP-LR Ref Type Further 

Evaluation

Aging Management 

Program (AMP)

Material Environment Related 

Item

Structure and/or 

Component

Related

21 Loss of 

material/ 

general, 

pitting, 

crevice, and 

microbiologically 

influenced 

corrosion, and 

fouling

3.3.2.2.9.2 BWR/ 

PWR

Yes, 

detection of 

aging 

effects is to 

be 

evaluated

Chapter XI.M39, 

"Lubricating Oil Analysis" 

The AMP is to be 

augmented by verifying 

the effectiveness of the 

lubricating oil analysis 

program . See Chapter 

XI.M32, “One-Time 

Inspection,” for an 

acceptable verification 

program.

Steel Lubricating oil AP-39 Heat exchanger 

components

H2.

22 Loss of 

material/ 

pitting and 

crevice 

corrosion 

(only for steel 

after lining 

degradation)

3.3.2.2.10.1 BWR/ 

PWR

Yes, 

detection of 

aging 

effects is to 

be 

evaluated

Chapter XI.M2, “Water 

Chemistry,” for PWR 

primary water 

The AMP is to be 

augmented by verifying 

the effectiveness of water 

chemistry control. See 

Chapter XI.M32, “OneTime Inspection,” for an 

acceptable verification 

program.

Steel with 

elastomer 

lining

Treated 

borated water

A-39 Piping, piping 

components, and 

piping elements

A3.2-a 

A3.3-a 

A3.5-a 

Chapter XI.M2, “Water 

Chemistry,” for BWR 

water 

The AMP is to be 

augmented by verifying 

the effectiveness of water 

chemistry control. See 

Chapter XI.M32, “OneTime Inspection,” for an 

acceptable verification 

program.

Steel with 

elastomer 

lining or 

stainless steel 

cladding

Treated water A-40 Piping, piping 

components, and 

piping elements

A4.2-a 

A4.3-a 

A4.5-a 
October 2005

B-99 NUREG-1833

Table B.3 Auxiliary Systems

ID Aging Effect/ 

Mechanism

SRP-LR Ref Type Further 

Evaluation

Aging Management 

Program (AMP)

Material Environment Related 

Item

Structure and/or 

Component

Related

23 Loss of 

material/ 

pitting and 

crevice

corrosion

3.3.2.2.10.2 BWR/ 

PWR

Yes, 

detection of 

aging 

effects is to 

be 

evaluated

Chapter XI.M2, “Water 

Chemistry,” for BWR 

water 

The AMP is to be 

augmented by verifying 

the effectiveness of water 

chemistry control. See 

Chapter XI.M32, “OneTime Inspection,” for an 

acceptable verification 

program.

Stainless 

steel; steel 

with stainless 

steel cladding

Treated water A-70 Heat exchanger 

components

A4.4-b 

24 Loss of 

material/ 

pitting and 

crevice 

corrosion

3.3.2.2.10.2 BWR/ 

PWR

Yes, 

detection of 

aging 

effects is to 

be 

evaluated

Chapter XI.M2, "Water 

Chemistry" 

The AMP is to be 

augmented by verifying 

the effectiveness of water 

chemistry control. See 

Chapter XI.M32, “OneTime Inspection,” for an 

acceptable verification 

program.

Aluminum Treated water AP-38 Piping, piping 

components, and 

piping elements

A4. E3. 

E4.

Chapter XI.M2, “Water 

Chemistry,” for BWR 

water 

The AMP is to be 

augmented by verifying 

the effectiveness of water 

chemistry control. See 

Chapter XI.M32, “OneTime Inspection,” for an 

acceptable verification 

program.

Stainless 

steel

Treated water A-58 Piping, piping 

components, and 

piping elements

A4.1-a 

A4.6-a 

E4.1-a 

E3. 
NUREG-1833

B-100 October 2005

Table B.3 Auxiliary Systems

ID Aging Effect/ 

Mechanism

SRP-LR Ref Type Further 

Evaluation

Aging Management 

Program (AMP)

Material Environment Related 

Item

Structure and/or 

Component

Related

25 Loss of 

material/ 

pitting and 

crevice 

corrosion

3.3.2.2.10.3 BWR/ 

PWR

Yes, plantspecificA plant-specific aging 

management program is 

to be evaluated.

Copper alloy Condensation 

(External)

A-46 Piping, piping 

components, and 

piping elements

F1.2-a 

F2.2-a 

F3.2-a 

F4.2-a 

26 Loss of 

material/ 

pitting and 

crevice 

corrosion

3.3.2.2.10.4 BWR/ 

PWR

Yes, 

detection of 

aging 

effects is to 

be 

evaluated

Chapter XI.M39, 

"Lubricating Oil Analysis" 

The AMP is to be 

augmented by verifying 

the effectiveness of the 

lubricating oil analysis 

program . See Chapter 

XI.M32, “One-Time 

Inspection,” for an 

acceptable verification 

program.

Copper alloy Lubricating oil AP-47 Piping, piping 

components, and 

piping elements

C1. C2. 

E1. E4. 

G. H2.

27 Loss of 

material/ 

pitting and 

crevice 

corrosion

3.3.2.2.10.5 BWR/ 

PWR

Yes, plantspecificA plant-specific aging 

management program is 

to be evaluated.

Aluminum Condensation AP-74 Piping, piping 

components, and 

piping elements

F1. F2. 

F3. F4.

Stainless 

steel

Condensation A-09 Ducting and 

components

F1.4-a 

F2.4-a 

F3.4-a 

28 Loss of 

material/ 

pitting and 

crevice 

corrosion

3.3.2.2.10.6 BWR/ 

PWR

Yes, plantspecificA plant-specific aging 

management program is 

to be evaluated.

Copper alloy Condensation 

(Internal)

AP-78 Piping, piping 

components, and 

piping elements

G.

29 Loss of 

material/ 

pitting and 

crevice 

corrosion

3.3.2.2.10.7 BWR/ 

PWR

Yes, plantspecificA plant-specific aging 

management program is 

to be evaluated.

Stainless 

steel

Soil AP-56 Piping, piping 

components, and 

piping elements

C1. C3. 

G. H1. 

H2.
October 2005

B-101 NUREG-1833

Table B.3 Auxiliary Systems

ID Aging Effect/ 

Mechanism

SRP-LR Ref Type Further 

Evaluation

Aging Management 

Program (AMP)

Material Environment Related 

Item

Structure and/or 

Component

Related

30 Loss of 

material/ 

pitting and 

crevice 

corrosion

3.3.2.2.10.8 BWR Yes, 

detection of 

aging 

effects is to 

be 

evaluated

Chapter XI.M2, “Water 

Chemistry,” for BWR 

water 

The AMP is to be 

augmented by verifying 

the effectiveness of water 

chemistry control. See 

Chapter XI.M32, “OneTime Inspection,” for an 

acceptable verification 

program.

Stainless 

steel

Sodium 

pentaborate 

solution

AP-73 Piping, piping 

components, and 

piping elements

E2.

31 Loss of 

material/ 

pitting, 

crevice, and 

galvanic 

corrosion

3.3.2.2.11 BWR/ 

PWR

Yes, 

detection of 

aging 

effects is to 

be 

evaluated

Chapter XI.M2, “Water 

Chemis try,” for BWR 

water 

The AMP is to be 

augmented by verifying 

the effectiveness of water 

chemistry control. See 

Chapter XI.M32, “OneTime Inspection,” for an 

acceptable verification 

program.

Copper alloy Treated water AP-64 Piping, piping 

components, and 

piping elements

A4. E3. 

E4.

32 3.3.2.2.12.1 BWR/ 

PWR

Aluminum Fuel oil AP-35 Piping, piping 

components, and 

piping elements

Loss of H1. H2.

material/ 

pitting, 

crevice, and 

microbiologically 

influenced 

corrosion

Yes, 

detection of 

aging 

effects is to 

be 

evaluated

Copper alloy Fuel oil AP-44 Piping, piping 

components, and 

piping elements

H1. H2. 

G.

Chapter XI.M30, “Fuel Oil 

Chemistry” 

The AMP is to be 

augmented by verifying 

the effectiveness of fuel oil 

chemistry control. See 

Chapter XI.M32, “OneTime Inspection,” for an 

acceptable verification 

program.

Stainless 

steel

Fuel oil AP-54 Piping, piping 

components, and 

piping elements

G. H1. 

H2.
NUREG-1833

B-102 October 2005

Table B.3 Auxiliary Systems

ID Aging Effect/ 

Mechanism

SRP-LR Ref Type Further 

Evaluation

Aging Management 

Program (AMP)

Material Environment Related 

Item

Structure and/or 

Component

Related

33 Loss of 

material/ 

pitting, 

crevice, and 

microbiologically 

influenced 

corrosion

3.3.2.2.12.2 BWR/ 

PWR

Yes, 

detection of 

aging 

effects is to 

be 

evaluated

Chapter XI.M39, 

"Lubricating Oil Analysis" 

The AMP is to be 

augmented by verifying 

the effectiveness of the 

lubricating oil analysis 

program . See Chapter 

XI.M32, “One-Time 

Inspection,” for an 

acceptable verification 

program.

Stainless 

steel

Lubricating oil AP-59 Piping, piping 

components, and 

piping elements

C1. C2. 

E1. E4. 

H2. G.

34 Loss of 

material/ wear

3.3.2.2.13 BWR/ 

PWR

Yes, plantspecificA plant-specific aging 

management program is 

to be evaluated.

Elastomers Air – indoor 

uncontrolled 

(External)

A-73 Elastomer seals and 

components

F1.1-c 

F2.1-c 

F3.1-c 

F4.1-c 

Air – indoor 

uncontrolled 

(Internal)

A-18 Elastomer seals and 

components

F1.1-c 

F2.1-c 

F3.1-c 

F4.1-c 

35 Loss of 

material/ 

cladding 

breach

3.3.2.2.14 PWR Yes, verify 

plantspecific 

program 

addresses 

cladding 

breach

A plant-specific aging 

management program is 

to be evaluated. 

Reference NRC 

Information Notice 94-63, 

“Boric Acid Corrosion of 

Charging Pump Casings 

Caused by Cladding 

Cracks."

Steel with 

stainless steel 

cladding

Treated 

borated water

AP-85 Pump Casings E1.

36 Reduction of 

neutronabsorbing 

capacity/ 

boraflex 

degradation

NA BWR No Chapter XI.M22, “Boraflex 

Monitoring”

Boraflex Treated water A-87 Spent fuel storage 

racks 

Neutron-absorbing 

sheets - BWR

A2.1-a 
October 2005

B-103 NUREG-1833

Table B.3 Auxiliary Systems

ID Aging Effect/ 

Mechanism

SRP-LR Ref Type Further 

Evaluation

Aging Management 

Program (AMP)

Material Environment Related 

Item

Structure and/or 

Component

Related

37 Cracking/ 

stress 

corrosion 

cracking, 

intergranular 

stress 

corrosion 

cracking

NA BWR No Chapter XI.M25, “BWR 

Reactor Water Cleanup 

System”

Stainless 

steel

Treated water 

>60°C 

(>140°F)

A-60 Piping, piping 

components, and 

piping elements

E3.1-a 

E3.2-a 

38 Cracking/ 

stress 

corrosion 

cracking

NA BWR No Chapter XI.M7, “BWR 

Stress Corrosion 

Cracking,” and 

Chapter XI.M2, “Water 

Chemistry,” for BWR 

water

Stainless 

steel

Treated water 

>60°C 

(>140°F)

A-61 Piping, piping 

components, and 

piping elements

E4.1-c 

E4.3-a 

39 Cracking/ 

stress 

corrosion 

cracking

NA BWR No Chapter XI.M2, “Water 

Chemistry,” for BWR 

water

Stainless 

steel

Treated water 

>60°C 

(>140°F)

A-96 Spent fuel storage 

racks 

Storage racks -

BWR

A2.1-c

40 Loss of 

material/ 

general, 

pitting, and 

crevice 

corrosion

NA BWR/ 

PWR

No Chapter XI.M29, 

“Aboveground Steel 

Tanks”

Steel Air – outdoor 

(External)

A-95 Tanks H1.4-b 

41 Cracking/ 

cyclic loading, 

stress 

corrosion 

cracking

NA BWR/ 

PWR

No Chapter XI.M18, “Bolting 

Integrity”

High-strength 

steel

Air with steam 

or water 

leakage

A-04 Closure bolting I.2-b 

42 Loss of 

material/ 

general 

corrosion

NA BWR/ 

PWR

No Chapter XI.M18, “Bolting 

Integrity”

Steel Air with steam 

or water 

leakage

A-03 Closure bolting I.2-a 
NUREG-1833

B-104 October 2005

Table B.3 Auxiliary Systems

ID Aging Effect/ 

Mechanism

SRP-LR Ref Type Further 

Evaluation

Aging Management 

Program (AMP)

Material Environment Related 

Item

Structure and/or 

Component

Related

43 Loss of 

material/ 

general, 

pitting, and 

crevice 

corrosion

NA BWR/ 

PWR

No Chapter XI.M18, “Bolting 

Integrity”

Steel Air – indoor 

uncontrolled 

(External)

AP-27 Closure bolting I.

Air – outdoor 

(External)

AP-28 Bolting I.

44 Loss of 

material/ 

general, 

pitting, and 

crevice 

corrosion

NA BWR/ 

PWR

No Chapter XI.M18, “Bolting 

Integrity”

Steel Condensation A-103 Closure bolting D.2-a

45 Loss of 

preload/ 

thermal 

effects, 

gasket creep, 

and selfloosening 

NA BWR/ 

PWR

No Chapter XI.M18, “Bolting 

Integrity”

Steel Air – indoor 

uncontrolled 

(External)

AP-26 Closure bolting I.

46 Cracking/ 

stress 

corrosion 

cracking

NA BWR/ 

PWR

No Chapter XI.M21, “ClosedCycle Cooling Water 

System”

Stainless 

steel

Closed cycle 

cooling water 

>60°C 

(>140°F)

AP-60 Piping, piping

components, and 

piping elements

C2. E3. 

E4.

Stainless 

steel; steel 

with stainless 

steel cladding

Closed cycle 

cooling water 

>60°C 

(>140°F)

A-68 Heat exchanger 

components

E3.4-a 
October 2005

B-105 NUREG-1833

Table B.3 Auxiliary Systems

ID Aging Effect/ 

Mechanism

SRP-LR Ref Type Further 

Evaluation

Aging Management 

Program (AMP)

Material Environment Related 

Item

Structure and/or 

Component

Related

47 Loss of 

material/ 

general, 

pitting, and 

crevice 

corrosion

NA BWR/ 

PWR

No Chapter XI.M21, “ClosedCycle Cooling Water 

System”

Steel Closed cycle 

cooling water

A-25 Piping, piping 

components, piping 

elements, and tanks

C2.1-a 

C2.2-a 

C2.3-a 

C2.4-a 

C2.5-a 

F1.3-a 

F2.3-a 

F3.3-a 

F4.3-a 

H2.1-a 

48 Loss of 

material/ 

general, 

pitting, 

crevice, and 

galvanic 

corrosion

NA BWR/ 

PWR

No Chapter XI.M21, “ClosedCycle Cooling Water 

System”

Steel Closed cycle 

cooling water

A-63 Heat exchanger 

components

A3.4-a 

A4.4-a 

E1.8-c 

E4.4-a 

C2. E3. 

F1. F2. 

F3. F4.

49 Loss of 

material/ 

microbiologic

ally influenced 

corrosion

NA BWR/ 

PWR

No Chapter XI.M21, “ClosedCycle Cooling Water 

System”

Stainless 

steel; steel 

with stainless 

steel cladding

Closed cycle 

cooling water

A-67 Heat exchanger 

components

E3.4-b 

E4.4-a 

50 Loss of 

material/ 

pitting and 

crevice 

corrosion

NA BWR/ 

PWR

No Chapter XI.M21, “ClosedCycle Cooling Water 

System”

Stainless 

steel

Closed cycle 

cooling water

A-52 Piping, piping 

components, and 

piping elements

C2.2-a 

51 Loss of 

material/ 

pitting, 

crevice, and 

galvanic 

corrosion

NA BWR/ 

PWR

No Chapter XI.M21, “ClosedCycle Cooling Water 

System”

Copper alloy Closed cycle 

cooling water

AP-12 Piping, piping 

components, and 

piping elements

A3. A4. 

C2. E1. 

E3. E4. 

F1. F2. 

F3. F4. 

H1. H2.

AP-34 Heat exchanger 

components

E1. F1. 

F3. 
NUREG-1833

B-106 October 2005

Table B.3 Auxiliary Systems

ID Aging Effect/ 

Mechanism

SRP-LR Ref Type Further 

Evaluation

Aging Management 

Program (AMP)

Material Environment Related 

Item

Structure and/or 

Component

Related

52 Reduction of 

heat transfer/ 

fouling

NA BWR/ 

PWR

No Chapter XI.M21, “ClosedCycle Cooling Water 

System”

Copper alloy Closed cycle 

cooling water

AP-80 Heat exchanger 

tubes

C2. F1. 

F2. F3.

Stainless 

steel

Closed cycle 

cooling water

AP-63 Heat exchanger 

tubes

C2. E3. 

E4. 

Steel Closed cycle 

cooling water

AP-77 Heat exchanger 

tubes

F1. F2. 

F3. F4.

53 Loss of 

material/ 

general and 

pitting 

corrosion

NA BWR/ 

PWR

No Chapter XI.M24, 

“Compressed Air 

Monitoring”

Steel Condensation 

(Internal)

A-26 Compressed air 

system 

Piping, piping 

components, and 

piping elements

D.1-a 

D.2-a 

D.3-a 

D.4-a 

D.5-a 

D.6-a 

54 Loss of 

material/ 

pitting and 

crevice 

corrosion

NA BWR/ 

PWR

No Chapter XI.M24, 

“Compressed Air 

Monitoring”

Stainless 

steel

Condensation 

(Internal)

AP-81 Piping, piping 

components, and 

piping elements

D. 

55 Loss of 

material/ 

general 

corrosion

NA BWR/ 

PWR

No Chapter XI.M36, "External 

Surfaces Monitoring"

Steel Air – indoor 

uncontrolled 

(External)

A-105 Ducting closure 

bolting

F1.1-a 

F2.1-a 

F3.1-a 

F4.1-a I.

56 Loss of 

material/ 

general 

corrosion

NA BWR/ 

PWR

No Chapter XI.M36, "External 

Surfaces Monitoring"

Steel Air – indoor 

uncontrolled 

(External)

A-10 Ducting and 

components external 

surfaces

F1.1-a 

F1.4-a 

F2.1-a 

F2.4-a 

F3.1-a 

F3.4-a 

F4.1-a 

57 Loss of 

material/ 

general 

corrosion

NA BWR/ 

PWR

No Chapter XI.M36, "External 

Surfaces Monitoring"

Steel Air – indoor 

uncontrolled 

(External)

A-80 Piping and 

components external 

surfaces

D.1-a 

D.2-a 

D.3-a 

D.4-a 

D.5-a 

D.6-a 
October 2005

B-107 NUREG-1833

Table B.3 Auxiliary Systems

ID Aging Effect/ 

Mechanism

SRP-LR Ref Type Further 

Evaluation

Aging Management 

Program (AMP)

Material Environment Related 

Item

Structure and/or 

Component

Related

58 Loss of 

material/ 

general 

corrosion

NA BWR/ 

PWR

No Chapter XI.M36, "External 

Surfaces Monitoring"

Steel Air – indoor 

uncontrolled 

(External)

A-77 External surfaces I.1-b 

Air – outdoor 

(External)

A-78 External surfaces I.1-b 

Condensation 

(External)

A-81 External surfaces I.1-b 

59 Loss of 

material/ 

general, 

pitting, and 

crevice 

corrosion

NA BWR/ 

PWR

No Chapter XI.M36, "External 

Surfaces Monitoring"

Steel Air – indoor 

uncontrolled 

(External)

AP-41 Heat exchanger 

components

F1. F2. 

F3. F4. 

G. H2.

Air – outdoor 

(External)

AP-40 Heat exchanger 

components

G. H2.

60 Loss of 

material/ 

general, 

pitting, and 

crevice 

corrosion

NA BWR/ 

PWR

No Chapter XI.M36, "External 

Surfaces Monitoring"

Steel Air – outdoor 

(External)

A-24 Piping, piping 

components, and 

piping elements

H1.1-a 

H1.2-a 

H1.3-a 

61 Increased 

hardness, 

shrinkage and 

loss of 

strength/ 

weathering

NA BWR/ 

PWR

No Chapter XI.M26, “Fire 

Protection”

Elastomers Air – indoor 

uncontrolled

A-19 Fire barrier 

penetration seals

G.1-a 

G.2-a 

G.3-a 

G.4-a 

Air – outdoor A-20 Fire barrier 

penetration seals

G.1-a 

G.2-a 

G.3-a 

G.4-a 
NUREG-1833

B-108 October 2005

Table B.3 Auxiliary Systems

ID Aging Effect/ 

Mechanism

SRP-LR Ref Type Further 

Evaluation

Aging Management 

Program (AMP)

Material Environment Related 

Item

Structure and/or 

Component

Related

62 Loss of 

material/ 

pitting and 

crevice 

corrosion

NA BWR/ 

PWR

No Chapter XI.M26, “Fire 

Protection”

Aluminum Raw water AP-83 Piping, piping 

components, and 

piping elements

G. 

63 Loss of 

material/ wear

NA BWR/ 

PWR

No Chapter XI.M26, “Fire 

Protection”

Steel Air – indoor 

uncontrolled

A-21 Fire rated doors G.1-d 

G.2-d 

G.3-d 

G.4-d 

G.5-c 

Air – outdoor A-22 Fire rated doors G.1-d 

G.2-d 

G.3-d 

G.4-d 

64 Loss of 

material/ 

general, 

pitting, and 

crevice 

corrosion

NA BWR/ 

PWR

No Chapter XI.M26, “Fire 

Protection,” and Chapter 

XI.M30, “Fuel Oil 

Chemistry” 

Steel Fuel oil A-28 Piping, piping 

components, and 

piping elements

G.8-a 

65 Concrete 

cracking and 

spalling/ 

aggressive 

chemical 

attack, and 

reaction with 

aggregates

NA BWR/ 

PWR

No Chapter XI.M26, “Fire 

Protection” and Chapter 

XI.S6, “Structures 

Monitoring Program”

Reinforced 

concrete

Air – indoor 

uncontrolled

A-90 Structural fire 

barriers: 

Walls, ceilings and 

floors

G.1-b 

G.2-b 

G.3-b 

G.4-b 

G.5-a 

66 Concrete 

cracking and 

spalling/ 

freeze-thaw, 

aggressive 

chemical 

attack, and 

reaction with 

aggregates

NA BWR/ 

PWR

No Chapter XI.M26, “Fire 

Protection” and Chapter 

XI.S6, “Structures 

Monitoring Program”

Reinforced 

concrete

Air – outdoor A-92 Structural fire 

barriers: 

Walls, ceilings and 

floors

G.1-b 

G.2-b 

G.3-b 

G.4-b 
October 2005

B-109 NUREG-1833

Table B.3 Auxiliary Systems

ID Aging Effect/ 

Mechanism

SRP-LR Ref Type Further 

Evaluation

Aging Management 

Program (AMP)

Material Environment Related 

Item

Structure and/or 

Component

Related

67 Loss of 

material/ 

corrosion of 

embedded 

steel

NA BWR/ 

PWR

No Chapter XI.M26, “Fire 

Protection” and Chapter 

XI.S6, “Structures 

Monitoring Program”

Reinforced 

concrete

Air – indoor 

uncontrolled

A-91 Structural fire 

barriers: 

Walls, ceilings and 

floors

G.1-c 

G.2-c 

G.3-c 

G.4-c 

G.5-b 

Air – outdoor A-93 Structural fire 

barriers: 

Walls, ceilings and 

floors

G.1-c 

G.2-c 

G.3-c 

G.4-c 

68 Loss of 

material/ 

general, 

pitting, 

crevice, and 

microbiologic

ally influenced 

corrosion, and 

fouling

NA BWR/ 

PWR

No Chapter XI.M27, “Fire 

Water System”

Steel Raw water A-33 Piping, piping 

components, and 

piping elements

G.6-a 

G.6-b 

69 Loss of 

material/ 

pitting and 

crevice 

corrosion, and 

fouling

NA BWR/ 

PWR

No Chapter XI.M27, “Fire 

Water System”

Stainless 

steel

Raw water A-55 Piping, piping 

components, and 

piping elements

G.6-a 

G.6-b 

70 Loss of 

material/ 

pitting, 

crevice, and 

microbiologic

ally influenced 

corrosion, and 

fouling

NA BWR/ 

PWR

No Chapter XI.M27, “Fire 

Water System”

Copper alloy Raw water A-45 Piping, piping 

components, and 

piping elements

G.6-b 
NUREG-1833

B-110 October 2005

Table B.3 Auxiliary Systems

ID Aging Effect/ 

Mechanism

SRP-LR Ref Type Further 

Evaluation

Aging Management 

Program (AMP)

Material Environment Related 

Item

Structure and/or 

Component

Related

71 Loss of 

material/ 

general, 

pitting, and 

crevice 

corrosion

NA BWR/ 

PWR

No Chapter XI.M38, 

"Inspection of Internal 

Surfaces in Miscellaneous 

Piping and Ducting 

Components"

Steel Moist air or 

condensation 

(Internal)

A-23 Piping, piping 

components, and 

piping elements

H2.2-a 

H2.3-a G. 

72 Loss of 

material/ 

general, 

pitting, 

crevice, and 

(for drip pans 

and drain 

lines) 

microbiologic

ally influenced 

corrosion

NA BWR/ 

PWR

No Chapter XI.M38, 

"Inspection of Internal 

Surfaces in Miscellaneous 

Piping and Ducting 

Components"

Steel Condensation 

(Internal)

A-08 Ducting and 

components internal 

surfaces

F1.1-a 

F2.1-a 

F3.1-a 

F4.1-a 

F1.4-a 

F2.4-a 

F3.4-a 

73 Loss of 

material/ 

general 

corrosion

NA BWR/ 

PWR

No Chapter XI.M23, 

“Inspection of Overhead 

Heavy Load and Light 

Load (Related to 

Refueling) Handling 

Systems”

Steel Air – indoor 

uncontrolled 

(External)

A-07 Cranes - Structural 

girders

B.1-b 

74 Loss of 

material/ wear

NA BWR/ 

PWR

No Chapter XI.M23, 

“Inspection of Overhead 

Heavy Load and Light 

Load (Related to 

Refueling) Handling 

Systems”

Steel Air – indoor 

uncontrolled 

(External)

A-05 Cranes - rails B.2-a 

75 Hardening 

and loss of 

strength/ 

elastomer 

degradation

NA BWR/ 

PWR

No Chapter XI.M20, “OpenCycle Cooling Water 

System”

Elastomers Raw water AP-75 Elastomer seals and 

components

C1.

Loss of 

material/ 

erosion

NA BWR/ 

PWR

No Chapter XI.M20, “OpenCycle Cooling Water 

System”

Elastomers Raw water AP-76 Elastomer seals and 

components

C1.
October 2005

B-111 NUREG-1833

Table B.3 Auxiliary Systems

ID Aging Effect/ 

Mechanism

SRP-LR Ref Type Further 

Evaluation

Aging Management 

Program (AMP)

Material Environment Related 

Item

Structure and/or 

Component

Related

76 Loss of 

material/ 

general, 

pitting, 

crevice, and 

microbiologic

ally influenced 

corrosion, 

fouling, and 

lining/coating 

degradation

NA BWR/ 

PWR

No Chapter XI.M20, “OpenCycle Cooling Water 

System”

Steel (with or 

without 

lining/coating 

or with 

degraded 

lining/coating)

Raw water A-38 Piping, piping 

components, and 

piping elements

C1.1-a 

C1.2-a 

C1.5-a 

C1.6-a 

H2.1-b 

C3.1-a 

C3.2-a 

C3.3-a 

77 Loss of 

material/ 

general, 

pitting, 

crevice, 

galvanic, and 

microbiologic

ally influenced

corrosion, and 

fouling

NA BWR/ 

PWR

No Chapter XI.M20, “OpenCycle Cooling Water 

System”

Steel Raw water A-64 Heat exchanger 

components

C1.3-a

78 Loss of 

material/ 

pitting and 

crevice 

corrosion

NA BWR/ 

PWR

No Chapter XI.M20, “OpenCycle Cooling Water 

System”

Copper alloy Raw water A-43 Piping, piping 

components, and 

piping elements

C3.1-a 

C3.2-a 

Nickel alloy Raw water AP-53 Piping, piping 

components, and 

piping elements

C1. C3. 

Stainless 

steel

Raw water A-53 Piping, piping 

components, and 

piping elements

C3.2-a 
NUREG-1833

B-112 October 2005

Table B.3 Auxiliary Systems

ID Aging Effect/ 

Mechanism

SRP-LR Ref Type Further 

Evaluation

Aging Management 

Program (AMP)

Material Environment Related 

Item

Structure and/or 

Component

Related

79 Loss of 

material/ 

pitting and 

crevice 

corrosion, and 

fouling

NA BWR/ 

PWR

No Chapter XI.M20, “OpenCycle Cooling Water 

System”

Stainless 

steel

Raw water A-54 Piping, piping 

components, and 

piping elements

C1.1-a 

C1.2-a 

C1.4-a 

C1.6-a 

80 Loss of 

material/ 

pitting, 

crevice, and 

microbiologic

ally influenced 

corrosion

NA BWR/ 

PWR

No Chapter XI.M20, “OpenCycle Cooling Water 

System”

Copper alloy Raw water AP-45 Piping, piping 

components, and 

piping elements

H2. 

Stainless 

steel

Raw water AP-55 Piping, piping 

components, and 

piping elements

H2.

81 Loss of 

material/ 

pitting, 

crevice, and 

microbiologic

ally influenced 

corrosion, and 

fouling

NA BWR/ 

PWR

No Chapter XI.M20, “OpenCycle Cooling Water 

System”

Copper alloy Raw water A-44 Piping, piping 

components, and 

piping elements

C1.1-a 

C1.2-a 

82 Loss of 

material/ 

pitting, 

crevice, 

galvanic, and 

microbiologic

ally influenced 

corrosion, and 

fouling

NA BWR/ 

PWR

No Chapter XI.M20, “OpenCycle Cooling Water 

System”

Copper alloy Raw water A-65 Heat exchanger 

components

C1.3-a

83 Reduction of 

heat transfer/ 

fouling

NA BWR/ 

PWR

No Chapter XI.M20, “OpenCycle Cooling Water 

System”

Copper alloy Raw water A-72 Heat exchanger 

tubes

C1.3-b 
October 2005

B-113 NUREG-1833

Table B.3 Auxiliary Systems

ID Aging Effect/ 

Mechanism

SRP-LR Ref Type Further 

Evaluation

Aging Management 

Program (AMP)

Material Environment Related 

Item

Structure and/or 

Component

Related

Stainless 

steel

Raw water AP-61 Heat exchanger 

tubes

C1. C3. 

G. H2.

84 Loss of 

material/ 

selective 

leaching

NA BWR/ 

PWR

No Chapter XI.M33, 

“Selective Leaching of 

Materials”

Copper alloy 

>15% Zn

Closed cycle 

cooling water

AP-43 Piping, piping 

components, and 

piping elements

A3. A4. 

C2.E1. 

E3. E4. 

F1. F2.

F3. F4. 

H1. H2.

Raw water A-47 Piping, piping 

components, and 

piping elements

C1.1-a 

C1.2-a 

C3.1-a 

C3.2-a 

G.6-b H2. 

A-66 Heat exchanger 

components

C1.3-a

Treated water AP-32 Piping, piping 

components, and 

piping elements

A4. C2. 

E3. E4.

AP-65 Heat exchanger 

components

E1. F1. 

F3. 

85 Loss of 

material/ 

selective 

leaching

NA BWR/ 

PWR

No Chapter XI.M33, 

“Selective Leaching of 

Materials" 

Gray cast iron Soil A-02 Piping, piping 

components, and 

piping elements

C1.1-c 

C3. G. 

H1. H2.

Chapter XI.M33, 

“Selective Leaching of 

Materials”

Gray cast iron Closed cycle 

cooling water

A-50 Piping, piping 

components, and 

piping elements

C2.3-a 

F3. 

Raw water A-51 Piping, piping 

components, and 

piping elements

C1.5-a 

C3. G. 

H2.

Treated water AP-31 Piping, piping 

components, and 

piping elements

A3. A4. 

C2. E1. 

E3. E4. 

F1. F2. 

F4. G.
NUREG-1833

B-114 October 2005

Table B.3 Auxiliary Systems

ID Aging Effect/ 

Mechanism

SRP-LR Ref Type Further 

Evaluation

Aging Management 

Program (AMP)

Material Environment Related 

Item

Structure and/or 

Component

Related

86 Loss of 

material/ 

general, 

pitting, and 

crevice 

corrosion

NA BWR/ 

PWR

No Chapter XI.S6, “Structures 

Monitoring Program”

Steel Air – indoor 

uncontrolled 

(External)

A-94 Structural Steel A1.1-a 

87 Reduction of 

neutronabsorbing 

capacity/ 

boraflex 

degradation

NA PWR No Chapter XI.M22, “Boraflex 

Monitoring”

Boraflex Treated 

borated water

A-86 Spent fuel storage 

racks 

Neutron-absorbing 

sheets - PWR

A2.1-a 

88 Loss of 

material/ boric 

acid corrosion

NA PWR No Chapter XI.M10, “Boric 

Acid Corrosion”

Aluminum Air with 

borated water 

leakage

AP-1 Piping, piping 

components, and 

piping elements

A3. E1. 

Copper alloy 

>15% Zn

Air with 

borated water 

leakage

AP-66 Piping, piping 

components, and 

piping elements

I.

89 Loss of 

material/ boric 

acid corrosion

NA PWR No Chapter XI.M10, “Boric 

Acid Corrosion”

Steel Air with 

borated water 

leakage

A-102 Bolting I.
October 2005

B-115 NUREG-1833

Table B.3 Auxiliary Systems

ID Aging Effect/ 

Mechanism

SRP-LR Ref Type Further 

Evaluation

Aging Management 

Program (AMP)

Material Environment Related 

Item

Structure and/or 

Component

Related

A-79 External surfaces A3.1-a 

A3.2-b 

A3.2-c 

A3.3-c 

A3.4-b 

A3.5-b 

A3.6-a 

E1.1-b 

E1.2-a 

E1.3-b 

E1.4-a 

E1.5-b 

E1.6-a 

E1.7-b 

E1.8-d 

E1.9-a 

E1.10-a 

I.1-a 

90 Cracking/ 

stress 

corrosion 

cracking

NA PWR No Chapter XI.M2, “Water 

Chemistry,” for PWR 

primary water

Stainless 

steel

Treated 

borated water 

>60°C 

(>140°F)

A-97 Spent fuel storage 

racks 

Storage racks -

PWR

A2.1-c

AP-82 Piping, piping 

components, piping 

elements, and tanks

E1. 

Steel with 

stainless steel 

cladding

Treated 

borated water 

>60°C 

(>140°F)

A-56 Piping, piping 

components, and 

piping elements

A3.3-b 

91 Loss of 

material/ 

pitting and 

crevice 

corrosion

NA PWR No Chapter XI.M2, “Water 

Chemistry,” for PWR 

primary water

Stainless 

steel; steel 

with stainless 

steel cladding

Treated 

borated water

AP-79 Piping, piping 

components, and 

piping elements

E1. A2. 

A3. 
NUREG-1833

B-116 October 2005

Table B.3 Auxiliary Systems

ID Aging Effect/ 

Mechanism

SRP-LR Ref Type Further 

Evaluation

Aging Management 

Program (AMP)

Material Environment Related 

Item

Structure and/or 

Component

Related

92 None NA BWR/ 

PWR

No None Galvanized 

steel

Air – indoor 

uncontrolled

AP-13 Piping, piping 

components, and 

piping elements

J.

93 None NA BWR/ 

PWR

No None Glass Air AP-48 Piping elements J.

Air – indoor 

uncontrolled 

(External)

AP-14 Piping elements J.

Fuel oil AP-49 Piping elements J.

Lubricating oil AP-15 Piping elements J.

Raw water AP-50 Piping elements J.

Treated 

borated water

AP-52 Piping elements J.

Treated water AP-51 Piping elements J.

94 None NA BWR/ 

PWR

No None Nickel alloy Air – indoor 

uncontrolled 

(External)

AP-16 Piping, piping 

components, and 

piping elements

J.

Stainless 

steel

Air – indoor 

uncontrolled 

(External)

AP-17 Piping, piping 

components, and 

piping elements

J.

95 None NA BWR/ 

PWR

No None Aluminum Air – indoor 

controlled 

(External)

AP-36 Piping, piping 

components, and 

piping elements

J.

Steel Air – indoor 

controlled 

(External)

AP-2 Piping, piping 

components, and 

piping elements

J.

96 None NA BWR/ 

PWR

No None Stainless 

steel

Concrete AP-19 Piping, piping 

components, and 

piping elements

J.

Steel Concrete AP-3 Piping, piping 

components, and 

piping elements

J.
October 2005

B-117 NUREG-1833

Table B.3 Auxiliary Systems

ID Aging Effect/ 

Mechanism

SRP-LR Ref Type Further 

Evaluation

Aging Management 

Program (AMP)

Material Environment Related 

Item

Structure and/or 

Component

Related

97 None NA BWR/ 

PWR

No None Aluminum Gas AP-37 Piping, piping 

components, and 

piping elements

J.

Copper alloy Gas AP-9 Piping, piping 

components, and 

piping elements

J.

Stainless 

steel

Gas AP-22 Piping, piping 

components, and 

piping elements

J.

Steel Gas AP-6 Piping, piping 

components, and 

piping elements

J.

98 None NA BWR/ 

PWR

No None Copper alloy Dried Air AP-8 Piping, piping 

components, and 

piping elements

J.

Stainless 

steel

Dried Air AP-20 Piping, piping 

components, and 

piping elements

J.

Steel Dried Air AP-4 Piping, piping 

components , and 

piping elements

J.

99 None NA PWR No None Copper alloy 

<15% Zn

Air with 

borated water 

leakage

AP-11 Piping, piping 

components, and 

piping elements

J.

Stainless 

steel

Air with 

borated water 

leakage

AP-18 Piping, piping 

components, and 

piping elements

J.
NUREG-1833 B-118 October 2005

This Page Intentionally Left Blank
October 2005

B-119 NUREG-1833

B.4 Steam and Power Conversion SRP-LR Development Tool

Table B.4 presents the steam and power conversion SRP-LR development tool.

Table B.4 Steam and Power Conversion

ID Aging Effect/ 

Mechanism

SRP-LR 

Ref

Type Further 

Evaluation

Aging Management 

Program (AMP)

Material Environment Related 

Item

Structure and/or 

Component

Related

1 Cumulative 

fatigue 

damage/ 

fatigue

3.4.2.2.1 BWR/ 

PWR

Yes, 

TLAA

Fatigue is a time-limited 

aging analysis (TLAA) to 

be evaluated for the 

period of extended 

operation. See the 

Standard Review Plan, 

Section 4.3 “Metal 

Fatigue,” for acceptable 

methods for meeting the 

requirements of 10 CFR 

54.21(c)(1).

Steel Steam or 

treated water

S-08 Piping, piping 

components, and 

piping elements

B1.1-b 

B2.1-c 

Treated water S-11 Piping, piping 

components, and 

piping elements

D1.1-b 

D2.1-c 

G.1-b 

2 Loss of 

material/ 

general, 

pitting, and 

crevice 

corrosion

3.4.2.2.2.1 BWR/ 

PWR

Yes, 

detection of 

aging 

effects is to 

be 

evaluated

Chapter XI.M2, “Water 

Chemistry,” for BWR 

water 

The AMP is to be 

augmented by verifying 

the effectiveness of water 

chemistry control. See 

Chapter XI.M32, “OneTime Inspection,” for an 

acceptable verification 

program.

Steel Steam S-04 Piping, piping 

components, and 

piping elements

A.1-b 

A.2-b 

C.1-b 

C.2-b 
NUREG-1833

B-120 October 2005

Table B.4 Steam and Power Conversion

ID Aging Effect/ 

Mechanism

SRP-LR 

Ref

Type Further 

Evaluation

Aging Management 

Program (AMP)

Material Environment Related 

Item

Structure and/or 

Component

Related

Chapter XI.M2, “Water 

Chemistry,” for PWR 

secondary water 

The AMP is to be 

augmented by verifying 

the effectiveness of water 

chemistry control. See 

Chapter XI.M32, “OneTime Inspection,” for an 

acceptable verification 

program.

Steel Steam S-06 Piping, piping 

components, and 

piping elements

A.1-b 

A.2-b 

C.1-b 

C.2-b 

3 Loss of 

material/ 

general, 

pitting, and 

crevice 

corrosion

3.4.2.2.2.1 BWR/ 

PWR

Yes, 

detection of 

aging 

effects is to 

be 

evaluated

Chapter XI.M2, “Water 

Chemistry,” for PWR 

secondary water 

The AMP is to be 

augmented by verifying 

the effectiveness of water 

chemistry control. See 

Chapter XI.M32, “OneTime Inspection,” for an 

acceptable verification 

program.

Steel Treated water S-19 PWR heat 

exchanger 

components

E.4-a 

E.4-d 

F.4-a 

F.4-d 

4 Loss of 

material/ 

general, 

pitting, and 

crevice 

corrosion

3.4.2.2.2.1 BWR/ 

PWR

Yes, 

detection of 

aging 

effects is to 

be 

evaluated

Chapter XI.M2, “Water 

Chemistry,” for BWR 

water 

The AMP is to be 

augmented by verifying 

the effectiveness of water 

chemistry control. See 

Chapter XI.M32, “OneTime Inspection,” for an 

acceptable verification 

program.

Steel Treated water S-09 Piping, piping 

components, and 

piping elements

B2. C. 

D2.1-b 

D2.2-b 

D2.3-b 

E.1-b 

E.2-b 

E.3-a 

E.5-a 

E.6-a 
October 2005

B-121 NUREG-1833

Table B.4 Steam and Power Conversion

ID Aging Effect/ 

Mechanism

SRP-LR 

Ref

Type Further 

Evaluation

Aging Management 

Program (AMP)

Material Environment Related 

Item

Structure and/or 

Component

Related

Chapter XI.M2, “Water 

Chemistry,” for PWR 

secondary water 

The AMP is to be 

augmented by verifying 

the effectiveness of water 

chemistry control. See 

Chapter XI.M32, “OneTime Inspection,” for an 

acceptable verification 

program.

Steel Treated water S-10 Piping, piping 

components, and 

piping elements

B1. C. 

D1.1-c 

D1.2-b 

D1.3-a 

E.1-b 

E.2-b 

E.3-a 

E.5-a 

E.6-a 

F.1-b 

F.2-b 

F.3-a 

G.1-c 

G.2-a 

G.3-a 

G.4-a 

5 Loss of 

material/ 

general (steel 

only), pitting 

and crevice 

corrosion

3.4.2.2.7.1 

for 

stainless 

steel 

componen

ts; 

3.4.2.2.2.1 

for steel 

tanks

BWR/ 

PWR

Yes, 

detection of 

aging 

effects is to 

be 

evaluated

Chapter XI.M2, “Water 

Chemistry” 

The AMP is to be 

augmented by verifying 

the effectiveness of water 

chemistry control. See 

Chapter XI.M32, “OneTime Inspection,” for an 

acceptable verification 

program.

Steel, 

Stainless 

steel

Treated water S-13 Tanks E.5-a 

E.5-b 

G.4-a 

G.4-b 

6 Loss of 

material/ 

general, 

pitting, and 

crevice 

corrosion

3.4.2.2.2.2 BWR/ 

PWR

Yes, 

detection of 

aging 

effects is to 

be 

evaluated

Chapter XI.M39, 

"Lubricating Oil Analysis" 

The AMP is to be 

augmented by verifying 

the effectiveness of the 

lubricating oil analysis 

program . See Chapter 

XI.M32, “One-Time 

Inspection,” for an 

acceptable verification 

program.

Steel Lubricating oil SP-25 Piping, piping 

components, and 

piping elements

A. D1. 

D2. E. G.
NUREG-1833

B-122 October 2005

Table B.4 Steam and Power Conversion

ID Aging Effect/ 

Mechanism

SRP-LR 

Ref

Type Further 

Evaluation

Aging Management 

Program (AMP)

Material Environment Related 

Item

Structure and/or 

Component

Related

7 Loss of 

material/ 

general, 

pitting, 

crevice, and 

microbiologic

ally influenced 

corrosion, and 

fouling

3.4.2.2.3 BWR/ 

PWR

Yes, plantspecificA plant-specific aging 

management program is 

to be evaluated.

Steel Raw water S-12 Piping, piping 

components, and 

piping elements

G.1-d 

8 Reduction of 

heat transfer/ 

fouling

3.4.2.2.4.1 BWR/ 

PWR

Yes, 

detection of 

aging 

effects is to 

be 

evaluated

Chapter XI.M2, “Water 

Chemistry” 

The AMP is to be 

augmented by verifying 

the effectiveness of water 

chemistry control. See 

Chapter XI.M32, “OneTime Inspection,” for an 

acceptable verification 

program.

Copper alloy Treated water SP-58 Heat exchanger 

tubes

E. F. G. 

Stainless 

steel

Treated water SP-40 Heat exchanger 

tubes

E. F.

9 Reduction of 

heat transfer/ 

fouling

3.4.2.2.4.2 BWR/ 

PWR

Yes, 

detection of 

aging 

effects is to 

be 

evaluated

Chapter XI.M39, 

"Lubricating Oil Analysis" 

The AMP is to be 

augmented by verifying 

the effectiveness of the 

lubricating oil analysis 

program. See Chapter 

XI.M32, “One-Time 

Inspection,” for an 

acceptable verification 

program.

Copper alloy Lubricating oil SP-53 Heat exchanger 

tubes

G.

Stainless 

steel

Lubricating oil SP-62 Heat exchanger 

tubes

G.

Steel Lubricating oil SP-63 Heat exchanger 

tubes

G.
October 2005

B-123 NUREG-1833

Table B.4 Steam and Power Conversion

ID Aging Effect/ 

Mechanism

SRP-LR 

Ref

Type Further 

Evaluation

Aging Management 

Program (AMP)

Material Environment Related 

Item

Structure and/or 

Component

Related

10 Loss of 

material/ 

general, 

pitting, 

crevice, and 

microbiologic

ally influenced 

corrosion

3.4.2.2.5.1 BWR/ 

PWR

No 

Yes, 

detection of 

aging 

effects and 

operating 

experience 

are to be 

further 

evaluated

Chapter XI.M28, “Buried 

Piping and Tanks 

Surveillance,” or 

Chapter XI.M34, “Buried 

Piping and Tanks 

Inspection”

Steel (with or 

without 

coating or 

wrapping)

Soil S-01 Buried piping, piping 

components, piping 

elements, and tanks

E.5-d 

G.1-e 

G.4-d 

11 Loss of 

material/ 

general, 

pitting, 

crevice, and 

microbiologic

ally influenced 

corrosion

3.4.2.2.5.2 BWR/ 

PWR

Yes, 

detection of 

aging 

effects is to 

be 

evaluated

Chapter XI.M39, 

"Lubricating Oil Analysis" 

The AMP is to be 

augmented by verifying 

the effectiveness of the 

lubricating oil analysis 

program . See Chapter 

XI.M32, “One-Time 

Inspection,” for an 

acceptable verification 

program.

Steel Lubricating oil S-17 Heat exchanger 

components

G.5-d 

12 Cracking/ 

stress 

corrosion 

cracking

3.4.2.2.6 BWR Yes, 

detection of 

aging 

effects is to 

be 

evaluated

Chapter XI.M2, “Water 

Chemistry,” for BWR 

water 

The AMP is to be 

augmented by verifying 

the effectiveness of water 

chemistry control. See 

Chapter XI.M32, “OneTime Inspection,” for an 

acceptable verification 

program.

Stainless 

steel

Steam SP-45 Piping, piping 

components, and 

piping elements

A. B2.
NUREG-1833

B-124 October 2005

Table B.4 Steam and Power Conversion

ID Aging Effect/ 

Mechanism

SRP-LR 

Ref

Type Further 

Evaluation

Aging Management 

Program (AMP)

Material Environment Related 

Item

Structure and/or 

Component

Related

13 Cracking/ 

stress 

corrosion 

cracking

3.4.2.2.6 BWR/ 

PWR

Yes, 

detection of 

aging 

effects is to 

be 

evaluated

Chapter XI.M2, “Water 

Chemistry,” for BWR 

water 

The AMP is to be 

augmented by verifying 

the effectiveness of water 

chemistry control. See 

Chapter XI.M32, “OneTime Inspection,” for an 

acceptable verification 

program.

Stainless 

steel

Treated water 

>60°C 

(>140°F)

SP-19 Piping, piping 

components, and 

piping elements

E.

Chapter XI.M2, “Water 

Chemistry,” for PWR 

secondary water 

The AMP is to be 

augmented by verifying 

the effectiveness of water 

chemistry control. See 

Chapter XI.M32, “OneTime Inspection,” for an 

acceptable verification 

program.

Stainless 

steel

Treated water 

>60°C 

(>140°F)

S-39 Heat exchanger 

components

F.4-a

SP-17 Piping, piping 

components, and 

piping elements

B1. C. E. 

D1. F. G. 

Chapter XI.M2, “Water 

Chemistry” 

The AMP is to be 

augmented by verifying 

the effectiveness of water 

chemistry control. See 

Chapter XI.M32, “OneTime Inspection,” for an 

acceptable verification 

program.

Stainless 

steel

Treated water 

>60°C 

(>140°F)

SP-42 Tanks E.
October 2005

B-125 NUREG-1833

Table B.4 Steam and Power Conversion

ID Aging Effect/ 

Mechanism

SRP-LR 

Ref

Type Further 

Evaluation

Aging Management 

Program (AMP)

Material Environment Related 

Item

Structure and/or 

Component

Related

14 Loss of 

material/ 

pitting and 

crevice 

corrosion

3.4.2.2.7.1 BWR/ 

PWR

Yes, 

detection of 

aging 

effects is to 

be 

evaluated

Chapter XI.M2, "Water 

Chemistry" 

The AMP is to be 

augmented by verifying 

the effectiveness of water 

chemistry control. See 

Chapter XI.M32, “OneTime Inspection,” for an 

acceptable verification 

program.

Aluminum Treated water SP-24 Piping, piping 

components, and 

piping elements

D1. D2. 

E. F. G.

Copper alloy Treated water SP-61 Piping, piping 

components, and 

piping elements

A. F.

15 Loss of 

material/ 

pitting and 

crevice 

corrosion

3.4.2.2.7.1 BWR/ 

PWR

Yes, 

detection of 

aging 

effects is to 

be 

evaluated

Chapter XI.M2, “Water 

Chemistry,” for BWR 

water 

The AMP is to be 

augmented by verifying 

the effectiveness of water 

chemistry control. See 

Chapter XI.M32, “OneTime Inspection,” for an 

acceptable verification 

program.

Stainless 

steel

Treated water S-21 Heat exchanger 

components

E.4-a 

E.4-d 

Chapter XI.M2, “Water 

Chemistry,” for PWR 

primary water 

The AMP is to be 

augmented by verifying 

the effectiveness of water 

chemistry control. See 

Chapter XI.M32, “OneTime Inspection,” for an 

acceptable verification 

program.

Stainless 

steel

Treated water S-22 PWR heat 

exchanger 

components

E.4-a 

E.4-d 

F.4-a 

F.4-d 
NUREG-1833

B-126 October 2005

Table B.4 Steam and Power Conversion

ID Aging Effect/ 

Mechanism

SRP-LR 

Ref

Type Further 

Evaluation

Aging Management 

Program (AMP)

Material Environment Related 

Item

Structure and/or 

Component

Related

Chapter XI.M2, “Water 

Chemistry” 

The AMP is to be 

augmented by verifying 

the effectiveness of water 

chemistry control. See 

Chapter XI.M32, “OneTime Inspection,” for an 

acceptable verification 

program.

Stainless 

steel

Treated water SP-16 Piping, piping 

components, and 

piping elements

B1. C. 

D1. F. G. 

E. D2. 

16 Loss of 

material/ 

pitting and 

crevice 

corrosion

3.4.2.2.7.2 BWR/ 

PWR

Yes, plantspecificA plant-specific aging 

management program is 

to be evaluated.

Stainless 

steel

Soil SP-37 Piping, piping 

components, and 

piping elements

E. G.

17 Loss of 

material/ 

pitting and 

crevice 

corrosion

3.4.2.2.7.3 BWR/ 

PWR

Yes, 

detection of 

aging 

effects is to 

be 

evaluated

Chapter XI.M39, 

"Lubricating Oil Analysis" 

The AMP is to be 

augmented by verifying 

the effectiveness of the 

lubricating oil analysis 

program . See Chapter 

XI.M32, “One-Time 

Inspection,” for an 

acceptable verification 

program.

Copper alloy Lubricating oil SP-32 Piping, piping 

components, and 

piping elements

A. D1. 

D2. E. G.
October 2005

B-127 NUREG-1833

Table B.4 Steam and Power Conversion

ID Aging Effect/ 

Mechanism

SRP-LR 

Ref

Type Further 

Evaluation

Aging Management 

Program (AMP)

Material Environment Related 

Item

Structure and/or 

Component

Related

18 Loss of 

material/ 

pitting, 

crevice, and 

microbiologic

ally influenced 

corrosion

3.4.2.2.8 BWR/ 

PWR

Yes, 

detection of 

aging 

effects is to 

be 

evaluated

Chapter XI.M39, 

"Lubricating Oil Analysis" 

The AMP is to be 

augmented by verifying 

the effectiveness of the 

lubricating oil analysis 

program . See Chapter 

XI.M32, “One-Time 

Inspection,” for an 

acceptable verification 

program.

Stainless 

steel

Lubricating oil S-20 Heat exchanger 

components

G.5-d 

SP-38 Piping, piping 

components, and 

piping elements

A. D1. 

D2. E. G.

19 Loss of 

material/ 

general, 

pitting, 

crevice, and 

galvanic 

corrosion

3.4.2.2.9 BWR/ 

PWR

Yes, 

detection of 

aging 

effects is to 

be 

evaluated

Chapter XI.M2, “Water 

Chemistry,” for BWR 

water 

The AMP is to be 

augmented by verifying 

the effectiveness of water 

chemistry control. See 

Chapter XI.M32, “OneTime Inspection,” for an 

acceptable verification 

program.

Steel Treated water S-18 Heat exchanger 

components

E.4-a 

E.4-d 

20 Loss of 

material/ 

general, 

pitting, and 

crevice 

corrosion

NA BWR/ 

PWR

No Chapter XI.M29, 

“Aboveground Steel 

Tanks”

Steel Air – outdoor 

(External)

S-31 Tanks E.5-c 

G.4-c 

21 Cracking/ 

cyclic loading, 

stress 

corrosion 

cracking

NA BWR/ 

PWR

No Chapter XI.M18, “Bolting 

Integrity”

High-strength 

steel

Air with steam 

or water 

leakage

S-03 Closure bolting H.2-b 
NUREG-1833

B-128 October 2005

Table B.4 Steam and Power Conversion

ID Aging Effect/ 

Mechanism

SRP-LR 

Ref

Type Further 

Evaluation

Aging Management 

Program (AMP)

Material Environment Related 

Item

Structure and/or 

Component

Related

22 Loss of 

material/ 

general 

corrosion

NA BWR/ 

PWR

No Chapter XI.M18, “Bolting 

Integrity”

Steel Air with steam 

or water 

leakage

S-02 Closure bolting H.2-a 

Loss of 

material/ 

general, 

pitting, and 

crevice 

corrosion

NA BWR/ 

PWR

No Chapter XI.M18, “Bolting 

Integrity”

Steel Air – indoor 

uncontrolled 

(External)

S-34 Closure bolting H.

Air – outdoor 

(External)

S-32 Bolting H.

Loss of 

preload/ 

thermal 

effects, 

gasket creep, 

and selfloosening 

NA BWR/ 

PWR

No Chapter XI.M18, “Bolting 

Integrity”

Steel Air – indoor 

uncontrolled 

(External)

S-33 Closure bolting H.

23 Cracking/ 

stress 

corrosion 

cracking

NA BWR/ 

PWR

No Chapter XI.M21, “ClosedCycle Cooling Water 

System”

Stainless 

steel

Closed cycle 

cooling water 

>60°C 

(>140°F)

SP-54 Piping, piping 

components, and 

piping elements

E. F. G.

24 Loss of 

material/ 

general, 

pitting, 

crevice, and 

galvanic 

corrosion

NA BWR/ 

PWR

No Chapter XI.M21, “ClosedCycle Cooling Water 

System”

Steel Closed cycle 

cooling water

S-23 Heat exchanger 

components

A. E.4-e 

F.4-e 

G.5-c 

25 Loss of 

material/ 

pitting and 

crevice 

corrosion

NA BWR/ 

PWR

No Chapter XI.M21, “ClosedCycle Cooling Water 

System”

Stainless 

steel

Closed cycle 

cooling water

S-25 Heat exchanger 

components

E.4-e 

F.4-e 

G.5-c 
October 2005

B-129 NUREG-1833

Table B.4 Steam and Power Conversion

ID Aging Effect/ 

Mechanism

SRP-LR 

Ref

Type Further 

Evaluation

Aging Management 

Program (AMP)

Material Environment Related 

Item

Structure and/or 

Component

Related

SP-39 Piping, piping 

components, and 

piping elements

E. F. G.

26 Loss of 

material/ 

pitting, 

crevice, and 

galvanic 

corrosion

NA BWR/ 

PWR

No Chapter XI.M21, “ClosedCycle Cooling Water 

System”

Copper alloy Closed cycle 

cooling water

SP-8 Piping, piping 

components, and 

piping elements

E. F. G.

27 Reduction of 

heat transfer/ 

fouling

NA BWR/ 

PWR

No Chapter XI.M21, “ClosedCycle Cooling Water 

System”

Copper alloy Closed cycle 

cooling water

SP-57 Heat exchanger 

tubes

E. 

Stainless 

steel

Closed cycle 

cooling water

SP-41 Heat exchanger 

tubes

E. F. G.

Steel Closed cycle 

cooling water

SP-64 Heat exchanger 

tubes

A. E.4-e 

F.4-e 

G.5-c 

28 Loss of 

material/ 

general 

corrosion

NA BWR/ 

PWR

No Chapter XI.M36, "External 

Surfaces Monitoring"

Steel Air – indoor 

uncontrolled 

(External)

S-29 External surfaces H.1-b 

Air – outdoor 

(External)

S-41 External surfaces H.1-b

Condensation 

(External)

S-42 External surfaces H.1-b

29 Wall thinning/ 

flowaccelerated 

corrosion

NA BWR/ 

PWR

No Chapter XI.M17, “FlowAccelerated Corrosion”Steel Steam S-15 Piping, piping 

components, and 

piping elements

A.1-a 

A.2-a 

B1.1-c 

B1.2-b 

B2.1-b 

B2.2-a 

C.1-a 

C.2-a 
NUREG-1833

B-130 October 2005

Table B.4 Steam and Power Conversion

ID Aging Effect/ 

Mechanism

SRP-LR 

Ref

Type Further 

Evaluation

Aging Management 

Program (AMP)

Material Environment Related 

Item

Structure and/or 

Component

Related

Treated water S-16 Piping, piping 

components, and 

piping elements

D1.1-a 

D1.2-a 

D1.3-b 

D2.1-a 

D2.2-a 

D2.3-a 

E.1-a 

E.2-a 

F.1-a 

F.2-a 

G.1-a 

30 Loss of 

material/ 

general, 

pitting, and 

crevice 

corrosion

NA BWR/ 

PWR

No Chapter XI.M38, 

"Inspection of Internal 

Surfaces in Miscellaneous 

Piping and Ducting 

Components"

Steel Air – outdoor 

(Internal)

SP-59 Piping, piping 

components, and 

piping elements

B1.

Condensation 

(Internal)

SP-60 Piping, piping 

components, and 

piping elements

B1. G.

31 Loss of 

material/ 

general, 

pitting, 

crevice, 

galvanic, and 

microbiologic

ally influenced 

corrosion, and 

fouling

NA BWR/ 

PWR

No Chapter XI.M20, “OpenCycle Cooling Water 

System”

Steel Raw water S-24 Heat exchanger 

components

E.4-b 

F.4-b 

G.5-a 

32 Loss of 

material/ 

pitting, 

crevice, and 

microbiologic

ally influenced 

corrosion

NA BWR/ 

PWR

No Chapter XI.M20, “OpenCycle Cooling Water 

System”

Copper alloy Raw water SP-31 Piping, piping 

components, and 

piping elements

A. E. F. 

G.
October 2005

B-131 NUREG-1833

Table B.4 Steam and Power Conversion

ID Aging Effect/ 

Mechanism

SRP-LR 

Ref

Type Further 

Evaluation

Aging Management 

Program (AMP)

Material Environment Related 

Item

Structure and/or 

Component

Related

Stainless 

steel

Raw water SP-36 Piping, piping 

components, and 

piping elements

E. F. G.

33 Loss of 

material/ 

pitting, 

crevice, and 

microbiologic

ally influenced 

corrosion, and 

fouling

NA BWR/ 

PWR

No Chapter XI.M20, “OpenCycle Cooling Water 

System”

Stainless 

steel

Raw water S-26 Heat exchanger 

components

E.4-b

F.4-b 

G.5-a 

34 Reduction of 

heat transfer/ 

fouling

NA BWR/ 

PWR

No Chapter XI.M20, “OpenCycle Cooling Water 

System”

Copper alloy Raw water SP-56 Heat exchanger 

tubes

E. F. G.

Stainless 

steel

Raw water S-28 Heat exchanger 

tubes

E.4-c 

F.4-c 

G.5-b 

Steel Raw water S-27 Heat exchanger 

tubes

G.5-b 

35 Loss of 

material/ 

selective 

leaching

NA BWR/ 

PWR

No Chapter XI.M33, 

“Selective Leaching of 

Materials”

Copper alloy 

>15% Zn

Closed cycle 

cooling water

SP-29 Piping, piping 

components, and 

piping elements

E. F. G.

Raw water SP-30 Piping, piping 

components, and 

piping elements

A. E. F. 

G.

Treated water SP-55 Piping, piping 

components, and 

piping elements

E. F. G.

36 Loss of 

material/ 

selective 

leaching

NA BWR/ 

PWR

No Chapter XI.M33, 

“Selective Leaching of 

Materials" 

Gray cast iron Soil SP-26 Piping, piping 

components, and 

piping elements

E. G.

Chapter XI.M33, 

“Selective Leaching of 

Materials”

Gray cast iron Raw water SP-28 Piping, piping 

components, and 

piping elements

A. G.
NUREG-1833

B-132 October 2005

Table B.4 Steam and Power Conversion

ID Aging Effect/ 

Mechanism

SRP-LR 

Ref

Type Further 

Evaluation

Aging Management 

Program (AMP)

Material Environment Related 

Item

Structure and/or 

Component

Related

Treated water SP-27 Piping, piping 

components, and 

piping elements

A. E. F. 

G.

37 Loss of 

material/ 

pitting and 

crevice 

corrosion

NA BWR/ 

PWR

No Chapter XI.M2, “Water 

Chemistry,” for BWR 

water

Stainless 

steel

Steam SP-46 Piping, piping 

components, and 

piping elements

A. B2.

Steel Steam S-05 Piping, piping 

components, and 

piping elements

B2.1-a 

B2.2-b 

Chapter XI.M2, “Water 

Chemistry,” for PWR 

secondary water

Nickel-based 

alloys

Steam SP-18 Piping, piping 

components, and 

piping elements

B1.

Stainless 

steel

Steam SP-43 Piping, piping 

components, and 

piping elements

A. B1.

Steel Steam S-07 Piping, piping 

components, and 

piping elements

B1.1-a 

B1.2-a 

38 Loss of 

material/ boric 

acid corrosion

NA PWR No Chapter XI.M10, “Boric 

Acid Corrosion”

Steel Air with 

borated water 

leakage

S-30 External surfaces H.1-a 

S-40 Bolting H.

39 Cracking/ 

stress 

corrosion 

cracking

NA PWR No Chapter XI.M2, “Water 

Chemistry,” for PWR 

secondary water

Stainless 

steel

Steam SP-44 Piping, piping 

components, and 

piping elements

A. B1.

40 None NA BWR/ 

PWR

No None Glass Air SP-33 Piping elements I.

Air – indoor 

uncontrolled 

(External)

SP-9 Piping elements I.

Lubricating oil SP-10 Piping elements I.
October 2005

B-133 NUREG-1833

Table B.4 Steam and Power Conversion

ID Aging Effect/ 

Mechanism

SRP-LR 

Ref

Type Further 

Evaluation

Aging Management 

Program (AMP)

Material Environment Related 

Item

Structure and/or 

Component

Related

Raw water SP-34 Piping elements I.

Treated water SP-35 Piping elements I.

41 None NA BWR/ 

PWR

No None Copper alloy Air – indoor 

uncontrolled 

(External)

SP-6 Piping, piping 

components, and 

piping elements

I.

Nickel alloy Air – indoor 

uncontrolled 

(External)

SP-11 Piping, piping 

components, and 

piping elements

I.

Stainless 

steel

Air – indoor 

uncontrolled 

(External)

SP-12 Piping, piping 

components, and 

piping elements

I.

42 None NA BWR/ 

PWR

No None Steel Air – indoor 

controlled 

(External)

SP-1 Piping, piping 

components, and 

piping elements

I.

43 None NA BWR/ 

PWR

No None Stainless 

steel

Concrete SP-13 Piping, piping 

components, and 

piping elements

I.

Steel Concrete SP-2 Piping, piping 

components, and 

piping elements

I.

44 None NA BWR/ 

PWR

No None Aluminum Gas SP-23 Piping, piping 

components, and 

piping elements

I.

Copper alloy Gas SP-5 Piping, piping 

components, and 

piping elements

I.

Stainless 

steel

Gas SP-15 Piping, piping 

components, and 

piping elements

I.

Steel Gas SP-4 Piping, piping 

components, and 

piping elements

I.
NUREG-1833 B-134 October 2005

This Page Intentionally Left Blank
October 2005

B-135 NUREG-1833

B.5 Structures SRP-LR Development Tool

Table B.5 presents the structures SRP-LR development tool.

Table B.5 Structures

ID Aging Effect/ 

Mechanism

SRP-LR Ref Type Further 

Evaluation

Aging Management Program (AMP) Material Environment Related 

Item

Structure 

and/or 

Component

Related

1 Cracking, loss 

of bond, and 

loss of 

material 

(spalling, 

scaling)/ 

corrosion of 

embedded 

steel

3.5.2.2.1.1 BWR/ 

PWR

Yes, plantspecific if 

environment 

is 

aggressive

Chapter XI.S2, “ASME Section XI, Subsection 

IWL.”

Accessible Areas: 

Inspections performed in accordance with IWL 

will indicate the presence of surface cracking, 

loss of bond, and loss of material (spalling, 

scaling) due to corrosion of embedded steel. 

Inaccessible Areas: 

For plants with non-aggressive ground 

water/soil; i.e., pH > 5.5, chlorides < 500 ppm, or 

sulfates <1500 ppm, as a minimum, consider (1) 

Examination of the exposed portions of the 

below grade concrete, when excavated for any 

reason, and 

(2) Periodic monitoring of below-grade water 

chemistry, including consideration of potential 

seasonal variations. 

For plants with aggressive groundwater/soil, 

and/or where the concrete structural elements 

have experienced degradation, a plant specific 

AMP accounting for the extent of the 

degradation experienced should be 

implemented to manage the concrete aging 

during the period of extended operation.

Concrete; 

steel

Air – indoor 

uncontrolled 

or air –

outdoor

C-05 Concrete: 

Dome; wall; 

basemat; ring 

girders; 

buttresses;

reinforcing steel

A1.1-e 

C-41 Concrete: 

Basemat; 

reinforcing steel

B2.2.1-d 

B1.2. 

C-42 Concrete: 

Dome; wall; 

basemat; 

reinforcing steel

B3.2.1-e
NUREG-1833

B-136 October 2005

Table B.5 Structures

ID Aging Effect/ 

Mechanism

SRP-LR Ref Type Further 

Evaluation

Aging Management Program (AMP) Material Environment Related 

Item

Structure 

and/or 

Component

Related

Chapter XI.S2, “ASME Section XI, Subsection 

IWL.”

Accessible Areas: 

Inspections performed in accordance with IWL 

will indicate the presence of surface cracking, 

loss of bond, and loss of material (spalling, 

scaling) due to corrosion of embedded steel. 

Inaccessible Areas: 

For plants with non-aggressive ground 

water/soil; i.e., pH > 5.5, chlorides < 500 ppm, or 

sulfates <1500 ppm, as a minimum, consider (1) 

Examination of the exposed portions of the 

below grade concrete, when excavated for any 

reason, and 

(2) Periodic monitoring of below-grade water 

chemistry, including consideration of potential 

seasonal variations. 

For plants with aggressive groundwater/soil, 

and/or where the concrete structural elements 

have experienced degradation, a plant specific 

AMP accounting for the extent of the 

degradation experienced should be 

implemented to manage the concrete aging 

during the period of extended operation. 

Concrete; 

steel

Air – indoor 

uncontrolled 

or air –

outdoor

C-43 Concrete: 

Basemat; 

reinforcing steel

A2.2-e 

B3.1.2-d 
October 2005

B-137 NUREG-1833

Table B.5 Structures

ID Aging Effect/ 

Mechanism

SRP-LR Ref Type Further 

Evaluation

Aging Management Program (AMP) Material Environment Related 

Item

Structure 

and/or 

Component

Related

Increase in 

porosity and 

permeability, 

cracking, loss 

of material 

(spalling, 

scaling)/ 

aggressive 

chemical 

attack

3.5.2.2.1.1 BWR/ 

PWR

Yes, plantspecific if 

environment 

is 

aggressive

Chapter XI.S2, “ASME Section XI, Subsection 

IWL.”

Accessible Areas: 

Inspections performed in accordance with IWL 

will indicate the presence of increase in porosity 

and permeability, surface cracking, or loss of 

material (spalling, scaling) due to aggressive 

chemical attack. 

Inaccessible Areas: 

For plants with non-aggressive ground 

water/soil; i.e., pH > 5.5, chlorides < 500 ppm, or 

sulfates <1500 ppm, as a minimum, consider (1) 

Examination of the exposed portions of the 

below grade concrete, when excavated for any 

reason, and 

(2) Periodic monitoring of below-grade water 

chemistry, including consideration of potential 

seasonal variations. 

For plants with aggressive groundwater/soil, 

and/or where the concrete structural elements 

have experienced degradation, a plant specific 

AMP accounting for the extent of the 

degradation experienced should be 

implemented to manage the concrete aging 

during the period of extended operation.

Concrete Ground 

water/soil or 

air-indoor 

uncontrolled 

or air-outdoor

C-03 Concrete: 

Dome; wall; 

basemat; ring 

girders; 

buttresses

A1.1-c 

C-25 Concrete: 

Basemat

A2.2-c 

B.3.1.2-b

C-26 Concrete: 

Containment; 

wall; basemat

B.2.2.1-b

B.1.2. 

C-27 Concrete: 

Dome; wall; 

basemat

B3.2.1-c
NUREG-1833

B-138 October 2005

Table B.5 Structures

ID Aging Effect/ 

Mechanism

SRP-LR Ref Type Further 

Evaluation

Aging Management Program (AMP) Material Environment Related 

Item

Structure 

and/or 

Component

Related

2 Cracks and 

distortion due 

to increased 

stress levels 

from 

settlement

3.5.2.2.1.2 BWR/ 

PWR

Yes, if not 

within the 

scope of the 

applicant’s 

structures 

monitoring 

program or 

a dewatering 

system is 

relied upon

Chapter XI.S6, “Structures Monitoring Program” 

If a de-watering system is relied upon for control 

of settlement, then the licensee is to ensure 

proper functioning of the de-watering system 

through the period of extended operation. 

Concrete Soil C-06 Concrete 

elements; All

B2.2.1-e 

B3.2.1-f 

B1.2. 

C-36 Concrete: 

Basemat

A2.2-f 

B3.1.2-e 

C-37 Concrete: 

Dome; wall; 

basemat; ring 

girders; 

buttresses

A1.1-f 

3 Reduction in 

foundation 

strength, 

cracking, 

differential 

settlement/ 

erosion of 

porous 

concrete 

subfoundation

3.5.2.2.1.2 BWR/ 

PWR

Yes, if not 

within the 

scope of the 

applicant’s 

structures 

monitoring 

program or 

a dewatering 

system is 

relied upon

Chapter XI.S6, “Structures Monitoring Program” 

Erosion of cement from porous concrete 

subfoundations beneath containment basemats 

is described in NRC IN 97-11. IN 98-26 

proposes Maintenance Rule Structures 

Monitoring for managing this aging effect, if 

applicable. If a de-watering system is relied 

upon for control of erosion of cement from 

porous concrete subfoundations, then the 

licensee is to ensure proper functioning of the 

de-watering system through the period of 

extended operation.

Concrete; 

porous 

concrete

Water –

flowing

C-07 Concrete: 

Foundation; 

subfoundation

A1.1-g 

A2.2-g 

B2.2.1-f 

B3.1.2-f 

B3.2.1-g 

B1.2.
October 2005

B-139 NUREG-1833

Table B.5 Structures

ID Aging Effect/ 

Mechanism

SRP-LR Ref Type Further 

Evaluation

Aging Management Program (AMP) Material Environment Related 

Item

Structure 

and/or 

Component

Related

4 Reduction of 

strength and 

modulus/ 

elevated 

temperature 

(>150°F 

general; 

>200°F local)

3.5.2.2.1.3 BWR/ 

PWR

Yes, if 

temperature 

limits are 

exceeded

Concrete Air – indoor 

uncontrolled 

or air –

outdoor

C-33 Concrete: 

Dome; wall; 

basemat

B3.2.1-h

C-34 Concrete: 

Basemat

A2.2-h 

C-35 Concrete: 

Containment; 

wall; basemat

B2.2.1-g 

B1.2.

Plant-specific aging managem ent program 

The implementation of 10 CFR 50.55a and 

ASME Section XI, Subsection IWL would not be 

able to identify the reduction of strength and 

modulus due to elevated temperature. Thus, for 

any portions of concrete containment that 

exceed specified temperature limits, further 

evaluations are warranted. Subsection CC-3400 

of ASME Section III, Division 2, specifies the 

concrete temperature limits for normal operation 

or any other long-term period. The temperatures 

shall not exceed 150°F except for local areas, 

such as around penetrations, which are not 

allowed to exceed 200°F. If significant 

equipment loads are supported by concrete at 

temperatures exceeding 150°F, an evaluation of 

the ability to withstand the postulated design 

loads is to be made. 

Higher temperatures than given above may be 

allowed in the concrete if tests and/or 

calculations are provided to evaluate the 

reduction in strength and this reduction is 

applied to the design allowables.

C-50 Concrete: 

Basemat, 

concrete fill-in 

annulus

B3.1.2-g
NUREG-1833

B-140 October 2005

Table B.5 Structures

ID Aging Effect/ 

Mechanism

SRP-LR Ref Type Further 

Evaluation

Aging Management Program (AMP) Material Environment Related 

Item

Structure 

and/or 

Component

Related

Plant-specific aging management program 

The implementation of 10 CFR 50.55a and 

ASME Section XI, Subsection IWL would not be 

able to identify the reduction of strength and 

modulus of elasticity due to elevated 

temperature. Thus, for any portions of concrete 

containment that exceed specified temperature 

limits, further evaluations are warranted. 

Subsection CC-3400 of ASME Section III, 

Division 2, specifies the concrete temperature 

limits for normal operation or any other longterm period. The temperatures shall not exceed 

150°F except for local areas, such as around 

penetrations, which are not allowed to exceed 

200°F. If significant equipment loads are 

supported by concrete at temperatures 

exceeding 150°F, an evaluation of the ability to 

withstand the postulated design loads is to be 

made. 

Higher temperatures than given above may be 

allowed in the concrete if tests and/or 

calculations are provided to evaluate the 

reduction in strength and this reduction is 

applied to the design allowables.

Concrete Air – indoor 

uncontrolled 

or air –

outdoor

C-08 Concrete: 

Dome; wall; 

basemat; ring 

girder; 

buttresses

A1.1-h
October 2005

B-141 NUREG-1833

Table B.5 Structures

ID Aging Effect/ 

Mechanism

SRP-LR Ref Type Further 

Evaluation

Aging Management Program (AMP) Material Environment Related 

Item

Structure 

and/or 

Component

Related

5 Loss of 

material/ 

general, 

pitting, and 

crevice 

corrosion

3.5.2.2.1.4 BWR Yes, if 

corrosion is 

significant 

for 

inaccessible 

areas 

No

Chapter XI.S1, “ASME Section XI, Subsection 

IWE” 

For inaccessible areas (embedded containment 

steel shell or liner), loss of material due to 

corrosion is not significant if the following 

conditions are satisfied: 

Concrete meeting the specifications of ACI 318 

or 349 and the guidance of 201.2R was used for 

the containment concrete in contact with the 

embedded containment shell or liner. The 

concrete is monitored to ensure that it is free of 

penetrating cracks that provide a path for water 

seepage to the surface of the containment shell 

or liner. The moisture barrier, at the junction 

where the shell or liner becomes embedded, is 

subject to aging management activities in 

accordance with ASME Section XI, Subsection 

IWE requirements. Water ponding on the 

containment concrete floor are not common and 

when detected are cleaned up in a timely 

manner. 

If any of the above conditions cannot be 

satisfied, then a plant-specific aging 

management program for corrosion is 

necessary.

Chapter XI.S4, “10 CFR Part 50, Appendix J”

Steel Air – indoor 

uncontrolled 

or treated 

water (as 

applicable)

C-46 Steel elements: 

 Suppression 

chamber; 

drywell liner; 

drywell head; 

embedded 

shell; sand 

pocket region; 

support skirt; 

downcomer 

pipes; region 

shielded by 

diaphragm floor 

NOTE: 

Inspection of 

containment 

supports is 

addressed by 

ASME 

Section XI, 

Subsection IWF 

(see III.B1.3) 

B2.1.1-a 

B2.2.2-a 

B1.2.

Yes, if 

corrosion is 

significant 

for 

inaccessible 

areas 

Chapter XI.S1, “ASME Section XI, Subsection 

IWE” 

For inaccessible areas (embedded containment 

steel shell or liner), loss of material due to 

corrosion is not significant if the following 

conditions are satisfied: 

Concrete meeting the specifications of ACI 318 

or 349 and the guidance of 201.2R was used for 

the containment concrete in contact with the 

embedded containment shell or liner. The 

concrete is monitored to ensure that it is free of 

penetrating cracks that provide a path for water 

Steel Air – indoor 

uncontrolled 

or treated 

water (as 

applicable)

C-19 Steel elements: 

Drywell; torus; 

drywell 

head; 

embedded shell 

and sand 

pocket regions; 

drywell support 

skirt; 

torus ring girder; 

downcomers; 

ECCS 

B1.1.1-a 

B3.1.1-a
NUREG-1833

B-142 October 2005

Table B.5 Structures

ID Aging Effect/ 

Mechanism

SRP-LR Ref Type Further 

Evaluation

Aging Management Program (AMP) Material Environment Related 

Item

Structure 

and/or 

Component

Related

 No

seepage to the surface of the containment shell 

or liner. The moisture barrier, at the junction 

where the shell or liner becomes embedded, is 

subject to aging management activities in 

accordance with ASME Section XI, Subsection 

IWE requirements. Water ponding on the 

containment concrete floor are not common and 

when detected are cleaned up in a timely 

manner. 

If any of the above conditions cannot be 

satisfied, then a plant-specific aging 

management program for corrosion is necessary

suction header 

NOTE: 

Inspection of 

containment 

supports is 

addressed by 

ASME 

Section XI, 

Subsection IWF 

(see III.B1.3) 
October 2005

B-143 NUREG-1833

Table B.5 Structures

ID Aging Effect/ 

Mechanism

SRP-LR Ref Type Further 

Evaluation

Aging Management Program (AMP) Material Environment Related 

Item

Structure 

and/or 

Component

Related

6 Loss of 

material/ 

general, 

pitting, and 

crevice 

corrosion

3.5.2.2.1.4 BWR/ 

PWR

Yes, if 

corrosion is 

significant 

for 

inaccessible 

areas 

 No

Chapter XI.S1, “ASME Section XI, Subsection 

IWE” 

For inaccessible areas (embedded containment 

steel shell or liner), loss of material due to 

corrosion is not significant if the following 

conditions are satisfied: 

1. Concrete meeting the requirements of ACI 

318 or 349 and the guidance of 201.2R was 

used for the containment concrete in contact 

with the embedded containment shell or liner. 

2. The concrete is monitored to ensure that it is 

free of penetrating cracks that provide a path for 

water seepage to the surface of the containment 

shell or liner. 

3. The moisture barrier, at the junction where 

the shell or liner becomes embedded, is subject 

to aging management activities in accordance 

with ASME Section XI, Subsection IWE 

requirements . 

4. Borated water spills and water ponding on the 

containment concrete floor are not common and 

when detected are cleaned up in a timely 

manner. 

If any of the above conditions cannot be 

satisfied, then a plant-specific aging 

management program for corrosion is 

necessary.

Chapter XI.S4, “10 CFR Part 50, Appendix J”

Steel Air – indoor 

uncontrolled

C-09 Steel elements: 

Liner; 

Liner anchors; 

Integral 

attachments

A1.2-a 

A2.1-a 

B3.2.2-a
NUREG-1833

B-144 October 2005

Table B.5 Structures

ID Aging Effect/ 

Mechanism

SRP-LR Ref Type Further 

Evaluation

Aging Management Program (AMP) Material Environment Related 

Item

Structure 

and/or 

Component

Related

7 Loss of 

prestress/ 

relaxation; 

shrinkage; 

creep; 

elevated 

temperature

3.5.2.2.1.5 BWR/ 

PWR

Yes, 

TLAA

Loss of tendon prestress is a time-limited aging 

analysis (TLAA) to be evaluated for the period of 

extended operation. 

See the Standard Review Plan, Section 4.5, 

“Concrete Containment Tendon Prestress” for 

acceptable methods for meeting the 

requirements of 10 CFR 54.21(c)(1)(i) and (ii). 

See Chapter X.S1 of this report for meeting the 

requirements of 10 CFR 54.21(c)(1)(iii). 

For periodic monitoring of prestress, see 

Chapter XI.S2. 

Steel Air – indoor 

uncontrolled 

or air –

outdoor

C-11 Prestressing 

system: 

Tendons

A1.3-b 

B2.2.3-b

8 Cumulative 

fatigue 

damage/ 

fatigue 

(Only if CLB 

fatigue 

analysis 

exists)

3.5.2.2.1.6 BWR Yes, 

TLAA

Fatigue is a time-limited aging analysis (TLAA) 

to be evaluated for the period of extended 

operation. See the Standard Review Plan, 

Section 4.6, “Containment Liner Plate and 

Penetration Fatigue Analysis” for acceptable 

methods for meeting the requirements of 

10 CFR 54.21(c)(1).

Stainless 

steel; steel

Air – indoor 

uncontrolled

C-21 Steel elements: 

Torus; 

Vent line; 

Vent header; 

Vent line 

bellows; 

Downcomers 

B1.1.1-c 

Air – indoor 

uncontrolled 

or treated 

water (as 

applicable)

C-48 Steel elements: 

Vent header; 

Downcomers 

B2.2.2-d

9 Cumulative 

fatigue 

damage/ 

fatigue 

(Only if CLB 

fatigue 

analysis 

exists)

3.5.2.2.1.6 BWR/ 

PWR

Yes, 

TLAA

Fatigue is a time-limited aging analysis (TLAA) 

to be evaluated for the period of extended 

operation. See the Standard Review Plan, 

Section 4.6, “Containment Liner Plate and 

Penetration Fatigue Analysis” for acceptable 

methods for meeting the requirements of 

10 CFR 54.21(c)(1).

Steel; 

stainless 

steel; 

dissimilar 

metal welds

Air – indoor 

uncontrolled 

or air –

outdoor

C-13 Penetration 

sleeves; 

Penetration 

bellows

A3.1-b 

B4.1-b 
October 2005

B-145 NUREG-1833

Table B.5 Structures

ID Aging Effect/ 

Mechanism

SRP-LR Ref Type Further 

Evaluation

Aging Management Program (AMP) Material Environment Related 

Item

Structure 

and/or 

Component

Related

Fatigue is a time-limited aging analysis (TLAA) 

to be evaluated for the period of extended 

operation. See the Standard Review Plan, 

Section 4.6, “Containment Liner Plate and 

Penetration Fatigue Analysis” for acceptable 

methods for meeting the requirements of 

10 CFR 54.21(c)(1).

Steel; 

stainless 

steel; 

dissimilar 

metal welds

Air – indoor 

uncontrolled 

or air –

outdoor

C-45 Suppression 

pool shell; 

unbraced 

downcomers

B2.1.1-c 

10 Cracking/ 

stress 

corrosion 

cracking

3.5.2.2.1.7 BWR/ 

PWR

Yes, 

detection of 

aging 

effects is to 

be 

evaluated

Chapter XI.S1, “ASME Section XI, Subsection 

IWE” and Chapter XI.S4, “10 CFR Part 50, 

Appendix J” 

Evaluation of 10 CFR 50.55a/ASME Section XI, 

Subsection IWE is augmented as follows: 

(4) Detection of Aging Effects: 

Transgranular Stress corrosion cracking 

(TGSCC) is a concern for dissimilar metal 

welds. In the case of bellows assemblies, SCC 

may cause aging effects particularly if the 

material is not shielded from a corrosive 

environment. ASME Section XI, Subsection IWE 

covers inspection of these items under 

examination categories E-B, E-F, and E-P 

(10 CFR Part 50, Appendix J pressure tests). 

10 CFR 50.55a identifies examination 

categories E-B and E-F as optional during the 

current term of operation. For the extended 

period of operation, Examination Categories E-B 

& E-F, and additional appropriate examinations 

to detect SCC in bellows assemblies and 

dissimilar metal welds are warranted to address 

this issue. 

(10) Operating Experience: 

IN 92-20 describes an instance of containment 

bellows cracking, resulting in loss of leak 

tightness.

Stainless 

steel; 

dissimilar 

metal welds

Air – indoor 

uncontrolled 

or air –

outdoor

C-15 Penetration 

sleeves; 

Penetration 

bellows

A3.1-d 

B4.1-d
NUREG-1833

B-146 October 2005

Table B.5 Structures

ID Aging Effect/ 

Mechanism

SRP-LR Ref Type Further 

Evaluation

Aging Management Program (AMP) Material Environment Related 

Item

Structure 

and/or 

Component

Related

11 Cracking/ 

stress 

corrosion 

cracking

3.5.2.2.1.7 BWR Yes, 

detection of 

aging 

effects is to 

be 

evaluated

Chapter XI.S1, “ASME Section XI, Subsection 

IWE “ and Chapter XI.S4, “10 CFR Part 50, 

Appendix J” 

Evaluation of 10 CFR 50.55a/ASME Section XI, 

Subsection IWE is augmented as follows: 

(4) Detection of Aging Effects: Stress corrosion 

cracking (SCC) is a concern for dissimilar metal 

welds. In the case of bellows assemblies, SCC 

may cause aging effects particularly if the 

material is not shielded from a corrosive 

environment. ASME Code 1995 edition, with 

addenda through 1996, ASME Section XI, 

Subsection IWE covers inspection of these 

items under Examination Categories E-B, E-F, 

and E-P (10 CFR Part 50, Appendix J pressure 

tests). 10 CFR 50.55a identifies examination 

categories E-B and E-F as optional during the 

current term of operation. For the extended 

period of operation, Examination Categories E-B 

and E-F, and additional appropriate 

examinations to detect SCC in bellows 

assemblies and dissimilar metal welds are 

warranted to address this issue. 

(10) Operating Experience: IN 92-20 describes

an instance of containment bellows cracking, 

resulting in loss of leak tightness.

Stainless 

steel

Air – indoor 

uncontrolled

C-22 Steel elements: 

Vent line 

bellows

B1.1.1-d

12 Cracking/ 

cyclic loading 

(CLB fatigue 

analysis does 

not exist)

3.5.2.2.1.8 BWR/ 

PWR

Yes, 

detection of 

aging 

effects is to 

be 

evaluated

Steel; 

stainless 

steel; 

dissimilar 

metal welds

Air – indoor 

uncontrolled 

or air –

outdoor

C-14 Penetration 

sleeves; 

Penetration 

bellows

A3.1-c 

B4.1-c 

Chapter XI.S1, “ASME Section XI, Subsection 

IWE ” and Chapter XI.S4, “10 CFR Part 50, 

Appendix J” 

Evaluation of 10 CFR 50.55a/ASME Section XI, 

Subsection IWE is to be supplemented to 

consider the following: 

(4) Detection of Aging Effects: VT-3 visual 

inspection may not detect fine cracks. C-44 Suppression 

pool shell; 

unbraced 

downcomers

B2.1.1-b 
October 2005

B-147 NUREG-1833

Table B.5 Structures

ID Aging Effect/ 

Mechanism

SRP-LR Ref Type Further 

Evaluation

Aging Management Program (AMP) Material Environment Related 

Item

Structure 

and/or 

Component

Related

13 Cracking/ 

cyclic loading 

(CLB fatigue 

analysis does 

not exist)

3.5.2.2.1.8 BWR Yes, 

detection of 

aging 

effects is to 

be 

evaluated

Chapter XI.S1, “ASME Section XI, Subsection 

IWE ” and Chapter XI.S4, “10 CFR Part 50, 

Appendix J” 

Evaluation of 10 CFR 50.55a/ ASME Section XI, 

Subsection IWE is augmented as follows: 

(4) Detection of Aging Effects: VT-3 visual 

inspection may not detect fine cracks.

Stainless 

steel; steel

Air – indoor 

uncontrolled

C-20 Steel elements: 

Torus; 

Vent line; 

Vent header; 

Vent line 

bellows ; 

Downcomers 

B1.1.1-b 

Chapter XI.S1, “ASME Section XI, Subsection 

IWE ” and Chapter XI.S4, “10 CFR Part 50, 

Appendix J” 

Evaluation of 10 CFR 50.55a/ASME Section XI, 

Subsection IWE is augmented as follows: 

(4) Detection of Aging Effects: VT-3 visual 

inspection may not detect fine cracks.

Stainless 

steel; steel

Air – indoor 

uncontrolled

C-47 Steel elements: 

Vent header; 

Downcomers 

B2.2.2-c

14 Loss of 

material 

(spalling, 

scaling) and 

cracking/ 

freeze-thaw

3.5.2.2.1.9 BWR/ 

PWR

Yes, for 

inaccessible 

areas of

plants 

located in 

moderate to 

severe 

weathering 

conditions

Concrete Air – outdoor C-01 Concrete: 

Dome; wall; 

basemat; ring 

girders; 

buttresses

A1.1-a 

C-28 Concrete: 

Basemat

Yes, for A2.2-a

inaccessible 

areas of 

plants 

located in 

moderate to 

severe 

weathering 

conditions

Chapter XI.S2, “ASME Section XI, Subsection 

IWL” 

Accessible areas: 

Inspections performed in accordance with IWL 

will indicate the presence of loss of material 

(spalling, scaling) and surface cracking due to 

freeze-thaw. 

Inaccessible Areas: 

Evaluation is needed for plants that are located 

in moderate to severe weathering conditions 

(weathering index >100 day-inch/yr) (NUREG1557). Documented evidence confirms that 

where the existing concrete had air content of 

3% to 6%, subsequent inspections did not 

exhibit degradation related to freeze-thaw. Such 

inspections should be considered a part of the 

evaluation. 

The weathering index for the continental US is 

shown in ASTM C33-90, Fig. 1.

C-29 Concrete: 

Dome; wall; 

basemat

B3.2.1-a 
NUREG-1833

B-148 October 2005

Table B.5 Structures

ID Aging Effect/ 

Mechanism

SRP-LR Ref Type Further 

Evaluation

Aging Management Program (AMP) Material Environment Related 

Item

Structure 

and/or 

Component

Related

15 Cracking due 

to expansion/ 

reaction with 

aggregates

3.5.2.2.1.10 BWR/ 

PWR

Yes, if 

concrete 

was not 

constructed 

as stated for 

inaccessible 

areas

Concrete Any C-04 Concrete: 

Dome; wall; 

basemat; ring 

girders; 

buttresses

A1.1-d 

C-38 Concrete: 

Basemat

A2.2-d

C-39 Concrete: 

Containment;

wall; basemat

B2.2.1-c 

B1.2.

C-40 Concrete: 

Dome; wall; 

basemat

B3.2.1-d

Chapter XI.S2, “ASME Section XI, Subsection 

IWL.”

Accessible Areas: 

Inspections performed in accordance with IWL 

will indicate the presence of surface cracking 

due to reaction with aggregates. 

Inaccessible Areas: 

As described in NUREG-1557, investigations, 

tests, and petrographic examinations of 

aggregates performed in accordance with ASTM 

C295-54 or ASTM C227-50 can demonstrate 

that those aggregates do not react within 

reinforced concrete. For potentially reactive 

aggregates, aggregate-reinforced concrete 

reaction is not significant if the concrete was 

constructed in accordance with ACI 

201.2R.Therefore, if these conditions are 

satisfied, aging management program is not 

necessary.

C-51 Concrete: 

Basemat, 

concrete fill-in 

annulus

B3.1.2-c 

Increase in 

porosity, 

permeability/ 

leaching of 

calcium 

hydroxide

3.5.2.2.1.10 BWR/ 

PWR

Yes, if 

concrete 

was not 

constructed 

as stated for 

inaccessible 

areas

Concrete Water –

flowing

C-02 Concrete: 

Dome; wall; 

basemat; ring 

girders; 

buttresses

Chapter XI.S2, “ASME Section XI, Subsection A1.1-b 

IWL” 

Accessible areas: 

Inspections performed in accordance with IWL 

will indicate the presence of increase in porosity, 

and permeability due to leaching of calcium 

hydroxide. 

Inaccessible Areas: 

An aging management program is not 

necessary, even if reinforced concrete is 

exposed to flowing water, if there is documented 

evidence that confirms the in-place concrete 

was constructed in accordance with the 

recommendations in ACI 201.2R.

C-32 Concrete: 

Dome; wall; 

basemat

B3.2.1-b
October 2005

B-149 NUREG-1833

Table B.5 Structures

ID Aging Effect/ 

Mechanism

SRP-LR Ref Type Further 

Evaluation

Aging Management Program (AMP) Material Environment Related 

Item

Structure 

and/or 

Component

Related

Chapter XI.S2, “ASME Section XI, Subsection 

IWL” 

Accessible areas: 

Inspections performed in accordance with IWL 

will indicate the presence of increase in porosity, 

and permeability due to leaching of calcium 

hydroxide. 

Inaccessible Areas: 

 An aging management program is not 

necessary, even if reinforced concrete is 

exposed to flowing water, if there is documented 

evidence that confirms the in-place concrete 

was constructed in accordance with the 

recommendations in ACI 201.2R.

Concrete Water –

flowing

C-30 Concrete: 

Basemat

A2.2-b 

B3.1.2-a

C-31 Concrete: 

Containm ent; 

wall; basemat

B2.2.1-a 

B1.2. 

16 Loss of 

sealing; 

Leakage 

through 

containment/ 

deterioration 

of seals, 

gaskets, and 

moisture 

barriers 

(caulking, 

flashing, and 

other 

sealants)

NA BWR/ 

PWR

No Chapter XI.S1, “ASME Section XI, Subsection 

IWE” 

Leak tightness will be monitored by 10 CFR 

Part 50, Appendix J Leak Rate Tests for 

pressure boundary, seals and gaskets (including 

O-rings).

Elastomers, 

rubber and 

other similar 

materials

Air – indoor 

uncontrolled 

or air –

outdoor

C-18 Seals, gaskets, 

and moisture 

barriers 

(caulking, 

flashing, and 

other sealants)

A3.3-a 

B4.3-a
NUREG-1833

B-150 October 2005

Table B.5 Structures

ID Aging Effect/ 

Mechanism

SRP-LR Ref Type Further 

Evaluation

Aging Management Program (AMP) Material Environment Related 

Item

Structure 

and/or 

Component

Related

17 Loss of leak 

tightness/ 

mechanical 

wear of locks, 

hinges and 

closure 

mechanisms

NA BWR/ 

PWR

No Chapter XI.S4, “10 CFR Part 50, Appendix J” 

and 

Plant Technical Specifications

Steel Air – indoor 

uncontrolled 

or air outdoor

C-17 Personnel 

airlock, 

equipment 

hatch, CRD 

hatch: 

Locks, hinges, 

and closure 

mechanisms

A3.2-b 

B4.2-b

18 Loss of 

material/ 

general, 

pitting, and 

crevice 

corrosion

NA BWR/ 

PWR

No 

No 

Chapter XI.S1, “ASME Section XI, Subsection 

IWE,” and 

(Note: IWE examination category E-F, surface 

examination of dissimilar metal welds, is 

recommended) 

Chapter XI.S4, “10 CFR Part 50, Appendix J” 

Steel; 

dissimilar 

metal welds

Air – indoor 

uncontrolled 

or air outdoor

C-12 Penetration 

sleeves

A3.1-a 

B4.1-a

No 

No

Chapter XI.S1, “ASME Section XI, Subsection 

IWE,” and

Chapter XI.S4, “10 CFR Part 50, Appendix J”

Steel Air – indoor 

uncontrolled 

or air –

outdoor

C-16 Personnel 

airlock, 

equipment 

hatch, CRD 

hatch

A3.2-a 

B4.2-a

19 Cracking/ 

stress 

corrosion 

cracking

NA BWR No Chapter XI.S1, “ASME Section XI, Subsection 

IWE” and Chapter XI.S4, “10 CFR Part 50, 

Appendix J”

Stainless 

steel

Air – indoor 

uncontrolled

C-24 Steel elements: 

Suppression 

chamber shell 

(interior surface)

B3.1.1-b 

B3.2.2-b

20 Loss of 

material/ 

general, 

pitting, and 

crevice 

corrosion

NA BWR No Chapter XI.S1, “ASME Section XI, Subsection 

IWE“ and Chapter XI.S4, “10 CFR Part 50, 

Appendix J"

Stainless 

steel; steel

Air – indoor 

uncontrolled 

or treated 

water (as 

applicable)

C-49 Steel elements: 

Suppression 

chamber liner 

(interior surface)

B2.2.2-b 

B1.2.

21 Fretting or 

lockup/ 

mechanical 

wear

NA BWR No Chapter XI.S1, “ASME Section XI, Subsection 

IWE”

Steel Air – indoor 

uncontrolled

C-23 Steel elements: 

Drywell head; 

Downcomers

B1.1.1-e 

B2.2.2-e 

B2.1.1-d 

B1.2.
October 2005

B-151 NUREG-1833

Table B.5 Structures

ID Aging Effect/ 

Mechanism

SRP-LR Ref Type Further 

Evaluation

Aging Management Program (AMP) Material Environment Related 

Item

Structure 

and/or 

Component

Related

22 Loss of 

material/ 

corrosion

NA BWR/ 

PWR

No Chapter XI.S2, “ASME Section XI, Subsection 

IWL”

Steel Air – indoor 

uncontrolled 

or air –

outdoor

C-10 Prestressing 

system: 

Tendons; 

anchorage 

components

A1.3-a 

B2.2.3-a

23 Cracking, loss 

of bond, and 

loss of 

material 

(spalling, 

scaling)/ 

corrosion of 

embedded 

steel

3.5.2.2.2.1 BWR/ 

PWR

Yes, if not 

within the 

scope of the 

applicant’s 

structures 

monitoring 

program

Chapter XI.S6, “Structures Monitoring Program” 

Accessible areas: 

Inspections performed in accordance with the 

Structures Monitoring Program will indicate the 

presence of cracking, loss of bond, and loss of 

material (spalling, scaling) due to corrosion of 

embedded steel. 

Reinforced 

concrete

Air – indoor 

uncontrolled 

or air –

outdoor

T-04 Concrete: 

Interior and 

above-grade 

exterior

A1.1-d 

A2.1-d 

A3.1-d 

A4.1-d 

A5.1-d 

A7.1-d 

A9.1-d

24 Increase in 

porosity and 

permeability, 

cracking, loss 

of material 

(spalling, 

scaling)/ 

aggressive 

chemical 

attack

3.5.2.2.2.1 BWR/ 

PWR

Yes, if not 

within the 

scope of the 

applicant’s 

structures 

monitoring 

program

Chapter XI.S6, "Structures Monitoring Program" 

Accessible Areas: 

Inspections performed in accordance with 

Structures Monitoring Program will indicate the 

presence of increase in porosity and 

permeability, cracking, or loss of material 

(spalling, scaling) due to aggressive chemical 

attack.

Reinforced 

concrete

Air-indoor 

uncontrolled 

or air-outdoor

T-06 Concrete: 

Interior and 

above-grade 

exterior

A1.1-f 

A2.1-f 

A3.1-f 

A4.1-a 

A5.1-f 

A7.1-f 

A9.1-f

25 Loss of 

material/ 

corrosion

3.5.2.2.2.1 BWR/ 

PWR

Yes, if not 

within the 

scope of the 

applicant’s 

structures 

monitoring 

program

Chapter XI.S6, “Structures Monitoring Program” 

If protective coatings are relied upon to manage 

the effects of aging, the structures monitoring 

program is to include provisions to address 

protective coating monitoring and maintenance.

Steel Air – indoor 

uncontrolled 

or air –

outdoor

T-11 Steel 

components: 

All structural 

steel

A1.2-a 

A2.2-a 

A3.2-a 

A4.2-a 

A5.2-a 

A7.2-a 

A8.2-a
NUREG-1833

B-152 October 2005

Table B.5 Structures

ID Aging Effect/ 

Mechanism

SRP-LR Ref Type Further 

Evaluation

Aging Management Program (AMP) Material Environment Related 

Item

Structure 

and/or 

Component

Related

26 Loss of 

material 

(spalling, 

scaling) and 

cracking/ 

freeze-thaw

3.5.2.2.2.1 

and 

3.5.2.2.2.2.1

BWR/ 

PWR

Yes, if not 

within the 

scope of the 

applicant’s 

structures 

monitoring 

program or 

for 

inaccessible 

areas of 

plants 

located in 

moderate to 

severe 

weathering 

conditions

Chapter XI.S6, “Structures Monitoring Program” 

Accessible Areas: 

Inspections performed in accordance with the 

Structures Monitoring Program will indicate the 

presence of loss of material (spalling, scaling) 

and cracking due to freeze-thaw. 

Inaccessible Areas: 

Evaluation is needed for plants that are located 

in moderate to severe weathering conditions 

(weathering index > 100 day-inch/yr) (NUREG1557). Documented evidence to confirm that 

existing concrete has air content of 3% to 6% 

and water-to-cement ratio of 0.35-0.45, and 

subsequent inspections did not exhibit 

degradation related to freeze-thaw, should be 

considered a part of the evaluation. 

The weathering index for the continental US is 

shown in ASTM C33-90, Fig.1.

Reinforced 

concrete

Air – outdoor T-01 Concrete: 

Exterior aboveand belowgrade; 

foundation

A1.1-a 

A2.1-a 

A3.1-a 

A5.1-a 

A7.1-a 

A8.1-a 

A9.1-a

27 Cracking due 

to expansion/ 

reaction with 

aggregates

3.5.2.2.2.1 

and 

3.5.2.2.2.2.2

BWR/ 

PWR

Yes, if not 

within the 

scope of the 

applicant’s 

structures 

monitoring 

program or 

concrete 

was not 

constructed 

as stated for 

inaccessible 

areas.

Chapter XI.S6, “Structures Monitoring Program” 

Accessible Areas: 

Inspections/evaluations performed in 

accordance with the Structures Monitoring 

Program will indicate the presence of expansion 

and cracking due to reaction with aggregates. 

Inaccessible Areas: 

As described in NUREG-1557, investigations, 

tests, and petrographic examinations of 

aggregates performed in accordance with ASTM 

C295-54 or ASTM C227-50 can demonstrate 

that those aggregates do not react within 

reinforced concrete. For potentially reactive 

aggregates, aggregate-reinforced concrete 

reaction is not significant if the concrete was 

constructed in accordance with ACI 201.2R. 

Therefore, if these conditions are satisfied, an 

aging management program is not necessary.

Reinforced 

concrete

Any T-03 Concrete: 

All

A1.1-c 

A2.1-c 

A3.1-c 

A4.1-b 

A5.1-c 

A7.1-c 

A8.1-c 

A9.1-c
October 2005

B-153 NUREG-1833

Table B.5 Structures

ID Aging Effect/ 

Mechanism

SRP-LR Ref Type Further 

Evaluation

Aging Management Program (AMP) Material Environment Related 

Item

Structure 

and/or 

Component

Related

28 Cracks and 

distortion due 

to increased 

stress levels 

from 

settlement

3.5.2.2.2.1 

and 

3.5.2.2.2.2.3

BWR/ 

PWR

Yes, if not 

within the 

scope of the 

applicant’s 

structures 

monitoring 

program or 

a dewatering 

system is 

relied upon

Chapter XI.S6, “Structures Monitoring Program” 

If a de-watering system is relied upon for control 

of settlement, then the licensee is to ensure 

proper functioning of the de-watering system 

through the period of extended operation. 

Reinforced 

concrete

Soil T-08 Concrete: 

All

A1.1-h 

A2.1-h 

A3.1-h 

A5.1-h 

A6.1-f 

A7.1-h 

A8.1-f

A9.1-h 

29 Reduction in 

foundation 

strength, 

cracking, 

differential 

settlement/ 

erosion of 

porous 

concrete 

subfoundation

3.5.2.2.2.1 

and 

3.5.2.2.2.2.3

BWR/ 

PWR

Yes, if not 

within the 

scope of the 

applicant’s 

structures 

monitoring 

program or 

a dewatering

system is 

relied upon

Chapter XI.S6, “Structures Monitoring Program” 

Erosion of cement from porous concrete 

subfoundations beneath containment basemats 

is described in NRC IN 97-11. NRC IN 98-26 

proposes Maintenance Rule Structures 

Monitoring for managing this aging effect, if 

applicable. If a de-watering system is relied 

upon for control of erosion of cement from 

porous concrete subfoundations, the licensee is 

to ensure proper functioning of the de-watering 

system through the period of extended 

operation.

Reinforced 

concrete; 

porous 

concrete

Water –

flowing under 

foundation

T-09 Concrete: 

Foundation; 

subfoundation

A1.1-I 

A2.1-I 

A3.1-I 

A5.1-I 

A6.1-g 

A7.1-I 

A8.1-g 

A9.1-i

30 Lock-up/ wear 3.5.2.2.2.1 BWR/ 

PWR

Yes, if not 

within the 

scope of 

Section XI, 

IWF or 

structures 

monitoring 

program

Chapter XI.S3, “ASME Section XI, Subsection 

IWF” or 

Chapter XI.S6, “Structures Monitoring Program”

Lubrite® Air – indoor 

uncontrolled

T-13 Steel 

components: 

Radial beam 

seats in BWR 

drywell; 

RPV support 

shoes for PWR 

with nozzle 

supports; 

Steam 

generator 

supports

A4.2-b
NUREG-1833

B-154 October 2005

Table B.5 Structures

ID Aging Effect/ 

Mechanism

SRP-LR Ref Type Further 

Evaluation

Aging Management Program (AMP) Material Environment Related 

Item

Structure 

and/or 

Component

Related

31 Cracking, loss 

of bond, and 

loss of 

material 

(spalling, 

scaling)/ 

corrosion of 

embedded 

steel

3.5.2.2.2.2.4 BWR/ 

PWR

Yes, plantspecific if 

environment 

is 

aggressive

Chapter XI.S6, "Structures Monitoring Program" 

Accessible Areas: 

Inspections performed in accordance with the 

Structures Monitoring Program will indicate the 

cracking, loss of bond, or loss of material 

(spalling, scaling) due to corrosion of embedded 

steel. 

Inaccessible Areas: 

For plants with non-aggressive ground 

water/soil; i.e., pH > 5.5, chlorides < 500 ppm, or 

sulfates <1500 ppm, as a minimum, consider 

(1) Examination of the exposed portions of the 

below-grade concrete, when excavated for any 

reason, and 

(2) Periodic monitoring of below-grade water 

chemistry, including consideration of potential 

seasonal variations . 

For plants with aggressive groundwater/soil, 

and/or where the concrete structural elements 

have experienced degradation, a plant specific 

AMP accounting for the extent of the 

degradation experienced should be 

implemented to manage the concrete aging 

during the period of extended operation.

Reinforced 

concrete

Ground 

water/soil

T-05 Concrete: 

Below-grade 

exterior; 

foundation

A1.1-e 

A2.1-e 

A3.1-e 

A5.1-e 

A7.1-e 

A8.1-d

A9.1-e
October 2005

B-155 NUREG-1833

Table B.5 Structures

ID Aging Effect/ 

Mechanism

SRP-LR Ref Type Further 

Evaluation

Aging Management Program (AMP) Material Environment Related 

Item

Structure 

and/or 

Component

Related

Increase in 

porosity and 

permeability, 

cracking, loss 

of material 

(spalling, 

scaling)/ 

aggressive 

chemical 

attack

3.5.2.2.2.2.4 BWR/ 

PWR

Yes, plantspecific if 

environment 

is 

aggressive

Inaccessible Areas: 

For plants with non-aggressive ground 

water/soil; i.e., pH > 5.5, chlorides < 500 ppm, or 

sulfates <1500 ppm, as a minimum, consider 

(1) Examination of the exposed portions of the 

below-grade concrete, when excavated for any 

reason, and 

(2) Periodic monitoring of below-grade water 

chemistry, including consideration of potential 

seasonal variations . 

For plants with aggressive groundwater/soil, 

and/or where the concrete structural elements 

have experienced degradation, a plant specific 

AMP accounting for the extent of the 

degradation experienced should be 

implemented to manage the concrete aging 

during the period of extended operation.

Reinforced 

concrete

Ground 

water/soil

T-07 Concrete: 

Below-grade 

exterior; 

foundation

A1.1-g 

A2.1-g 

A3.1-g 

A5.1-g 

A7.1-g 

A8.1-e 

A9.1-g

32 Increase in 

porosity and 

permeability, 

loss of 

strength/ 

leaching of 

calcium 

hydroxide

3.5.2.2.2.2.5 BWR/ 

PWR

Yes, if 

concrete 

was not 

constructed 

as stated for 

inaccessible 

areas

Chapter XI.S6, "Structures Monitoring Program" 

Accessible areas: 

Inspections performed in accordance with the 

Structures Monitoring Program will indicate the 

presence of increase in porosity, and 

permeability due to leaching of calcium 

hydroxide. 

Inaccessible Areas: 

An aging management program is not 

necessary, even if reinforced concrete is 

exposed to flowing water, if there is documented 

evidence that confirms the in-place concrete 

was constructed in accordance with the 

recommendations in ACI 201.2R.

Reinforced 

concrete

Water –

flowing

T-02 Concrete: 

Exterior aboveand belowgrade; 

foundation

A1.1-b 

A2.1-b 

A3.1-b 

A5.1-b 

A7.1-b 

A8.1-b 

A9.1-b
NUREG-1833

B-156 October 2005

Table B.5 Structures

ID Aging Effect/ 

Mechanism

SRP-LR Ref Type Further 

Evaluation

Aging Management Program (AMP) Material Environment Related 

Item

Structure 

and/or 

Component

Related

33 Reduction of 

strength and 

modulus/ 

elevated 

temperature 

(>150°F 

general; 

>200°F local)

3.5.2.2.2.3 BWR/ 

PWR

Yes, if 

temperature 

limits are 

exceeded

Plant-specific aging management program 

For any concrete elements that exceed specified 

temperature limits, further evaluations are 

warranted. Appendix A of ACI 349-85 specifies 

the concrete temperature limits for normal 

operation or any other long-term period. The 

temperatures shall not exceed 150°F except for 

local areas which are allowed to have increased 

temperatures not to exceed 200°F.

Reinforced 

concrete

Air – indoor 

uncontrolled

T-10 Concrete: 

All

A1.1-j 

A2.1-j 

A3.1-j 

A4.1-c 

A5.1-j
October 2005

B-157 NUREG-1833

Table B.5 Structures

ID Aging Effect/ 

Mechanism

SRP-LR Ref Type Further 

Evaluation

Aging Management Program (AMP) Material Environment Related 

Item

Structure 

and/or 

Component

Related

34 Cracking, loss 

of bond, and 

loss of 

material 

(spalling, 

scaling)/ 

corrosion of 

embedded 

steel

3.5.2.2.2.4.1 BWR/ 

PWR

Yes, plantspecific if 

environment 

is 

aggressive

Chapter XI.S7, “Regulatory Guide 1.127, 

Inspection of Water-Control Structures 

Associated with Nuclear Power Plants” or the 

FERC / US Army Corp of Engineers dam 

inspections and maintenance programs. 

Accessible areas: 

As described in NUREG-1557, corrosion of 

exterior above-grade and interior embedded 

steel is not significant if the steel is not exposed 

to an aggressive environment (concrete pH 

<11.5 or chlorides >500 ppm). If such steel is 

exposed to an aggressive environment, 

corrosion is not significant if the concrete in 

which the steel is embedded has a low water-tocement ratio (0.35-0.45), adequate air 

entrainment (3-6%), low permeability, and is 

designed in accordance with ACI 318-63 or ACI 

349-85. Therefore, if these conditions are 

satisfied, aging management is not necessary. 

Inaccessible areas: 

For plants with non-aggressive ground 

water/soil; i.e., pH > 5.5, chlorides < 500 ppm, or 

sulfates <1500 ppm, as a minimum, consider (1) 

Examination of the exposed portions of the 

below grade water chemistry, including 

consideration of potential seasonal variations. 

For plants with aggressive groundwater/soil, 

and/or where the concrete structural elements 

have experienced degradation, a plant specific 

AMP accounting for the extent of the 

degradation experienced should be 

implemented to manage the concrete aging 

during the period of extended operation.

Reinforced 

concrete

Air – indoor 

uncontrolled 

or air –

outdoor

T-18 Concrete: 

All

A6.1-d
NUREG-1833

B-158 October 2005

Table B.5 Structures

ID Aging Effect/ 

Mechanism

SRP-LR Ref Type Further 

Evaluation

Aging Management Program (AMP) Material Environment Related 

Item

Structure 

and/or 

Component

Related

Increase in 

porosity and 

permeability, 

cracking, loss 

of material 

(spalling, 

scaling)/ 

aggressive 

chemical 

attack

3.5.2.2.2.4.1 BWR/ 

PWR

Yes, plantspecific if 

environment 

is 

aggressive

Chapter XI.S7, “Regulatory Guide 1.127, 

Inspection of Water-Control Structures 

Associated with Nuclear Power Plants” or the 

FERC / US Army Corp of Engineers dam 

inspections and maintenance programs. 

Accessible Areas: 

Inspections performed in accordance with 

“Regulatory Guide 1.127, Inspection of WaterControl Structures Associated with Nuclear 

Power Plants” or the FERC / US Army Corp of 

Engineers dam inspections and maintenance 

programs will indicate the presence of increase 

in porosity and permeability, cracking, or loss of 

material (spalling, scaling) due to aggressive 

chemical attack. 

Inaccessible areas: 

For plants with non-aggressive ground 

water/soil; i.e. pH > 5.5, chlorides < 500 ppm, or 

sulfates <1500 ppm, as a minimum, consider: 

(1) Examination of the exposed portions of the 

below grade concrete, when excavated for any 

reason, and 

(2) Periodic monitoring of below-grade water 

chemistry, including consideration of potential 

seasonal variations. 

For plants with aggressive groundwater/soil, 

and/or where the concrete structural elements 

have experienced degradation, a plant specific 

AMP accounting for the extent of the 

degradation experienced should be 

implemented to manage the concrete aging 

during the period of extended operation.

Reinforced 

concrete

Ground 

water/soil

T-19 Concrete:

All

A6.1-e
October 2005

B-159 NUREG-1833

Table B.5 Structures

ID Aging Effect/ 

Mechanism

SRP-LR Ref Type Further 

Evaluation

Aging Management Program (AMP) Material Environment Related 

Item

Structure 

and/or 

Component

Related

35 Loss of 

material 

(spalling, 

scaling) and 

cracking/ 

freeze-thaw

3.5.2.2.2.4.2 BWR/ 

PWR

Yes, for 

inaccessible 

areas of 

plants 

located in 

moderate to 

severe 

weathering 

conditions

Chapter XI.S7, “Regulatory Guide 1.127, 

Inspection of Water-Control Structures 

Associated with Nuclear Power Plants” or the 

FERC / US Army Corp of Engineers dam 

inspections and maintenance programs.

Accessible Areas: 

Inspections performed in accordance with 

Chapter XI.S7, “Regulatory Guide 1.127, 

Inspection of Water-Control Structures 

Associated with Nuclear Power Plants” or the 

FERC / US Army Corp of Engineers dam 

inspections and maintenance programs will 

indicate the presence of loss of material 

(spalling, scaling) and cracking due to freezethaw. 

Inaccessible Areas: 

As described in NUREG-1557, freeze-thaw does 

not cause loss of material from reinforced 

concrete in foundations, or in above- and belowgrade exterior concrete, for plants located in a 

geographic region of negligible weathering 

conditions (weathering index <100 day-inch/yr). 

Loss of material from such concrete is not 

significant at plants located in areas in which 

weathering conditions are severe (weathering 

index >500 day- inch/yr), provided that the 

concrete mix design meets the air content 

(entrained air 3-6%) and water-to-cement ratio 

(0.35-0.45) specified in ACI 318-63 or ACI 349-

85. Therefore, if these conditions are satisfied, 

aging management is not necessary. #*# 

#*#The weathering index is defined in ASTM 

C33-90, Table 3, Footnote E. Fig. 1 of ASTM 

C33-90 illustrates the various weathering index 

regions throughout the U.S.

Reinforced 

concrete

Air – outdoor T-15 Concrete: 

Exterior aboveand belowgrade; 

foundation

A6.1-a
NUREG-1833

B-160 October 2005

Table B.5 Structures

ID Aging Effect/ 

Mechanism

SRP-LR Ref Type Further 

Evaluation

Aging Management Program (AMP) Material Environment Related 

Item

Structure 

and/or 

Component

Related

36 Cracking due 

to expansion/ 

reaction with 

aggregates

3.5.2.2.2.4.3 BWR/ 

PWR

Yes, if 

concrete 

was not 

constructed 

as stated for 

inaccessible 

areas

Chapter XI.S7, “Regulatory Guide 1.127, 

Inspection of Water-Control Structures 

Associated with Nuclear Power Plants” or the 

FERC / US Army Corp of Engineers dam 

inspections and maintenance programs. 

Accessible Areas: 

Inspections/evaluations performed in 

accordance with “Regulatory Guide 1.127, 

Inspection of Water-Control Structures 

Associated with Nuclear Power Plants” or the 

FERC / US Army Corp of Engineers dam 

inspections and maintenance programs will 

indicate the presence of expansion and cracking 

due to reaction with aggregates. 

Inaccessible areas: 

As described in NUREG-1557, investigations, 

tests, and petrographic examinations of 

aggregates performed in accordance with ASTM 

C295-54 or ASTM C227-50 can demonstrate 

that those aggregates do not react within 

reinforced concrete. For potentially reactive 

aggregates, aggregate-reinforced concrete 

reaction is not significant if the concrete was 

constructed in accordance with ACI 201.2R. 

Therefore, if these conditions are satisfied, 

aging management is not necessary.

Reinforced 

concrete

Any T-17 Concrete: 

All

A6.1-c
October 2005

B-161 NUREG-1833

Table B.5 Structures

ID Aging Effect/ 

Mechanism

SRP-LR Ref Type Further 

Evaluation

Aging Management Program (AMP) Material Environment Related 

Item

Structure 

and/or 

Component

Related

37 Increase in 

porosity and 

permeability, 

loss of 

strength/ 

leaching of 

calcium 

hydroxide

3.5.2.2.2.4.3 BWR/ 

PWR

Yes, if

concrete 

was not 

constructed 

as stated for 

inaccessible 

areas

Chapter XI.S7, “Regulatory Guide 1.127, 

Inspection of Water-Control Structures 

Associated with Nuclear Power Plants” or the 

FERC / US Army Corp of Engineers dam 

inspections and maintenance programs

Accessible Areas: 

Inspections performed in accordance with 

Chapter XI.S7, “Regulatory Guide 1.127, 

Inspection of Water-Control Structures 

Associated with Nuclear Power Plants” or the 

FERC / US Army Corp of Engineers dam 

inspections and maintenance programs will 

indicate the presence of increase in porosity and 

permeability, loss of strength/ leaching of 

calcium hydroxide 

Inaccessible Areas: 

As described in NUREG-1557, leaching of 

calcium hydroxide from reinforced concrete 

becomes significant only if the concrete is 

exposed to flowing water. Even if reinforced 

concrete is exposed to flowing water, such 

leaching is not significant if the concrete is 

constructed to ensure that it is dense, wellcured, has low permeability, and that cracking is 

well controlled. Cracking is controlled through 

proper arrangement and distribution of 

reinforcing bars. All of the above characteristics 

are assured if the concrete was constructed with 

the guidance of ACI 201.2R-77. Therefore, if 

these conditions are satisfied, aging 

management is not necessary.

Reinforced 

concrete

Water –

flowing

T-16 Concrete: 

Exterior aboveand belowgrade; 

foundation; 

interior slab

A6.1-b
NUREG-1833

B-162 October 2005

Table B.5 Structures

ID Aging Effect/ 

Mechanism

SRP-LR Ref Type Further 

Evaluation

Aging Management Program (AMP) Material Environment Related 

Item

Structure 

and/or 

Component

Related

38 Cracking/ 

stress 

corrosion 

cracking 

Loss of 

material/

pitting and 

crevice 

corrosion

3.5.2.2.2.5 BWR/ 

PWR

Yes, plantspecificA plant-specific aging management program is 

to be developed and evaluated.

Stainless 

steel

Water –

standing

T-23 Steel 

components: 

Tank liner

A7.2-b 

A8.2-b

39 Loss of 

material/ 

general and 

pitting 

corrosion

3.5.2.2.2.6 BWR/ 

PWR

Yes, if not 

within the 

scope of the 

applicant’s 

structures 

monitoring 

program

Chapter XI.S6, “Structures Monitoring Program” Steel Air – indoor 

uncontrolled 

or air –

outdoor

T-30 Support 

members; 

welds; bolted 

connections; 

support 

anchorage to 

building 

structure

B2.1-a 

B3.1-a 

B4.1-a 

B5.1-a

40 Reduction in 

concrete 

anchor 

capacity due 

to local 

concrete 

degradation/ 

serviceinduced 

cracking or 

other 

concrete 

aging 

mechanisms

3.5.2.2.2.6 BWR/ 

PWR

Yes, if not 

within the 

scope of the 

applicant’s 

structures 

monitoring 

program

Chapter XI.S6, “Structures Monitoring Program” Reinforced 

concrete; 

grout

Air – indoor 

uncontrolled 

or air –

outdoor

T-29 Building 

concrete at 

locations of 

expansion and 

grouted 

anchors; grout 

pads for support 

base plates

B1.1.4-a 

B1.2.3-a

B1.3.3-a 

B2.2-a 

B3.2-a 

B4.3-a 

B5.2-a
October 2005

B-163 NUREG-1833

Table B.5 Structures

ID Aging Effect/ 

Mechanism

SRP-LR Ref Type Further 

Evaluation

Aging Management Program (AMP) Material Environment Related 

Item

Structure 

and/or 

Component

Related

41 Reduction or 

loss of 

isolation 

function/ 

radiation 

hardening, 

temperature, 

humidity, 

sustained 

vibratory 

loading

3.5.2.2.2.6 BWR/ 

PWR

Yes, if not 

within the 

scope of the 

applicant’s 

structures 

monitoring 

program

Chapter XI.S6, “Structures Monitoring Program” Nonmetallic 

(e.g., 

Rubber)

Air – indoor 

uncontrolled 

or air –

outdoor

T-31 Vibration 

isolation 

elements

B4.2-a

42 Cumulative 

fatigue 

damage/ 

fatigue 

(Only if CLB 

fatigue 

analysis 

exists)

3.5.2.2.2.7 BWR/ 

PWR

Yes, 

TLAA

Fatigue is a time-limited aging analysis (TLAA) 

to be evaluated for the period of extended 

operation. See the Standard Review Plan, 

Section 4.3 “Metal Fatigue,” for acceptable 

methods for meeting the requirements of 10 

CFR 54.21(c)(1).

Steel Air – indoor 

uncontrolled

T-26 Support 

members; 

welds; bolted 

connections; 

support 

anchorage to 

building 

structure

B1.1.1-c 

B1.2.1-c 

B1.3.1-b

43 Cracking due 

to restraint 

shrinkage, 

creep, and 

aggressive 

environment

NA BWR/ 

PWR

No Chapter XI.S5, “Masonry Wall Program” Concrete 

block

Air – indoor 

uncontrolled 

or air –

outdoor

T-12 Masonry walls: 

All

A1.3-a 

A2.3-a 

A3.3-a 

A5.3-a 

A6.3-a

44 Loss of 

sealing/ 

deterioration 

of seals, 

gaskets, and 

moisture 

barriers 

(caulking, 

flashing, and 

other 

sealants)

NA BWR/ 

PWR

No Chapter XI.S6, “Structures Monitoring Program” Elastomers 

such as 

EPDM 

rubber

Various TP-7 Seals, gaskets, 

and moisture 

barriers 

(caulking, 

flashing, and 

other sealants)

A6.5. 
NUREG-1833

B-164 October 2005

Table B.5 Structures

ID Aging Effect/ 

Mechanism

SRP-LR Ref Type Further 

Evaluation

Aging Management Program (AMP) Material Environment Related 

Item

Structure 

and/or 

Component

Related

45 Loss of 

material/ 

abrasion; 

cavitation

NA BWR/ 

PWR

No Chapter XI.S7, “Regulatory Guide 1.127, 

Inspection of Water-Control Structures 

Associated with Nuclear Power Plants” or the 

FERC / US Army Corp of Engineers dam 

inspections and maintenance programs.

Reinforced 

concrete

Water –

flowing

T-20 Concrete: 

Exterior aboveand belowgrade; 

foundation; 

interior slab

A6.1-h

46 Cracking/ 

stress 

corrosion 

cracking 

Loss of 

material/

pitting and 

crevice 

corrosion

NA BWR/ 

PWR

No Chapter XI.M2, "Water Chemistry" and, 

Monitoring of the spent fuel pool water level in 

accordance with technical specifications and 

leakage from the leak chase channels.

Stainless 

steel

Treated water 

or treated 

borated water

T-14 Steel 

components: 

Fuel pool liner

A5.2-b

47 Loss of 

material/ 

general (steel 

only), pitting 

and crevice 

corrosion

NA BWR/ 

PWR

No Chapter XI.S7, “Regulatory Guide 1.127, 

Inspection of Water-Control Structures 

Associated with Nuclear Power Plants” or the 

FERC / US Army Corp of Engineers dam 

inspections and maintenance programs.

If protective coatings are relied upon to manage 

the effects of aging, this AMP is to include 

provisions to address protective coating 

monitoring and maintenance.

Steel; 

copper 

alloys

Air – indoor 

uncontrolled 

or air -

outdoor; 

Water –

flowing or 

water –

standing

T-21 Metal 

components: 

All structural 

members

A6.2-a

48 Loss of 

material, loss 

of form/ 

erosion, 

settlement, 

sedimentation

, frost action, 

waves, 

currents, 

surface 

runoff, 

seepage

NA BWR/ 

PWR

No Chapter XI.S7, “Regulatory Guide 1.127, 

Inspection of Water-Control Structures 

Associated with Nuclear Power Plants” or the 

FERC / US Army Corp of Engineers dam 

inspections and maintenance programs.

Various Water –

flowing 

Water –

standing

T-22 Earthen watercontrol 

structures: 

Dams, 

Embankments, 

Reservoirs, 

Channels, 

Canals and 

ponds

A6.4-a
October 2005

B-165 NUREG-1833

Table B.5 Structures

ID Aging Effect/ 

Mechanism

SRP-LR Ref Type Further 

Evaluation

Aging Management Program (AMP) Material Environment Related 

Item

Structure 

and/or 

Component

Related

49 Loss of 

material/ 

general, 

pitting, and 

crevice 

corrosion

NA BWR No Chapter XI.M2, “Water Chemistry,” for BWR 

water, and 

Chapter XI.S3, “ASME Section XI, Subsection 

IWF”

Stainless 

steel; steel

Treated Water 

< 60C (<140 

F)

TP-10 Support 

members; 

welds; bolted 

connections; 

support 

anchorage to 

building 

structure

B1.1 

50 Loss of 

material/ 

pitting and 

crevice 

corrosion

NA BWR/ 

PWR

No Chapter XI.S6, “Structures Monitoring Program” Galvanized 

steel, 

aluminum, 

stainless 

steel

Air – outdoor TP-6 Support 

members; 

welds; bolted 

connections; 

support 

anchorage to 

building 

structure

B2. B4.

51 Cracking/ 

stress 

corrosion 

cracking

NA BWR/ 

PWR

No Chapter XI.M18, “Bolting Integrity” Low alloy 

steel, yield 

strength 

>150 ksi

Air – indoor 

uncontrolled 

(External)

T-27 High strength 

bolting for 

NSSS 

component 

supports

B1.1.2-a

Loss of 

material/ 

general 

corrosion

NA BWR/ 

PWR

No Chapter XI.M18, “Bolting Integrity” Low alloy 

steel, yield 

strength 

>150 ksi

Air – indoor 

uncontrolled 

(External)

TP-9 High strength 

bolting for 

NSSS 

component

supports

B1.1

52 Loss of 

mechanical 

function/ 

corrosion, 

distortion, dirt, 

overload, 

fatigue due to 

vibratory and 

cyclic thermal 

loads

NA BWR/ 

PWR

No Chapter XI.S6, “Structures Monitoring Program” Lubrite® Air – indoor 

uncontrolled

TP-1 Sliding 

support 

bearings and 

sliding support 

surfaces

B2. B4.
NUREG-1833

B-166 October 2005

Table B.5 Structures

ID Aging Effect/ 

Mechanism

SRP-LR Ref Type Further 

Evaluation

Aging Management Program (AMP) Material Environment Related 

Item

Structure 

and/or 

Component

Related

Air – outdoor TP-2 Sliding support 

bearings and 

sliding support 

surfaces

B2. B4.

53 Loss of 

material/ 

general and 

pitting 

corrosion

NA BWR/ 

PWR

No Chapter XI.S3, “ASME Section XI, Subsection 

IWF”

Steel Air – indoor 

uncontrolled 

or air –

outdoor

T-24 Support 

members; 

welds; bolted 

connections; 

support 

anchorage to 

building 

structure

B1.1.1-a 

B1.2.1-a 

B1.3.1-a

54 Loss of 

mechanical 

function/ 

corrosion, 

distortion, dirt, 

overload, 

fatigue due to 

vibratory and 

cyclic thermal 

loads; 

elastomer 

hardening

NA BWR/ 

PWR

No Chapter XI.S3, “ASME Section XI, Subsection 

IWF”

Steel and 

non-steel 

materials 

(e.g., 

Lubrite®

plates, 

vibration 

isolators, 

etc.)

Air – indoor 

uncontrolled 

or air –

outdoor

T-28 Constant and 

variable load 

spring hangers; 

guides; stops; 

sliding surfaces; 

design 

clearances; 

vibration 

isolators

B1.1.3-a 

B1.2.2-a 

B1.3.2-a

55 Loss of 

material/ boric 

acid corrosion

NA PWR No Chapter XI.M10, “Boric Acid Corrosion” Galvanized 

steel, 

aluminum

Air with 

borated water 

leakage

TP-3 Support 

members; 

welds; bolted 

connections; 

support 

anchorage to 

building 

structure

B1.1. 

B1.2. 

B1.3. B2. 

B3. B4. 

B5. 
October 2005

B-167 NUREG-1833

Table B.5 Structures

ID Aging Effect/ 

Mechanism

SRP-LR Ref Type Further 

Evaluation

Aging Management Program (AMP) Material Environment Related 

Item

Structure 

and/or 

Component

Related

Steel Air with 

borated water 

leakage

T-25 Support 

members; 

welds; bolted 

connections; 

support 

anchorage to

building 

structure

B1.1.1-b 

B1.2.1-b 

B2.1-b 

B3.1-b 

B4.1-b 

B5.1-b

56 Loss of 

mechanical 

function due 

to corrosion, 

distortion, dirt, 

overload, 

fatigue due to 

vibratory and 

cyclic thermal 

loads

NA BWR/ 

PWR

No Chapter XI.S3, “ASME Section XI, Subsection 

IWF”

Lubrite® Air–indoor 

uncontrolled 

or air–outdoor

T-32 Sliding surfaces B1.1.3-a 

B1.2.2-a 

B1.3.2-a

57 Reduction or 

loss of 

isolation 

function/ 

radiation 

hardening, 

temperature, 

humidity, 

sustained 

vibratory 

loading

NA BWR/ 

PWR

No Chapter XI.S3, “ASME Section XI, Subsection 

IWF”

Nonmetallic 

(e.g., 

Rubber)

Air–indoor 

uncontrolled 

or air–outdoor

T-33 Vibration 

isolation 

elements

III.B1.1.3

-a 

III.B1.2.2

-a 

III.B1.3.2

-a

58 None NA BWR/ 

PWR

No None Aluminum Air – indoor 

uncontrolled

TP-8 Support 

members; 

welds; bolted 

connections; 

support 

anchorage to 

building 

structure

B1.1. 

B1.2. 

B1.3. B2. 

B3. B4. 

B5. 
NUREG-1833

B-168 October 2005

Table B.5 Structures

ID Aging Effect/ 

Mechanism

SRP-LR Ref Type Further 

Evaluation

Aging Management Program (AMP) Material Environment Related 

Item

Structure 

and/or 

Component

Related

Galvanized 

steel

Air – indoor 

uncontrolled

TP-11 Support 

members; 

welds; bolted 

connections; 

support 

anchorage to 

building 

structure

B1.1. 

B1.2. 

B1.3. B2. 

B3. B4. 

B5. 

59 None NA BWR/ 

PWR

No None Stainless 

steel

Air – indoor 

uncontrolled

TP-5 Support 

members; 

welds; bolted 

connections; 

support 

anchorage to 

building 

structure

B1.1. 

B1.2. 

B1.3. B2. 

B3. B4. 

B5. 

Air with 

borated water 

leakage

TP-4 Support 

members; 

welds; bolted 

connections; 

support 

anchorage to 

building 

structure

B1.1. 

B1.2. 

B1.3. B2. 

B3. B4. 

B5. 
October 2005

B-169 NUREG-1833

B.6 Electrical SRP-LR Development Tool

Table B.6 presents the electrical SRP-LR development tool.

Table B.6 Electrical

ID Aging Effect/ 

Mechanism

SRP-LR 

Ref

Type Further 

Evaluation

Aging Management 

Program (AMP)

Material Environment Related 

Item

Structure and/or 

Component

Related

1 Various 

degradation/ 

various 

mechanisms

3.6.2.2.1 BWR/ 

PWR

Yes, 

TLAA

EQ is a time-limited aging 

analysis (TLAA) to be 

evaluated for the period of 

extended operation. See 

the Standard Review 

Plan, Section 4.4, 

"Environmental 

Qualification (EQ) of 

Electrical Equipment," for 

acceptable methods for 

meeting the requirements 

of 10 CFR 54.21(c)(1)(i) 

and (ii). 

See Chapter X.E1, 

“Environmental 

Qualification (EQ) of 

Electric Components,” of 

this report for meeting the 

requirements of 10 CFR 

54.21(c)(1)(iii).

Various 

polymeric and 

metallic 

materials

Adverse 

localized 

environment 

caused by 

heat, 

radiation, 

oxygen, 

moisture, or 

voltage

L-05 Electrical equipment 

subject to 

10 CFR 50.49 EQ 

requirements

B.1-a

11 Degradation of 

insulator 

quality/presence 

of any salt 

deposits or 

surface 

contamination

3.6.2.2.2 BWR/ 

PWR

Yes, plantspecificA plant-specific aging 

management program is 

to be evaluated for plants 

located such that the 

potential exists for salt 

deposits or surface 

contamination (e.g., in the 

vicinity of salt water 

bodies or industrial 

pollution). 

Porcelain, 

Malleable 

iron, 

aluminum, 

galvanized 

steel, cement

Air – outdoor LP-07 High voltage 

insulators

A.
NUREG-1833

B-170 October 2005

Table B.6 Electrical

ID Aging Effect/ 

Mechanism

SRP-LR 

Ref

Type Further 

Evaluation

Aging Management 

Program (AMP)

Material Environment Related 

Item

Structure and/or 

Component

Related

11 Loss of material/ 

mechanical 

wear due to 

wind blowing on 

transmission 

conductors

3.6.2.2.2 BWR/ 

PWR

Yes, plantspecificA plant-specific aging 

management program is 

to be evaluated.

Porcelain, 

Malleable 

iron, 

aluminum, 

galvanized 

steel, cement

Air – outdoor LP-11 High voltage 

insulators

A.

12 Loss of material/ 

wind induced 

abrasion and 

fatigue 

Loss of 

conductor 

strength/ 

corrosion 

Increased 

resistance of 

connection/ 

oxidation or loss 

of pre-load

3.6.2.2.3 BWR/ 

PWR

Yes, plantspecificA plant-specific aging 

management program is 

to be evaluated.

Aluminum, 

copper, 

bronze, 

stainless 

steel, 

galvanized 

steel

Air – outdoor LP-09 Switchyard bus and 

connections

A.

Aluminum, 

steel

Air – outdoor LP-08 Transmission 

conductors and 

connections

A.
October 2005

B-171 NUREG-1833

Table B.6 Electrical

ID Aging Effect/ 

Mechanism

SRP-LR 

Ref

Type Further 

Evaluation

Aging Management 

Program (AMP)

Material Environment Related 

Item

Structure and/or 

Component

Related

2 Embrittlement, 

cracking, 

melting, 

discoloration, 

swelling, or loss 

of dielectric 

strength leading 

to reduced 

insulation 

resistance (IR); 

electrical failure/ 

degradation 

(Thermal/ 

thermoxidative) 

of 

organics/thermo

plastics, 

radiationinduced 

oxidation, 

moisture 

intrusion and 

ohmic heating

NA BWR/ 

PWR

No Chapter XI.E1, “Electrical 

Cables and Connections 

Not Subject to 10 CFR 

50.49 Environmental 

Qualification 

Requirements” 

Insulation 

material –

bakelite, 

phenolic 

melamine or 

ceramic, 

molded 

polycarbonate 

and other

Adverse 

localized 

environment 

caused by 

heat, 

radiation, or 

moisture in 

the presence 

of oxygen or 

> 60-year 

service 

limiting 

temperature

LP-03 Fuse Holders (Not 

Part of a Larger 

Assembly); 

Insulation

A.
NUREG-1833

B-172 October 2005

Table B.6 Electrical

ID Aging Effect/ 

Mechanism

SRP-LR 

Ref

Type Further 

Evaluation

Aging Management 

Program (AMP)

Material Environment Related 

Item

Structure and/or 

Component

Related

Embrittlement, 

cracking, 

melting, 

discoloration, 

swelling, or loss 

of dielectric 

strength leading 

to reduced 

insulation 

resistance (IR); 

electrical failure/ 

degradation of 

organics 

(Thermal/ 

thermoxidative), 

radiolysis and 

photolysis 

(UV sensitive 

materials only) 

of organics; 

radiationinduced 

oxidation, and 

moisture 

intrusion

NA BWR/ 

PWR

No Chapter XI.E1, “Electrical 

Cables and Connections 

Not Subject to 10 CFR 

50.49 Environmental 

Qualification 

Requirements” 

Various 

organic 

polymers 

(e.g., EPR, 

SR, EPDM,

XLPE)

Adverse 

localized 

environment 

caused by 

heat, 

radiation, or 

moisture in 

the presence 

of oxygen

L-01 Conductor insulation 

for electrical cables 

and connections

A.1-a
October 2005

B-173 NUREG-1833

Table B.6 Electrical

ID Aging Effect/ 

Mechanism

SRP-LR 

Ref

Type Further 

Evaluation

Aging Management 

Program (AMP)

Material Environment Related 

Item

Structure and/or 

Component

Related

3 Embrittlement, 

cracking, 

melting, 

discoloration, 

swelling, or loss 

of dielectric 

strength leading 

to reduced 

insulation 

resistance (IR); 

electrical failure/ 

degradation of 

organics 

(Thermal/ 

thermoxidative), 

radiolysis and 

photolysis 

(UV sensitive 

materials only) 

of organics; 

radiationinduced 

oxidation, and 

moisture 

intrusion

NA BWR/ 

PWR

No Chapter XI.E2, "Electrical 

Cables and Connections 

Not Subject to 

10 CFR 50.49 

Environmental 

Qualification 

Requirements Used in 

Instrumentation Circuits"

Various 

organic 

polymers 

(e.g., EPR, 

SR, EPDM, 

XLPE)

Adverse 

localized 

environment 

caused by 

heat, 

radiation, or 

moisture in 

the presence 

of oxygen

L-02 Conductor insulation 

for electrical cables 

and connections 

used in 

instrumentation 

circuits that are 

sensitive to 

reduction in 

conductor insulation 

resistance (IR)

A.1-b

4 Localized 

damage and 

breakdown of 

insulation 

leading to 

electrical failure/ 

moisture 

intrusion, water 

trees

NA BWR/ 

PWR

No Chapter XI.E3, 

"Inaccessible Medium 

Voltage Cables Not 

Subject to 10 CFR 50.49 

Environmental 

Qualification 

Requirements"

Various 

organic 

polymers 

(e.g., EPR, 

SR, EPDM, 

XLPE)

Adverse 

localized 

environment 

caused by 

exposure to 

moisture and 

voltage

L-03 Conductor insulation 

for inaccessible 

medium -voltage 

(2kV to 35kV) cables 

(e.g., installed in 

conduit or direct 

buried)

A.1-c
NUREG-1833

B-174 October 2005

Table B.6 Electrical

ID Aging Effect/ 

Mechanism

SRP-LR 

Ref

Type Further 

Evaluation

Aging Management 

Program (AMP)

Material Environment Related 

Item

Structure and/or 

Component

Related

5 Corrosion of 

connector 

contact 

surfaces/ 

intrusion of 

borated water

NA PWR No Chapter XI.M10, “Boric 

Acid Corrosion”

Various 

metals used 

for electrical 

contacts

Air with 

borated water 

leakage

L-04 Connector contacts 

for electrical 

connectors exposed 

to borated water 

leakage

A.2-a

6 Fatigue/ohmic 

heating, thermal 

cycling, 

electrical 

transients, 

frequent 

manipulation, 

vibration, 

chemical 

contamination, 

corrosion, and 

oxidation

NA BWR/ 

PWR

No Chapter XI.E5, "Fuse 

Holders" 

Copper alloy Air – indoor LP-01 Fuse Holders (Not 

Part of a Larger 

Assembly); 

Metallic Clamp

A.

7 Loosening of 

bolted 

connections/ 

thermal cycling 

and ohmic 

heating

NA BWR/ 

PWR

No Chapter XI.E4, "Metal 

Enclosed Bus"

Aluminum/ 

Silver Plated 

Aluminum 

Copper/ Silver 

Plated 

Copper; 

Stainless 

steel, steel

Air – indoor 

and outdoor

LP-04 Metal enclosed bus 

Bus/connections

A.
October 2005

B-175 NUREG-1833

Table B.6 Electrical

ID Aging Effect/ 

Mechanism

SRP-LR 

Ref

Type Further 

Evaluation

Aging Management 

Program (AMP)

Material Environment Related 

Item

Structure and/or 

Component

Related

8 Embrittlement, 

cracking, 

melting, 

discoloration, 

swelling, or loss 

of dielectric 

strength leading 

to reduced 

insulation 

resistance (IR); 

electrical failure/ 

thermal/thermoxi

dative 

degradation of 

organics /thermo

plastics, 

radiationinduced 

oxidation; 

moisture/debris 

intrusion, and 

ohmic heating

NA BWR/ 

PWR

No Chapter XI.E4, "Metal 

Enclosed Bus"

Porcelain, 

xenoy, 

thermo-plastic 

organic 

polymers

Air – indoor 

and outdoor

LP-05 Metal enclosed bus 

Insulation/insulators

A.

9 Loss of material/ 

general 

corrosion

NA BWR/ 

PWR

No Chapter XI.S6, “Structures 

Monitoring Program”

Steel; 

galvanized 

steel

Air – indoor 

and outdoor

LP-06 Metal enclosed bus 

Enclosure 

assemblies

A.

10 Hardening and 

loss of strength/ 

elastomer 

degradation

NA BWR/ 

PWR

No Chapter XI.S6, “Structures 

Monitoring Program”

Elastomers Air – indoor 

and outdoor

LP-10 Metal enclosed bus 

Enclosure 

assemblies

A.
NUREG-1833

B-176 October 2005

Table B.6 Electrical

ID Aging Effect/ 

Mechanism

SRP-LR 

Ref

Type Further 

Evaluation

Aging Management 

Program (AMP)

Material Environment Related 

Item

Structure and/or 

Component

Related

13 Loosening of 

bolted 

connections due 

to thermal 

cycling, ohmic 

heating, 

electrical 

transients, 

vibration, 

chemical 

contamination, 

corrosion, and 

oxidation

NA BWR/ 

PWR

No Chapter XI.E6, "Electrical 

Connections Not Subject 

to 10 CFR 50.49 

Environmental 

Qualification 

Requirements"

Various 

metals used 

for electrical 

contacts

Air – indoor 

and outdoor

LP-12 Cable Connections 

(Metallic Parts)

A.

14 None NA BWR/ 

PWR

No None Insulation 

material –

bakelite, 

phenolic 

melamine or 

ceramic, 

molded 

polycarbonate 

and other

Air – indoor 

uncontrolled 

(Internal/Exter

nal)

LP-02 Fuse Holders (Not 

Part of a Larger 

Assembly); 

Insulation

A.
October 2005 C-i NUREG-1833

APPENDIX C

GALL Rev. 0 to GALL Rev. 1 Relationship Tables
NUREG-1833 C-ii October 2005

This Page Intentionally Left Blank
October 2005 C-1 NUREG-1833

Introduction

In GALL Rev. 1, Volume 2 contains item numbers (e.g., “R-59”) that have been assigned to each AMR 

line item. To assist in relating these line items to the AMR line items in GALL Rev 0, the tables in this 

appendix have been provided. 

For each system chapter in GALL Volume 2 (Chapters II through VIII), these tables relate the item 

numbers in GALL Rev. 0 to the item numbers contained in GALL Rev. 1. For example, as shown in 

Table IVA, “Relationship of Reactor Vessel, Internals and Reactor Coolant (RCS) System IDs in GALL 

V 2,” item “A1.1-a” from GALL Rev. 0 (which is located in the reactor vessel subsystem in Chapter IV) 

relates to item “R-59” in GALL Rev 1. 

All GALL Rev. 0 line items are related to one or more line items in GALL Rev. 1. However, not all GALL 

Rev. 1 items relate back to a GALL Rev. 0 line item (i.e., when a new item was added to GALL Rev. 1).

In such cases, although there is no GALL Rev. 0 item number to relate to, the relationship table still 

contains a row for the new item. However, the GALL Rev. 0 column contains only a subsystem 

identifier, not a GALL Rev. 0 item number. For example, RP-25 is a new item in GALL Rev. 1. Table 

IVA, “Relationship of Reactor Vessel, Internals and Reactor Coolant (RCS) System IDs in GALL V 2” 

shows “RP-25” is related to “A1.” in GALL Rev. 0, indicating that RP-25 has been added in Rev. 1 of 

GALL and it can be found in subsystem A1, the reactor vessel subsystem in Chapter IV.
NUREG-1833 C-2 October 2005

This Page Intentionally Left Blank
October 2005 C-3 NUREG-1833

C.1 GALL Rev. 0 to GALL Rev. 1 Relationship Tables

Table IIA. 

Relationship of 

Containment 

Structures IDs in 

GALL V 2

GALL

Rev.0

GALL 

Rev. 1

A1.1-a C-01

A1.1-b C-02

A1.1-c C-03

A1.1-d C-04

A1.1-e C-05

A1.1-f C-37

A1.1-g C-07

A1.1-h C-08

A1.2-a C-09

A1.3-a C-10

A1.3-b C-11

A2.1-a C-09

A2.2-a C-28

A2.2-b C-30

A2.2-c C-25

A2.2-d C-38

A2.2-e C-43

A2.2-f C-36

A2.2-g C-07

A2.2-h C-34

A3.1-a C-12

A3.1-b C-13

A3.1-c C-14

A3.1-d C-15

A3.2-a C-16

A3.2-b C-17

A3.3-a C-18

B1.1.1-a C-19

B1.1.1-b C-20

B1.1.1-c C-21

B1.1.1-d C-22

B1.1.1-e C-23

B1.2. C-41

B1.2. C-35

B1.2. C-06

B1.2. C-07

B1.2. C-39

B1.2. C-23

B1.2. C-26

Table IIA. 

Relationship of 

Containment 

Structures IDs in 

GALL V 2

GALL

Rev.0

GALL 

Rev. 1

B1.2. C-46

B1.2. C-31

B1.2. C-49

B2.1.1-a C-46

B2.1.1-b C-44

B2.1.1-c C-45

B2.1.1-d C-23

B2.2.1-a C-31

B2.2.1-b C-26

B2.2.1-c C-39

B2.2.1-d C-41

B2.2.1-e C-06

B2.2.1-f C-07

B2.2.1-g C-35

B2.2.2-a C-46

B2.2.2-b C-49

B2.2.2-c C-47

B2.2.2-d C-48

B2.2.2-e C-23

B2.2.3-a C-10

B2.2.3-b C-11

B3.1.1-a C-19

B3.1.1-b C-24

B3.1.2-a C-30

B3.1.2-b C-25

B3.1.2-c C-51

B3.1.2-d C-43

B3.1.2-e C-36

B3.1.2-f C-07

B3.1.2-g C-50

B3.1.2-g C-50

B3.2.1-a C-29

B3.2.1-b C-32

B3.2.1-c C-27

B3.2.1-d C-40

B3.2.1-e C-42

B3.2.1-f C-06

B3.2.1-g C-07

B3.2.1-h C-33

Table IIA. 

Relationship of 

Containment 

Structures IDs in 

GALL V 2

GALL

Rev.0

GALL 

Rev. 1

B3.2.2-a C-09

B3.2.2-b C-24

B4.1-a C-12

B4.1-b C-13

B4.1-c C-14

B4.1-d C-15

B4.2-a C-16

B4.2-b C-17

B4.3-a C-18
NUREG-1833 C-4 October 2005

Table IIIA. 

Relationship of 

Structures and 

Component Supports 

IDs in GALL V 2

GALL 

Rev. 0

GALL 

Rev. 1

A1.1-a T-01

A1.1-b T-02

A1.1-c T-03

A1.1-d T-04

A1.1-e T-05

A1.1-f T-06

A1.1-g T-07

A1.1-h T-08

A1.1-i T-09

A1.1-j T-10

A1.2-a T-11

A1.3-a T-12

A2.1-a T-01

A2.1-b T-02

A2.1-c T-03

A2.1-d T-04

A2.1-e T-05

A2.1-f T-06

A2.1-g T-07

A2.1-h T-08

A2.1-i T-09

A2.1-j T-10

A2.2-a T-11

A2.3-a T-12

A3.1-a T-01

A3.1-b T-02

A3.1-c T-03

A3.1-d T-04

A3.1-e T-05

A3.1-f T-06

A3.1-g T-07

A3.1-h T-08

A3.1-i T-09

A3.1-j T-10

A3.2-a T-11

A3.3-a T-12

A4.1-a T-06

A4.1-b T-03

A4.1-c T-10

A4.1-d T-04

A4.2-a T-11

A4.2-b T-13

Table IIIA. 

Relationship of 

Structures and 

Component Supports 

IDs in GALL V 2

GALL 

Rev. 0

GALL 

Rev. 1

A5.1-a T-01

A5.1-b T-02

A5.1-c T-03

A5.1-d T-04

A5.1-e T-05

A5.1-f T-06

A5.1-g T-07

A5.1-h T-08

A5.1-i T-09

A5.1-j T-10

A5.2-a T-11

A5.2-b T-14

A5.3-a T-12

A6.1-a T-15

A6.1-b T-16

A6.1-c T-17

A6.1-d T-18

A6.1-e T-19

A6.1-f T-08

A6.1-g T-09

A6.1-h T-20

A6.2-a T-21

A6.3-a T-12

A6.4-a T-22

A6. TP-7

A7.1-a T-01

A7.1-b T-02

A7.1-c T-03

A7.1-d T-04

A7.1-e T-05

A7.1-f T-06

A7.1-g T-07

A7.1-h T-08

A7.1-i T-09

A7.2-a T-11

A7.2-b T-23

A8.1-a T-01

A8.1-b T-02

A8.1-c T-03

A8.1-d T-05

A8.1-e T-07

A8.1-f T-08

Table IIIA. 

Relationship of 

Structures and 

Component Supports 

IDs in GALL V 2

GALL 

Rev. 0

GALL 

Rev. 1

A8.1-g T-09

A8.2-a T-11

A8.2-b T-23

A9.1-a T-01

A9.1-b T-02

A9.1-c T-03

A9.1-d T-04

A9.1-e T-05

A9.1-f T-06

A9.1-g T-07

A9.1-h T-08

A9.1-i T-09

B1.1 TP-9

B1.1 TP-10

B1.1. TP-11

B1.1. TP-3

B1.1. TP-8

B1.1. TP-5

B1.1. TP-4

B1.1.1-a T-24

B1.1.1-b T-25

B1.1.1-c T-26

B1.1.2-a T-27

B1.1.3-a T-28

B1.1.4-a T-29

B1.2. TP-3

B1.2. TP-5

B1.2. TP-8

B1.2. TP-4

B1.2. TP-11

B1.2.1-a T-24

B1.2.1-b T-25

B1.2.1-c T-26

B1.2.2-a T-28

B1.2.3-a T-29

B1.3. TP-3

B1.3. TP-4

B1.3. TP-5

B1.3. TP-11

B1.3. TP-8

B1.3.1-a T-24

B1.3.1-b T-26
October 2005 C-5 NUREG-1833

Table IIIA. 

Relationship of 

Structures and 

Component Supports 

IDs in GALL V 2

GALL 

Rev. 0

GALL 

Rev. 1

B1.3.2-a T-28

B1.3.3-a T-29

B2. TP-4

B2. TP-11

B2. TP-2

B2. TP-8

B2. TP-6

B2. TP-1

B2. TP-5

B2. TP-3

B2.1-a T-30

B2.1-b T-25

B2.2-a T-29

B3. TP-8

B3. TP-3

B3. TP-4

B3. TP-5

B3. TP-11

B3.1-a T-30

B3.1-b T-25

B3.2-a T-29

B4. TP-1

B4. TP-6

B4. TP-2

B4. TP-5

B4. TP-3

B4. TP-4

B4. TP-11

B4. TP-8

B4.1-a T-30

B4.1-b T-25

B4.2-a T-31

B4.3-a T-29

B5. TP-3

B5. TP-4

B5. TP-8

B5. TP-5

B5. TP-11

B5.1-a T-30

B5.1-b T-25

B5.2-a T-29

Table IVA. Relationship 

of Reactor Vessel, 

Internals, and Reactor 

Coolant (RCS) System 

IDs in GALL V. 2

GALL 

Rev. 0 GALL Rev. 1

A1. RP-25

A1.1-a R-59

A1.1-b R-04

A1.1-c R-60

A1.1-d R-61

A1.2-a R-04

A1.2-b R-04

A1.2-c R-62

A1.2-d R-63

A1.2-e R-64

A1.3-a R-04

A1.3-b R-65

A1.3-c R-66

A1.3-d R-04

A1.3-e R-67

A1.4-a R-68

A1.4-b R-04

A1.5-a R-69

A1.5-b R-04

A1.6-a R-04

A1.7-a R-70

A2. RP-28

A2. RP-13

A2.1-a R-17

A2.1-b R-219

A2.1-c R-71

A2.1-d R-72

A2.1-e R-73

A2.1-f R-74

A2.2-a R-75

A2.2-b R-76

A2.2-c R-219

A2.2-d R-77

A2.2-e R-78

A2.2-f R-79

A2.2-g R-80

A2.3-a R-81

A2.3-b R-82

A2.3-c R-219

A2.4-a R-219

A2.4-b R-83

A2.5-a R-84

Table IVA. Relationship 

of Reactor Vessel, 

Internals, and Reactor 

Coolant (RCS) System 

IDs in GALL V. 2

GALL 

Rev. 0 GALL Rev. 1

A2.5-b R-85

A2.5-c R-86

A2.5-d R-219

A2.5-e R-17

A2.5-f R-87

A2.6-a R-88

A2.7-a R-89

A2.7-b R-90

A2.8-a R-70

A2.8-b R-17

B1. RP-26

B1. RP-18

B1.1-a R-92

B1.1-b R-93

B1.1-c R-53

B1.1-d R-94

B1.1-e R-95

B1.1-f R-96

B1.1-g R-97

B1.2-a R-98

B1.2-b R-53

B1.3-a R-99

B1.3-b R-53

B1.4-a R-100

B1.4-b R-53

B1.4-c R-101

B1.4-d R-102

B1.5-a R-103

B1.5-b R-53

B1.5-c R-104

B1.6-a R-105

B1.6-b R-53

B2. RP-24

B2.1-a R-106

B2.1-b R-107

B2.1-c R-53

B2.1-d R-108

B2.1-e R-109

B2.1-f R-110

B2.1-g R-111

B2.1-h R-53

B2.1-i R-112
NUREG-1833 C-6 October 2005

Table IVA. Relationship 

of Reactor Vessel, 

Internals, and Reactor 

Coolant (RCS) System 

IDs in GALL V. 2

GALL 

Rev. 0 GALL Rev. 1

B2.1-j R-113

B2.1-k R-114

B2.1-l R-115

B2.1-m R-53

B2.2-a R-116

B2.2-b R-117

B2.2-c R-53

B2.2-d R-118

B2.2-e R-119

B2.2-f R-53

B2.3-a R-120

B2.3-b R-121

B2.3-c R-122

B2.3-d R-53

B2.4-a R-123

B2.4-b R-124

B2.4-c R-125

B2.4-d R-126

B2.4-e R-127

B2.4-f R-128

B2.4-g R-53

B2.4-h R-129

B2.5-a R-130

B2.5-b R-131

B2.5-c R-132

B2.5-d R-53

B2.5-e R-133

B2.5-f R-134

B2.5-g R-135

B2.5-h R-136

B2.5-i R-137

B2.5-j R-53

B2.5-k R-138

B2.5-l R-139

B2.5-m R-140

B2.5-n R-141

B2.5-o R-142

B2.5-p R-53

B2.6-a R-143

B2.6-b R-144

B2.6-c R-145

B3. RP-24

Table IVA. Relationship 

of Reactor Vessel, 

Internals, and Reactor 

Coolant (RCS) System 

IDs in GALL V. 2

GALL 

Rev. 0 GALL Rev. 1

B3.1-a R-146

B3.1-b R-147

B3.1-c R-148

B3.2-a R-149

B3.2-b R-150

B3.2-c R-151

B3.2-d R-152

B3.2-e R-153

B3.2-f R-53

B3.2-g R-154

B3.3-a R-157

B3.3-a R-155

B3.3-b R-158

B3.3-b R-156

B3.4-a R-159

B3.4-b R-160

B3.4-c R-161

B3.4-d R-53

B3.4-e R-162

B3.4-f R-163

B3.4-g R-164

B3.4-h R-165

B3.5-a R-166

B3.5-b R-167

B3.5-c R-168

B3.5-d R-169

B3.5-e R-170

B3.5-f R-171

B3.5-g R-53

B4. RP-24

B4.1-a R-172

B4.1-b R-173

B4.1-c R-174

B4.1-d R-53

B4.2-a R-175

B4.2-b R-176

B4.2-c R-177

B4.2-d R-53

B4.2-e R-178

B4.2-f R-179

B4.3-a R-180

B4.3-b R-181

Table IVA. Relationship 

of Reactor Vessel, 

Internals, and Reactor 

Coolant (RCS) System 

IDs in GALL V. 2

GALL 

Rev. 0 GALL Rev. 1

B4.3-c R-182

B4.3-d R-183

B4.3-e R-184

B4.3-f R-53

B4.4-a R-185

B4.4-b R-186

B4.4-c R-187

B4.4-d R-188

B4.4-e R-53

B4.4-f R-190

B4.4-g R-191

B4.4-h R-192

B4.5-a R-193

B4.5-b R-194

B4.5-c R-195

B4.5-d R-196

B4.5-e R-197

B4.5-f R-53

B4.5-g R-125

B4.5-h R-199

B4.5-i R-128

B4.5-j R-201

B4.6-a R-202

B4.6-b R-203

B4.6-c R-204

B4.6-d R-205

B4.6-e R-206

B4.6-f R-53

B4.6-g R-207

B4.6-h R-208

B4.7-a R-209

B4.7-b R-210

B4.7-c R-211

B4.7-d R-212

B4.7-e R-213

B4.8-a R-214

B4.8-b R-215

B4.8-c R-216

C1. RP-27

C1.1-a R-23

C1.1-b R-220

C1.1-c R-23
October 2005 C-7 NUREG-1833

Table IVA. Relationship 

of Reactor Vessel, 

Internals, and Reactor 

Coolant (RCS) System 

IDs in GALL V. 2

GALL 

Rev. 0 GALL Rev. 1

C1.1-d R-220

C1.1-e R-220

C1.1-e R-220

C1.1-f R-20

C1.1-f R-21

C1.1-g R-52

C1.1-h R-220

C1.1-i R-03

C1.2-a R-220

C1.2-b R-20

C1.2-c R-08

C1.2-d R-29

C1.2-d R-26

C1.2-e R-27

C1.2-f R-28

C1.3-a R-23

C1.3-b R-08

C1.3-c R-20

C1.3-d R-220

C1.3-e R-26

C1.3-e R-29

C1.3-f R-27

C1.3-g R-28

C1.4-a R-15

C1.4-a R-225

C1.4-b R-16

C2. RP-12

C2. RP-31

C2. RP-23

C2. RP-11

C2. RP-10

C2. RP-22

C2.1-a R-223

C2.1-b R-223

C2.1-c R-56

C2.1-c R-30

C2.1-d R-17

C2.1-e R-05

C2.1-f R-52

C2.1-g R-02

C2.2-a R-223

C2.2-b R-223

Table IVA. Relationship 

of Reactor Vessel, 

Internals, and Reactor 

Coolant (RCS) System 

IDs in GALL V. 2

GALL 

Rev. 0 GALL Rev. 1

C2.2-c R-223

C2.2-d R-17

C2.2-e R-52

C2.2-f R-07

C2.2-g R-05

C2.2-h R-02

C2.3-a R-223

C2.3-a R-223

C2.3-b R-09

C2.3-c R-08

C2.3-d R-18

C2.3-e R-11

C2.3-f R-17

C2.3-g R-12

C2.4-a R-223

C2.4-b R-09

C2.4-c R-08

C2.4-d R-18

C2.4-e R-11

C2.4-f R-17

C2.4-g R-12

C2.5-a R-223

C2.5-b R-17

C2.5-c R-25

C2.5-c R-58

C2.5-d R-223

C2.5-e R-223

C2.5-f R-223

C2.5-g R-25

C2.5-g R-58

C2.5-h R-07

C2.5-i R-05

C2.5-j R-24

C2.5-k R-06

C2.5-l R-52

C2.5-m R-07

C2.5-m R-06

C2.5-n R-11

C2.5-o R-17

C2.5-p R-12

C2.5-q R-223

C2.5-r R-217

Table IVA. Relationship 

of Reactor Vessel, 

Internals, and Reactor 

Coolant (RCS) System 

IDs in GALL V. 2

GALL 

Rev. 0 GALL Rev. 1

C2.5-s R-06

C2.5-t R-18

C2.5-u R-17

C2.5-v R-19

C2.5-w R-18

C2.6-a R-13

C2.6-b R-17

C2.6-c R-14

D1. RP-21

D1. RP-17

D1. RP-14

D1. RP-15

D1. RP-16

D1.1-a R-33

D1.1-b R-33

D1.1-c R-34

D1.1-d R-37

D1.1-e R-39

D1.1-f R-32

D1.1-g R-17

D1.1-h R-221

D1.1-i R-01

D1.1-i R-07

D1.1-j R-01

D1.1-k R-17

D1.1-l R-10

D1.2-a R-44

D1.2-b R-47

D1.2-c R-48

D1.2-d R-46

D1.2-e R-49

D1.2-f R-50

D1.2-g R-43

D1.2-h R-41

D1.2-i R-40

D1.2-j R-40

D1.2-k R-42

D1.3-a R-51

D2. R-226

D2. R-42

D2.1-a R-35

D2.1-b R-17
NUREG-1833 C-8 October 2005

Table IVA. Relationship 

of Reactor Vessel, 

Internals, and Reactor 

Coolant (RCS) System 

IDs in GALL V. 2

GALL 

Rev. 0 GALL Rev. 1

D2.1-c R-222

D2.1-d R-33

D2.1-e R-224

D2.1-f R-38

D2.1-g R-33

D2.1-h R-01

D2.1-i R-36

D2.1-j R-17

D2.1-k R-32

D2.1-l R-31

D2.2-a R-44

D2.2-b R-47

D2.2-c R-48

D2.2-d R-49

D2.2-e R-46

D2.2-f R-40

D2.2-g R-40

E. RP-04

E. RP-06

E. RP-07

E. RP-05

E. RP-01

E. RP-03

Table VA. Relationship 

of Engineered Safety 

Features (ESF) System 

IDs in GALL V. 2

GALL 

Rev. 0 GALL Rev. 1

A. EP-39

A. EP-47

A. EP-43

A. EP-34

A. E-43

A. EP-44

A. EP-53

A. EP-33

A. EP-13

A. EP-42

A. EP-50

A. EP-35

A. EP-45

A. EP-27

A. EP-46

A. EP-41

A. EP-36

A. EP-37

A. EP-40

A.1-a E-12

A.1-b E-28

A.1-c E-12

A.2-a E-29

A.2-a E-26

A.3-a E-12

A.3-b E-28

A.4-a E-12

A.4-b E-28

A.5-a E-26

A.5-a E-29

A.5-b E-28

A.6-a E-18

A.6-a E-20

A.6-b E-21

A.6-c E-19

A.6-c E-17

A.6-d E-28

B. EP-36

B. EP-37

B. EP-27

B. E-42

B. EP-54

B.1-a E-26

Table VA. Relationship 

of Engineered Safety 

Features (ESF) System 

IDs in GALL V. 2

GALL 

Rev. 0 GALL Rev. 1

B.1-a E-40

B.1-b E-06

B.2-a E-25

B.2-a E-26

B.2-b E-06

C. EP-33

C. EP-48

C. EP-44

C.1-a E-35

C.1-a E-22

C.1-a E-30

C.1-a E-31

C.1-b E-34

C.1-b E-33

D1. E-43

D1. EP-44

D1. EP-31

D1. EP-54

D1. EP-50

D1. EP-45

D1. EP-52

D1. EP-36

D1. EP-40

D1. EP-27

D1. EP-33

D1. EP-46

D1. EP-37

D1. EP-13

D1. EP-35

D1. EP-41

D1. EP-53

D1. EP-49

D1. EP-55

D1. EP-51

D1. EP-47

D1.1-a E-12

D1.1-b E-47

D1.1-c E-13

D1.1-d E-28

D1.2-a E-12

D1.2-b E-28

D1.2-c E-24

D1.3-a E-28
October 2005 C-9 NUREG-1833

Table VA. Relationship 

of Engineered Safety 

Features (ESF) System 

IDs in GALL V. 2

GALL 

Rev. 0 GALL Rev. 1

D1.4-a E-13

D1.4-b E-12

D1.4-c E-28

D1.5-a E-17

D1.5-a E-19

D1.5-b E-28

D1.6-a E-19

D1.6-a E-17

D1.6-b E-18

D1.6-b E-20

D1.6-c E-21

D1.6-d E-28

D1.7-a E-28

D1.7-b E-38

D1.7-b E-12

D1.8-a E-12

D1.8-b E-28

D1.8-c E-01

D2. EP-13

D2. EP-2

D2. EP-45

D2. EP-36

D2. EP-34

D2. EP-47

D2. EP-26

D2. EP-37

D2. EP-50

D2. EP-27

D2. EP-44

D2. EP-32

D2. EP-35

D2. EP-54

D2. EP-40

D2. EP-31

D2. EP-46

D2. EP-33

D2.1-a E-08

D2.1-b E-10

D2.1-c E-37

D2.1-d E-11

D2.1-e E-26

D2.1-e E-14

D2.1-e E-27

Table VA. Relationship 

of Engineered Safety 

Features (ESF) System 

IDs in GALL V. 2

GALL 

Rev. 0 GALL Rev. 1

D2.1-f E-07

D2.2-a E-08

D2.3-a E-09

D2.3-b E-08

D2.3-c E-37

D2.4-a E-20

D2.4-a E-18

D2.4-b E-21

D2.4-b E-23

D2.4-c E-19

D2.4-c E-17

D2.5-a E-26

D2.5-a E-29

D2.5-b E-04

E. E-41

E. EP-38

E. EP-24

E. EP-1

E. EP-25

E. E-44

E. E-45

E.1-a E-28

E.1-b E-46

E.2-a E-02

E.2-b E-03

F. EP-4

F. EP-3

F. EP-14

F. EP-12

F. EP-5

F. EP-29

F. EP-30

F. EP-20

F. EP-9

F. EP-18

F. EP-7

F. EP-10

F. EP-16

F. EP-15

F. EP-28

F. EP-17

F. EP-19

F. EP-22
NUREG-1833 C-10 October 2005

Table VIA. Relationship 

of Electrical 

Components System 

IDs in GALL V. 2

GALL 

Rev. 0 GALL Rev. 1

A. LP-01

A. LP-02

A. LP-03

A. LP-04

A. LP-05

A. LP-06

A. LP-07

A. LP-08

A. LP-09

A. LP-10

A. LP-11

A. LP-12

A.1-a L-01

A.1-b L-02

A.1-c L-03

A.2-a L-04

B.1-a L-05

Table VIIA. Relationship 

of Auxiliary System IDs 

in GALL V. 2

GALL 

Rev. 0 GALL Rev. 1

A1.1-a A-94

A2. AP-79

A2.1-a A-86

A2.1-a A-87

A2.1-b A-89

A2.1-b A-88

A2.1-c A-97

A2.1-c A-96

A3. AP-43

A3. AP-79

A3. AP-31

A3. AP-1

A3. AP-12

A3.1-a A-79

A3.2-a A-39

A3.2-a A-15

A3.2-b A-79

A3.2-c A-79

A3.2-d A-15

A3.3-a A-15

A3.3-a A-39

A3.3-b A-56

A3.3-c A-79

A3.3-d A-15

A3.4-a A-63

A3.4-b A-79

A3.5-a A-15

A3.5-a A-39

A3.5-b A-79

A3.5-c A-15

A3.6-a A-79

A4. AP-31

A4. AP-12

A4. AP-38

A4. AP-62

A4. AP-32

A4. AP-64

A4. AP-43

A4.1-a A-58

A4.2-a A-16

A4.2-a A-40

A4.2-b A-16

A4.3-a A-16

A4.3-a A-40

Table VIIA. Relationship 

of Auxiliary System IDs 

in GALL V. 2

GALL 

Rev. 0 GALL Rev. 1

A4.3-b A-16

A4.4-a A-63

A4.4-b A-70

A4.5-a A-40

A4.5-a A-16

A4.5-b A-16

A4.6-a A-58

B.1-a A-06

B.1-b A-07

B.2-a A-05

C1. AP-59

C1. AP-61

C1. AP-47

C1. AP-56

C1. AP-75

C1. AP-76

C1. AP-30

C1. AP-53

C1.1-a A-38

C1.1-a A-44

C1.1-a A-54

C1.1-a A-47

C1.1-b A-01

C1.1-c A-02

C1.2-a A-44

C1.2-a A-38

C1.2-a A-47

C1.2-a A-54

C1.3-a A-66

C1.3-a A-65

C1.3-a A-64

C1.3-b A-72

C1.4-a A-54

C1.5-a A-51

C1.5-a A-38

C1.6-a A-38

C1.6-a A-54

C2. AP-59

C2. AP-31

C2. AP-30

C2. AP-80

C2. AP-12

C2. AP-63

C2. AP-60
October 2005 C-11 NUREG-1833

Table VIIA. Relationship 

of Auxiliary System IDs 

in GALL V. 2

GALL 

Rev. 0 GALL Rev. 1

C2. AP-47

C2. A-63

C2. AP-32

C2. AP-43

C2.1-a A-25

C2.2-a A-25

C2.2-a A-52

C2.3-a A-25

C2.3-a A-50

C2.4-a A-25

C2.5-a A-25

C3. A-01

C3. AP-53

C3. AP-56

C3. A-02

C3. A-51

C3. AP-61

C3.1-a A-47

C3.1-a A-43

C3.1-a A-38

C3.2-a A-43

C3.2-a A-47

C3.2-a A-38

C3.2-a A-53

C3.3-a A-38

D. AP-81

D.1-a A-80

D.1-a A-26

D.2-a A-80

D.2-a A-26

D.2-a A-103

D.3-a A-80

D.3-a A-26

D.4-a A-26

D.4-a A-80

D.5-a A-26

D.5-a A-80

D.6-a A-26

D.6-a A-80

E1. AP-43

E1. AP-59

E1. AP-65

E1. AP-12

E1. AP-82

Table VIIA. Relationship 

of Auxiliary System IDs 

in GALL V. 2

GALL 

Rev. 0 GALL Rev. 1

E1. AP-47

E1. AP-31

E1. AP-34

E1. AP-30

E1. AP-1

E1. AP-85

E1. AP-79

E1.10-a A-79

E1.1-a A-34

E1.1-a A-57

E1.1-b A-79

E1.2-a A-79

E1.3-a A-34

E1.3-a A-57

E1.3-b A-79

E1.4-a A-79

E1.5-a A-104

E1.5-a A-76

E1.5-b A-79

E1.6-a A-79

E1.7-a A-57

E1.7-a A-34

E1.7-b A-79

E1.7-c A-84

E1.8-a A-57

E1.8-a A-34

E1.8-a A-100

E1.8-b A-69

E1.8-c A-63

E1.8-d A-79

E1.9-a A-79

E1.10-a A-79

E2. AP-73

E2.1-a A-59

E2.2-a A-59

E2.3-a A-59

E2.4-a A-59

E3. A-63

E3. A-58

E3. AP-43

E3. AP-12

E3. AP-32

E3. AP-31

E3. AP-38

Table VIIA. Relationship 

of Auxiliary System IDs 

in GALL V. 2

GALL 

Rev. 0 GALL Rev. 1

E3. AP-60

E3. A-35

E3. AP-63

E3. AP-64

E3. AP-62

E3.1-a A-60

E3.1-b A-62

E3.2-a A-60

E3.2-b A-62

E3.2-c A-34

E3.3-d A-85

E3.4-a A-68

E3.4-a A-71

E3.4-b A-67

E4. AP-59

E4. AP-43

E4. AP-38

E4. AP-31

E4. AP-64

E4. AP-63

E4. AP-47

E4. AP-32

E4. AP-30

E4. AP-12

E4. AP-60

E4.1-a A-35

E4.1-a A-58

E4.1-b A-62

E4.1-c A-61

E4.2-a A-35

E4.3-a A-61

E4.4-a A-67

E4.4-a A-63

F1. AP-43

F1. AP-12

F1. AP-65

F1. AP-34

F1. AP-80

F1. AP-77

F1. AP-30

F1. AP-74

F1. A-63

F1. AP-31

F1. AP-41
NUREG-1833 C-12 October 2005

Table VIIA. Relationship 

of Auxiliary System IDs 

in GALL V. 2

GALL 

Rev. 0 GALL Rev. 1

F1.1-a A-105

F1.1-a A-08

F1.1-a A-10

F1.1-b A-17

F1.1-c A-18

F1.1-c A-73

F1.2-a A-46

F1.3-a A-25

F1.4-a A-09

F1.4-a A-08

F1.4-a A-10

F1.4-b A-17

F2. AP-12

F2. AP-77

F2. AP-30

F2. AP-43

F2. AP-80

F2. A-63

F2. AP-74

F2. AP-41

F2. AP-31

F2.1-a A-10

F2.1-a A-08

F2.1-a A-105

F2.1-b A-17

F2.1-c A-18

F2.1-c A-73

F2.2-a A-46

F2.3-a A-25

F2.4-a A-08

F2.4-a A-09

F2.4-a A-10

F2.4-b A-17

F3. AP-30

F3. AP-41

F3. AP-34

F3. A-50

F3. AP-80

F3. AP-74

F3. A-63

F3. AP-12

F3. AP-65

F3. AP-77

F3. AP-43

Table VIIA. Relationship 

of Auxiliary System IDs 

in GALL V. 2

GALL 

Rev. 0 GALL Rev. 1

F3.1-a A-08

F3.1-a A-10

F3.1-a A-105

F3.1-b A-17

F3.1-c A-18

F3.1-c A-73

F3.2-a A-46

F3.3-a A-25

F3.4-a A-08

F3.4-a A-09

F3.4-a A-10

F3.4-b A-17

F4. AP-41

F4. A-63

F4. AP-12

F4. AP-31

F4. AP-74

F4. AP-77

F4. AP-43

F4. AP-30

F4.1-a A-08

F4.1-a A-10

F4.1-a A-105

F4.1-b A-17

F4.1-c A-18

F4.1-c A-73

F4.2-a A-46

F4.3-a A-25

G. AP-83

G. AP-44

G. AP-56

G. AP-78

G. AP-40

G. AP-54

G. AP-41

G. A-51

G. A-23

G. AP-31

G. AP-30

G. AP-61

G. AP-59

G. A-02

G. A-01

G. AP-47

Table VIIA. Relationship 

of Auxiliary System IDs 

in GALL V. 2

GALL 

Rev. 0 GALL Rev. 1

G.1-a A-19

G.1-a A-20

G.1-b A-92

G.1-b A-90

G.1-c A-93

G.1-c A-91

G.1-d A-22

G.1-d A-21

G.2-a A-19

G.2-a A-20

G.2-b A-90

G.2-b A-92

G.2-c A-93

G.2-c A-91

G.2-d A-21

G.2-d A-22

G.3-a A-20

G.3-a A-19

G.3-b A-92

G.3-b A-90

G.3-c A-91

G.3-c A-93

G.3-d A-22

G.3-d A-21

G.4-a A-20

G.4-a A-19

G.4-b A-90

G.4-b A-92

G.4-c A-91

G.4-c A-93

G.4-d A-22

G.4-d A-21

G.5-a A-90

G.5-b A-91

G.5-c A-21

G.6-a A-55

G.6-a A-33

G.6-b A-45

G.6-b A-33

G.6-b A-55

G.6-b A-47

G.7-a A-82

G.7-b A-83

G.8-a A-28
October 2005

C-13 NUREG-1833

Table VIIA. Relationship 

of Auxiliary System IDs 

in GALL V. 2

GALL Rev. 0 GALL Rev. 1

H1. AP-56

H1. AP-54

H1. AP-35

H1. AP-44

H1. AP-43

H1.A-02

H1. AP-12

H1.1-aA-24

H1.1-bA-01

H1.2-aA-24

H1.3-aA-24

H1.4-aA-30

H1.4-bA-95

H2. AP-55

H2. AP-59

H2. AP-61

H2. AP-39

H2. AP-40

H2.A-47

H2.A-02

H2. AP-47

H2. AP-56

H2. AP-12

H2. AP-33

H2. AP-54

H2. AP-30

H2.A-51

H2. AP-35

H2. AP-43

H2. AP-44

H2. AP-41

H2. AP-45

H2.1-aA-25

H2.1-bA-38

H2.2-aA-23

H2.3-aA-23

H2.4-aA-27

H2.5-aA-30

I. AP-66

I. AP-26

I. AP-27

I.A-105

I. AP-28

I.A-102

Table VIIA. Relationship 

of Auxiliary System IDs 

in GALL V. 2

GALL Rev. 0 GALL Rev. 1

I.1-aA-79

I.1-bA-77

I.1-bA-78

I.1-bA-81

I.2-aA-03

I.2-bA-04

J. AP-51

J. AP-22

J. AP-15

J. AP-13

J. AP-50

J. AP-9

J. AP-2

J. AP-18

J. AP-17

J. AP-20

J. AP-48

J. AP-19

J. AP-3

J. AP-37

J. AP-36

J. AP-52

J. AP-6

J. AP-8

J. AP-11

J. AP-49

J. AP-16

J. AP-4

J. AP-14

Table VIIIA. 

Relationship of Steam 

and Power Conversion 

(SPC) System IDs in 

GALL V. 2

GALL 

Rev. 0 GALL Rev. 1

A. SP-25

A. SP-30

A. SP-46

A.S-23

A. SP-45

A. SP-44

A. SP-32

A. SP-38

A. SP-64

A. SP-27

A. SP-31

A. SP-28

A. SP-43

A. SP-61

A.1-aS-15

A.1-bS-04

A.1-bS-06

A.2-aS-15

A.2-bS-04

A.2-bS-06

B1. SP-43

B1. SP-59

B1. SP-17

B1. SP-44

B1. SP-16

B1.S-10

B1. SP-18

B1. SP-60

B1.1-aS-07

B1.1-bS-08

B1.1-cS-15

B1.2-aS-07

B1.2-bS-15

B2. SP-45

B2. SP-46

B2.S-09

B2.1-aS-05

B2.1-bS-15

B2.1-cS-08

B2.2-aS-15

B2.2-bS-05

C.S-10
NUREG-1833 C-14 October 2005

Table VIIIA. 

Relationship of Steam 

and Power Conversion 

(SPC) System IDs in 

GALL V. 2

GALL 

Rev. 0 GALL Rev. 1

C. S-09

C. SP-16

C. SP-17

C.1-a S-15

C.1-b S-04

C.1-b S-06

C.2-a S-15

C.2-b S-04

C.2-b S-06

D1. SP-16

D1. SP-25

D1. SP-24

D1. SP-38

D1. SP-17

D1. SP-32

D1.1-a S-16

D1.1-b S-11

D1.1-c S-10

D1.2-a S-16

D1.2-b S-10

D1.3-a S-10

D1.3-b S-16

D2. SP-16

D2. SP-38

D2. SP-25

D2. SP-32

D2. SP-24

D2.1-a S-16

D2.1-b S-09

D2.1-c S-11

D2.2-a S-16

D2.2-b S-09

D2.3-a S-16

D2.3-b S-09

E. SP-29

E. SP-38

E. SP-56

E. SP-39

E. SP-17

E. SP-40

E. SP-55

E. SP-19

Table VIIIA. 

Relationship of Steam 

and Power Conversion 

(SPC) System IDs in 

GALL V. 2

GALL 

Rev. 0 GALL Rev. 1

E. SP-36

E. SP-30

E. SP-25

E. SP-27

E. SP-24

E. SP-54

E. SP-26

E. SP-32

E. SP-31

E. SP-41

E. SP-37

E. SP-57

E. SP-8

E. SP-16

E. SP-58

E. SP-42

E.1-a S-16

E.1-b S-10

E.1-b S-09

E.2-a S-16

E.2-b S-09

E.2-b S-10

E.3-a S-10

E.3-a S-09

E.4-a S-22

E.4-a S-21

E.4-a S-19

E.4-a S-18

E.4-b S-24

E.4-b S-26

E.4-c S-28

E.4-d S-21

E.4-d S-22

E.4-d S-19

E.4-d S-18

E.4-e SP-64

E.4-e S-25

E.4-e S-23

E.5-a S-09

E.5-a S-13

E.5-a S-10

E.5-b S-13

Table VIIIA. 

Relationship of Steam 

and Power Conversion 

(SPC) System IDs in 

GALL V. 2

GALL 

Rev. 0 GALL Rev. 1

E.5-c S-31

E.5-d S-01

E.6-a S-10

E.6-a S-09

F. SP-61

F. SP-17

F. SP-27

F. SP-30

F. SP-31

F. SP-55

F. SP-29

F. SP-40

F. SP-56

F. SP-41

F. SP-36

F. SP-54

F. SP-39

F. SP-24

F. SP-8

F. SP-58

F. SP-16

F.1-a S-16

F.1-b S-10

F.2-a S-16

F.2-b S-10

F.3-a S-10

F.4-a S-39

F.4-a S-22

F.4-a S-19

F.4-b S-24

F.4-b S-26

F.4-c S-28

F.4-d S-19

F.4-d S-22

F.4-e S-23

F.4-e S-25

F.4-e SP-64

G. SP-32

G. SP-29

G. SP-31

G. SP-36

G. SP-38
October 2005 C-15 NUREG-1833

Table VIIIA. 

Relationship of Steam 

and Power Conversion 

(SPC) System IDs in 

GALL V. 2

GALL 

Rev. 0 GALL Rev. 1

G. SP-60

G. SP-55

G. SP-56

G. SP-30

G. SP-58

G. SP-37

G. SP-25

G. SP-53

G. SP-54

G. SP-39

G. SP-27

G. SP-16

G. SP-63

G. SP-17

G. SP-41

G. SP-8

G. SP-62

G. SP-28

G. SP-26

G. SP-24

G.1-a S-16

G.1-b S-11

G.1-c S-10

G.1-d S-12

G.1-e S-01

G.2-a S-10

G.3-a S-10

G.4-a S-10

G.4-a S-13

G.4-b S-13

G.4-c S-31

G.4-d S-01

G.5-a S-26

G.5-a S-24

G.5-b S-27

G.5-b S-28

G.5-c S-23

G.5-c S-25

G.5-c SP-64

G.5-d S-17

G.5-d S-20

H. S-40

Table VIIIA. 

Relationship of Steam 

and Power Conversion 

(SPC) System IDs in 

GALL V. 2

GALL 

Rev. 0 GALL Rev. 1

H. S-32

H. S-33

H. S-34

H.1-a S-30

H.1-b S-42

H.1-b S-41

H.1-b S-29

H.2-a S-02

H.2-b S-03

I. SP-35

I. SP-10

I. SP-13

I. SP-6

I. SP-5

I. SP-23

I. SP-34

I. SP-15

I. SP-12

I. SP-11

I. SP-4

I. SP-33

I. SP-9

I. SP-2

I. SP-1
NUREG-1833 C-16 October 2005

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