ML12033A155

Transmittal of Errata Associated with the South Texas Project License Renewal Application

ML12033A155
Person / Time
Site:	South Texas
Issue date:	01/26/2012
From:	Rencurrel D South Texas
To:	Document Control Desk, Office of Nuclear Reactor Regulation
References
NOC-AE-12002789, STI: 33273341, TAC ME4936, TAC ME4937
Download: ML12033A155 (35)

Text

Nuclear Operating Company South Texas Pro/ect Electric Generating Station P.O Box 289 Wadsworth. Texas 77483 January 26, 2012 NOC-AE-12002789 10 CFR 54 STI: 33273341 File: G25 U. S. Nuclear Regulatory Commission Attention: Document Control Desk One White Flint North 11555 Rockville Pike Rockville, MD 20852-2738 South Texas Project Units 1 and 2 Docket Nos. STN 50-498, STN 50-499 Transmittal of Errata Associated with the South Texas Proiect License Renewal Application (TAC Nos. ME4936 and ME4937)

Reference:

STPNOC letter dated October 25, 2010, from G. T. Powell to NRC Document Control Desk, "License Renewal Application" (NOC-AE-10002607) (ML103010257)

By the referenced correspondence, STP Nuclear Operating Company (STPNOC) submitted a License Renewal Application (LRA) for South Texas Project (STP) Units 1 and 2. Subsequent to the application, STPNOC transmitted several letters responding to NRC requests for additional information that resulted in revision to the LRA. STPNOC reviewed these transmittals and identified some errors. This letter is submitted to correct the errors.

The enclosure to this letter provides the errata. Corrections to LRA are depicted in line-in/line-out pages in the enclosure.

There are no regulatory commitments provided in this letter.

Should you have any questions regarding this letter, please contact either Arden Aldridge, STP License Renewal Project Lead, at (361) 972-8243 or Ken Taplett, STP License Renewal Project regulatory point-of-contact, at (361) 972-8416.

I declare under penalty of perjury that the foregoing is true and correct.

Executed on 2/2 6 !2.,t.,

bate Senior Vice President, Technical Support & Oversight KJT

Enclosure:

Errata and Corrections to the STPNOC License Renewal Application 4'7

\\-I-r

NOC-AE-12002789 Page 2 cc:

(paper copy)

(electronic copy)

Regional Administrator, Region IV U. S. Nuclear Regulatory Commission 1600 East Lamar Boulevard Arlington, Texas 76011-4511 Balwant K. Singal Senior Project Manager U.S. Nuclear Regulatory Commission One White Flint North (MS 8B1) 11555 Rockville Pike Rockville, MD 20852 Senior Resident Inspector U. S. Nuclear Regulatory Commission P.O. Box 289, Mail Code: MN116 Wadsworth, TX 77483 C. M. Canady City of Austin Electric Utility Department 721 Barton Springs Road Austin, TX 78704 John W. Daily License Renewal Project Manager (Safety)

U.S. Nuclear Regulatory Commission One White Flint North (MS 011-F1)

Washington, DC 20555-0001 Tam Tran License Renewal Project Manager (Environmental)

U. S. Nuclear Regulatory Commission One White Flint North (MS 011 F01)

Washington, DC 20555-0001 A. H. Gutterman, Esquire Kathryn M. Sutton, Esquire Morgan, Lewis & Bockius, LLP John Ragan Chris O'Hara Jim von Suskil NRG South Texas LP Kevin Polio Richard Pena City Public Service Peter Nemeth Crain Caton & James, P.C.

C. Mele City of Austin Richard A. Ratliff Alice Rogers Texas Department of State Health Services Balwant K. Singal John W. Daily Tam Tran U. S. Nuclear Regulatory Commission

Enclosure NOC-AE-12002789 Page 1 of 33 Enclosure Errata and Corrections to the STPNOC License Renewal Application Reference Affected LRA Section Reason for Correction NOC-AE-1 1002742 Table 3.1.2-1 The Aging Effect Requiring Management for MLI11335A131 Component Type "RVI Neutron Shield Panel" is revised from "Reactor Coolant (Ext)" to "Cracking". The intention of the table revision was to indicate "cracking".

NOC-AE-1 1002742 Table 3.3.2-2 The notes from the original LRA Table 3.3.2-1 ML11335A131 were incorrectly transferred to the referenced letter Table 3.3.2-2. The correct notes from the original LRA Table 3.2.2-2 are reinserted and the note added in the referenced letter as note 3 is renumbered as note 5.

NOC-AE-11002742 Table 3.3.2-19 Plant Specific Note "3" inserted originally in MLI11335A131 the referenced letter is renumbered to note "4". Two letters, NOC-AE-1 1002742 and NOC-AE-11002758 (ML11335A140), used the same note "3" when revising this table.

NOC-AE-1 1002742 Table 3.3.2-21 "Table 1 Item" column for added component ML11335A131 type "Flame Arrestor" is revised to "3.2.1.50" instead of "3.3.1.50" that was in the referenced letter.

NOC-AE-1 1002742 Table 3.3.2-22 Table is revised to delete Plant Specific Note 2 ML11335A131 that was not deleted with deletion of line item in NOC-AE-1 1002742. This is the only line item in the referenced letter that contains this note. As a result, Plant Specific Notes 3 and 4 are renumbered 2 and 3 respectively, and the Notes column for all affected line items in Table 3.3.2-22 are renumbered, where appropriate.

NOC-AE-1 1002750 Table 3.4.2-6 Plant Specific Note "4" in the referenced letter ML11319A026 is revised to note "5". Two letters, NOC-AE-11002750 and NOC-AE-11002758 (ML11335A140), used the same note "4".

NOC-AE-1 1002759 Table 3.5.2-7 First line of Table for Component type ML11334A047 "Concrete Elements" is "lined-in" as a new line item to the Table as it should have been indicated in the referenced letter.

NOC-AE-1 1002750 Appendix Al.16 The words "non-destructive examination ML11319A026 (NDE)" are reinserted in the Appendix. These words were intended to be depicted as revised wording and underlined. These words are consistent with the original LRA but were inadvertently not included in the previous change to this LRA Section (Ref: NOC-AE-11002681, ML11172A096).

Enclosure NOC-AE-12002789 Page 2 of 33 Reference Affected LRA Section Reason for Correction The word "environmental" is revised to "environment" and the word "effect" is added to improve understanding.

The word "period" is depicted as revised wording and underlined. This wording was inadvertently changed to "interval" in the previous change to this LRA Section. The wording is changed back to "period" to match the original LRA.

NOC-AE-1 1002758 Appendix B2.1.17 Under the "Program Description" section, the ML11335A140 word "10" is changed back to "five". The change to five years was made in a previous change (Ref: NOC-AE-1 1002750, ML11319A026) and there was no intention to change back to 10 years in NOC-AE-1 1002758.

In addition, when the change was made in NOC-AE-1 1002750, Table A4-1 was not revised to reflect that the implementation schedule Item 12 is revised to "During the 5 years prior to the period of extended operation".

NOC-AE-1 1002759 Appendix B3.1 Under the "Program Description" section the ML11334A047 title of RIS 2008-30 is reinserted. These words were inadvertently deleted.

Under Item (3) of the "Corrective Actions (Element 7)" of the "Enhancement" section, the word "the" is revised to "of". This editorial error occurred in an earlier change to this Appendix.

The remainder of the program description is included. This description was inadvertently not included in NOC-AE-1 1002759. Although the description that was not included is not depicted as a change, it is the intention that whenever an aging management program is revised that the entire program description be included with the change.

NOC-AE-1 1002750 Table A4-1, Item #12 Item 12 is revised to "During the 5 years prior to the period of extended operation" to be consistent with the change made to Appendix B2.1.17.

NOC-AE-1 1002772 Table A4-1, Item # 20 The redundant words "power cables" under the second bullet in the Commitment column are deleted.

NOC-AE-1 1002772 Table A4-1, Item # 25 The word "prior" to is corrected to "period" in the 6 th bullet in the Commitment column

Enclosure NOC-AE-12002789 Page 3 of 33 Table 3.1.2-1 Internals Reactor Vessel, Internals, and Reactor Coolant System - Summary of Aging Management Evaluation - Reactor Vessel and Component Type Intended Function RVI Lower Core Support-Energy Absorber Assembly Material Stainless Steel Environment f Aging Effect Requiring Management

- Aging Management Program NUREG-1801 Vol.

2 Item IV. B2-24 Coolant Cracking ASME Section XI Inservice Inspection, Subsections IWB, IWC, and IW.D (B12.1__. )

ReactorCoolan FASME Section XI Inservice Inspection, Cracking

'Subsections IWB, IWC, T able1.I Notes Item j 3.1.1.30 E, 5 IV.B2-8 13.1.1.30 E, 5 RVI Neutron Shield SLD Stainless z Reactor Coolant Panel Steel (Ext)

RVI Radial Support TSS Nickel Alloys Reactor Coolant Keys and Clevis (Ext)

Inserts j

I I Cracking

.and IWD (B2.1.1)

ýASME Section XI Inservice Inspection,

,Subsections IWB, IWC,

and IWD (B2.1.1)

IV.B32-20 3.1.1.37 fE, 7

Enclosure NOC-AE-12002789 Page 4 of 33 Table 3.3.2-2 Piping Piping Pump Auxiliary Systems - Summary of Aging Management Evaluation - Spent Fuel Pool Cooling and Cleanup System (Continued)

DE, LBS, jStainless Treated Borated Cracking Water Chemistry VII.A3-10 3.31.90 IE, 3, 4 PB, SIA Steel Water (Int)

(3B2.1.2) and One-Time DF, LBS, PB, SIA LBS, PB, SIA 1Stainless

'Steel i Stainless Steel Treated Borated W ater (I.nt).............

I Borated Water LeakageiExt).

Wall thinning None Il nspeCl, k!/ b4. 1. 1 y.

Flow-Accelerated None Corrosion (B2. 1.6)

None VII.J-16 None H, 35 A

3.3.1.99 Notes for Table 3.3.2-2:

Standard Notes:

A Consistent with NUREG-1 801 item for component, material, environment, and aging effect. AMP is consistent with NUREG-1 801 AMP.

B Consistent with NUREG-1 801 item for component, material, environment, and aging effect. AMP takes some exceptions to NUREG-1 801 AMP C

Component is different, but consistent with NUREG-1801 item for material, environment, and aging effect. AMP is consistent with NUREG-1801 AMP.

E Consistent with NUREG-1801 for material, environment, and aging effect, but a different aging management program is credited or NUREG-1801 identifies a plant-specific aging management program.

G Environment not in NUREG-1801 for this component and material.

H Aging effect not in NUREG-1801 for this component, material and environment combination.

Plant Specific Notes:

1 Loss of preload is conservatively considered to be applicable for all closure bolting.

2 Reduction in heat transfer due to fouling is a potential aging effect/mechanism for stainless steel heat exchanger components in treated borated water. This non-NUREG-1801 line is based upon the component, material, aging effects and aging management program combination of NUREG-1801, line V.A-16.

3 The One-Time Inspection program (B2.1.16) verifies the effectiveness of the Water Chemistry program (B2.1.2) in managing the aging of stainless steel components exposed to treated borated water.

4 The Water Chemistry program (B2.1.2) and the One-Time Inspection program (B2.1.16) manage loss of material due to pitting and crevice corrosion and cracking due to stress corrosion cracking. The One-Time Inspection program (B2.1.16) includes selected components at susceptible locations.

5 Wall thinning due to erosion-corrosion is managed by the Flow-Accelerated Corrosion program (B2.1.6).

Enclosure NOC-AE-12002789 Page 5 of 33 Table 3.3.2-19 Auxiliary Systems - Summary of Aqinq Manaciement Evaluation - Chemical and Volume Control System Component Type Material Environment Aging Effect Ag en Utee nctionT ~

IRequiring Program 1801 o Ie

_I

]Management

'2Item Heat Exchanger PB (CVCS Seal Water I Stainless Steel Return),

Heat Exchanger (CVCS Seal Water Heat Exchanger (CVCS Seal Water Return) tHT, PB Stainless Steel Treated I

Borated Water Treated

{Borated Water

[( n t)

Treated Borated Water

,(,Int)......

Loss of material Water Chemistry VII.El-17

((B2.1.2) and One-Time

_Inspection (1B2.1.16).

Reduction of heat Water Chemistry None transfer (B2.1.2) and One-Time 1l nspection (B2.1. 16)

Cracking

'Water Chemistry VII.E1-5

((B2.1.2) and One-Time Inspection (1B2.1.16) 3.3.1.91 None 3.3.1.08 E, 2 1H, 34 E, 2Aliz1-HT, PB Plant Specific Notes:

1 NUREG-1801 does not address the aging effect of nickel-alloys in borated water leakage. Nickel-alloys subject to an air with borated water leakage environment are similar to stainless steel in a borated water leakage environment and do not experience aging effects due to borated water leakage.

2 The Water Chemistry program (B2.1.2) and the One-Time Inspection program (B2.1.16) manage loss of material due to pitting and crevice corrosion and cracking due to stress corrosion cracking. The One-Time Inspection program (B2.1.16) includes selected components at susceptible locations.

3 Non-inhibited copper alloy > 15% zinc SSCs with surfaces exposed to ventilation atmosphere (internal) or plant indoor air (internal) are subject to wetting due to condensation and thus are subject to loss of material due to selective leaching.

4 The reduction of heat transfer aging effect is not identified in NUREG-1 801 for this component, material, and environment combination. Reduction of heat transfer is not expected in heat exchangers with reactor coolant or treated borated water environments as long as water chemistry is maintained. Reduction of heat transfer is managed with Water Chemistry (B2.1.2) and One Time Inspection (B2.1.16).

Enclosure NOC-AE-12002789 Page 6 of 33 Table 3.3.2-21 Auxiliary Systems - Summary of Aging Management Evaluation - Nonsafety-related Diesel Generators and Auxiliary Fuel Oil System Component Type Intended Material' En vironmnt' Aging Effect Aging Management NUREG-Table I Notes Function Requiring Program 1801 Vol.

Item Management 2 Item Flame Arrestor 1PB Aluminum Fuel Oil (Int)

Loss of material None Fuel Oil Chemistry

((B2.1.14) and One-

.Time Inspection

((B2.1.16)

VII.H1-1 Flame Arrestor IPB Flame Arrestor.

PB 3.3.1.32 3.2.1.50 B

Aluminum IPlant Indoor Air Carbon Fuel Oil (Int)

None V. F-2 Loss of Steel material Fuel Oil Chemistry (B2.1.14) and One-

.Time Inspection (B2.1. 1_

6),

VII.H1-10 13.3.1.20 A

D

Enclosure NOC-AE-12002789 Page 7 of 33 Table 3.3.2-22 Auxiliary Systems - Summary of Aging Management Evaluation - Liquid Waste Processing System Componient Intended Mate'rialI Environmenit Aging Effect Type Function T

~

Requiring >

_________________________I__

Management lAttemperator

!LBS Carbon Steel Attem perator A ttemp er a't o'r closure Bolting Closure Bolting

-Cosu re-b FoIt in...

Closure Bolting

'Closure Bolting Closure Boltigng_

'Closure Bolting SClosure Bolting Filter' Filter LBS LBS LBS LBS iPB, LBS LBS, PB LBS, PB

[BS, SIA 1LBS, SIA I LBS, SIA Carbon Steel Carbon Steel Carbon Steel Carbon Steel Carbon Steel Carbon Steel Stainless Steel Stainless Steel Stainless Steel Stainless Steel

!Plant Indoor Air (Ext)

Steam (Int)

Borated Water Leakage (Ext)

Borated Water Leakage (Ext)

Borated Water

'Leakage (Ext)

Plant Indoor Air (Ext)

P iant Indo-or Air

{.L ?xt)..........

Borated Water Leakage (Ext)

Plant Indoor Air (Ext)

Plant Indoor Air (Ext)..

Raw Water (Int)

Loss of material Wall thinning Loss of preload Loss of material Loss of material Loss of material Loss of preload Loss of preload Loss of preload None Loss of material Loss of material Aging Management Program External Surfaces Monitoring Program

~(B2.1.20)

Water Chemistry (B2.1.2) and One-Time 4Inspection (B2.1.16)

Flow-Accelerated I..corrosion (B2.i.. 6)

!Bolting Integrity (B2.1.7)

Boric Acid Corrosion I(B2.1.4)

Boric Acid Corrosion i(B2.1.4)

{Bolting Integrity (B2.1.7)

Bolting Integrity (B12.1.7)

I.B..olting Integrity,,(B2.1*.)*

Bolting Integrity (132.1.7)

None Inspection of Internal Surfaces in Miscellaneous Piping and Ducting Lo.mpo m£neqnts (B2.1. 22)

VIllI.A-16 3.4.1.02 VIII.A-17 IV. C2-8 VII1. 1-2 VII1. 1-2 VI1. 1-4 VII1. 1-5 IV. C2-8 None VII.J-15 iNUREG,- Table 1 Item

, Notes VII.I-8 13.3.1.58 B

13.4.1.29 3.1.1.52 3.3.1.89

'3.3.1.89 13.3.1.43 13.3.1.45 3.1.1.52 None 3.3.1.94 A

B B

A B

B

A VIC1-15 i'3.3.1.79 E, 32

Enclosure NOC-AE-12002789 Page 8 of 33 Table 3.3.2-22 Auxiliary Systems - Summary of Agin* Management Evaluation - Liquid Waste Processing System (Continued)

Component Intended " Material Environment Aging Effect Aging Management

NUREG, Table I Item Notes Type Function I,

Requiring Program 1801 Vol.

Management 2 Item,_

Flow Element Flow Element Flow Element Flow Element Flow Element Flow Elmn LBS, SIA LBS LBS ILBS_

LBS LBS Stainless Steel Stainless Steel Stainless Steel Stainless Steel Stainless Steel Borated Water Leakage (Ext)

Demineralized Water (Int)

Plant Indoor Air (Ext)..

Steam (Int) steam (Int)

Treated Borated Water (Int)

None Loss of material None Cracking Loss of material Loss of material Cracking Loss of material Water Chemistry (B2.1.2) and One-Time Inspectin (B2-..16)_q_

None Water Chemistry (B2.1.2) and One-Time Inspection (B2.1.16)

Water Chemistry (B2.1.2) and One-Time Inspection (B2.1.16)

Water Chemistry (B2.1.2) and One-Time Inspection (82.1.16)

Water Chemistry (B2.1.2) and One-Time Inspection (q2.1.16)

Boric Acid Corrosion (B2.1.4)

None VII.J-16 13.3.1.99 VIII.E-29 13.4.1.16 VII.J-15 3.3.1.94 VIII.A-10 3.4.1.39 A

A E, 43 E, 43 E, 43 tE, 43 A

VIII.A-12 3.4.1.37 FlowElement LBS, SIA Flow Element LBS, SIA Heat I-LBS, SIA iExchanger (RCDT Heat I vrhannorN I

t Stainless Steel Stainless Treated Borated Steel Water (Int)

Carbon Steel

[Heat

[Exchanger (RCDT Heat Exchanger)

Heat Exchanger I(RCDT Heat

'Exchanger)

ILBS, SIA ICarbon Steel F!BS'tSIA__ {Carbon Steel Borated Water Leakage Closed Cycle Cooling Water (Int)

Plant Indoor Air (Ext)

VlI.E1-17 3.3.1.91 VII.El-20 3.3.1.90 VIl.l-10 3.3.1.89 VII.C2-1 3.3.1.48 VII.I-8 3.i3..58 Loss of material Closed-Cycle Coolin

!Water System (B2.1 Loss of material External Surfaces Monitoring Program

[~(82.1.20) g

.10)

A B

B

Enclosure NOC-AE-12002789 Page 9 of 33 Table 3.3.2-22 Auxiliary Systems - Summary of Aging Management Evaluation - Liquid Waste Processing System (Continued)

Component:

Intended Material Environment Agng Effect Aging Management-NUREG-Tablel]Iltem Notes Type Functki*

.Requiring Program 18i Vol.

eat_

LBS, S a

st e

Management on2 Item 3.3.1.99 Heat LBS, SIA 'Stainless Borated Water None None VI.-6 3.3.1.99

'A

'Exchanger 1(RCDT Heat SExchanger)

Heat Exchanger (RCDT Heat Exchanger)

Heat Exchanger (RCDT Heat

,Exchanger)

Orifice rnf-ice Orifice Orifice Orifice Piping Piping Steel Leakage (Ext)

LBS, SIA Stainless

!Treated Borated Steel Water (Int)

-LBS, SIA Stainless Treated Borated Steel Water (I nt)

LBS, SIA Stainless Steel ILBS.

Stainless Steel ILBS, SIA Stainless I A.

Steel LBS, SlA Stainless Steel Borated Water Leakage (Ext)

Demineralized Water (Int)

P0lant Indo'o-r Air i(Ext).

"-Raw Water (Int)

Loss of material Cracking None Loss of material None Loss of material Loss of material Cracking Loss of _material Loss of material Water Chemistry l(B2.1.2) and One-Time Inspection (B2.1.16)

Water Chemistry

'(B2.1.2) and One-Time Inspection (B2.1.16)

VII.E1-17 3.3.1.91 E, 43 V13.3.1.90 1E, 43 iNone VII.J-16 3.3.1.99 VIII.E-29 13.4.1.16 1A

'A LBS, SIA Stainless Treated Borated Steel iWater (Int)

LBS, SIA Stainless

!Treated Borated Steel Water (I nt) iWater Chemistry (B2.1.2) and One-Time Inspection (B2.1.16)

None Inspection of Internal Surfaces in Miscellaneous Piping and Ducting Components (B2.1.22)

Water Chemistry (B2.1.2) and One-Time Inspection (B2.1.16)

Water Chemistry

((B2.1.2) and One-Time I nspection (B2.1.16)

Boric Acid Corrosion (132 1.4)

Closed-Cycle Cooling Water System (B12.1.10)

VII.J-15 3.3.1.94 A

VI3C11-15 3.3.1.79

'E, 32 VII.E1-17 3.3.1.91 VII.E1-20 3.3.1.90 VIl.-lO 13.3.1.89 VII.C2-14

'3.3.1.47 E, 43 E, 43

ýB LBS LBS Carbon Steel CaribonSteel I Borated Water ILeakage (Ext).

Closed Cycle

'[Cool!ng Water (!nt.

Enclosure NOC-AE-12002789 Page 10 of 33 ient Evaluation - Liquid Waste Processing System (Contim Aging Effect

. Requiring Management Aging Management Program NUREGq-Table I Item 1801 V.V, Notes I Loss of material (Int)

Piping LBTS Piping TCF*

Indoor Air 1Loss of material

!(Ext)

Steel,PIant In door Air j(Int)

Piping Piping Piping Piping Piping iPiping LBS Carbon Steel Plant Indoor Air (Int)

LBS LBS ILBS LBS LBS Carbon Steel Raw Water (Int)

Cumulative fatigue damage Loss of material Loss of material ICumulative fatigue damage LLoss of material Loss of material Cumulative fatigue damage Water Chemistry (B2.1.2) and One-Time Inspection (B2.1.16)

External Surfaces Monitoring Program

_(B2-1 20),......

Time-Limited Aging Analysis evaluated for the period of extended Inspection of Internal Surfaces in Miscellaneous Piping and Ducting Components (B2..1.22)_

Inspection of Internal Surfaces in Miscellaneous Piping and Ducting Components (B2.1.22)_

Time-Limited Aging Analysis evaluated for the period of extended operation Water Chemistry (B2.1.2) and One-Time Inspection (B2-1. 116)_

Water Chemistry (B2.1.2) and One-Time Inspection (B2.1_.16).

Time-Limited Aging Analysis evaluated for the period of extended operation VIII. E-34 VA-19 3.2.1.32 B

VIIE1-18 3.3.1.02 VII.I-8 3.3.1.58 Carbon Steel Stainless Steel Carbon Steel Secondary Water (Int)

Secondary Water (Int)

Secondary Water (Int)

VII.C1-19 3.3.1.76 VII.E1-16 13.3.1.02

ýVIIIE-29 3.4.1.16 A

VIII. E-34 3.4.1.04 A

Carbon Steel Steam (Int)

VIII.B1-10 3.4.1.01 A

Enclosure NOC-AE-12002789 Page 11 of 33 Table 3.3.2-22 Auxiliary Systems - Summary of Aging Management Evaluation - Liquid Waste Processing System (Continued) r.

Component Intended Material Aging Effect Aging Management NUREG-Table I Item Type Function 1,.Requiring Program 1801 Vol.

Management j 2Item II De If, k

Qf I Cf I +

P IJV Piping Piping Piping Piping Piping Piping Piping iping Piping L LJ.J 01 LJ U I UU~~ 1 UC3 Ilk I~I Carbon SteeliSteam (1nt)

LBS, SIA

LBS, PB, S SS

LBS, SIA,

LBS, LBS, PB, I Stainless

_ Steel SIA jStainless Steel IA, Stainless Steel PB, Stainless SS Steel SIA Stainless Steel SIA Stainless Steel PB, Stainless Steel PB, Stainless Steel

.Stainiess Steel Cast jAustenitic Borated Water Leakage (Ext)

Demineralized Water (Int)

Dry Gas (Int)

Plant Indoor Air (Ext)

Plant Indoor Air (Int)

Raw Water (Int)

,Treated Borated Water (Int)

Treated Borated Water (Int)

Plant Indoor Air (Ext)

Loss of material Wall thinning None Loss of material rNone Loss of material Loss of material Cracking None lWater Chemistry l(B2.1.2) and One-Time Inspection (B2.1.16_

Flow-Accelerated Corrosion (B2.1.6) jNone Water Chemistry (B2.1.2) and One-Time Inspection (B2.1.16)_

None i V III./-*-

I*)

iI VIII.A-17 iVII.J-16 VIII.E-29 3.4.1.29 B

3.3.1.99 W

I AIIII A ICZ I I A I W)

A 3.4.1.16 A

VlI.J-19 3.3.1.97 A

None VII.J-15 Inspection of Internal V.A-26 Surfaces in Miscellaneous Piping and Ducting Components (B2.1.22)

Inspection of Internal VII. C1-15 Surfaces in Miscellaneous Piping land Ducting oComponents (B2.1.22) i 0Water Chem istry VIL.E1-17 (B2.1.2) and One-Time I nspection_(2J. 1D,6)

Water Chemistry VIIEl-20 (B2.1.2) and One-Time

]inspect ion(B2.,-16)

None VlI.J-15 3.3.1.94 A

i 3.2.1.08 3.3.1.79 E

E, 32 E, 43

LBS, SIA

LBS, SIA

- iiS 3.3.1.91 i3.3.1.90 E, 43 3.3.1.94 IA

Enclosure NOC-AE-12002789 Page 12 of 33 Table 3.3.2-22 Auxiliary Systems - Summary of Aging Management Evaluation - Liquid Waste Processing System (Continued)

Component Intended Material Environtment Aging Effect Aging Management NUREG-,Table I Item Notes Type Function Requiring Program 1801 Vol.

____T___

Management 2 Item Piping LBS LBS Stainless Steel Cast Austenitic Raw Water (Int)

Pump Carbon Steel Demineralized Water (Int)

Carbon Steel Plant Indoor Air I(Ext)

Pump LBS Loss of material Loss of material Loss of material

!Loss of material Loss of material Loss of material None Inspection of Internal VII.C1-15 Surfaces in Miscellaneous Piping and Ducting Components (B2.1.22)_ !.

Water Chemistry VIII.E-34

((B2.1.2) and One-Time Inspection (B2.1.16)

External Surfaces VI1.l-8 Monitoring Program I(B2.1.20),,

Water Chemistry VIII.E-34 (B2.1.2) and One-Time Inspection B2.1.16)

Selective Leaching of VII.E1.14 Materials (B2.1.17)

External Surfaces VII. 1-8

,Monitoring Program (B12 1 20) i None VII.J-15 3.3.1.79 3.4.1.04 A

3.3.1.58 B

3.4.1.04 A

E, 32 Pump Pum Pump Pump Pump Pump

[Pump

-LBS*

Cast Iron (Gray Cast Iron)

LBS Cast Iron (Gray Cast

_ Iron)

LBS rCast Iron (Gray Cast ILBS, SIA I Stainless Steel LBS, SIA IStainless Steel LBS Stainless Steel Demineralized Water (Int)

Demineralized Water (Int)

Plant Indoor A-r I(Ext)

Plant Indoor Air Raw Water (Int)

Secondary Water (Int)

Borated Water Leakage (Ext) 3.3.1.85 B

3.3.1.58 B

3.3.1.94 Loss of material Inspection of Internal

VII.C1-15 Surfaces in Miscellaneous Piping and Ducting Components (B12.1.22)

Loss of material Water Chemistry iVIII.E-29 (B2.1.2) and One-Time I nspection (B2.1 6) 13.3.1.79 A

E, 32 A

A 3.4.1.16 LBS, SIA Stainless Steel Cast iAustenitic None None VII.J-16 3.3.1.99

Enclosure NOC-AE-12002789 Page 13 of 33 Table 3. 3.2-22 Auxiliarv Systems - Summary of Aainca Manaaement Evaluation - Liouid Waste Processina Svstem (Continued)

Component Intended Material Environment Aging Effect Aging Management

,-NUREG-Table I Item Notes Type

-Function Requiring "Program 1801 Vol.

Management 2 Item Pump Pump 1SIA ISIA

!Stainless Steel Cast IAustenitic Stainless Steel Cast Austenitic Plant Indoor Air (Ext)

None Pump 1LBS, SIA IStainless ISteel Cast

'Austenitic Pump LBS, SIA Stainless

':Steel Cast Austenitic Sample Vessel LBS Stainless Steel Sample VesseI LBS

'Stainless

'Steel Raw Water (Int)

Treated Borated Water (Int)

Treated Borated Water (Int)

Plant Indoor Air (Ext)

Raw Water (Int)

Plant Indoor Air (Ext)

Loss of material Loss of material ICracking None-Loss of material Loss of material Loss of material None tlnspection of Internal Surfaces in Miscellaneous Piping Iand Ducting lComponents (§2.1.22)

Water Chemistry i(B2.1.2) and One-Time Inspection (B12.1.16)

Water Chemistry (B2.1.2) and One-Time Inspecion (B2.,1.16).

None Inspection of Internal Surfaces in Miscellaneous Piping and Ducting Co.mponents (B2. 1.22)

External Surfaces Monitoring Program

.,B_ -*.20)...........

Inspection of Internal Surfaces in Miscellaneous Piping and Ducting Components (B2.1.22)

.VII.J-15 II.C1 13.3.1.79 1 E, 32 3.3.1.94 A

VII.El-i17 3.3.1.91

-VI I....

E12

}319 0 V1 I.J--1 513.3.1.94 VII.CI-15 13.3.1.79 E, 43 E, 43 A

B E, 32 Sight Gauge Sight Gauge Sight Gauge Sight Gauge Sight Gauge LBS LBS LBSJC LBS Carbon Steel FCarbon Steel Raw Water (Int)

VII.C1-89 VI.-13 3.3.1.58 3.3.1.76 Glass Glass IGlass Demineralized Water (Int)

Plant Indoor Air (Ext)

Raw Water (Int)

None None None None None None 3.3.1.93 A

VII.J-8 13.3.1.93

-TA VII.J-11 3.3.1.93 k

Enclosure NOC-AE-12002789 Page 14 of 33 Table 3.3.2-22 Auxiliary Systems-Summary of Acaincg Manaaement Evaluation - Liquid Waste Processin* System (Continued)

Component Intended Material Environment Aging Effect Aging Management NUREG-1 Table IItem Notes

(...Function Requiring I

Program 1801 Vol. I Management 2 Item J_

Sight Gauge Sight Gauge Strainer Strainer

[Strainer

[Strainer Tank Tank Tank

{Tank LBS LBS LBS tLBS TLBS Stainless Steel FStainless Steel Carbon Steel Carbon Steel Stainless Steel Demineralized Water (Int)

Plant Indoor Air

,(E x t).....................

Plant Indoor Air (Ext)

Raw Water (Int)

Demineralized Water (Int)

Loss of material I

LBS Stainless Plant Indoor Air Steel (Ext)_ __

LBS Carbon Steel Borated Water

.. Leakage(Ext)

LBS Carbon Steel Plant Indoor Air (Ext)

LBS Carbon Steel Plant Indoor Air (infi Loss of material Loss of material Loss of material None Loss of material Loss of material Loss of material Loss of material None I'None Water Chemistry VIII.E-29 (B2.1.2) and One-Time Inspection (B2.1.16).

None VII.J-15 External Surfaces iVII.l-8 Monitoring Program Inspection of Internal VIIV.C1-1 Surfaces in Miscellaneous Piping and Ducting Components (B211.22)

Water Chemistry VIII.E-29 (B2.1.2) and One-Time Ispection (B2.1.16)

None iVII.J-15 Boric Acid Corrosion IVIII-10 External Surfaces VII.I-8 Monitoring Program (B2.-20)

Inspection of Internal

!V.A-19 Surfaces in Miscellaneous Piping and Ducting Components (B2 1,22) __

Water Chemistry VIII. E-34 (B2.1.2) and One-Time Inspection (B2.1.16).

None iVII.J-16 3.4.1.16 3.3.1.94 3.3.1.58 3.3.1.76 3.4.1.16 3.3.1.94 13.3.1.8 9 E, 32 A

A B

B A

A I

3.3.1.58 3.2.1.32 LBS Carbon Steel

\\,*,v.

Secondary Water (Int)

Borated Water Leakage (Ext)

Borated Water Leakage (Ext) 3.4.1.04 A

3.3.1.99 A

3.3.1.99 C

Tank.

Tank SLBS, SIA Stainless Steel SIA Stainless

_ ISteel None VII.J-16

Enclosure NOC-AE-12002789 Page 15 of 33 Table 3.3.2-22 Auxiliary Systems - Summary of Aging Management Evaluation -

Component Type Intended Function Material Environment Aging Effect Requiring_

Management Aging, Management

• ' Program 1.

Tank Tank Tank Tank Tank T-ank LBS iStainless Demineralized

'Steel Water (Int)

LBS, SIA Stainless J

• Steel LB3S, SIA 'Stainless Steel LBS, SIA iStainless ISteel Dry Gas (Int)

Plant Indoor Air (Ext)_

Plant Indoor Air (Int) jRaw Water (I nt)

SIA

Stainless Steel Loss of material None None Loss of material Loss of material Loss of material Cracking None None Loss of material Water Chemistry (B2.1.2) and One-Time Inspection (P2..16 None None VII.J-15 3.3.1.94 Inspection of Internal

ýV.A-26 3.2.1.08 Surfaces in Miscellaneous Piping and Ducting Components B(2.l1.22)

Inspection of Internal VII.C1-15 3.3.1.79 Surfaces in Miscellaneous Piping and Ducting Components (B2.1.2_

j

2)

Water Chemistry VII.EI-17 3.3.1.91 (B2.1.2) and One-Time ILnspe ection (B12.11).16 Water Chemistry VII.E1-20 3.3.1.90 (B2.1.2) and One-Time Inspection (B2.1.16)

None rVII.J-16 3.3.1.99 C

E E, 32 E, 43 E, 43 A

A

VII.J-19 3.3.1.97 A

LBS, SIA IStainless Steel Tank

' LBS, SIA Stainless Steel Thermowell ILBS, SIA 'Stainless Steel Thermowell LBS Stainless I

Steel Thermowell JLBS Stainless Steel Thermowell LBS IStainless Steel Water (Int)

Borated Water Seakage_(E.xt) -..

I Plant Indoor Air (Ext).

Raw Water (Int)

None VII.J-15 3.3.1.94 t

Steam (Int)

Cracking Inspection of Internal VII.C1-15 Surfaces in Miscellaneous Piping and Ducting Components (B2.1.22)

Water Chemistry VIIIA-10 (B2.1.2) and One-Time Inspection (B2.1.16) j 3.3.1.79 1EIt, 3 t3.4.1 yiý-

Enclosure NOC-AE-12002789 Page 16 of 33 Table 3.3.2-22 Auxiliary Systems - Summary of Agqinq Management Evaluation - Liquid Waste Processinq System (Continued)

Component Intended Material Environment Aging Effect Aging Management NUREG*

fTale I Item Notes Type Function I

Requiring Program 1801 Vol.

_I j

{

,Management 2 Item Thermowell I LBS Stainless Steel

[Thermowell Thermowell Tubing

'Tubing Tubing jubing

.t ub~ig...............

Tubing 6Tubing Tubing

LBS, LBS, LBS LBS LBS

,LBS

...LBS-SIA Stainless Steel SIA Stainless Steel SIA Stainless Steel Stainless Steel Stainless Steel Stainless Steel

.Stainless Steel Stainless Steel Steam (Int)

Loss of material Treated Borated Loss of material Water (Int)

Treated Borated Cracking Water (Int)

Water Chemistry (B2.1.2) and One-Time Inspection (B2.1.16)_..

Water Chemistry (B2.1.2) and One-Time Inspection (B2.1.16)_

Water Chemistry

,(B2.1.2) and One-Time 1 Inspection (B2.1.161 VIII.A-12

!3.4.1.37 IE, 43 VII.E1-17

'3.3.1.91 VII.E1-20 13.3.1.90 Borated Water Leakage (Ext)

Demineralized Water (Int)

Plant Indoor Ai None None Loss of material _Water Chemistry (B2.1.2) and One-Time Inspection (B2_1,.16) r

ýNone Nn VII.J-16 3.3.1.99

ýV

.E-9 K4.'1'.16 IE, 43 E, 43 A

A VII.J-15

-3.3.1.94

.(Ext)

Plant Indoor Air Loss of n (Int)

Raw Water (Int)

Steam (Int)

Steam (Int)

Treated Borated Water (Int)

Loss of n Cracking naterial Inspection of Internal V.A-26 Surfaces in Miscellaneous Piping and Ducting I Components (B2.1.22) _

naterial Inspection of Internal VII.C1-15 Surfaces in Miscellaneous Piping and Ducting Components (B2.1,.22)

Water Chemistry VIII.A-10 3.2.1.08 E

13.3.1.79 E, 32 LBS 7 Stainless iSteel 11.BSS§,*iStStainless Steel

((B2.1.2) and One-Time Inspection (B2.1.16)

Loss of material Water Chemistry VIII.A-12 (B2.1.2) and One-Time Inspection (B2.1.16)__......

Loss of material Water Chemistry VII.E1-17 1(B2.1.2) and One-Time

_____ I[,nspection (B23.1.16).

3.4.1.39 1.37 13.3.1.91 E, 43 E, 43 E, 43

Enclosure NOC-AE-12002789 Page 17 of 33 Table 3.3.2-22 Aux~iliarv Svstems - Summairy of Aciinc Manac1ement Evaluiation - Linuiid Waste Prociessina Svsftem (Continuedi)

Component Intended Material Environment Aging Effect Type

Function, Requiring

_Management Tubing Valve Valve iILBS, SIA !Stainless cSteel

ýLBS Carbon Steel Valve Valve Valve Valve IValve Valve LBS LBS LBS LBS LBS LBS iL LBS iLBS lCarbon Steel Carbon Steel Carbon Steel Treated Borated Water (Int)

Closed Cycle Cooling Water(I nt)_

Demineralized Water (Int)

Plant Indoor Air (Ext)

Plant Indoor Air (Int)

Loss of material Loss of material Loss of material Loss of material Loss of material Cracking I Aging Management

ý,ýProgram Water Chemistry (B2.1.2) and One-Time Inspection (B?. 1.16).

Closed-Cycle Cooling Water System r(B2. 1.10)

Water Chemistry (B2.1.2) and One-Time I!nspection (q2.1.16)

External Surfaces Monitoring Program 1(B2.1.20)

'Inspection of Internal

!Surfaces in Miscellaneous Piping and Ducting Comnponents _(B2, 1.22)

Inspection of Internal VII.El-20 VII.C2-14 3.3.1.47 VIII.E-34

[3.4.1.04 VII.I-8 V.A-19 I

NUREG-Table I Item Notes

-1801 Vol.

2 Item 3.3.1.90 E, 43 3.3.1.58 3.2.1.32 B

A B

B A

-Carbon Steel Raw Water (Int) 4 tCarbon Steel Secondary Water (Int)

!Carbon Steel Steam (Int)

Loss of ma Loss of ma Wall thinnir Loss of ma None Surfaces in Miscellaneous Piping and Ducting Components (B2.1.22) terial Water Chemistry (12.1.2) and One-Time Ilnspection (B2.1.-16) terial Water Chemistry i(B2.1.2) and One-Time Inspection (B_2.1-16) ng Flow-Accelerated Corrosion (B2.1.6) terial Water Chemistry (B2.1.2) and One-Time Inspection (B2.1.16)

None VIII.A-16 VII.C1-19 3.3.1.76 VIII.E-34 13.4.1.04 3.4.1.02 A

dCarbon Steel ISteam (Int)

VIII.A-17 3.4.t.29 B

Valve Valve lCopper Alloy t&opper Alloy Demineralized Water (Int)

Plant Indoor Air (Ext).

VIll.A-5 VIII.1-2 3.4.1.15 A

3.4.1.41

Enclosure NOC-AE-12002789 Page 18 of 33 Table 3.3.2-22 Auxiliary Systems - Summary of Aging Management Evaluation - Liquid Waste Processing System (Continued)

Component Intended Material Environment Aging Effect Aging Management NUREG-.Table I Item Note Type.

Function Requiring Program-1801 Vol.

Management 2 Item Valve I Valve Vaive Valve Valve Z Valve Valve LBS Copper Alloy Raw Water (Int)

Loss of material Loss of material None LBS ILBS, PB,

'SIA LBS LBS, PB, SIA LBS, PB, SIA LBS, SIA

{Copper Alloy Stainless Steel Stainless Steel Stainless Steel Stainless Steel Stainless Steel Stainless Steel L

Stainless Steel Stainless Steel Secondary Water (Int)

Borated Water Leakage_(Ext)____

Demineralized Water (Int)

Dry Gas (Int)

Plant Indoor Air (Ext)

Plant Indoor Air (Int)

Raw Water (Int)

Secondary Water (Int)

Inspection of Internal Surfaces in Miscellaneous Piping and Ducting Commponents (B2-122_

Water Chemistry (B2.1.2) and One-Time Inspection (B2.1.16)._

None Water Chemistry (B2.1.2) and One-Time Inspection (B2. 1.16)_

None VIl.C 1-9 3.3.1.81 VIII.A-5 72lI.J-16

ýVIII.E-29 VII.J-19 3.4.1.15 E, 32 A

3.3.1.99

!A 3.4.1.16

!A Loss of material None None Loss of material Valve Valve Valve LBS, SIA Loss of material None iVII.J-15 Inspection of Internal V.A-26 Surfaces in Miscellaneous Piping and Ducting Components (B2.1.22)

Inspection of Internal VII.C1-15 Surfaces in Miscellaneous Piping and Ducting Components (B2.1.22)_

Water Chemistry VIII.E-29 (B2.1.2) and One-Time Inspection (B2.1.16) 3.3.1.97 3.3.1.94 3.2.1.08 13.3.1.79 A

A E,32

'43 I

Loss of material LBS 3.4.1.16 3.4.1.39 E

Steam (Int)

Cracking Water Chemistry VIll.A-10 (B2.1.2) and One-Time Inspection (B2.1.16)

Enclosure NOC-AE-12002789 Page 19 of 33 Table 3.3.2-22 Auxiliary Svstems-Summary of Aaina Manaaement Evaluation - Liauid Waste Processina Svstem (Continued)

Component Intended Material" Environiment IAgingEfc Aging Management NUREG-Table 1 Item Notes Type Function Requiring Program 1801 Vol.

_Management

__2 Item Valve LBS Stainless Steel Steam (Int)

Valve Valve Valve LBS, PB, SIA Stainless.

Treated Borated Steel Water (Int)

Valve L[,

PB, Stainless SIA Steel LBS, PB, Stainless SIA Steel Cast Austenitic LBS, SIA IStainless Steel Cast Austenitic LBS IStainless

!Steel Cast Austenitic Valve Treated Borated Water (Int)

Borated Water Leakage (Ext)

Plant Indoor Air (Ext)

Plant Indoor Air (I nt)

Raw Water (Int)

Treated Borated Water (Int) lTreated Borated Water (Int)

ILoss of material 11-oss of material lCracking None None Loss of material Loss of material

,Loss of material Cracking Water Chemistry lVIII.A-12 (B2.1.2) and One-Time Inspecton(B2.1.16)

Water Chemistry VII.El-17 (B2.1.2) and One-Time Inspection (B2.1.16)

Water Chemistry VII.E1-20 (B2.1.2) and One-Time Inspection (B2.1.16)

None VII.J-16 3.3.1.91 3.3.1.90 3.3.1.99 3.4.1.37 E, 43 None IVII.J-15 13.3.1.94 E, 43 E, 43 A

Valve 1LBS, SIA Stainless Steel Cast Austen itic Inspection of Internal Surfaces in Miscellaneous Piping and Ducting Components (B2.1.22)

FInspecton of Internal Surfaces in Miscellaneous Piping and Ducting

,Components (B2..22)_

Water Chemistry (B2.1.2) and One-Time I nspecti.on (B21 _.16)

Water Chemistry (B2.1.2) and One-Time I nspection (B2.,1..16)

VII.C1-15 VII.E1-17 V.A-26 13.2.1.08 E

3.3.1.79 3.3.1.91 Valve Valve LBS, PB, Stainless SIA Steel Cast

-Austenitic LBS, PB, !Stainless SIA

!Steel Cast I

jAustenitic E, 32 VIl.E1-20 3.3.1.90

Enclosure NOC-AE-12002789 Page 20 of 33 Notes for Table 3.3.2-22:

Standard Notes:

A Consistent with NUREG-1801 item for component, material, environment, and aging effect. AMP is consistent with NUREG-1801 AMP.

B Consistent with NUREG-1801 item for component, material, environment, and aging effect. AMP takes some exceptions to NUREG-1801 AMP.

C Component is different, but consistent with NUREG-1801 item for material, environment, and aging effect. AMP is consistent with NUREG-1801 AMP.

E Consistent with NUREG-1801 for material, environment, and aging effect, but a different aging management program is credited or NUREG-1 801 identifies a plant-specific aging management program.

G Environment not in NUREG-1801 for this component and material.

H Aging effect not in NUREG-1 801 for this component, material and environment combination.

Plant Specific Notes:

1 Loss of preload is conservatively considered to be applicable for all closure bolting.

2-Operating experience does not suggest there is any aging effect, and the use of stainless steel up to 20002F ;and-5 weight percent NaOH is commo in idustrial applications with no specaial consideration for aging. There is no NUREG4 1801 line that covers NaO 3-2 The component environment is miscellaneous radioactive waste drains that have been evaluated as a raw water environment. Loss of material on internal component surfaces exposed to a mixed waste water environment classified as raw water is managed by Inspection of Internal Surfaces in Miscellaneous Piping and Ducting Components (B2.1.22) instead of Open-Cycle Cooling Water System (B2.1.9).

4-,a The Water Chemistry program (B2.1.2) and the One-Time Inspection program (B2.1.16) manage loss of material due to pitting and crevice corrosion and cracking due to stress corrosion cracking. The One-Time Inspection program (B2.1.16) includes selected components at susceptible locations.

Enclosure NOC-AE-12002789 Page 21 of 33 Table 3.4.2-6 Steam and Power Conversion System - Summary of Aaincl Manaqement Evaluation - Auxiliary Feedwater System Component Intended Material Environiment>*

Aging Effect Aging Management NUREG-Table I Item Notes Type Function I

ý. Requiring Program 1801 Vol.

i:,

Management 2 Item Tank PB Tank Tank Stainless Steel Stainless Steel Stainless steel Atmosphere/

Weather (fExt)_

Concrete (Ext)

Dry Gas (Int)

None None iNone None G

Loss of material None Inspection of Internal None Surfaces in Miscellaneous Piping and Ducting Components (B2.1.22)L None VIII.1-12 None 3.4.1.44 G, 45 A

~PB

_L__

Plant Specific Notes:

1 Loss of preload is conservatively considered to be applicable for all closure bolting.

2 Non-inhibited copper alloy >15% zinc SSCs with surfaces exposed to ventilation atmosphere (internal) or plant indoor air (internal) are subject to wetting due to condensation and thus are subject to loss of material due to selective leaching.

3 The Water Chemistry program (B2.1.2) and the One-Time Inspection program (B2.1.16) manage loss of material due to pitting and crevice corrosion and cracking due to stress corrosion cracking. The One-Time Inspection program (B2.1.16) includes selected components at susceptible locations.

4 These items are assigned the environment of Atmosphere/ Weather (Internal). The items are vented or open to the outside atmosphere so the distinction between internal and external is not relevant for aging purposes. These stainless steel components are located outside with an uncontrolled external air environment and are not exposed to aggressive chemical species. The STP plant outdoor environment is not subject to industry air pollution or saline environment. Alternate wetting and drying has shown a tendency to "wash" the surface material rather than concentrate contaminants. Stainless steel does not experience any appreciable aging effects in this environment.

5 A visual inspection of the external surface of the bottom of tanks sittina directly on soil or concrete cannot be performed. A volumetric examination from the inside of the bottom of the tank is performed in lieu of an external inspection.

Enclosure NOC-AE-12002789 Page 22 of 33 Table 3.5.2-7 Containments, Structures, and Component Supports - Summary of Aging Management Evaluation - Electrical Componenit Type Concrete Elements Foundations and Structures (Continued)

Intended Material Environment A

E Function

Requiring..

Bre(Srcua)

Managemenzt FLB, SH, Concrete Buried (Structural) Increase in SS (Ext) porosity and permeability, cracking, loss of material (spalling, scalin~g),

B.

Concrete Plant Indoor Air Cracking due to ISH, SPB, (Structural) (Ext) expansion Aging Management[

U REG-Table I item Notes Prog tran 1801 Vol.

Structures Monitoring IlI.A.3-5 3.5.1.1 3 1

A

!Program (B2.1.32)

Structures Monitoring Program (B2.1.32)

Concrete Elements Concre ete Elements

ýSS SHs..SS.

III.A3-2 3.5.1.27 1

-:9......... 3 5 1 '

ILA 3.5.1.2,

!A

ýA Concrete I Plant Indoor Air

!(Structural) (Ext)

Cracking, loss of Structures Monitoring bond, and loss of Program (B2.1.32) material (spalling, scaling).

Enclosure NOC-AE-12002789 Page 23 of 33 A1.16 One-Time Inspection The One-Time Inspection program conducts one-time inspections of plant system piping and components to verify the effectiveness of the Water Chemistry program (A1.2), Fuel Oil Chemistry program (A1.14), and Lubricating Oil Analysis program (A1.23). The aging effects to be evaluated by the One-Time Inspection program are loss of material, cracking, and reduction of heat transfer. The One-Time Inspection program determines non-destructive examination (NDE) sample sizes based on the population of components in a group sharing the same material, environment and aging effects. For each population, a representative sample size of 20 percent of the population is selected up to a maximum of 25 components. The components making up the sample are those determined to be most susceptible to degradation based on a review of environment, condition and operating experience. The program will focus on bounding or lead components most susceptible to aging due to time in service and severity of operating conditions. Inspections will be performed using a variety of NDE methods, including visual, volumetric, and surface techniques by qualified inspectors. The program will not be used for component inspections with known age-related degradation mechanisms, or when the environment in the period of extended operation is not equivalent to that in the prior 40 years.

The One-Time Inspection program specifies corrective actions if aging effects are found. The corrective action program may specify follow-up inspections for confirmation of aging effects at the same or different locations. If aging effects are detected, a plant-specific program will be developed for the material, environmental, and aging effect combination that produced the aging effects.

This new program will be implemented and completed within the 10 year intewal eri prior to the period of extended operation. Industry and plant-specific operating experience will be evaluated in the development and implementation of this program.

Enclosure NOC-AE-12002789 Page 24 of 33 B2.1.17 Selective Leaching of Materials Program Description The Selective Leaching of Materials program manages the loss of material due to selective leaching for copper alloys with greater than 15 percent zinc and gray cast iron components exposed to treated water, raw water, and groundwater (buried) within the scope of license renewal.

The Selective Leaching of Materials program is a new program which includes a one-time inspection of a sample of components made from gray cast iron and copper alloys with greater than 15 percent zinc. Sample selection criteria will focus on bounding or lead components most susceptible to aging due to time in service, severity of operating conditions, and lowest design margin. The program procedure provides for visual and mechanical inspections for each system/material/environment combination and for follow-up engineering evaluation in the event that graphitization of gray cast iron or dezincification of copper alloys with greater than 15 percent zinc components is detected. Sample sizes for selective leaching are based on 20 percent of the material/environment group population to a maximum of 25 components. If buried gray cast iron valves are removed from the fire protection system, then at least one of them will be evaluated to determine the extent of selective leaching of the valve. The plant-specific Selective Leaching of Aluminum Bronze program (B2.1.37) covers aluminum bronze components. Inspection of buried components subject to selective leaching is covered in Buried Piping and Tanks Inspection (B2.1.18).

The Selective Leaching of Materials program will be implemented during the 40-five years prior to the period of extended operation.

NUREG-1801 Consistency The Selective Leaching of Materials program is a new program that, when implemented, will be consistent, with exception to NUREG-1801,Section XI.M33, Selective Leaching of Materials.

Exceptions to NUREG-1801 Proqram Elements Affected:

Scope of Program (Element 1)

NUREG-1 801,Section XI.M33 states that the Selective Leaching of Materials program should include bronze or aluminum bronze components that may be exposed to a raw water, treated water, or groundwater environment. Aluminum bronze is not managed by the Selective Leaching of Materials program. STP currently has a plant specific Selective Leaching of Aluminum Bronze program (B2.1.37), which covers these aluminum bronze components.

Scope of Program (Element 1), Parameters Monitored or Inspected (Element 3), and Detection of Aging Effects (Element 4)

NUREG-1801,Section XI.M33 recommends hardness testing of sample components in addition to visual inspections. However, a qualitative determination of selective leaching is used in lieu of Brinell hardness testing for components within the scope of the STP Selective Leaching of Materials program. The exception involves the use of examinations, other than Brinell hardness testing, identified in NUREG-1801 to identify the presence of selective leaching of materials.

The exception is justified; because (1) hardness testing may not be feasible for most

Enclosure NOC-AE-12002789 Page 25 of 33 components due to form and configuration and (2) other mechanical means (e.g., scraping, or chipping) provide an equally valid means of identification.

Additionally, hardness testing only provides definitive results if baseline values are available for comparison purposes. Specific material contents for copper alloys may not be known and gray cast irons may not have published hardness numbers. Without specific numbers for comparison, hardness testing would yield unusable results. In lieu of hardness testing, visual and mechanical inspections will be performed on a sampling of components constructed of copper alloys with greater than 15 percent zinc and gray cast iron from various station system environments. Follow-up examinations or evaluations are performed on component material samples where indications of dezincification, de-alloying, or graphitization are visually detected and additional analysis, as part of the engineering evaluation, is required. The engineering evaluation may require confirmation with a metallurgical evaluation (which may include a microstructure examination).

NUREG 1801,Section XI.M33 requires visual inspection and hardness measurement of

'materials susceptible to selective leaching. This is consistent with the strategy in the Buried Piping and Tanks Inspection program (B2.1.18) for managing loss of material in buried fire protection piping.

Enhancements None Operating Experience To date, there have been no reported cases of loss of material attributable to graphitization or dezincification.

Through-wall cracks have been identified in essential cooling water system piping initiated by pre-existing weld defects and propagated by a de-alloying phenomenon. The flaws evaluated appeared in welds with backing rings. STP has analyzed the effects of the cracking and found that the degradation is slow so that rapid or catastrophic failure is not a consideration and determined that the leakage can be detected before the flaw reaches a limiting size that would affect the intended function of the essential cooling water system. A monitoring and inspection program provides confidence in the ability to detect the leakage. In order to identify and evaluate future leaks, the accessible large bore piping welds with backing rings are visually inspected every six months for evidence of leakage. A walk down of the yard above buried essential cooling water system pipe is performed every six months for evidence of soil changes that may indicate pressure boundary leakage. The most susceptible components are cast aluminum bronze fittings (flanges and tees) with backing ring welds. A special VT-2 visual examination of the system is performed every six months to identify new de-alloying locations.

An operability review and an NRC relief request are performed for all through-wall leaks in piping larger than one-inch in diameter. The long-term strategy for essential cooling water system piping de-alloying is to replace fittings when through-wall de-alloying is discovered. This strategy is acceptable based on the very slow degradation mechanism coupled with the preservation of structural integrity and is consistent with the EPRI Service Water Piping Guideline. These ongoing activities are detailed in the Selective Leaching of Aluminum Bronze program (B2.1.37) and are examples of where selective leaching was detected and plant procedures and inspection activities were implemented to ensure that the intended functions of the essential cooling water system are maintained.

Enclosure NOC-AE-12002789 Page 26 of 33 As additional industry and plant-specific applicable operating experience becomes available, it will be evaluated and incorporated into the program through the STP condition reporting and operating experience programs.

Conclusion The implementation of the Selective Leaching of Materials program will provide reasonable assurance that aging effects will be managed such that the systems and components within the scope of this program will continue to perform their intended functions consistent with the current licensing basis for the period of extended operation.

Enclosure NOC-AE-12002789 Page 27 of 33 B3.1 METAL FATIGUE OF REACTOR COOLANT PRESSURE BOUNDARY Program Description The Metal Fatigue of Reactor Coolant Pressure Boundary program manages fatigue cracking caused by anticipated cyclic strains in metal components of the RCPB. The program ensures that actual plant experience remains bounded by the transients assumed in the design calculations, or that appropriate corrective actions maintain the design and licensing basis by other acceptable means.

The Metal Fatigue of Reactor Coolant Pressure Boundary program consists of cycle counting activities. The program will be enhanced to monitor and trend fatigue usage at selected locations in the reactor coolant pressure boundary. The program will be enhanced to include additional transients and locations identified by the evaluation of ASME Section III fatigue analyses, locations necessary to ensure accurate calculations of fatigue, and the NUREG/CR-6260 locations for a newer-vintage Westinghouse Plant. The supporting environmental life correction factor calculations were performed with NUREG/CR-6583 for carbon and low alloy steels and with NUREG/CR-5704 for austenitic stainless steels.

The Metal Fatigue of Reactor Coolant Pressure Boundary program tracks the occurrences of selected transients and will be enhanced to monitor the cumulative usage factors (CUFs) at selected locations using one of the following methods:

1) The Cycle Counting (CC) method does not periodically calculate CUF; however, transient event cycles affecting the location (e.g. plant heatup and plant cooldown) are counted to ensure that the numbers of transient events assumed by the design calculations are not exceeded.

2) The Cycle Based Fatigue (CBF) management method utilizes the CC results and stress intensity ranges generated with the ASME Ill methods that use six stress-tensors to perform periodic CUF calculations, consistent with RIS 2008-30, Fatigue Analysis of Nuclear Power Plant Components for a selected location. The fatigue accumulation is tracked to determine approach to the ASME allowable fatigue limit of 1.0.

The Metal Fatigue of Reactor Coolant Pressure Boundary program continuously monitors plant data, and maintains a record of the data collected. The collected data are analyzed to identify operational transients and events, calculate usage factors for selected monitored locations, and compare the calculated usage factors to allowable limits. Periodic review of the calculations ensures that usage factors will not exceed the allowable value of 1.0 without an appropriate evaluation and any further necessary actions. If a cycle count or CUF value increases to a program action limit, corrective actions will be initiated to evaluate the design limits and determine appropriate specific corrective actions. Action limits permit completion of corrective actions before an assumed number of events in a fatigue analysis is exceeded.

NUREG-1801 Consistency The Metal Fatigue of Reactor Coolant Pressure Boundary program is an existing program that, following enhancement, will be consistent with NUREG-1801,Section X.M1, Metal Fatigue of Reactor Coolant Pressure Boundary.

Enclosure NOC-AE-12002789 Page 28 of 33 Exceptions to NUREG-1801 None Enhancements Prior to the period of extended operation, the following enhancements will be implemented in the following program elements:

Scope of Program (Element 1) and Monitoring and Trending (Element 5)

Procedures will be enhanced to include locations identified by the evaluation of ASME Section III fatigue analyses, locations necessary to ensure accurate calculations of fatigue, and the NUREG/CR-6260 locations for a newer-vintage Westinghouse Plant.

Scope of the Program (Element 1), and Parameters Monitored or Inspected (Element 3)

Procedures will be enhanced to include additional transients that contribute significantly to fatigue usage identified by the evaluation of ASME Section III fatigue analyses.

Scope of the Program (Element 1)

Procedures will be enhanced to ensure the fatigue crack growth analyses, which support the leak-before-break analyses and ASME Section Xl evaluations, remain valid by counting the transients used in the analyses.

Detection of Aging Effects (Element 4)

The procedures will be enhanced to 1) include additional transients necessary to ensure accurate calculations of fatigue, 2) fatigue usage monitoring at specified locations, and

3) specify the frequency and process of periodic reviews of the results of the monitored cycle count and CUF data at least once per fuel cycle. This review will compare the results against the corrective action limits to determine any approach to action limits and any necessary revisions to the fatigue analyses will be included in the corrective actions.

Monitoring and Trending (Element 5)

STP will perform a review of design basis ASME Class 1 component fatigue evaluations to determine whether the NUREG/CR-6260-based components that have been evaluated for the effects of the reactor coolant environment on fatigue usage are the limiting components for the STP configuration. If more limiting components are identified, the most limiting component will be evaluated for the effects of the reactor coolant environment on fatigue usage. If the limiting location consists of nickel alloy, the methodology for nickel alloy in NUREG/CR-6909 will be used to perform the environmentally-assisted fatigue calculation.

Preventive Actions (Element 2) and Acceptance Criteria (Element 6)

The procedures will be enhanced to include additional cycle count and fatigue usage action limits, which will invoke appropriate corrective actions if a component approaches a cycle count action limit or a fatigue usage action limit. Action limits permit completion of corrective actions before the design limits are exceeded. The acceptance criteria associated with the NUREG/CR-6260 sample locations for a newer vintage Westinghouse plant will account for environmental effects on fatigue.

Enclosure NOC-AE-12002789 Page 29 of 33 Cycle Count Action Limits:

Cycle count action limits are selected to initiate corrective action when the cycle count for any of the critical thermal or pressure transients is projected to reach the design limit within the next three fuel cycles.

CUF Action Limits:

CUF action limits require corrective action when the calculated CUF for any monitored location is projected to reach 1.0 within the next three fuel cycles.

Corrective Actions (Element 7)

Procedures will be enhanced to include appropriate corrective actions to be invoked if a component approaches a cycle count or CUF action limit.

If a cycle count action limit is reached, acceptable corrective actions include:

1) Review of fatigue usage calculations:

a) To identify the components and analyses affected by the transient in question.

b) To determine whether the transient in question contributes significantly to CUF.

c) To ensure that the analytical bases of the high energy line break (HELB) locations are maintained.

2) Evaluation of remaining margins on CUF.

3) Review of the fatigue crack growth and stability analyses which support the leak before break exemptions and relief from the ASME Section Xl flaw removal or inspection requirements to ensure that the analytical bases remain valid. Re-analysis of a fatigue crack growth analysis must be consistent with or reconciled to the originally submitted analysis and receive the same level of regulatory review as the original analysis.

4) Redefinition of the specified number of cycles (e.g., by reducing specified numbers of cycles for other transients and using the margin to increase the allowed number of cycles for the transient that is approaching its specified number of cycles).

5) Redefinition of the transient to remove conservatism in the pressure and temperature ranges.

These preliminary actions are designed to determine how close the approach is to the 1.0 limit, and from those determinations, set new action limits. If the CUF has approached 1.0 then further actions described below for cumulative fatigue usage action limits may be invoked.

If a CUF action limit is reached acceptable corrective actions include:

1) Repair the component.

2) Replace the component. If a limiting component is replaced, assess the effect on locations monitored by the program. If a limiting component is replaced, resetting its cumulative fatigue usage factor to zero, a component which was previously bounded by the replaced component will become the limiting component and may need to be monitored.

3) Perform a more rigorous analysis of the component to demonstrate that the design code limit will not be exceeded.

Enclosure NOC-AE-12002789 Page 30 of 33 Operating Experience The STP industry operating experience program reviews industry experience, including experience that may affect fatigue management, to ensure that applicable experience is evaluated and incorporated in plant analyses and procedures. Any necessary evaluations are conducted under the plant corrective action program.

The Metal Fatigue of Reactor Coolant Pressure Boundary program was implemented in response to industry experience that indicated that the design basis set of transients used for fatigue analyses of the reactor coolant pressure boundary did not include some significant transients, and therefore might not be limiting for components affected by them. Examples:

Thermal stratification of pressurizer surge line piping:

In response to NRC Bulletin 88-11, Westinghouse performed a plant-specific evaluation of STP pressurizer surge lines. The surge line stratification analysis was based on STP design transients. It was concluded that thermal stratification does not affect the integrity of the pressurizer surge lines. STP responses to NRC Bulletin 88-1 1 describe the inspections, analyses, and procedural revisions made to ensure that thermal stratification does not affect the integrity of the pressurizer surge lines. In addition, the responses noted that fatigue analyses were updated to ensure compliance with applicable codes and license commitments.

Thermal fatigue cracking in normally-isolated piping:

In 1988, as identified in NRC Bulletin 88-08, there were several instances of thermal fatigue cracking in normally stagnant lines attached to reactor coolant system (RCS) piping. This issue was addressed by utilities by conducting evaluations and monitoring to ensure that further leakage would not occur. STP performed a complete analysis of systems connected to the RCS. The review concluded that the potential for the described thermal conditions existed only in the normal charging, alternate charging, and auxiliary spray lines. However, these systems are separated and only hot water can leak through the charging and auxiliary spray lines, reducing the potential for thermal cycling.

Conclusion The continued implementation of the Metal Fatigue of Reactor Coolant Pressure Boundary program provides reasonable assurance that aging effects will be managed such that the systems and components within the scope of this program will continue to perform their intended functions consistent with the current licensing basis for the period of extended operation.

Enclosure NOC-AE-12002789 Page 31 of 33 A4 LICENSE RENEWAL COMMITMENTS Table A4-1 identifies proposed actions committed to by STPNOC for STP Units 1 and 2 in its License Renewal Application. These and other actions are proposed regulatory commitments. This list will be revised, as necessary, in subsequent amendments to reflect changes resulting from NRC questions and STPNOC responses. STPNOC will utilize the STP commitment tracking system to track regulatory commitments. The Condition Report (CR) number in the Implementation Schedule column of the table is for STPNOC tracking purposes and is not part of the amended LRA.

Table A4-1 License Renewal Commitments Item #

Commitment LRA Implementation SeCtiOs

.Schedule 12 Implement the Selective Leaching of Materials program as described in LRA Section B2.1.17.

B2.1.17 During the 4-0 five years prior to the period of extended operation 20 Enhance the Inaccessible Medium Voltage Cables Not Subject to 10 CFR 50.49 Environmental B2.1.25 Prior to the period of Qualification Requirements program procedures to:

extended operation identify the cables, manholes, and trenches that are within the scope of the program, require all in-scope non-EQ inaccessible medium and low voltage power cables (>400 CR 10-23275-1 volts) pweF-Gables exposed to significant moisture be tested at least once every six years with the first test being completed prior to period of extended operation, require that the acceptance criteria be defined prior to each test for the specific type of test performed and the specific cable tested, require an engineering evaluation that considers the age and operating environment of the cable be performed when the test acceptance criteria are not met. The engineering evaluation shall consider the significance of the test or inspection results, the operability of the component, the reportability of the event, the extent of the concern, the potential root causes for not meeting the test or inspection acceptance criteria, the corrective actions required, and the likelihood of recurrence.

inspect in-scope manholes and trenches based on plant-specific operating experience with water accumulation, require inspections be conducted at least annually, event-driven inspections of in-scope manholes will be performed as an on-demand activity based on actual plant experience.

perform direct observation that cables are not wetted or submerged, remove collected water and verification of sump pump operability, initiate a corrective action if wetted cables or inoperable sump pumps are found,

Enclosure NOC-AE-12002789 Page 32 of 33 Table A4-1 License Renewal Commitments Item #

Commitment LRA Implementation Section Schedule inspect cables/splices and cable support structures if wetted cables are found, take corrective actions to keep cables dry, manhole inspection results are evaluated based on actual plant experience with the inspection frequency increased based on experience with water accumulation.

testing of in-scope inaccessible medium and low voltage (>400 volts) power cables exposed to significant moisture using a test capable of detecting reduced insulation resistance, trend inspection and test results to provide additional information on the rate of cable insulation degradation, test frequency may be adjusted based on test results or operating experience, require that the acceptance criterion for manhole and trench be cables/splices and support structures is that they are not submerged or immersed in water, and require an extent of condition when an unacceptable condition or situation is identified.

25 Enhance the Structures Monitoring Program procedures to:

B2.1.32 Prior to the period of include the switchyard control building into the scope of the Structures extended operation Monitoring Program, specify inspections of seismic gaps, caulking and sealants, duct banks and CR 10-23600-1 manholes, valve pits and access vaults, doors, electrical conduits, raceways, cable trays, electrical cabinets/enclosures and associated anchorage, monitor at least two groundwater samples every five years for pH, sulfates, and chloride concentrations, specify that the inspection frequency for structures within the scope of license renewal will be in accordance with ACI 349.3R, Table 6.1, which specifies:

o For below-grade structures and structures in controlled interior environment (except inside primary containment), all accessible areas of both units will be inspected every 10 years.

o For all other structures (including inside primary containment), all accessible areas of both units will be inspected every 5 years.

specify inspector qualifications in accordance with ACI 349.3R-96, require the performance of a periodic visual inspection of the accessible sections of the spent fuel pool and transfer canal tell-tale drain lines for blockage every five years. The first inspection will be performed within the 5 years before entering the p"GI period of extended operation,

Enclosure NOC-AE-12002789 Page 33 of 33 Table A4-1 License Renewal Commitments Item #

Commitment LAImplementation Secio Schedule specify ACI 349.3R-96 and ACI 201.1 R-68 as the basis for defining quantitative acceptance criteria, and specify the preventive actions for storage, protection and lubricants recommended in Section 2 of Research Council for Structural Connections publication "Specification for Structural Joints Using ASTM A325 or A490 Bolts" for ASTM A325, ASTM F1 852 and/or ASTM 490 bolts.

Procedures will be enhanced to perform opportunistic inspections of exposed portions of the below-grade concrete when excavated for any reason, Procedures will be enhanced to require an evaluation should ground water be determined to be aggressive or inspections of accessible concrete structural elements identify degradation. The evaluation will be performed to determine the appropriate actions necessary to assure that the affected structures will continue to perform their intended function. These actions may include increased visual inspections or other examination techniques.

specify that visual examinations will be augmented with volumetric examinations, in accordance with ASME Code Section Xl, Table IWB-2500-1, Examination Category B-G-l, to detect SCC for 20 percent (25 bolts maximum) of high strength bolts greater than 1-inch nominal diameter and with an actual yield strength greater than or equal to 150 ksi.