GO2-11-185, License Renewal Application Supplement

License Renewal Application Supplement

ML11325A056
Person / Time
Site:	Columbia
Issue date:	11/16/2011
From:	Javorik A Energy Northwest
To:	Document Control Desk, Office of Nuclear Reactor Regulation
References
GO2-11-185
Download: ML11325A056 (41)

Text

0 ENERAlex L. Javorik Columbia Generating Station NORT W EST.O.Box 968, PE0 Richland, WA 99352-0968 6

NORTHI IEST Ph. 509-377-8555 F. 509-377-2354 aljavorik@ energy-northwest.com November 16, 2011 G02-11-185 U.S. Nuclear Regulatory Commission ATTN: Document Control Desk Washington, D.C. 20555-0001

Subject:

COLUMBIA GENERATING STATION, DOCKET NO. 50-397 LICENSE RENEWAL APPLICATION SUPPLEMENT

References:

1) Letter, G02-1 0-11, dated January 19, 2010, WS Oxenford (Energy Northwest) to NRC, "License Renewal Application"

2) Letter dated October 14, 2010, NRC to SK Gambhir (Energy Northwest),

"Request for Additional Information for the Review of the Columbia Generating Station, License Renewal Application," (ADAMS Accession No. ML102800426)

3) Letter dated October 5, 2011, DA Swank (Energy Northwest) to NRC, "Response to Request for Additional Information License Renewal Application," (G02-11-164)

Dear Sir or Madam:

By Reference 1, Energy Northwest requested the renewal of the Columbia Generating Station (Columbia) operating license. Via Reference 2, the Nuclear Regulatory Commission (NRC) requested additional information related to the Energy Northwest submittal. Energy Northwest has recently identified additional information related to a topic discussed in Reference 2. This information contradicts statements made in Reference 2 and the draft Safety Evaluation Report (SER). The clarification is provided in the Attachment to this letter and Energy Northwest requests the applicable section of the draft SER be revised with this clarifying information prior to final issuance of the SER.

Via reference 3 Energy Northwest submitted Amendment 43 to the Columbia License Renewal Application (LRA) which provided the evaluation of the Time-Limited Aging Analysis (TLAA) for in-scope cranes and hoists at Columbia. However, this amendment did not include the amended pages for the FSAR supplement related to this TLAA. contains these pages as part of Amendment 48.

K) (I~J

LICENSE RENEWAL APPLICATION SUPPLEMENT Page 2 of 2 Additionally, based on recent conversations with NRC staff, discussions held during the Advisory Committee on Reactor Safeguards (ACRS) subcommittee meeting, and typographical errors or omissions, Energy Northwest is providing supplemental information for the LRA.

Transmitted herewith in the Attachment is supplemental information to the Columbia LRA. Enclosure 1 contains Amendment 48 to the Columbia License Renewal Application. No new commitments are included in this supplement.

As was provided in the original application, revised Boundary Drawings are provided in as information only to aid the reviewers and are not part of the LRA submittal.

If you have any questions or require additional information, please contact Abbas Mostala at (509) 377-4197.

I declare under penalty of perjury that the foregoing is true and correct. Executed on the date of this letter.

Respectfully, AL Javo-i-k Acting Vice President, Engineering

Attachment:

License Renewal Application Supplement :

License Renewal Application Amendment 48 :

Revised Boundary Drawings cc:

NRC Region IV Administrator NRC NRR Project Manager NRC Senior Resident Inspector/988C EFSEC Manager RN Sherman - BPA/1 399 WA Horin - Winston & Strawn AD Cunanan - NRC NRR (w/a)

BE Holian - NRC NRR RR Cowley - WDOH

LICENSE RENEWAL APPLICATION SUPPLEMENT Page 1 of 3 License Renewal Application Supplement Energy Northwest is providing a License Renewal Application (LRA) supplement based on ACRS Sub-committee questions, miscellaneous LRA revisions based on errors and omissions, and LRA editorials. Following are issues addressed per this supplement:

Summary of Issues

1. During a walkdown it was noted that some non-safety related piping and components containing fluid or steam near safety related auxiliary steam valves AS-V-68A/B were not in scope for 10 CFR 54.4(a)(2). These valves are supported off the external wall of the Reactor Building (seismic category I structure), but within the Service building which is a seismic category II structure.

Due to this unique configuration, the potential for non-safety related components to affect safety related components was overlooked during the initial scoping process. Amendment 48 contains the new LRA line items for components that could affect these safety related valves. The fire protection system located in this area of the Service Building was brought into scope. A new boundary drawing LR-217-00,144, and revised boundary drawings LR-M513, LR-M514-1, and LR-M515-4 are included for information.

2. During the ACRS sub-committee meeting on October 19, 2011, a sub-committee member questioned the identification of leakage associated with buried piping as a result of internal corrosion which was identified in the LRA, B.2.5 Buried Piping and Tanks Inspection Program under Operating Experience. After further review, the statement referred to leakage in the potable water system that occurred in a portion of the system that is outside the scope of license renewal. This sentence in LRA section B.2.5 Buried Piping and Tanks Inspection Program Operating Experience discussion is clarified in the attached amendment, to state that the subject leakage occurred in a portion of the system that is outside the scope of license renewal. There has been no in-scope buried piping that has had leakage due to internal corrosion.

3. The original License Renewal Application (LRA) did not credit the FAC program for aging management of the non-class 1 portions of the RHR system. The Columbia FAC program does monitor some of the non-class 1 RHR lines during startup and shutdown. The LRA is amended to add the non-class 1 portions of the RHR system that are in the FAC program. LRA Table 3.2.1, item number 3.2.1-19, LRA Table 3.2.2-1, row numbers 127 through 136 and plant specific note 208 have been added to the LRA under Amendment 48. An extent of condition review was performed and no other systems were found where the non-class 1 sections that were being managed by the FAC program were not listed in the LRA.

4. The response to RAI B.2.47-1 (G02-11-018) did not include the appropriate amended License Renewal Application (LRA) page regarding the sampling methodology for the Selective Leaching Inspection program (B.2.47). The

LICENSE RENEWAL APPLICATION SUPPLEMENT Page 2 of 3 sampling methodology chosen is based on NUREG-1 801 for 20% of each population, based on material-environment combinations, up to a maximum of 25 inspections per population. The appropriate page (B-1 80) is now amended per Amendment 48.

5. Letter G02-11-164 provided the evaluation of the Time-Limited Aging Analysis (TLAA) for in-scope cranes and hoists at Columbia and included Amendment 43 to the license renewal application (LRA) for revision of the affected pages.

However, this amendment did not include an update to the Final Safety Analysis Report (FSAR) supplement of the LRA for this plant specific TLAA. Amendment 48 included with this letter provides the FSAR supplement for this TLAA.

6. The draft SER notes under the discussion in section 3.5.2.2.1 that "the applicant has no leakage detection system or alarm that could identify this possible leakage into the annular space between the steel containment and the shield wall, other than the sand pocket drains." This was based on discussions held in a conference call in September 2010 as documented in RAI 3.5.2.2.1.4-1 issued by letter dated October 14, 2010 (ADAMS Accession No. ML102800426).

Recently, Energy Northwest has confirmed that leak detection with alarm capability does exist for this annular space. This is provided by drain lines from the region of primary containment at the top of this annular space and below the refuel bellows seal which would be the most likely source of any leakage into the annular space. All the drain lines in this region funnel into a common drain line header which has a flow indicating switch (FIS) installed in the piping. This FIS provides alarm to the main control room at Columbia if a flow of greater than 1.0 gpm is detected in this drain piping. This FIS is calibrated every six years and based on a search of control room logs and the corrective action database, this alarm has not been received to date. Therefore, Energy Northwest requests the SER be revised to reflect this availability of leak detection and alarm for the annular space. Note that this will not require an amendment to the above mentioned RAI or the LRA as this function was not discussed in the response to the RAI or in the LRA. All commitments as stated in the LRA related to monitoring of potential leakage and loss of material in this annular space will still be maintained..

7. During work to identify inaccessible cables that operate at greater than or equal to 400 volts, Energy Northwest identified another manhole that is subject to the requirements of the Inaccessible Power Cables Not Subject to 10 CFR 50.49 EQ Requirements Program. This manhole does not contain in scope medium Voltage cables and was therefore not subject to the program until the program was modified to include cables that operate at greater than or equal to 400 volts (GALL Rev. 2). This manhole is located in the Circulating Water Pumphouse underneath (below ground level) the motor control centers and is referred to as room B105 "Electrical Vault". This location is subject to water intrusion and has an installed sump pump. Amendment 48 updates the Inaccessible Power Cables Not Subject to 10 CFR 50.49 EQ Requirements Program to address sump pumps.

LICENSE RENEWAL APPLICATION SUPPLEMENT Page 3 of 3

8. Miscellaneous Editorials - typographical errors and LRA omissions as noted in Amendment 48.

LICENSE RENEWAL APPLICATION SUPPLEMENT Page 1 of 2 LICENSE RENEWAL APPLICATION AMENDMENT 48 Section Page RAI Number Number Number 2.3.3.22 2.3-94 Supplemental 2.3.3.22 2.3-94a Supplemental 2.3.3.48 2.3-162a Supplemental 2.5.5.2 2.5-5 Supplemental Table 3.2.1 Line 3.2-20 Supplemental Item 3.2.1-19 Table 3.2.2-1 Insert Line 3.2-49a Supplemental Items Table 3.2.2-1 Insert Line 3.2-49b Supplemental Items 127 - 131 Table 3.2.2-1 Insert Line 3.2-49c Supplemental Items 132 - 136 Plant-Specific Notes, Insert 3.2-90 Supplemental Line Item 0208 Table 3.3.2-22, Insert Line 3.3-256f Supplemental Items Table 3.3.2-22, Insert Line 3.3-256g Supplemental Items 236 - 241 Tables 3.3.2-45, Insert Line 3.3-397g Supplemental Items Table 3.3.2-45, Insert Line 3.3-397o Supplemental Items 54 - 60 Plant-Specific Notes, Line Item 3.6-28 Supplemental 0605 A. 1.2.32 A-18a Supplemental A.1.2.32 A-18b Supplemental A.1.3.7.5 A-41 Supplemental A.1.3.7.5 A-41b Supplemental

LICENSE RENEWAL APPLICATION SUPPLEMENT Page 2 of 2 Section Page RAI Number Number Number Table A-i, Line A-44 Editorial Item -10 Table A-i, Line A-45a Editorial Item 14 Table A-i, Line A-46a Editorial Items 17 & 18 Table B-i Insert B-18b Supplemental Line Item Table B-2 B-22 Supplemental Table B-2 Insert B-25 Supplemental Line Items B.2.5 B-40 Supplemental B.2.32 B-1 33a Supplemental B.2.32 B-1 34a Supplemental B.2.32 B-135a Supplemental B.2.47 B-180 Supplemental

Columbia Generating Station ISection 2.3.3.22 License Renewal Application Technical Information 1301 provides automatic fire protection for the main control room Power Generation Control Cabinet (PGCC) under-floor areas.

Eighteen Halon 1301 systems are installed in the various main control room PGCC sub-floor duct sections to discharge on activation of their associated thermal detector units.

Thermal detector operation also causes a local alarm and indication on the main control room fire control panel. Smoke detectors are located in each PGCC section to provide early warning alarm. Each system includes supervision features that actuate a trouble alarm and indication on the main control room fire control panel in case of a wiring or component failure.

Dry Chemical Fire Suppression System -

A dry chemical suppression system is installed in approved portable hazardous material storage buildings within the plant.

The system automatically actuates by melting of the fusible links or manually by a local pull station.

Reason for Scope Determination The Fire Protection System provides isolation of the fire water supply to the SGT System filter units and to the Radwaste Building Mixed Air System emergency filter units.

These system-intended functions are safety-related.

Therefore, the Fire Protection System meets the scoping criteria of 10 CFR 54.4(a)(1).

The Fire Protection System does not contain any NSR components that perform a 10 CFR 54.4(a)(1) function. The Fire Protection System does, however, contain NSR components that are attached to or located near safety-related SSCs, whose failure creates a potential for spatial interaction that could prevent the satisfactory accomplishment of one or more of the functions identified in 10 CFR 54.4(a)(1).

Therefore, the Fire Protection System meets the scoping criteria of 10 CFR 54.4(a)(2).

The Fire Protection System is relied upon to demonstrate compliance with, and meets the 10 CFR 54.4(a)(3) scoping criteria for, the Fire Protection (10 CFR 50.48) regulated event.

FSAR References Section F.2.4 of the FSAR describes the Fire Suppression Systems, evaluated for license renewal as the Fire Protection System.

License Renewal Drawings The following license renewal drawings depict the evaluation boundaries for the system components within the scope of license renewal:

LR-M515-1, LR-M515-2, LR-M515-4, LR-M515-5, LR-M573-2, LR-M544, LR-M545-3, LR-M548-1 LR-M545-,LR-M54-1

'-----ilnsert A from Page 2.3-94a Scoping and Screening Results Page 2.3-94,'

.FY 20 149 Insert B from Page ldnAmendment 2.3-94a Amendment.,-i..48

Columbia Generating Station License Renewal Application Technical Information Insert A to Page 2.3-94 LR-02H13-05,221,2, LR-02H13-05,221,2A, LR-02H13-05,250,1, LR-M515-3 Scoping and Screening Results Page 2.3-94a mmendmoet 2 jAmendment 48 -4,

Columbia Generating Station License Renewal Application Technical Information 2.3.3.48 Heating Steam System

System Description

The Heating Steam (HS) System originates from four pressure reducing stations (two in the Turbine Generator Building and one each in the Reactor and Radwaste buildings).

Steam at 200 psig pressure is supplied to these pressure reducing stations from either the auxiliary boiler or the gland steam evaporator. At the pressure reducing stations, the steam pressure is reduced to 50 psig and this steam is fed to the heating coils, humidifiers, steam unit heaters, and hot water heat exchanger.

Reason for ScoDe Determination The HS System does not perform any safety-related system intended functions that meet the scoping criteria of 10 CFR 54.4(a)(1).

The HS System does not contain any NSR components that perform a

10 CFR 54.4(a)(1) function. The HS System does, however, contain NSR components that are attached to or located near safety-related SSCs, whose failure creates a potential for spatial interaction that could prevent the satisfactory accomplishment of one or more of the functions identified in 10 CFR 54.4(a)(1). Therefore, the HS System meets the scoping criteria of 10 CFR 54.4(a)(2).

The HS System is not relied upon to demonstrate compliance with the 10 CFR 54.4(a)(3) scoping criteria for any regulated events.

FSAR References Section 9.4.16.2 of the FSAR describes the Heating Steam System.

License Renewal Drawings Ilhe tollowing license renewal drawing depicts the evaluation boundaries tor the system components within the scope of license renewal:

LR-M514-1 Components assigned by equipment piece number (EPN) to the Radwaste Building Mixed Air (WMA), Radwaste Building Outside Air (WOA), aPd Radwaste Building Return Air (WRA. systems are included within the evaluation boundaries of the HS System for copteness (see LR-M514-1).

r and Service Building Return Air (SRA)

Scoping and Screening Results Page 2 3-162a Amendmenct 1 r~menment48

Columbia Generating Station License Renewal Application Technical Information 2.5.5.2 Metal-Enclosed Bus Metal-enclosed bus connects two or more elements of an electric power circuit and is used to connect active electrical components such as switchgear, transformers, and switches.

The metal-enclosed bus within the Columbia license renewal scope is the non-segregated phase bus associated with startup transformer E-TR-S, found in the 6.0 kV

.l..tr..al system (F. BUS N.NS......

X) and else in the 4.16 kV electrical system (E-BUS-NONSEG/S/Y).

The in-scope metal-enclosed bus is of a rigid metallic construction, with flexible link attachments at the bus-to-switchgear connections. The license renewal evaluation of the non-segregated metal-enclosed bus includes only the bus sections between active electrical components.

The distribution bus and the connections inside the enclosures of active components are inspected and maintained transformer as partffte active components, and are therefore excluded from AMR.

I,the 6.9 kV non-segregated bus associated with the start-up tra sf_4meiors, and The 6.9 kV and 4.1 [/kV non-segregated phase bus associated with the unit normal auxiliary transformers and the 25 kV iso-phase bus are not within the scope of license renewal. These metal-enclosed buses are excluded from the license renewal review because back-feed through the main transformers is not credited for station blackout recovery at Columbia, and these components do not perform any other license renewal function. There is no segregated metal-enclosed bus at Columbia.

The non-segregated phase metal-enclosed bus is enclosed within its own passive enclosure and is not part of an active component, such as switchgear, a load center, or a motor control center. Non-segregated phase bus (evaluated as metal-enclosed bus for license renewal) is electrical bus constructed with all phase conductors in a common metal enclosure without barriers (i.e., with only an air space) between the phases. The bus assembly is comprised of two parts:

the portion associated with the electrical conductor (the bus bar and its connections) and the portion associated with the bus enclosure and supports. The bus enclosure and support assembly is evaluated as a structural commodity (see Section 2.4.13). The gaskets (elastomers) in the enclosure assembly (at the enclosure joints) are also listed as a structural commodity.

The function of a non-segregated metal-enclosed bus is to provide electrical connection to specified portions of an electrical circuit to deliver voltage and current. The internal bus supports also provide insulation. Non-segregated metal-enclosed bus is a passive, long-lived component.

Therefore, non-segregated metal-enclosed bus meets the criteria of 10 CFR 54.21(a)(1) and is subject to AMR.

2.5.5.3 Switchyard Bus and Connections Switchyard bus is uninsulated, unenclosed, rigid electrical conductor used in plant switchyards and switching stations to connect two or more elements of an electrical power circuit. The switchyard bus which connects backup transformer E-TR-B to circuit breaker E-CB-TRB, and the switchyard bus between the 230 kV overhead line and Scoping and Screening Results Page 2.5-5 Jeday 2010 JAmendment 48 A-dn 18

Columbia Generating Station License Renewal Application Technical Information i

Table 3.2.1 Summary of Aging Management Programs for Engineered Safety Features Evaluated in Chapter V of NUREG-1801 Item Aging Effect/

Aging Management Further Number Component/Commodity Aginfec tManiragmet Evaluation Discussion Number CMechanism Programs Recommended 3.2.1-18 Stainless steel piping, piping Cracking due to BWR Stress Corrosion No Not applicable.

components, and piping stress corrosion Cracking and Water elements exposed to treated cracking and Chemistry There are no stainless steel water >60 °C (>140 'F) intergranular stress piping, piping components, or corrosion cracking piping elements in the ESF systems that are exposed to treated water >60 °C (>140 OF).

3.2.1-19 Steel piping, piping components, Wall thinning due to Flow-Accelerated No Consistent with NUREG-1801.

and piping elements exposed to flow-accelerated Corrosion steam or treated water corrosion The Flow-Accelerated Corrosion Program is credited to manage loss of material (wall thinning) due to flow-accelerated corrosion for steel piping, piping components, and piping elements in the ESF systems that are exposed to steam.

-Well-thinning due to flow-accelerated corrosion is not applicable for steel piping, piping components, and piping elements in the ESF systems that are exposed to treated water.

Except for the Residual Heat Removal (RHR) System heat exchangers, piping and piping components, wall Aging Management Review Results Page 3.2-20 jAmendment 48

(

---N Columbia Generating Station License Renewal Application Technical Information Insert A for Page 3.2-49 Table 3.2.2-1 Aging Management Review Results - Residual Heat Removal System Row Component Intended Aging Effect NUREG-Material Environment Requiring Aging Management 1801 Table Notes No.

Type Function(s)

Management Program Volume I Item 2 Item 125 Piping Pressure Stainless Treated Cracking -

TLAA VIE4-1 3.3.1-A Boundary Steel water Fatigue 2

Pressure Steel Treated Cracking -

3.2.1-A 126 Piping Boundary water Fatigue TLAA V.D2-32 1

Insert A from pages

ý3.2-49b and 3.2-49c Aging Management Review Results Page 3.2-49a Amendment 23

Columbia Generating Station License Renewal Application Technical Information Insert A for Page 3.2-49a Table 3.2.2-1 Aging Management Review Results - Residual Heat Removal System Aging Effect NUREG-

-Row Component Intended Material Environment Requiring Aging Management 1801 Table 1 Notes No.

Type Function(s)

Management Program Volume 2 Item Item Heat 127 Exchanger Pressure Steel Treated water Loss of Flow-Accelerated V. D2-34 3.2.1-19 C

(RHR-HX-boundary (Internal) material Corrosion (FAC) 0208 1A/B) (shell)

Heat C

Exchanger Pressure Treated water Loss of Flow-Accelerated 0208 128 (RHR-HX-Peure Steel TEatednate Loss of Fo AccrVd D2-34 3.2.1-19 1 A/B) boundary (External) material Corrosion (FAC)

(tubesheet)

Heat C

129 Exchanger Pressure Steel Treated water Loss of Flow-Accelerated V D2-34 3.2.1-19 0208 (RHR-HX-boundary (Internal) material Corrosion (FAC) 2A/B (shell) 130 Pressure Treated water Loss of Flow-Accelerated VD2-34 3.2.1-19 A

Piping boundary Steel (Internal) material Corrosion (FAC) 0208 Pump Casing A

131 (column)

Flow-Accelerated V D2-34 3.2.1-19 0208 (RHR-P-Pressure Treated water Loss of Corrosion (FAC) 2A/B) boundary Steel (Internal) material Aging Management Review Results Page 3.2-4gb Amendment 48 Aging Management Review Results Page 3.2-49b Amendment 48

Columbia Generating Station License Renewal Application Technical Information Table 3.2.2-1 Aging Management Review Results - Residual Heat Removal System Aging ffectNUREG-Row Component Intended Material Environment Requiring Aging Management 1801 Table 1 Notes No.

Type Function(s)

Management Program Volume 2 Item Item Pump Casing A

132 (column)

Flow-Accelerated V.D2-34 3.2.1-19 0208 (RHR-P-Pressure Treated water Loss of Corrosion (FAC) 2A/B) boundary Steel (External) material Pump Casing Flow-Accelerated A

133 (RHR-P-Pressure Gray Cast Treated water Loss of Corrosion (FAC)

V.D2-34 3.2.1-19 0208 2A/B) boundary Iron (Internal) material Pump Casing Flow-Accelerated A

134 (RHR-P-Pressure Gray Cast Treated water Loss of Corrosion (FAC)

V.D2-34 3.2.1-19 0208 2A/B) boundary Iron (External) material Pump Casing Flow-Accelerated A

135 (shell) (RHR-Pressure Treated water Loss of Corrosion (FAC)

V.D2-34 3.2.1-19 0208 P-2A/B) boundary Steel (External) material 136 Pressure Treated water Loss of Flow-Accelerated V.D2-34 3.2.1-19 A

Valve Body boundary Steel (Internal) material Corrosion (FAC) 0208 Aging Management Review Results Page 3.2-49c Amendment 48

Columbia Generating Station License Renewal Application Technical Information Plant-Specific Notes:

0204 In addition to the turbine casing itself, Preventive Maintenance - RCIC Turbine Casing will manage loss of material for piping and piping components associated with the steam supply and exhaust lines, to and including the barometric condenser, RCIC-HX-1.

0205 In addition to loss of material due to crevice, general, and pitting corrosion, the Lubricating Oil Analysis Program will also manage loss of material due to selective leaching, by assuring that there is no long-term water contamination. The Lubricating Oil Inspection activity will provide confirmation of the effectiveness of the Lubricating Oil Analysis Program in managing loss of material.

0206 The material is not brass or bronze > 15% Zn or aluminum bronze > 8% Aluminum, which is required for the mechanism of crevice or pitting corrosion to be applicable.

0207 The aging effect determination for the Air-indoor uncontrolled (Internal) environment is the same as the NUREG-1801 determination for an Air-indoor uncontrolled (External) environment because the material is the same and the internal environment is equivalent to the external environment evaluated in the NUREG-1801 item. There are no aging effects requiring management.

0208 Residual Heat Removal (RHR) lines that operate at greater than 200 degree F only during startup and shutdown are monitored for flow-accelerated corrosion (FAC) and, therefore, are in the scope of the FAC Program for license renewal.

Aging Management Review Results Page 3.2-90 Aging Management Review Results Page 3.2-90 l;4A.'

J.-- aFy2Q!Q jAmendment 48

Columbia Generating Station License Renewal Application Technical Information Table 3.3.2-22 Aging Management Review Results - Fire Protection System Aging Effect Aging NUREG-Row Component Intended Material Environment Requiring Management 1801 Table Notes No.

Type Function(s)

Management Program Volume 2 1 Item Item 230 Tank (FP-TK-Pressure Steel Gas (Internal)

None None VIIJ-23 3.3.1-C 230 C02/1,2) boundary 97 0328 Tank(FP-TK-Pressure Air-indoor External 3.3.1-231 C02/1,2) boundary Steel uncontrolled Loss of material Surfaces VII.l-8 58 A

C02/1,2)_boundary_

_(External)

Monitoring Pressure Copper 3.3.1-C 232 Tubing boundary Alloy Gas (Internal)

None None VIIJ-97 0328 233 Tubing Pressure Copper Air-indoor None None N/A N/A G

boundary Alloy uncontrolled (Internal) 234 Water motor Pressure Steel Raw water Loss of material Fire Water VII.G-24 3.3.1-A alarm housing boundary (Internal) 68 235 Water motor Pressure Steel Air-indoor Loss of material External VII.1-8 3.3.1-A alarm housing boundary uncontrolled Surfaces 58 (External)

Monitoring Insert A from page

\\

3.3-256g Aging Management Review Results Page 3.3-256f Amondmcnt 2 Aging Management Review Results Page 3.3-256f Amendment 2 jAmendment 48

Columbia Generating Station License Renewal Application Technical Information Insert A to pagqe 3.3-256f Aging Management Review Results Page 3.3-256g Amendment 48 Aging Management Review Results Page 3.3-256g Amendment 48

Columbia Generating Station License Renewal Application Technical Information Table 3.3.245 Aging Management Review Results - Heating Steam System Aging Effet NUREG-Row Type Intended Material Environment Requiring Aging Management 1801 Table Notes

-o.

Type Functions

_Management Program Volume 1 Item Structural Steam Loss of Chemistry Program 50 Valve Body Integrity Steel (Internal) material Effectiveness N/A N/A G

_ _ _ In sp e ctio n 51 Valve Body Structural Steel Steam Loss of Row-Accelerated NIA N/A G

integrity (Internal) material Corrosion (FAC) 52 Valve B Structural Air-indoor Loss of External Surfaces 331-Integrity (External) material Monitoring 58 53 Piping Structural Steel Steam Cracking-TLAA VIIIB2-5 3.4.1-1 A

Integrity (Internal)

Fatigue Insert A from page 3.3-397o Page 3.3-397g Amendment-I-.

Aging Management Review Results Page 3.3-397g Amendment"-.

Columbia Generating Station License Renewal Application Technical Information Insert A to Daqe 3.3-397a Heat 54 Exchanger Structural Steel Steam Loss of BWR Water N/A N/A G

(header)

Integrity (Internal) material Chemistry (SRA-SUH-1 Heat Chemistry 55 Exchanger Structural Steel Steam Loss of Program N/A N/A G

(header)

Integrity (Internal) material Effectiveness (SRA-SU H-1)

Inspection Heat Flow-56 Exchanger Structural Steel Steam Loss of Accelerated N/A N/A G

(header)

Integrity (Internal) material Corrosion (SRA-SUH-1 (FAC)

HeatAir-indoor External 57 Exchanger Structural Steel uncontrolled Loss of Surfaces VII.1-8 3.3.1-A (header)

Integrity unotroll material 58 (SRA-SU H-1 (External)

Monitoring Heat Exchanger Structural Steam Loss of BWR Water 58 (ue)Itgiy Copper Alloy N/AeN/AoG (tubes)

Integrity (Internal) material Chemistry (SRA-SUH-1)

Heat Chemistry Ex Steam Loss of Program N/A N/A (tubchanger Structural y

Copper Alloy (Internal) material Effectiveness (SRA-SUH-1 Inspection Heat 6 eanr Air-indoor Exchanger Structural Copper Alloy uncontrolled None None N/A N/A G

(tubes)

Integrity (External)

(SRA-SUH-1)

Aging Management Review Results Page 3.3-397o Amendment 48

Columbia Generating Station License Renewal Application Technical Information Plant-Specific Notes:

0601 Loss of material due to wear is not an applicable aging effect for the in-scope high-voltage insulators at Columbia - see Section 3.6.2.2.2 for evaluation.

0602 For the switchyard bus and connections, no aging effects are identified that require aging management - refer to Section 3.6.2.2.3 for evaluation.

A review of the Columbia fuse list and other engineering documents showed that there are no in-scope passive fuses that are pulled on a routine basis such that deformation (fatigue) would cause loosening of the fuse holder.

The in-scope fuse holders at Columbia are located in metallic electrical boxes (terminal boxes) which have covers to protect the interior of the box from the ambient environment. The boxes are not exposed to weather conditions (they are located indoors); they are not exposed to chemical contamination or spills; they are not exposed to mechanical stress inside the box; and, due to the 0603 Columbia location in rural central Washington, they are not located in an evironment with industrial pollution or salt deposition.

Therefore, chemical contamination, corrosion, and oxidation are not applicable aging mechanisms for the fuse holders within the license renewal scope at Columbia.

With respect to electrical transients and ohmic heating, these fuses are not heavily loaded and do not experience frequent electrical and thermal cycling. With respect to vibration, it is an induced aging mechanism, and the fuse boxes are securely mounted on walls, so vibration itself is not an applicable stressor.

The transmission conductors within the license renewal scope are those that connect start-up transformer E-TR-S to circuit breaker A 809 in the Ashe substation switchyard. This circuit breaker constitutes part of the station blackout license renewal boundary.

0604 This segment of transmission conductor does not exhibit significant aging mechanisms or effects. An aging management program is not required for the segment of transmission conductor that is within the scope of license renewal. See Section 3.6.2.2.3 for details.

The inspection of the metal-enclosed bus enclosure assembly elastomers (joints, seals, gaskets) will be performed as part of the Metal-Enclosed Bus Program. The elastomers will be inspected when the covers of the various bus enclosure sections are 0605 removed. The Structures Monitoring Program will address the metallic portion of the enclosure assembly and the external structural supports for the various bus assemblies (along with the building penetrations and seals where the bus ducts enter the Reann uka).

• --~rieBidn In addition to steel and galvanized steel, Columbia uses aluminum enclosures (a material not mentioned in NUREG-1801, Item 0606 VI.A-13). Note A is used, because the Structures Monitoring Program includes consideration of aluminum and is consistent with NUREG-1801.

0607 Inspection of a sample of the passive fuse boxes within the scope of license renewal (performed in September 2007) showed that conditions are clean and dry, with no corrosion or moisture intrusion found.

Aging Management Review Results Page 3.6-28 j~n dm en-t 4-813'ja-wry

I Section A. 1.2.32 Columbia Generating Station License Renewal Application Technical Information Isr A ower The Ina) cessible,veuiani-Voltage Cables Not Subject to 10 CFR 50.49 EQ Requir e#ents, Program will manage the aging of in-scope, mediumetg cables exposed to significant moisture and significant voltage. First tests or first inspections for license renewal will be completed before the period n ed operation. These cables will be tested at least once every 1-G-ars to provide an indication of the condition of the conductor insulation. The specific type of test performed will be determined prior to the initial test, and is to be a proven test for detecting deterioration of the insulation system due to wetting, such as power factor, partial discharge, or polarization index, as described in EPRI TR -103834-P or other testing that is state-of-the-art at the time the test is performed.

Sigificant moisture is defined as periodic exposures that last more than a few days (e.g., cable in standing water). Periodic exposures that last less than a few days (e.g., normal rain and drain) are not significant. Significant voltage expo.ure i dfined as being s8ubjected to system voltage for morm than 2%o,_f the tm..

The mo-isture and voltage 9*expsures deascribeod assgnificant in these-deafinitions (Reference A.1.4-3) arc not Sigllificant for mcedium voltage eablcc that arc des' cond~tions (e.g.,

continuous wetting and continuous enrg

.igificant for. submarine cables). In addition, inspection for water collecti be performed based on actual plant experience with water accumulation manholes. However, the inspection frequency will be at least

-ye*f.

<4-Manhole inspections will also be performed periodically, in response to event-driven occurrences (such as heavy rain or flooding). k.__.lnsert D r m p geA-8F Insert B:

and testing for contamination, and cleaning if required, of the high voltage station post insulators between the 230-kV overhead line running to Columbia Generating Station and circuit breaker E-CB-TRS.

Insert C:

The program requires enhancement prior to the period of extended operation to have the insulators located in the Ashe substation tested for contamination, and cleaned if required, every 8 years.

Final Safety Analysis Report Supplement Page A-18a A.1,e---*w...-t 5 Amendment m48n1 AMendment 1

ý-n291

Columbia Generating Station License Renewal Application Technical Information Insert D:

The inspection will include direct observation that cables are not wetted or submerged, that cables/splices and cable support structures are intact, and sump pump systems and associated alarms operate properly.

In addition, sump pumps will be inspected and operation verified prior to any known or predicted heavy rain or flooding events which could require the sump pump to operate.

Final Safety Analysis Report Supplement Page A-18b Amendment 48 Final Safety Analysis Report Supplement Page A-18b Amendment 48

Columbia Generating Station License Renewal Application Technical Information A.1.3.7.3 Main Steam Flow Restrictor Erosion Analyses The main steam line flow restrictors are designed to limit coolant flow rate from the reactor vessel (before the MSIVs are closed) to less than 200 percent of normal flow in the event of a main steam line break outside the containment.

Erosion of a flow restrictor is a safety concern since it could impair the ability of the flow restrictor to limit vessel blowdown following a main steam line break. Since erosion is a time-related phenomenon, the analysis for the effect it has on the flow restrictors over the life of the plant is a TLAA. Cast stainless steel (SA351, Type CF8) was selected for the steam flow restrictor material because it has excellent resistance to erosion-corrosion from high velocity steam.

The erosion of the main steam flow restrictors has been projected for the period of extended operation. The projection concludes that after 60 years of erosion on the main steam flow restrictors, the choked flow will still be less than 200 percent of normal flow. Therefore, the main steam flow restrictors will continue to perform their intended function and the existing accident radiological release analysis will remain valid for the period of extended operation.

Disposition The TLAA for erosion of the main steam line flow restrictors has been projected to the end of the period of extended operation.

A.1.4 References page A-41 a A.1.4-1 BWROG Report GE-NE-523-A71-0594-A, Rev 1, "Alternate BWR Feedwater Nozzle Inspection Requirements," May 2000 A. 1.4-2 EPRI Report No. 1011838, "Recommendations for An Effective Flow Accelerated Corrosion Program (NSAC-202L-R3)," May 2006 A.1.5 License Renewal Commitment List A listing of commitments identified in association with Columbia license renewal is provided in Table A-I.

These commitments will be tracked within the Columbia regulatory commitment management program. Any other actions discussed in the LRA represent intended or planned actions. They are described to the NRC for information and are not regulatory commitments.

A.1.4-3 EPRI TR-103834-P1-2, "Effects of Moisture on the Life of Power Plant Cables," August 1994 Final Safety Analysis Report Supplement Page A-41

....... 2'1 A

ndmente nd t-29--

Insert B from page A-41 b IAmc

Columbia Generating Station License Renewal Application Technical Information Insert B:

A.1.3.7.5 Crane Load Cycle Limit All in-scope cranes at Columbia were designed to Crane Manufacturers Association of America (CMAA) Specification 70, "Specification for Electric Overhead Traveling Cranes" which provides a design load cycle limit based on service class for the associated cranes. This load cycle limit for each crane was identified as a potential TLAA.

Disposition To address this potential TLAA a 60-year projection of load cycles was developed for all cranes in the scope of license renewal and compared to the design load cycle limits of CMAA 70. For all cranes the 60-year projection of load cycles is within the applicable design load cycle limit of CMAA 70. Therefore, this TLAA remains valid for the period of extended operation.

Final Safety Analysis Report Supplement Page A-41b Amendment 48 Final Safety Analysis Report Supplement Page A-41 b Amendment 48

Columbia Generating Station License Renewal Application Technical Information Table A-1 Columbia License Renewal Commitments FSAR Enhancement Item Number Commitment Supplement or Location Implementation (LRA App. A)

Schedule

9)

BWR Vessel ID The BWR Vessel ID Attachment Welds Program is an existing A.1.2.9 Ongoing Attachment program that will be continued for the period of extended operation.

Welds Program

10) BWR Vessel The BWR Vessel Internals Program is an existing program that will A. 1.2.10 Ongoing Internals be continued for the period of extended operation.

Program

'A

11) BWR Water The BWR Water Chemistry Program is an existing program that will A.1.2.11 Ongoing Chemistry be continued for the period of extended operation.

Program

12) Chemistry The Chemistry Program Effectiveness Inspection is a new activity.

A.1.2.12 Within the 10-Program The Chemistry Program Effectiveness Inspection detects and year period prior Effectiveness characterizes the condition of materials in representative low flow to the period of Inspection and stagnant areas of systems with water chemistry controlled by the extended BWR Water Chemistry Program or the Closed Cooling Water operation.

Chemistry Program, and with fuel oil chemistry controlled by the Fuel Oil Chemistry Program. The inspection provides direct evidence as to whether, and to what extent, the relevant effects of aging have occurred.

Jnse4 A from page Final Safety Analysis Report Supplement Page A-44 Amndment 361---Am e 2 Amendment 48

Columbia Generating Station License Renewal Application Technical Information Insert A into Daae A-45 The Cooling Units Inspection Program is a new program.

The Cooling Units Inspection Program manages the effects of loss of material of aluminum, steel, copper alloy, and stainless steel cooling unit components that are exposed to condensation.

The inspection also manages the effects of a reduction in heat transfer due to fouling of heat exchanger tubes and fins and cracking due to SCC of aluminum components exposed to condensation.

The Cooling Unites Inspection Program consists of baseline inspections prior to the period of extended operation followed by opportunistic inspections during the period of extended operation.

Following the baseline inspection, inspection findings will be reviewed periodically to ensure that each material exposed to condensation has been examined via opportunistic inspectioef actions are taken to ensure inspections are performed. Initial interval for review off rnspection findings is 5 years and may be adjusted based on operating experience Insert B into a(aae A-45 Implementation prior to the period of extended operation and initial inspection within the 10-year period prior to the period of extended operation. Then ongoing.

Final Safety Analysis Report Supplement Page A-45a Ameadmem--t mAmendment 48

Columbia Generating Station License Renewal Application Technical Information Insert A into page A-46 The Diesel Systems Inspection Program is a new program.

The Diesel Systems Inspection Program manages the effects of loss of material due to corrosion and cracking due to stress corrosion cracking of materials for the interior of the steel and stainless steel exhaust piping components for the Division 1, 2, and 3 diesels in the Diesel Engine Exhaust System, including the loop seal drains from the exhaust piping.

The Diesel Systems Inspection Program consists of baseline inspections prior to the period of extended operation followed by opportunistic inspections during the period of extended operation.

Following the baseline inspection, inspection findings will be reviewed periodically to ensure that each material exposed to air-outdoor and raw water has been examined via opportunistic inspection or aetieR are taken to ensure inspections are performed. Initial interval for review of inspectioifindings is 5 years and may be adjusted based on operating experience, actions Insert B into pagqe A-46 The Diesel-Driven Fire Pumps Inspection Program is a new program.

The Diesel-Driven Fire Pumps Inspection Program manages the effects of loss of material, due to corrosion or erosion, and reduction in heat transfer of the interior of the Fire Protection System diesel engine exhaust piping, and of Fire Protection System diesel heat exchangers exposed to a raw water environment.

The program also manages cracking due to SCC of susceptible materials.

The Diesel-Driven Fire Pumps Inspection Program consists of baseline inspections prior to the period of extended operation followed by opportunistic inspections during the period of extended operation.

Following the baseline inspection, inspection findings will be reviewed periodically to ensure that each material exposed to air-outdoor and raw water has been examined via opportunistic inspection or are taken to ensure inspections are performed. Initial interval for review of inspection findings is 5 years and may be adjusted based on operating experience.

Final Safety Analysis Report Supplement Page A-46a

,Amondmont 21 IAmendment 48 7

Columbia Generating Station License Renewal Application Technical Information Insert A to Page B-18 Number NUREG-1801 Program Corresponding Columbia AMP Service Level 1 Protective Coatings Program N/A Plant-Specific Program See Section B.2.55.

Insert B tQ Page B-18 N/A Plant-Specific Program Cooling Units Inspection Program See Section B.2.14.

N/A Plant-Specific Program Diesel Systems Inspection Program See Section B.2.17.

N/A Plant-Specific Program Diesel-Driven Fire Pumps Inspection Program See Section B.2.18.

N/A Plant-Specific Program Flexible Connection Inspection Program See Section B.2.27.

N/A Plant-Specific Program Monitoring and Collection Systems Inspection Program See Section B.2.41.

N/A Plant-Specific Program Service Air System Inspection Program See Section B.2.48.

N/A Plant-Specific Program Small Bore Class 1 Piping See Section B.2.49 Aging Management Programs Page B-18b Amondmont 11 Aging Management Programs Page 13-18b Am9REJM914 14 Amendment 48

Columbia Generating Station License Renewal Application Technical Information Table B-2 Consistency of Columbia Aging Management Programs with NUREG-1801 (continued)

Consistent Consistent with New Cosset wt Plant-Enhancement Program Name Newsingwith NUREG-NUREG-plant-enhneen Existing 1801 1801 with Specific Required Exceptions Fire Water Program Existing Yes Section B.2.26 Flexible Connection Inspection NeNew Section B.2.27 Flow-Accelerated Corrosion (FAC)

Existing Yes Yes Program Section B.2.28 Fuel Oil Chemistry Program Existing Yes Section B.2.29 Heat Exchangers Inspection New Yes Section B.2.30 High-Voltage Porcelain Insulators Aging Management Existing Yes

/

Program Section B.2.31 Inaccessible lQA~jiwm vo'**Ie Cables Not Subject to 10 CFR 50.49 New Yes EQ Requirements Program Section B.2.32 Inservice Inspection (ISI) Program Existing Yes Section B.2.33 Inservice Inspection (ISI) Program - IWE Existing Yes Section B.2.34 JPowerI\\11 Aging Management Programs Page B-22 Amendment 48 A

-1 FtAmendment/

\\1/

Columbia Generating Station License Renewal Application Technical Information Table B-2 Consistency of Columbia Aging Management Programs with NUREG-1801 (continued)

Consistent Consistent with New Cosset wt Plant-Enhancement Program Name ne with NUREG-NUREG-plant-enhneen Existing 1801 1801 with Specific Required Exceptions Thermal Aging and Neutron Embrittlement of Cast Austenitic New Yes Stainless Steel (CASS) Program Section B.2.52 Water Control Structures Existing Yes Yes Inspection Section B.2.53 Boron Carbide Monitoring Program Existing Yes Section B.2.54 Service Level 1 Protective Coatings Existing Yes Program Section B.2.55 Aging Management Programs Page B-25 AAmendmentP48BJy

B2.5 Buried Piping and Tanks Inspection Program Columbia Generating Station License Renewal Application Technical Information 0

I!!-":!o lftr! *aina M;trc RcqUi-e that an in.pection Of a neprcsentatiyc sample of buried piping be pera frned Within the 10 year period prior to entering the period of extenedc o~perationR (i.e., between year 30 and year 10).

Require an additional irnspecti of a represetatie sample of buried piping w

i be pefCormed withir 10 yeaarhs aftef eteraing the peried of extended operatior (i.e.,

between year 40 and year 50).

InsRt51 B 49eM page B 9

stainless steel, Operating Experience pln-pcfcand polymeric plan-speific(PVC)

No history of piping degradation duq to external corrosion of buried piping was luub for Columbia through searches of operating experience or discussions with program owners. Columbia operating experience demonstrates that the coating of buried steel) piping and tanks is effective in managing the effects of aging.

Plant design considerations addressed the potential for degradation of buried piping components through the application of protective coatings

_ Insert I to LRA Section B.2.5 on Page B-40b.

in a portion of the Potable Water System that is outside the scope of License Renewal A review was conducted of station piping failures, and it was determined that there had been no documented failures attributed to externally-initiated corrosion.

Identified instances of leakage associated with buried piping have been the result of internal corrosio Insert J to LRA Section B.2.5 on Page B-40b.

Insert K to LRA Section

/d

• B.2.5 on Page B-40b.

The environmental conditions at Columbia are very good base the sandy soil and electrolyte resistivity of the soil which is considered very high.

This has resulted in minimal degradation of buried piping as evidenced by excavations of certain sections of piping for examination. There have been no significant areas of degradation caused by protective coating failure.

This was determined after a section of buried Standby Service Water (SW) System piping was excavated and evaluated in 2007.

Conclusion Insert L to LRA Section C

B1.2.5 on Page B-40c

-Repace with Insert A on Page B,!0a i rie DUI-iO, Fi--ily a11C id a

\\K i

DUUe1iioi Poi-ruad, Will mi nai Rlbb L

IT v

1i aU1d211i OUe !u coroin for su-sceptible piping: componRents and tanks in buried environments The Buried Piping and Tanks Inspection Program, with the required enhancements, ovides reasonable assurance that the aging effects will be managed such that mponents subject to aging management review will continue to perform heir int ded functions consistent with the current licensing basis for the period of exten eld eration.

Insert M to LRA Section B.2.5 on Page B-40c.

page. B

'l.

Aging Management Programs Page B-40 r

Imc inst.4

113.2.32 1

I I

Columbia Generating Station License Renewal Application Technical Information Insert A The inspection frequency for water collection is established and performed based on plant-specific operating experience with water accumulation (in the electrical manholes) over time and also event-driven occurrences, such as heavy rain or flooding.

The manholes will be inspected at least annually and will also be inspected after events that could cause water to accumulate to the level of installed Gables.e conduits.

Icables or]--/-I The inspection will include direct observation that cables are not wetted or submerged, that cables/splices and cable support structures are intact, 1n4CIn

+i Arn ctctnn

+,n Azccnnon nI',rc

+nr.t Ir In [2 H II.

OL I IF i

F l

I I* 'l.

3OyYO*

I I i

CA"j aO V*aJ.I LU a CA11I1 Il UFUICzl U

O VIlUL I I Y.

I"I addition, sump pumps will be inspected and operation verified prior to any known or predicted heavy rain or flooding events which could require the sump pump to operate.

Aging Management Programs Page B-1 33a Amondment 16

[Amendment 481

JB.2.32 j Columbia Generating Station License Renewal Application Technical Information Insert A Acceptance criteria for inspection of manholes are defined by the observation that the cables are not submerged or immersed in standing water at the time of inspection.

S structures Insert B corrective actions are taken and an engineering evaluation is performed when the test or inspection acceptance criteria are not met.

Such an evaluation considers 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. When an unacceptable condition or situation is identified, a determination is made as to whether the same condition or situation is applicable to other accessible or inaccessible, in-scope power cables.

Actions may include the installation of sump pumps and alarms, the installation of permanent drainage systems, and the implementation of a cable condition monitoring program. As discussed in the Appendix for GALL, the staff finds the requirements of 10 CFR Part 50, Appendix B, acceptable to address the corrective actions.

Aging Management Programs Page B-134a Amcndmcnt 16 IAmendment 48

Columbia Generating Station B.2.32 ILicense Renewal Application Technical Information Insert A Also, in September 2010, an electrical manhole in the transformer yard was found full of water. It was determined that the configuration of the manhole, a sloped ground-level cable trough entering from the side, allowed a build-up of water related to suspected problems with the French drain. The drain will be repaired via the corrective action program. The complementary manhole (for the other electrical train) was found to be totally dry The electrical cable vault located underneath the motor control centers in the

/ICirculating Water Pump House is also subject to water intrusion from the H-Circulating Water Pump basins when the basin level is abnormally high. A sump Insert B

/pump was installed before 1991 to deal with the water intrusion. Operating proceoures are in place to Ilimit te occurrence of water intrusion into tne vauil.

The program will include inaccessible underground power cables (400 V to 2kV), in response to industry and plant-specific operating experience.

In addition, the program will perform cable testing on a frequency of at least every 6 years, with the inspections of electrical manholes having a frequency of at least annually.

Also, manhole inspections will be performed in response to event-driven occurrences (such as heavy rain or flooding).

Aging Management Programs Page B-135a JAmendment 48

B.12.47 Selective Leaching Inspection Columbia Generating Station License Renewal Application Technical Information Parameters Monitored or Inspected The Selective Leaching Inspection will perform a combination of visual examination and hardness testing, or NRC approved alternative, of components within the scope of the program as a measure of loss of material due to selective leaching.

The Selective Leaching Inspection activities will be conducted after the issuance of the renewed operating license and prior to the end of the current operating license, with sufficient time to implement programmatic oversight prior to the period of extended operation. The activities will be conducted no earlier than 5 years prior to the end of the current operating license, so that conditions are more representative of the conditions expected during the period of extended operation.

The sample size will be 20% of each population, based on material-environmen combination up to a maximum o1 25 inspectio per population.

-L__

Detection of Aging Effects The Selective Leaching Inspection will include provision for a combination of visual examination and hardness testing, or NRC approved alternative, of a sample of components with susceptible materials in environments conducive to the occurrence of selective leaching. The program will include the criteria for visual inspection and for hardness testing. The results of the inspections will be evaluated to determine the condition of the material.

Engineering evaluation in conjunction with the corrective action program will determine whether components with degraded materials are capable of performing their intended functions.

S, ns The aging management activities include: (a) determination of the sample size based on an assessment of materials of fabrication, environment and conditions, and operating experience; (b) identification of the inspection locations in the susceptible system or component; (c) determination of the examination technique, including acceptance criteria; and (d) evaluation of the need for follow-up examinations to monitor the progression of aging if age-related degradation is found that could jeopardize an intended function before the end of the period of extended operation.

The results of the inspections will be evaluated against the acceptance criteria.

Additional testing will be performed, as necessary, based on review of the inspection results.

" Monitoring and Trending No actions are taken as part of the Selective Leaching Inspection to monitor or trend inspection results. This is a one-time inspection activity used to determine if, and to what extent, further actions, including monitoring and trending, may be required.

The inspection results will be evaluated through the site corrective action process.

" Acceptance Criteria The Selective Leaching Inspection will include acceptance criteria for visual inspections and for hardness testing, or NRC approved alternative.

Inspection Aging Management Programs Page B-180 2.. n

[Amendment 48

LICENSE RENEWAL APPLICATION SUPPLEMENT Page 1 of 1 For Information Only - 1 copy New and Revised Boundary Drawings Drawing Reason Number LR-217-00,144 New drawing LR-M513 Revised LR-M15-1 Revised LR-M515-4 Revised

THIS PAGE IS AN OVERSIZED DRAWING OR

FIGURE, THAT CAN BE VIEWED AT THE RECORD TITLED:

"MACHINE SHOP - SERVICE BLDG SYSTEM NO. 10, NEW BOUNDARY DRAWING, DRAWING NO. LR-217-00, 144, AMEND. 48" WITHIN THIS PACKAGE D-01

THIS PAGE IS AN OVERSIZED DRAWING OR

FIGURE, THAT CAN BE VIEWED AT THE RECORD TITLED:

"LICENSE RENEWAL BOUNDARY DRAWING AUXILIARY & PROCESS STEAM SYSTEMS ALL BUILDINGS, DRAWING NO. LR-M513, REV. 1, REVISED IN AMEND 48" WITHIN THIS PACKAGE D-02

THIS PAGE IS AN OVERSIZED DRAWING OR

FIGURE, THAT CAN BE VIEWED AT THE RECORD TITLED:

"FLOW DIAGRAM HEATING STEAM SYSTEM ALL BUILDINGS, DRAWING NO. LR-M514-1, REV. 0, REVISED IN AMEND 48" WITHIN THIS PACKAGE D-03

THIS PAGE IS AN OVERSIZED DRAWING OR

FIGURE, THAT CAN BE VIEWED AT THE RECORD TITLED:

"LICENSE RENEWAL BOUNDARY DRAWING FIRE PROTECTION SYSTEM GENERAL SERVICES BUILDING AND TURBINE GENERATOR BUILDING, DRAWING NO. LR-M515-4, REV. 2, REVISED IN AMEND 48" WITHIN THIS PACKAGE D-04