Text

Subsequent License Renewal Application - Fourth Annual Update
	ML25324A217
Person / Time
Site:	Saint Lucie ; (DPR-067, NPF-016)
Issue date:	11/20/2025
From:	Mack K; Florida Power & Light Co
To:	; Office of Nuclear Reactor Regulation, Document Control Desk
References
	L-2025-184
	Download: ML25324A217 (1)
	v • d • e

U.S. Nuclear Regulatory Commission Attn: Document Control Desk 11545 Rockville Pike One \v'hite Flint North Rockville, lvID 20852-2746 St. Lucie Nuclear Plant Units 1 and 2 Dockets 50-335 and 50-389 Facility Operating Licenses DPR-67 and NPF-16 SUBSEQUENT LICENSE RENEWAL.APPLICATION-FOURTH ANNUAL UPDATE

References:

November 20, 2025 L-2025-184 10 CFR 54.17

1.

Florida Power & Light Company (FPL) letter L-2021-192, Subsequent License Renewal Application -Revision 1, October 12, 2021 (ADAMS Package Accession No. ML21285A106)

2.

FPL Letter L-2022-163 dated September 28, 2022, Subsequent License Renewal Application - First Annual Update (ADAMS Accession No. ML22271A399)

3.

FPL Letter L-2023-131 dated September 28, 2023, Subsequent License Renewal Application - Second Annual Update (ADAMS Accession No. ML23271A117)

4.

FPL Letter L-2024-155 dated September 27, 2024, Subsequent License Renewal Application - Third Annual Update (ADAi\tIS Accession No. ML24271A063)

5.

U.S. NRC Safety Evaluation Related to the Subsequent License Renewal of St. Lucie Plant, Units 1 and 2, Revision 1, September 2023 (ADAMS Accession No. :i\1IL23219A003)

6.

FPL letter L-2024-185, License Amendment Request L-2024-185, Licensing Basis Changes in Support of St. Lucie Unit 2 Transition to 24-Month Fuel Cycles, November 26, 2024 (ADAMS Accession No. :i\1IL24331A249)

7.

FPL Letter L-2022-043 dated April 7, 2022, Subsequent License Renewal Application Revision 1 - Supplement 1 (ADAMS Accession No. :i\1IL22097A202)

FPL, owner and licensee for St. Lucie Nuclear Plant (PSL) Units 1 and 2, has submitted a revised subsequent license renewal application (SLRA) for the Facility Operating Licenses for PSL Units 1 and 2 (Reference 1), the first annual update (Reference 2), the second annual update (Reference 3), and the third annual update (Reference 4). The License Renewal Rule, 10 CFR 54.21 (b), requires that each year following submittal of an LR.A, and at least 3 months before scheduled completion of the NRC review, an update to the LRA must be submitted that identifies any change to the current licensing basis (CLB) of the facility that materially affects the content of the LRA including the Updated Final Safety Analysis Report Supplement.

In accordance,vith the License Renewal Rule, FPL has performed the fourth annual review of PSL Units 1 and 2 CLB changes since the SLRA submittal to determine whether any sections of the SLRA were materially affected by these changes. As a result of this annual review, FPL identified changes that materially affect the PSL Units 1 and 2 SLR.A content and the NRC SLR SE (References 5). Descriptions of these changes and the corresponding affected SLR.A content revisions are attached. Please note the PSL Unit 2 License Amendment Request for transition to 24-month fuel cycles (Reference 6) revises PSL Unit 2 UFSAR Table 5.3-9, Capsule Assembly Removal Schedule, that was included in the SLRA.

During performa1~ce of the 4th annual review, an error in the NRC SLR SE (Reference 5), Table A.1, Commitment 18, was identified. Details of the error are documented in Attachment 1.

For ease of reference, the index of attached information is provided on page 3 of this letter. Attachment 2 includes associated revisions to the SLR.A (Enclosure 3 Attachment 1 of Reference 1) denoted by strilwtli:rough (deletion) and/or Florida Power & Light Company 15430 Endeavor Drive,Jupiter, FL 33478

St. Lucie Nuclear Plant Units 1 and 2 Dockets 50-335 and 50-389 L-2025-184 Page 2 of3 bold red underline (insertion) text. Previous SLRA revisions are denoted by bold black text. SLRA table revisions are included as excerpts from each affected table.

Should you have any questions regarding this submittal, please contact i\1Is. Maribel Valdez, Fleet Licensing j'vianager at 561-904-5164.

I declare under penalty of perjmy that the foregoing is tJ.ue and correct.

Executed on the 20th day of November 2025.

Sincerely, Kenn~_y-0" Director, Licensing and Regulato1y Compliance Florida Power & Light Company Attachments (2)

Cc:

Regional Administrator, USNRC, Region II Senior Resident Inspector, USNRC, St. Lucie Plant Chief, USNRC, Division of New and Renewed Licenses Senior Project Manager, USNRC, Division of New and Renewed Licenses Mr. Clark Eldredge, Florida Department of Health

St. Lucie Nuclear Plant Units I and 2 Dockets 50-335 and 50-389 Attachment No.

Subject 1

Current Licensing Basis (CLB) Changes Affecting the SLRA 2

Affected SLRA Content Revisions L-2025-184 Page 3 of3

St. Lucie Nuclear Plant Units 1 and 2 Dockets 50-335 and 50-389 L-2025-184 Page 1 of2 CURRENT LICENSING BASIS (CLB) CHANGES AFFECTING THE SLRA PSL 1 and 2 CLB Change Screening / Aging SLRA Sections Affected Management Review/

Program (AMR/ AMP)

Documents Affected Updated Aging Management NEESL00008-REPT-004 Section 3.3.2.2.7 Evaluations and a Further Table 3.3-1 Evaluation to address steel Table 3.4-1 components with internal and external coatings/linings.

Clarified that Unit 1 Refueling NEESL00008-REPT-0 11 Section 3.2.2.1.2 Water Tank has no internal Table 3.2-1 coatings; fiberglass-reinforced Table 3.2.2-2 vinyl ester bottom is not a Appendix B, Section B.2.3.28 coating.

Updated coated component NEESL00008-REPT-0 16 Section 3.3.2.1.2 descriptions to align with SLR-Table 3.3.2-2 GALL guidance and AMP XI.M42; removed aging effects for non-coated materials exposed to raw water (int).

Updated coated component NEESL00008-REPT-0 18 Section 3.3.2.1.4 descriptions; clarified Unit 1 Table 3.3.2-4 diesel oil storage tank coating applies only to underside of roof.

Updated coated component NEESL00008-REPT-020 Section 3.3.2.1.5 descriptions; removed aging Table 3.3.2-5 effects for non-coated materials in raw water (int); combined gray and ductile iron for identical conditions.

Added Selective Leaching AMP NEESL00008-REPT-022 Section 3.3.2.1.7 per NRC RAI B.2.3.21-3 NEESL00008-REPT-030 Section 3.4.2.1.1 response (FPL letter L-2023-059).

Updated coated component NEESL00008-REPT-0 19 Section 3.3.2.1.8, Table 3.3.2-8 descriptions; removed aging NEESL00008-REPT-027 Section 3.3.2.1.9, Table 3.3.2-9 effects for non-coated NEESL00008-REPT-028 Section 3.3.2.1.11, Table 3.3.2-11 components because they are not exposed to environment due to coating.

St. Lucie Nuclear Plant Units 1 and 2 Dockets 50-335 and 50-389 PSL 1 and 2 CLB Change Updated coated component descriptions to align with SLR-GALL guidance and AMP XI.M42.

Updated Section 3.4.2.1.3 to add underground environment per FPL letter L-2022-043, Table 3.4.2-3, page 3.4-71.

Updated the Open-Cycle Cooling Water System aging management program (AMP) to address carbon steel components with internal and external coatings and linings.

The PSL Internal Coatings /

Linings for In-Scope Piping, Piping Components, Heat Exchangers, and Tanks AMP revised to manage loss of coating integrity for external coatings. Loss of material, cracking, and loss of material due to selective leaching need not be managed by another program.

Updates error in SER Table A. I, Commitment 18( c) to reflect SLRA Revision I -

Supplement I (Reference 7, 0, Page 64 of 70)

Screening / Aging Management Review/

Program (AMR I AMP)

Documents Affected NEESL00008-REPT-032 NEESL00008-REPT-032 NEESL00008-REPT-049 NEESL00008-REPT-081 NIA SLRA Sections Affected Section 3.4.2.1.3 Table 3.4.2-3 Section 3.4.2.1.3 L-2025-184 Page 2 of2 Appendix B, Section B.2.3.11 AppendixAI, Section 19.2.2.28 Appendix A2, Section 19.2.2.28 Appendix B, Section B.2.3.28 Appendix Al, Table 19-3, CommitmentNo. 18(c)

St. Lucie Nuclear Plant Units I and 2 Dockets 50-335 and 50-389 SLRA Section 3.2.2.1.2, page 3.2-2 is revised as follows:

Environments L-2025-184 Page I of 66 The containment cooling system components are exposed to the following environments:

Air - indoor uncontrolled Air with borated water leakage Treated water Waste water Aging Effects Requiring Management The following aging effects associated with the containment cooling system require management:

Cracking Flow blockage Hardening or loss of strength Loss of material Loss of preload Reduction of heat transfer Aging Management Programs The following AMPs manage the aging effects for the containment cooling system components:

Bolting Integrity (8.2.3.9)

Boric Acid Corrosion (8.2.3.4)

Closed Treated Water Systems (B.2.3.12)

External Surfaces Monitoring of Mechanical Components (B.2.3.23)

Inspection of Internal Surfaces in Miscellaneous Piping and Ducting Components (B.2.3.24) 3.2.2.1.2 Containment Spray Materials The materials of construction for the containment spray system components are:

Aluminum Carbon steel Carbon steel with stainless steel cladding Coating Fiberglass reinforced vinyl ester Glass Gray cast iron Nickel alloy Stainless steel Steel

St. Lucie Nuclear Plant Units 1 and 2 Dockets 50-335 and 50-389 SLRA Section 3.2.2.1.2, page 3.2-3 is revised as follows:

Environments The containment spray system components are exposed to the following environments:

Air - indoor uncontrolled Air - outdoor Air with borated water leakage Concrete Gas Treated borated water Treated water Waste water Aging Effects Requiring Management L-2025-184 Page 2 of66 The following aging effects associated with the containment spray system require management:

Cracking Delamination Flow blockage Loss of coating or lining integrity Loss of material Loss of preload Reduction of heat transfer Wall thinning - erosion Aging Management Programs The following AMPs manage the aging effects for the containment spray system components:

Bolting Integrity (B.2.3.9)

Boric Acid Corrosion (B.2.3.4)

Closed Treated Water Systems (B.2.3.12)

External Surfaces Monitoring of Mechanical Components (B.2.3.23)

Inspection of Internal Surfaces in Miscellaneous Piping and Ducting Components (B.2.3.24)

Internal Coatings/Linings for In Scope Piping, Piping Components, Heat Exchangers, and Tanks (B.2.3.28)

Outdoor and Large Atmospheric Metallic Storage Tanks (B.2.3.17)

One-Time Inspection (B.2.3.20)

Selective Leaching (B.2.3.21)

Water Chemistry (B.2.3.2)

St. Lucie Nuclear Plant Units 1 and 2 Dockets 50-335 and 50-389 SLRA Table 3.2-1, page 3.2-32 is revised as follows:

Table 3.2-1: Summary of Aging Management Evaluations for the Engineered Safety Features Item Component Aging Aging Management Further Number Effect/Mechanism Program I TLAA Evaluation Recommended 3.2-1, 072 Any material piping, Loss of coating or lining AMP XI.M42, "Internal No piping components, integrity due to blistering, Coatings/Linings for heat exchangers, cracking, flaking, peeling, In-Scope Piping, tanks with internal delamination, rusting, or Piping Components, coatings/linings physical damage; loss of Heat Exchangers, and exposed to material or cracking for Tanks" closed-cycle cooling cementitious water, raw water, coatings/linings treated water, treated borated water, lubricating oil, condensation 3.2-1, 073 Any material piping, Loss of material due to AMP XI.M42, "Internal No piping components, general, pitting, crevice Coatings/Linings for heat exchangers, corrosion, MIC In-Scope Piping, tanks with internal Piping Components, coatings/linings Heat Exchangers, and exposed to Tanks" closed-cycle cooling water, raw water, treated water, treated borated water, lubricating oil, condensation 3.2-1, 074 Gray cast iron, Loss of material due to AMP XI.M42, "Internal No ductile iron piping, selective leaching Coatings/Linings for piping components In-Scope Piping, with internal Piping Components, coatings/linings Heat Exchangers, and exposed to Tanks" closed-cycle cooling water, raw water, treated water, treated borated water, waste water Discussion GeAsisteAt witl=i t>J6lReG 2191.

L-2025-184 Page 3 of68

+Re IAteFAal GeatiA§JSlbiAiA§lS feF IA Ssepe Pi13iA§l, Pi13iA§l Geffif:)eAeAts, Fleat e*GRaA§leFS, aAEl +aAks AMP is l:lsee te ffiaAa§le less ef seatiA§l eF liAiA§l iAte§lFity feF tRe 61Ait 1 Refl:leliA§l V\lateF +aAk.

Not applicable.

The Unit 1 Refueling Water Tank Fiberglass reinforced vin)ll ester bottom is managed through the Outdoor and Large Atmospheric Metallic Storage Tanks AMP for cracking and de lamination.

Net applisal3Ie.

+Re eA§liAeeFeEl Safety i;;:eatl:lFes Systeffis ee Aet iAGl!:lee aAy ffiateFial 13i13iA§l, 13i13iA§l Geffif:)eAeAtS, Reat e*GRaA§leFS, eF taAks witR iAteFAal seatiA§JSlliAiA§lS e*pesee te slesee sysle seeliA§l wateF, Faw v,ateF, tFeatee wateF, tFeatee 13emtee wateF, eF seAEleAsatieA.

Not used.

Loss of material for the Unit 2 refueling water tank is addressed by line item 3.2-1, 070.

Not applicable.

The Engineered Safety Features Systems do not include any material piping, piping components, heat exchangers, or tanks with internal coatings/linings exposed to closed-cycle cooling water, raw water, treated water, or treated borated water.

St. Lucie Nuclear Plant Units 1 and 2 Dockets 50-335 and 50-389 SLRA Table 3.2.2-2, page 3.2-62 is revised as follows:

Table 3.2.2-2: Containment Spray - Summary of Aging Management Evaluation Component Type Intended Material Environment Aging Effect Function Requiring Management Tank (Unit 1 NaOH Pressure Stainless steel Air-indoor Loss of material storage) boundary uncontrolled (ext)

Tank (Unit 1 NaOH Pressure Stainless steel Gas (int)

None storaqe) boundary Tank (Unit 1 NaOH Pressure Stainless steel Treated water Loss of material storage) boundary (int)

Tank (Unit 1 Pressure Aluminum Air-outdoor Cracking refueling water) boundary (ext)

Tank (Unit 1 Pressure Aluminum Air - outdoor Loss of material refueling water) boundary (ext)

Tank (Unit 1 Pressure Aluminum Air-outdoor Cracking refueling water) boundary (int)

Tank (Unit 1 Pressure Aluminum Air-outdoor Loss of material refueling water) boundary (int)

Tank (Unit 1 Pressure Aluminum Treated borated Loss of material refueling water) boundary water (int)

+aAk (61Ait 1 PFess1:1Fe CoatiAg 11

rdF iAElO0F boss of GoatiAg rnf1:1eliAg wateF) bo1:1AElary 01:1tElooF (iAt)

OF liAiAg iAtegFity

+aAk (61Ait 1 PFeSSl:!Fe CoatiAg

+FeateEl boFateEl boss of GoatiAg mf1:1eliAg wateF) bo1:1AElary wateF (iAt)

OF liAiAg iAtegFity Aging Management Program External Surfaces Monitoring of Mechanical Components (B.2.3.23)

None Water Chemistry (B.2.3.2) One Time Inspection (B.2.3.20)

Outdoor and Large Atmospheric Metallic Storage Tanks (B.2.3.17)

IAtemal CoatiAgs,lbiAiAgs foF IA

~Gape PipiAg, PipiAg CoFRpOAeAts, Fleat ExGhaAgms, aAEl +aAks (B.~.a.;rn)

IAtemal CoatiAgs,lbiAiAgs foF IA

~Gape PipiAg, PipiAg CoFRpOAeAtS, Fleat ExGhaAgeFS, aAEl +aAkS (B.~.a.~8)

NUREG-2191 Item V.D1.EP-107b V.F.EP-22 V.C.EP-63 V. D 1. E-445a V.D1.E-448a V. D 1. E-445a V.D1.E-448a V.D1.E-404 VII.DJ\ 416 V.A.E 401 L-2025-184 Page 4 of66 Table 1 Notes Item 3.2-1, A

004 3.2-1, A

063 3.2-1,

A 022 3.2-1, B

102 3.2-1, B

105 3.2-1, B

102 3.2-1, B

105 3.2-1, B

070

~

A 4a8

~

A

~

St. Lucie Nuclear Plant Units I and 2 Dockets 50-335 and 50-389 SLRA Section 3.3.2.1.2, page 3.3-3 is revised as follows:

Aging Management Programs L-2025-184 Page 5 of68 The following AMPs manage the aging effects for the chemical and volume control system components:

Bolting Integrity (B.2.3.9)

Boric Acid Corrosion (B.2.3.4)

Closed Treated Water Systems (B.2.3.12)

Compressed Air Monitoring (B.2.3.14)

External Surfaces Monitoring of Mechanical Components (B.2.3.23)

Inspection of Internal Surfaces in Miscellaneous Piping and Ducting Components (B.2.3.24)

One-Time Inspection (B.2.3.20)

Thermal Aging Embrittlement of Cast Austenitic Stainless Steel (B.2.3.6)

Water Chemistry (B.2.3.2) 3.3.2.1.2 Component Cooling Water Materials The materials of construction for the CCW system components are:

Carbon steel CoatingCarbon steel with internal coating Copper alloy > 8% Al Copper alloy > 15% Zn Glass Gray cast iron Stainless steel Steel Environments The CCW system components are exposed to the following environments:

Air - indoor uncontrolled Air - outdoor Air with borated water leakage Raw water Treated water Aging Effects Requiring Management The following aging effects associated with the CCW system require management:

Cracking Flow blockage Long-term loss of material Loss of coating or lining integrity Loss of material Loss of preload

St. Lucie Nuclear Plant Units I and 2 Dockets 50-335 and 50-389 SLRA Section 3.3.2.1.4, page 3.3-5 is revised as follows:

3.3.2.1.4 Diesel Generators and Support Systems Materials L-2025-184 Page 6 of66 The materials of construction for the emergency diesel generator system components are:

Aluminum Aluminum alloy Carbon steel CoatingCarbon steel with internal coating/lining Copper alloy Copper alloy >15% Zn Glass Gray cast iron Plexiglas Polyester Rubber Stainless steel Environments The emergency diesel generator system components are exposed to the following environments:

Air-dry Air - indoor uncontrolled Air-outdoor Concrete Diesel exhaust Fuel oil Lubricating oil Treated water Underground Aging Effects Requiring Management The following aging effects associated with the emergency diesel generator system require management:

Cracking Cumulative fatigue damage Hardening or loss of strength Loss of coating or lining integrity Loss of material Loss of preload Reduction of heat transfer

St. Lucie Nuclear Plant Units I and 2 Dockets 50-335 and 50-389 SLRA Section 3.3.2.1.5, page 3.3-6 is revised as follows:

Aging Management Programs L-2025-184 Page 7 of66 The following AMPs manage the aging effects for the emergency diesel generator system components:

Bolting Integrity (B.2.3.9)

Buried and Underground Piping and Tanks (B.2.3.27)

Closed Treated Water Systems (B.2.3.12)

Compressed Air Monitoring (B.2.3.14)

External Surfaces Monitoring of Mechanical Components (B.2.3.23)

Fuel Oil Chemistry (B.2.3.18)

Inspection of Internal Surfaces in Miscellaneous Piping and Ducting Components (B.2.3.24)

Internal Coatings/Lining for In-Scope Piping, Piping Components, Heat Exchangers, and Tanks (B.2.3.28)

Lubricating Oil Analysis (B.2.3.25)

One-Time Inspection (B.2.3.20)

Outdoor and Large Atmospheric Metallic Storage Tank (B.2.3.17)

Selective Leaching (B.2.3.21 )

3.3.2.1.5 Fire Protection / Service Water Materials The materials of construction for the fire protection and service water system components are:

Aluminum Carbon steel Cast iron CoatingCarbon steel with internal coating/lining Coating (cementitious)

Copper alloy Copper alloy > 15% Zn Ductile iron Ductile and Gray cast iron with internal coating/lining Ductile and Gray cast iron with internal coating/lining (cementitious)

Fiberglass Galvanized steel Glass Gray cast iron PVC/CPVC Stainless steel Steel Environments The fire protection and service water system components are exposed to the following environments:

Air - indoor uncontrolled Air - outdoor Air with borated water leakage

St. Lucie Nuclear Plant Units I and 2 Dockets 50-335 and 50-389 SLRA Sections 3.3.2.1.7 and 3.3.2.1.8, page 3.3-9 are revised as follows:

Environments L-2025-184 Page 8 of66 The instrument air and bulk gas system components are exposed to the following environments:

Air-dry Air - indoor uncontrolled Air - outdoor Air with borated water leakage Gas Aging Effects Requiring Management The following aging effects associated with the instrument air instrument air and bulk gas system require management:

Cracking Hardening or loss of strength Loss of material Loss of preload Aging Management Programs The following AMPs manage the aging effects for the instrument air and bulk gas system components:

Bolting Integrity (8.2.3.9)

Boric Acid Corrosion (8.2.3.4)

Compressed Air Monitoring (B.2.3.14)

External Surfaces Monitoring of Mechanical Components (B.2.3.23)

Inspection of Internal Surfaces in Miscellaneous Piping and Ducting Components (B.2.3.24)

Selective Leaching (B.2.3.21) 3.3.2.1.8 Intake Cooling Water/ Emergency Cooling Canal Materials The materials of construction for the ICW and ECC system components are:

Carbon steel CoatingCarbon steel with internal coating/lining CoatingCarbon steel with internal coating/lining (cementitious)

Copper alloy Copper alloy > 8% Al Copper alloy > 15% Zn Elastomer Fiberglass Gray cast iron Gray cast iron with internal coating/lining Monel Stainless steel

St. Lucie Nuclear Plant Units 1 and 2 Dockets 50-335 and 50-389 SLRA Sections 3.3.2.1.8 and 3.3.2.1.9, page 3.3-10 is revised as follows:

Environments L-2025-184 Page 9 of66 The ICW and ECC system components are exposed to the following environments:

Air - indoor uncontrolled Air - outdoor Air with borated water leakage Concrete Raw water Soil Aging Effects Requiring Management The following aging effects associated with the ICW and ECC system require management:

Cracking Flow blockage Hardening or loss of strength Long term loss of material Loss of coating or lining integrity Loss of material Loss of preload VVall thinning erosion Aging Management Programs The following AMPs manage the aging effects for the ICW and ECC system components:

Bolting Integrity (B.2.3.9)

Boric Acid Corrosion (B.2.3.4)

Buried and Underground Piping and Tanks (B.2.3.27)

External Surfaces Monitoring of Mechanical Components (B.2.3.23)

Inspection of Internal Surfaces in Miscellaneous Piping and Ducting Components (B.2.3.24)

Internal Coatings/Linings for In-Scope Piping, Piping Components, Heat Exchangers, and Tanks (B.2.3.28)

One-Time Inspection (B.2.3.20)

Open-Cycle Cooling Water System (B.2.3.11)

Selective Leaching (B.2.3.21 )

3.3.2.1.9 Primary Makeup Water Materials The materials of construction for the PMW system components are:

Carbon steel CoatingCarbon steel with internal coating/lining

St. Lucie Nuclear Plant Units I and 2 Dockets 50-335 and 50-389 SLRA Section 3.3.2.1.11, page 3.3-13 is revised as follows:

Materials The materials of construction for the turbine cooling water system components are:

Carbon steel Carbon steel with internal coating/lining Coating Copper alloy > 15% Zn Glass Stainless steel Environments L-2025-184 Page 10 of66 The turbine cooling water system components are exposed to the following environments:

Air - indoor uncontrolled Treated water Aging Effects Requiring Management The following aging effects associated with the turbine cooling water system require management:

Cracking Loss of coating or lining integrity Loss of material Loss of preload Reduction of heat transfer Aging Management Programs The following AMPs manage the aging effects for the turbine cooling water system components:

Bolting Integrity (B.2.3.9)

Closed Treated Water Systems (B.2.3.12)

External Surfaces Monitoring of Mechanical Components (B.2.3.23)

Inspection of Internal Surfaces in Miscellaneous Piping and Ducting Components (B.2.3.24)

Internal Coatings/Linings for In-Scope Piping, Piping Components, Heat Exchangers, and Tanks (B.2.3.28)

Selective Leaching (B.2.3.21 )

St. Lucie Nuclear Plant Units 1 and 2 Dockets 50-335 and 50-389 SLRA Section 3.3.2.2.7, page 3.3-21 is revised as follows:

L-2025-184 Page 11 of66 aging effect has occurred in three or more refueling outage cycles; or (b) a 5 year search of plant specific OE reveals the aging effect has occurred in two or more refueling outage cycles and resulted in the component either not meeting plant specific acceptance criteria or experiencing a reduction in wall thickness greater than 50 percent (regardless of the minimum wall thickness).

The GALL-SLR Report recommends that GALL-SLR Report AMP XI.M20, "Open-Cycle Cooling Water System, 11 GALL-SLR Report AMP XI. M27, "Fire Water System, 11 or GALL-SLR Report AMP XI.M38, "Inspection of Internal Surfaces in Miscellaneous Piping and Ducting Components, 11 be evaluated for inclusion of augmented requirements to ensure the adequate management of any recurring aging effect(s). Alternatively, a plant-specific AMP may be proposed. Potential augmented requirements include: alternative examination methods (e.g., volumetric versus external visual), augmented inspections (e.g., a greater number of locations, additional locations based on risk insights based on susceptibility to aging effect and consequences of failure, a greater frequency of inspections), and additional trending parameters and decision points where increased inspections would be implemented.

The applicant states: (a) why the program's examination methods will be sufficient to detect the recurring aging effect before affecting the ability of a component to perform its intended function, (b) the basis for the adequacy of augmented or lack of augmented inspections, (c) what parameters will be trended as well as the decision points where increased inspections would be implemented (e.g., the extent of degradation at individual corrosion sites, the rate of degradation change), (d) how inspections of components that are not easily accessed (i.e., buried, underground) will be conducted, and (e) how leaks in any involved buried or underground components will be identified.

Plant-specific OE examples should be evaluated to determine if the chosen AMP should be augmented even if the thresholds for significance of aging effect or frequency of occurrence of aging effect have not been exceeded. For example, during a 10-year search of plant-specific OE, two instances of 360 degree 30 percent wall loss occurred at copper alloy to steel joints. Neither the significance of the aging effect nor the frequency of occurrence of aging effect threshold has been exceeded. Nevertheless, the OE should be evaluated to determine if the AMP that is proposed to manage the aging effect is sufficient (e.g., method of inspection, frequency of inspection, number of inspections) to provide reasonable assurance that the current licensing basis (CLB) intended functions of the component will be met throughout the subsequent period of extended operation.

While recurring internal corrosion is not as likely in other environments as raw water and waste water (e.g., treated water), the aging effect should be addressed in a similar manner.

Site OE does not lead to the conclusion that treated water and waste water systems have experienced recurring internal corrosion. However, site OE shows that carbon steel components with coatings/linings exposed to raw water in the intake cooling water system have experienced recurring internal and external corrosion. The Open-Cycle Cooling Water System AMP is enhanced to manage loss of material due to recurring internal and external corrosion and details related to management of recurring internal corrosion are provided in AMP Section B.2.3.11.

St. Lucie Nuclear Plant Units 1 and 2 Dockets 50-335 and 50-389 SLRA Table 3.3-1, page 3.3-33 is revised as follows:

Table 3.3-1: Summary of Aging Management Evaluations for the Auxiliary Systems Item Component Aging Effect/Mechanism Aging Management Number Program (AMP)/TLAA 3.3-1, 037 Steel piping, piping Loss of material due to AMP XI.M20, components general, pitting, crevice "Open-Cycle Cooling exposed to raw corrosion, MIC; flow Water System" water blockage due to fouling Further Evaluation Recommended No Discussion L-2025-184 Page 12 of68 Consistent with NUREG-2191. +i=lis liAe item is also used f.or i=leat exci=laAger compoAents. The Open-Cycle Cooling Water System AMP is used to manage tess of material aAd flow blockage in steel piping, and piping components, and steel with internal coating/lining ~i~ing and ~i~ing i=leat exci=laAger components exposed to raw water.

St. Lucie Nuclear Plant Units 1 and 2 Dockets 50-335 and 50-389 SLRA Table 3.3-1, page 3.3-51 is revised as follows:

Table 3.3-1: Summary of Aging Management Evaluations for the Auxiliary Systems Item Component Aging Effect/Mechanism Aging Management Number Program (AMP)/TLAA 3.3-1, 127 Metallic piping, Loss of material due to AMP XI.M20, piping components, recurring internal "Open-Cycle Cooling tanks exposed to corrosion Water System," AMP raw water, raw XI.M27, "Fire water (potable),

Water System," or AMP treated water, waste XI.M38, water "Inspection of Internal Surfaces in Miscellaneous Piping and Ducting Components" 3.3-1, 128 Steel tanks (within Loss of material due to AMP XI.M29, the scope of AMP general, pitting, crevice "Outdoor and Large XI.M29, "Outdoor corrosion, MIC (soil, raw Atmospheric Metallic and Large water only)

Storage Tanks" Atmospheric Metallic Storage Tanks") exposed to soil, concrete, air, condensation, raw water 3.3-1, 130 Metallic sprinklers Loss of material due to AMP XI.M27, exposed to air, general (where "Fire Water System" condensation, raw applicable), pitting, crevice water, raw water corrosion, MIC (except for (potable), treated aluminum, and in raw water water, raw water (potable),

treated water only); flow blockage due to fouling Further Evaluation Recommended Yes (SRP-SLR Section 3.3.2.2.7)

No No Discussion L-2025-184 Page 13 of66 Consistent with NUREG-2191. Based on plant specific OE, recurring internal corrosion is an applicable effect for carbon steel components in the intake cooling water system. The Open-Cycle Cooling Water System AMP is used to manage the loss of material due to recurring internal and external corrosion aging effect for carbon steel, components with coatings/linings exposed to raw water in the intake cooling water system.

Further evaluation is documented in Section 3.3.2.2.7.

Consistent with NUREG-2191 with exception. The Outdoor and Large Atmospheric Metallic Storage Tanks AMP is used to manage loss of material in steel tanks exposed to uncontrolled air, outdoor air, and concrete.

Consistent with NUREG-2191. The Fire Water System AMP is used to manage loss of material and flow blockage in metallic sprinklers exposed to raw water.

St. Lucie Nuclear Plant Units 1 and 2 Dockets 50-335 and 50-389 SLRA Table 3.3-1, page 3.3-53 is revised as follows:

Table 3.3-1: Summary of Aging Management Evaluations for the Auxiliary Systems Item Component Aging Effect/Mechanism Aging Management Number Program (AMP)/TLAA 3.3-1, 136 Steel fire water Loss of material due to AMP XI.M27, storage tanks general, pitting, crevice "Fire Water System" exposed to air, corrosion, MIC (raw water, condensation, soil, raw water (potable),

concrete, raw water, treated water, soil only) raw water (potable),

treated water 3.3-1, 137 Steel, stainless Loss of material due to AMP XI.M29, steel, aluminum general (steel only),

"Outdoor and Large tanks (within the pitting, crevice corrosion, Atmospheric Metallic scope of AMP MIC (steel, stainless steel Storage Tanks" XI.M29, only)

"Outdoor and Large Atmospheric Metallic Storage Tanks") exposed to treated water, raw water, waste water 3.3-1, 138 Any material piping, Loss of coating or lining AMP XI.M42, piping components, integrity due to blistering, "Internal heat exchangers, cracking, flaking, peeling, Coatings/Linings for tanks with internal delamination, rusting, or In-Scope Piping, Piping coatings/linings physical damage; loss of Components, Heat exposed to material or cracking for Exchangers, and Tanks" closed-cycle cooling cementitious water, raw water, coatings/Ii n ings raw water (potable),

treated water, treated borated water, fuel oil, lubricating oil, waste water, air-dry, air, condensation Further Evaluation Recommended No No No Discussion L-2025-184 Page 14 of66 Consistent with NUREG-2191 for steel fire water storage tanks. This line item is also applied to steel vortex breakers. The Fire Water System AMP is used to manage loss of material in steel fire water storage tanks and vortex breakers exposed to uncontrolled air, concrete, and raw water.

Not used.

Consistent with NU REG 2191 with e*Ge!')tion. Line item 3.3-1 1 139 is used to manage loss of material due to general 1 12itting1 crevice corrosion 1 and MIC. The Outdoor and Large Atmospheric Metallic Storage Tanks AMP is not used to manage loss of material in steel tanks that are exposed to treated water in the Auxiliary Systems.

Consistent with NUREG-2191. The Internal Coatings/Linings for In-Scope Piping, Piping Components, Heat Exchangers, and Tanks and Fire VVater /\MPs-are~

used to manage loss of coating or lining integrity, for any material with a coating or loss of material or cracking for an~ material with a cementitious coating or lining.

St. Lucie Nuclear Plant Units 1 and 2 Dockets 50-335 and 50-389 SLRA Table 3.3-1, page 3.3-54 is revised as follows:

Table 3.3-1: Summary of Aging Management Evaluations for the Auxiliary Systems Item Component Aging Effect/Mechanism Aging Management Number Program (AMP)/TLAA 3.3-1, 139 Any material piping, Loss of material due to AMP XI.M42, piping components, general, pitting, crevice "Internal heat exchangers, corrosion, MIC Coatings/Linings for tanks with internal In-Scope Piping, Piping coatings/linings Components, Heat exposed to Exchangers, and Tanks" closed-cycle cooling water, raw water, raw water (potable),

treated water, treated borated water, fuel oil, lubricating oil, waste water, air-dry, air, condensation 3.3-1, 140 Gray cast iron, Loss of material due to AMP XI.M42, ductile iron piping selective leaching "Internal components with Coatings/Linings for internal In-Scope Piping, Piping coatings/linings Components, Heat exposed to Exchangers, and Tanks" closed-cycle cooling water, raw water, raw water (potable),

treated water, waste water Further Evaluation Recommended No No Discussion L-2025-184 Page 15 of 66 Net 1:JseEl. Consistent with NUREG-2191.

The Internal Coatings/Linings for In-Scope Piping, Piping Components, Heat Exchangers, and Tanks AMP is oo-t-used to manage loss of material for any material with an internal coating or lining ex~osed to raw water1 air1 treated water1 or fuel oil environments and externally coated steel com~onents subject to raw water environment.

~let 1:JseEl. Consistent with NUREG-2191.

IRteFAal eeatiR§S I liRiR§S aFe Ret The Internal Coatings/Linings for In-Scope Piping, Piping Components, Heat Exchangers, and Tanks AMP is used to manage loss of material due to selective leaching for components with internal coatings/linings in the Auxiliary Systems.

St. Lucie Nuclear Plant Units 1 and 2 Dockets 50-335 and 50-389 SLRA Table 3.3.2-2, page 3.3-94 is revised as follows:

Table 3.3.2-2: Component Cooling Water-Summary of Aging Management Evaluation Component Type Intended Material Environment Aging Effect Function Requiring Management Bolting Mechanical Carbon steel Air-indoor Loss of material closure uncontrolled (ext)

Bolting Mechanical Carbon steel Air-indoor Loss of preload closure uncontrolled (ext)

Bolting Mechanical Carbon steel Air-outdoor Loss of material closure (ext)

Bolting Mechanical Carbon steel Air-outdoor Loss of preload closure (ext)

Bolting Mechanical Stainless Air-indoor Cracking closure steel uncontrolled ( ext)

Bolting Mechanical Stainless Air-indoor Loss of material closure steel uncontrolled (ext)

Bolting Mechanical Stainless Air-indoor Loss of preload closure steel uncontrolled (ext)

Bolting Mechanical Stainless Air-outdoor Cracking closure steel (ext)

Bolting Mechanical Stainless Air-outdoor Loss of material closure steel (ext)

Bolting Mechanical Stainless Air-outdoor Loss of preload closure steel (ext)

Fleat e*sl=laR§leF PFeSSl:lFe CaFbOR steel Ra..,..,ateF (iRt)

Vi Vi LOR§! teFm loss of (CCVVsl=laRRels aRd bol:lRdary mateFial GOOFSf Fleat e*sl=laR§leF PFeSSl:lFe CaFbOR steel Rmv wateF (iRt)

Loss of mateFial (CCW sl=laRRels a Rd bOl:lRdary Flow bloska§le GOOFSf Fleat e*sl=laR§leF PFessl:lFe CaFbOR steel Raw wateF (iRt)

VVall tl=liRRiR§l (CCWsl=laRRels aRd bol:lRdary erosioR GOOFSf Aging Management NUREG-2191 Program Item Bolting Integrity VII.I.A-03 (B.2.3.9)

Bolting Integrity VII.I.AP-124 (B.2.3.9)

Bolting Integrity VII.I.A-03 (B.2.3.9)

Bolting Integrity VII.I.AP-124 (B.2.3.9)

Bolting Integrity VII.I.A-426 (B.2.3.9)

Bolting Integrity VII.I.A-03 (B.2.3.9)

Bolting Integrity VII.I.AP-124 (B.2.3.9)

Bolting Integrity VII.I.A-426 (B.2.3.9)

Bolting Integrity VII.I.A-03 (B.2.3.9)

Bolting Integrity VII.I.AP-124 (B.2.3.9)

ORe Time IRspestioR VII.C1.A 532 (B.2.3.20)

OpeR Cysle CooliR§l VII.C1.AP 194 VVateF System (B.2.3.11)

O13eR Cysle CooliR§l VII.C1./\ 409 VVateF System (B.2.3.11 )

L-2025-184 Page 16 of68 Table 1 Notes Item 3.3-1, 012 A

3.3-1, 015 A

3.3-1, 012 A

3.3-1, 015 A

3.3-1, 145 A

3.3-1, 012 A

3.3-1, 015 A

3.3-1, 145 A

3.3-1, 012 A

3.3-1, 015 A

3.3 1, 193 A

3.3 1, 037 G

3.3 1, 126 E;-4

St. Lucie Nuclear Plant Units 1 and 2 Dockets 50-335 and 50-389 SLRA Table 3.3.2-2, page 3.3-94 (cont'd) is revised as follows:

Table 3.3.2-2: Component Cooling Water-Summary of Aging Management Evaluation Component Type Intended Material Environment Aging Effect Function Requiring Management Heat exchanger Pressure Coating Raw water (int)

Loss of coating or (CCW channels and boundary Carbon steel lining integrity doors) with internal coating Aging Management Program Internal Coatings/Linings for In-Scope Piping, Piping Components, Heat Exchangers, and Tanks (B.2.3.28)

NUREG-2191 Item VII.C1.A-416 Table 1 Item L-2025-184 Page 17 of66 Notes 3.3-1, 138 A

St. Lucie Nuclear Plant Units 1 and 2 Dockets 50-335 and 50-389 SLRA Table 3.3.2-2, page 3.3-95 is revised as follows:

Table 3.3.2-2: Component Cooling Water-Summary of Aging Management Evaluation Component Type Intended Material Environment Aging Effect Function Requiring Management Heat exchanger Pressure Carbon steel Raw water {int}

Loss of material

{CCW channels and boundarv with internal doors}

coating Heat exchanger Pressure Carbon steel Air-outdoor Loss of material (CCW channels and boundary (ext) doors) (Unit 1 only)

Heat exchanger Pressure Carbon steel Air-indoor Loss of material (CCW channels and boundary uncontrolled ( ext) doors) (Unit 2 only)

Heat exchanger Pressure Carbon steel Air-outdoor Loss of material (CCW shell) (Unit 1 boundary (ext) only)

Heat exchanger Pressure Carbon steel Air-indoor Loss of material (CCWshell) (Unit2 boundary uncontrolled ( ext) only)

Heat exchanger Pressure Carbon steel Treated water Loss of material (CCW shells and boundary (int) baffles)

Heat exchanger Heat Copper alloy Raw water (int)

Reduction of heat (CCWtubes) transfer

> 15% Zn transfer Aging Management Program Internal Coatings/Linings for ln-Sco~e Pi~ing, Pi~ing Com~onents, Heat Exchangers, and Tanks {B.2.3.28}

External Surfaces Monitoring of Mechanical Components (B.2.3.23)

Closed Treated Water Systems (B.2.3.12)

Open-Cycle Cooling Water System (B.2.3.11 )

NUREG-2191 Item VII.C1.A-414 VII.I.A-77 Vll.1.A-77 VII.I.A-77 VII.I.A-77 VII.C2.AP-189 VII.C1.AP-187 L-2025-184 Page 18 of66 Table 1 Notes Item 3.3-1, 139

~

3.3-1, 078 A

3.3-1, 046 A

3.3-1, 042 A

St. Lucie Nuclear Plant Units 1 and 2 Dockets 50-335 and 50-389 SLRA Table 3.3.2-2, page 3.3-96 is revised as follows:

Table 3.3.2-2: Component Cooling Water-Summary of Aging Management Evaluation Component Type Intended Material Environment Aging Effect Function Requiring Manaaement Heat exchanger Pressure Copper alloy Treated water Loss of material (CCWtubes) boundary

> 15% Zn (ext)

Heat exchanger Pressure Copper alloy Treated water Loss of material (CCWtubes) boundarv

> 15% Zn (ext) l=leat e*GAaA§eF PFeSS!:lFe CoatiA§ Raw wateF (iAt) boss Of GoatiA§ OF (CCWt!:lbesAeet) bO!:lAdary liAiA§ iAte§Fity Heat exchanger Pressure Copper alloy Raw water (int)

Loss of material (CCWtubesheet) boundary

>8%AI Heat exchanger Pressure Copper alloy Raw water (int)

Loss of material (CCWtubesheet) boundary

>8%AI Flow blockage Heat exchanger Pressure Copper alloy Treated water Loss of material (CCWtubesheet) boundary

>8%AI (ext)

Heat exchanger Pressure Copper alloy Treated water Loss of material (CCW tubesheet) boundarv

> 8%AI (ext)

Orifice Pressure Stainless Air-indoor Cracking boundary steel uncontrolled (ext)

Orifice Pressure Stainless Air-indoor Loss of material boundary steel uncontrolled (ext)

Aging Management Program Closed Treated Water Systems (B.2.3.12)

Selective Leaching (B.2.3.21 )

IAteFAal CoatiA§StbiAiA§S fOF IA ~Go13e Pi13iA§,

Pi13iA§ COA9iE)OAeAtS, l=leat E*GAaA§eFS, aAd +aAkS (el.2.3.28)

Selective Leaching (B.2.3.21 )

Open-Cycle Cooling Water System (B.2.3.11 )

Closed Treated Water Systems (B.2.3.12)

Selective Leaching (B.2.3.21 )

External Surfaces Monitoring of Mechanical Components (B.2.3.23)

NUREG-2191 Item VII.C2.AP-199 VII.C2.AP-43 VII.CU\ 416 VII.C1.A-66 VII.C1.AP-179 VII.C2.AP:199 VII.C2.AP-43 VII.E1.AP-209b VII.E1.AP-221b L-2025-184 Page 19 of66 Table 1 Notes Item 3.3-1, 046 C

3.3-1, 072 C

3.31,138 A

3.3-1, 072 A

3.3-1, 038 A

3.3-1, 046 C

3.3-1, 072 C

3.3-1, 004 A

3.3-1, 006 A

St. Lucie Nuclear Plant Units 1 and 2 Dockets 50-335 and 50-389 SLRA Table 3.3.2-2, page 3.3-101 is revised as follows:

Table 3.3.2-2: Component Cooling Water-Summary of Aging Management Evaluation Component Type Intended Material Environment Aging Effect Function Requiring Management Tank (component Pressure Carbon steel Air-indoor Loss of material cooling water surge) boundary with internal uncontrolled (int) coatings

+ank (component PFeSSUFe Cmbon steel

+mates 'NateF Loss of mateFial coolin§ wateF SUF§e) bounsary fifltt Aging Management Program Inspection of Internal Surfaces in Miscellaneous Pipin§ ans Quctin§ Components (13.2.3.24)

Internal Coatings/Linings for ln-SCOQe PiQing, PiQing ComQonents, Heat Exchangers, and Tanks {B.2.3.28}

Closes +Feates VVateF Systems (B.2.3.12)

NUREG-2191 Item V./\.E 29 VI.D.A-414 VII.C2.AP 202 L-2025-184 Page 20 of66 Table 1 Notes Item 3.2 1,044 A

3.3-1, 139 3.3 1, 045 A

St. Lucie Nuclear Plant Units 1 and 2 Dockets 50-335 and 50-389 SLRA Table 3.3.2-2, page 3.3-102 is revised as follows:

Table 3.3.2-2: Component Cooling Water - Summary of Aging Management Evaluation Component Type Intended Material Environment Aging Effect Function Requiring Management Tank (component Pressure Coating Air-indoor Loss of coating or cooling water surge) boundary Carbon steel uncontrolled (int) lining integrity with internal coating Tank (component Pressure Coating Treated water Loss of coating or cooling water surge) boundary Carbon steel (int) lining integrity with internal coating Tank {com12onent Pressure Carbon steel Treated Loss of material cooling water boundarv with internal water {int}

surge}

coating Thermowell Pressure Copper alloy Air-indoor Cracking boundary

> 15% Zn uncontrolled ( ext)

Thermowell Pressure Copper alloy Treated water Loss of material boundary

> 15% Zn (int)

Thermowell Pressure Copper alloy Treated water Loss of material boundary

> 15% Zn (int)

Aging Management Program Internal Coatings/Linings for In-Scope Piping, Piping Components, Heat Exchangers, and Tanks (B.2.3.28)

Internal Coatings/Linings for In-Scope Piping, Piping Components, Heat Exchangers, and Tanks (B.2.3.28)

Internal Coatings/Linings for ln-Sco12e PiQing1 PiQing Com12onents1 Heat Exchangers1 and Tanks {B.2.3.28}

External Surfaces Monitoring of Mechanical Components (B.2.3.23)

Closed Treated Water Systems (B.2.3.12)

Selective Leaching (B.2.3.21 )

NUREG-2191 Item VII.D.A-416 VII.C2.A-416 VII.C2.A-414 VIII.H.S-454 VII.C2.AP-199 VII.C2.AP-43 L-2025-184 Page 21 of66 Table 1 Notes Item 3.3-1, 138 A

3.3-1, 138 A

3.3-11 139

~

3.4-1, 106 A

3.3-1, 046 A

3.3-1, 072 A

St. Lucie Nuclear Plant Units 1 and 2 Dockets 50-335 and 50-389 SLRA Table 3.3.2-4, page 3.3-129 is revised as follows:

Table 3.3.2-4: Diesel Generators and Support Systems - Summary of Aging Management Evaluation Component Type Intended Material Environment Aging Effect Aging Management Function Requiring Program Management Tank (Unit 1 air Pressure Carbon steel Air-indoor Loss of material External Surfaces start) boundary uncontrolled ( ext)

Monitoring of Mechanical Components (B.2.3.23)

Tank (Unit 1 diesel Pressure Carbon steel Air-outdoor Loss of material Outdoor and Large oil storage) boundary (ext)

Atmospheric Metallic Storage Tanks (B.2.3.17)

Tank (Unit 1 diesel Pressure Carbon steel Air - outdoor (int)

Loss of material Outdoor and Large oil storage) boundary Atmospheric Metallic Storage Tanks (B.2.3.17)

Tank (Unit 1 diesel Pressure Carbon steel Concrete ( ext)

Loss of material Outdoor and Large oil storage) boundary Atmospheric Metallic Storage Tanks (B.2.3.17)

Tank (Unit 1 diesel Pressure Carbon steel Fuel oil (int)

Loss of material Fuel Oil Chemistry oil storage) boundary (B.2.3.18)

One-Time Inspection (B.2.3.20)

Tank (Unit 1 diesel Pressure Coating Air - outdoor (int)

Loss of coating or Internal oil storage boundary Carbon steel lining integrity Coatings/Linings for underside of roof with internal In-Scope Piping, only) coating/lining Piping Components, Heat Exchangers, and Tanks (B.2.3.28)

Tank {Unit 1 Pressure Carbon steel Air - outdoor Loss of material Internal diesel oil storage bounda!:Y with internal

{int)

Coatings/Linings underside of roof coating/lining for ln-SCOE!e only)

Pi!;!ingI Pi!;!ing Com!;!onentsI Heat ExchangersI and Tanks {B.2.3.28}

NUREG-2191 Item VII.I.A-77 VII.H1.A-401 VII.H1.A-401 VII.H1.A-401 VII.H1.AP-105 VII.D.A-416 VII.D.A-414 L-2025-184 Page 22 of66 Table 1 Notes Item 3.3-1, 078 A

3.3-1, 128 B

3.3-1, 070 B

A 3.3-1, 138 A

3.3-11 139 A

St. Lucie Nuclear Plant Units 1 and 2 Dockets 50-335 and 50-389 SLRA Table 3.3.2-4, page 3.3-130 is revised as follows:

Table 3.3.2-4: Diesel Generators and Support Systems - Summary of Aging Management Evaluation Component Type Intended Material Environment Aging Effect Aging Management Function Requiring Program Management Tank (Unit 2 air Pressure Stainless steel Air-indoor Loss of material External Surfaces start) boundary uncontrolled Monitoring of (ext)

Mechanical Components (B.2.3.23)

Tank (Unit 2 diesel PFeSSl:lFe Cmbon steel A'

rdF inElooF Loss of mateFial lnspeotion of lntemal oil storage) bo1:1nElary 1:1noontrnlleEl (int)

S1:1Ffaoes in Misoellaneo1:1s Piping anEl l:::l1:1oting Components (B.2.3.24)

Tank (Unit 2 diesel Pressure Carbon steel Fuel oil (int)

Loss of material Fuel Oil Chemistry oil storage) boundary (B.2.3.18)

One-Time Inspection (B.2.3.20)

Tank (Unit 2 diesel Pressure Carbon steel Air-indoor Loss of material External Surfaces oil storage) boundary uncontrolled (ext)

Monitoring of Mechanical Components (B.2.3.23)

Tank (Unit 2 diesel Pressure Carbon steel Concrete (ext)

None None oil storage) boundary Tank (Unit 2 diesel Pressure Coating Air-indoor Loss of coating or Internal oil storage) boundary Carbon steel uncontrolled (int) lining integrity Coatings/Linings for with internal In-Scope Piping, coating/lining Piping Components, Heat Exchangers, and Tanks (B.2.3.28)

NUREG-2191 Item VI I. H2.AP-221 b V./\.E 29 VII.H1.A-105 VII.I.A-77 Vll.J.AP-282 VII.D.A-416 L-2025-184 Page 23 of66 Table 1 Notes Item 3.3-1, 006 C

3.2 1, 044 A

3.3-1, 070 B

A 3.3-1, 078 A

3.3-1, 112 C

3.3-1, 138 A

St. Lucie Nuclear Plant Units 1 and 2 Dockets 50-335 and 50-389 SLRA Table 3.3.2-4, page 3.3-130 (cont'd) is revised as follows:

Table 3.3.2-4: Diesel Generators and Support Systems - Summary of Aging Management Ev~luation Component Type Intended Material Environment Aging Effect Aging Management Function Requiring Program Management Tank {Unit 2 Pressure Carbon steel Air-indoor Loss of material Internal diesel oil storage}

bounda0£ with internal uncontrolled Coatings/Linings coating/lining

{int}

for ln-Scoge Piging, Piging Comgonents, Heat Exchangers, and Tanks {B.2.3.28}

Tank (Unit 2 diesel Pressure Coating Fuel oil (int)

Loss of coating or Internal oil storage) boundary Carbon steel lining integrity Coatings/Linings for with internal In-Scope Piping, coating/lining Piping Components, Heat Exchangers, and Tanks (B.2.3.28)

Tank {Unit 2 Pressure Carbon steel Fuel oil {int}

Loss of material Internal diesel oil storage}

bounda0£ with internal Coatings/Linings coating/lining for ln-Scoge Piging, Piging Comgonents, Heat Exchangers, and Tanks {B.2.3.28}

NUREG-2191 Table 1 Item Item VII.D.A-414 3.3-1, 139 VII.H1.A-416 3.3-1, 138 VII.H1.A-414 3.3-1, 139 L-2025-184 Page 24 of66 Notes A

A A

St. Lucie Nuclear Plant Units 1 and 2 Dockets 50-335 and 50-389 SLRA Table 3.3.2-5, page 3.3-146 is revised as follows:

Table 3.3.2-5: Fire Protection/ Service Water - Summary of Aging Management Evaluation Component Type Intended Material Environment Aging Effect Function Requiring Management Piping Pressure Carbon steel Raw water (int)

Loss of material boundary Flow blockage Piping Pressure Carbon steel Raw water (int)

Wall thinning -

boundary erosion Piping Pressure Carbon steel Raw water (int)

Wall thinning -

boundary erosion Piping Pressure Carbon steel Soil (ext)

Cracking boundary Piping Pressure Carbon steel Soil (ext)

Loss of material boundary Piping Pressure Coating Raw water (int)

Loss of coating boundary Gra~ cast iron, or lining integrity ductile iron with internal coating/lining Piping Pressure Gra~ cast iron, Raw water {int}

Loss of boundari ductile iron material with internal

{selective coating/lining leaching}

Aging Management Program Fire Water System (B.2.3.16)

Inspection of Internal Surfaces in Miscellaneous Piping and Ducting Components (B.2.3.24)

Fire Water System (B.2.3.16)

Inspection of Internal Surfaces in Miscellaneous Piping and Ducting Components (B.2.3.24)

Buried and Underground Piping and Tanks (B.2.3.27)

Internal Coatings/Linings for In-Scope Piping, Piping Components, Heat Exchangers, and Tanks (B.2.3.28)

Internal Coatings/Linings for In-Scope Piping, Piping Components, Heat Exchangers, and Tanks {B.2.3.28}

NUREG-2191 Item VII.G.A-33 VII.C1.A-727 VII.C1.A-409 VII.C1.A-409 VII.I.A-425 VII.I.AP-198 VII.G.A-416 VII.G.A-415 L-2025-184 Page 25 of66 Table 1 Notes Item 3.3-1,

A 064 3.3-1, A

134 3.3-1,

E, 1 126 3.3-1, E,2 126 3.3-1, B

144 3.3-1,

B 109 3.3-1,

A 138 3.3-1,

~

140

St. Lucie Nuclear Plant Units 1 and 2 Dockets 50-335 and 50-389 SLRA Table 3.3.2-5, page 3.3-146 (cont'd) is revised as follows:

Table 3.3.2-5: Fire Protection I Service Water - Summary of Aging Management Evaluation Component Type Intended Material Environment Aging Effect Function Requiring Management Piping Pressure Grall cast ironI Raw water {int)

Loss of bounda!Y ductile iron material or with internal cracking coating/lining Piping Pressure Coating Raw water (int)

Loss of coating boundary Grall cast ironI or lining integrity ductile iron or loss of with internal material or coating/lining cracking

( cementitious)

Piping Pressure Grall cast ironI Raw water {int)

Loss of bounda!Y ductile iron material with internal

{selective coating/lining leaching)

{cementitious)

Piping Pressure Grall cast ironI Raw water {int)

Loss of bounda!Y ductile iron material with internal coating/lining

{cementitious)

Piping Pressure Copper alloy Air-indoor None boundary uncontrolled (ext)

Aging Management Program Internal Coatings/Linings for In-Scope PipingI Piping ComponentsI Heat ExchangersI and Tanks {B.2.3.28)

Internal Coatings/Linings for In-Scope Piping, Piping Components, Heat Exchangers, and Tanks (B.2.3.28)

Internal Coatings/Linings for In-Scope PipingI Piping ComponentsI Heat ExchangersI and Tanks {B.2.3.28)

None NUREG-2191 Item VII.G.A-414 VII.G.A-416 VII.G.A-415 VII.G.A-414 VII.J.AP-144 Table 1 Item 3.3-11 139 3.3-1, 138 3.3-11 140 3.3-11 139 3.3-1, 114 L-2025-184 Page 26 of 66 Notes A

A A

St. Lucie Nuclear Plant Units 1 and 2 Dockets 50-335 and 50-389 SLRA Table 3.3.2-5, page 3.3-147 is revised as follows:

Table 3.3.2-5: Fire Protection I Service Water - Summary of Aging Management Evaluation Component Type Intended Material Environment Aging Effect Function Requiring Management Piping Pressure Copper alloy Air-outdoor (ext)

None boundary Piping Pressure Copper alloy Raw water (int)

Loss of material boundary Flow blockaqe Piping Pressure Copper alloy Raw water (int)

Wall thinning -

boundary erosion Piping Pressure Copper alloy Air-indoor Cracking boundary

> 15% Zn uncontrolled ( ext)

Piping Pressure Copper alloy Air-indoor None boundary

> 15% Zn uncontrolled (int)

Piping Pressure Copper alloy Air-outdoor (ext)

Cracking boundary

> 15% Zn Piping Pressure Copper alloy > Air-outdoor (ext) Loss of material boundary 15%Zn Piping Pressure Copper alloy Air - outdoor (int)

Loss of material boundary

> 15% Zn

~

PFeSSUFe Ductile iFOn I\.

nlF outdooF (m<t)

Loss of mateFial boundary

~

PFeSSUFe Ductile iFon ConcFete (e*t)

Loss of mateFial boundary

~

PFeSSUFe -

Ductile iFon Raw wateF (int)

Long teFm loss L.-

of mateFial Aging Management NUREG-2191 Program Item None VII.J.AP-144 Fire Water System VII.G.AP-197 (B.2.3.16)

Fire Water System VI I. C 1.A-409 (B.2.3.16)

External Surfaces VIII.H.S-454 Monitoring of Mechanical Components (B.2.3.23)

None VII.J.AP-144 External Surfaces VIII.H.S-454 Monitoring of Mechanical Components (B.2.3.23)

Selective Leaching (B.2.3.21)

Selective Leaching (B.2.3.21) e*ternal guFfaces VII.I.A 77 MonitOFing of Mecl=lanical Components (B.2.J.2J)

BuFied and VII.I.AP 198 l::::lndeFgFound Piping and +anks (R2.:l27)

Gne +ime Inspection VII.G.A §J2

/ I"),.,.., ')() \

L-2025-184 Page 27 of66 Table 1 Notes Item 3.3-1, A

114 3.3-1, A

064 3.3-1, E, 1 126 3.4-1, A

106 3.3-1,

A 114 3.4-1, A

106 H,6 H,6

~ A G+8

~ AB 4-09

~ A 4-W

St. Lucie Nuclear Plant Units 1 and 2 Dockets 50-335 and 50-389 SLRA Table 3.3.2-5, page 3.3-147 (cont'd) is revised as follows:

Table 3.3.2-5: Fire Protection I Service Water-Summary of Aging Mana1 ement Evaluation Component Type Intended Material Environment Aging Effect Function Requiring Mana~ement

~

PFeSStlFe Q1;1etile iFaA Ra1N 1NateF (iAt) bass af FAateFial L-

1-.-..

-~

~

PFeSStlFe Q1;1etile iFaA Raw wateF (iAt) bass af FAateFial

,-~

Cl L

~

PFeSStlFe Q1;1etile irnA Raw wateF (iAt)

Wall tRiAAiA§l

'--,........r_,,..,_

ernsiaA Aging Management NUREG-2191 Program Item Seleetive beael:!iA§l VII.G.A §1 I D') ':l ')~ \

FiFe lJVateF SysteFA VII.G.,A, JJ

/ 0')':l~Q \

Firn WateF SysteFA VII.C1.A 409

, n,.,..., a"" '

Table 1 Item

~

004

~

L-2025-184 Page 28 of66 Notes A

A e;-4

St. Lucie Nuclear Plant Units 1 and 2 Dockets 50-335 and 50-389 SLRA Table 3.3.2-5, page 3.3-148 is revised as follows:

Table 3.3.2-5: Fire Protection I Service Water - Summary of Aging Management Evaluation Component Type Intended Material Environment Aging Effect Function Requiring Manaaement

~

PFess1:iFe D1:ictile irnn Soil (ext)

Cmcking bo1:inElary

~

PFeSSl:lFe O1:lctile iFOn Soil (ext)

Loss of mateFial bo1:inElary

~

PFeSSl:lFe D1:ictile iFon Soil (ext)

Loss of mateFial L-

---J,....,..

-~

Piping Pressure Galvanized Air-outdoor (ext)

Loss of material boundary steel Piping Pressure Galvanized Air - outdoor (int)

Loss of material boundary steel Piping Pressure Galvanized Raw water (int)

Long-term loss boundary steel of material Piping Pressure Galvanized Raw water (int)

Loss of material boundarv steel Flow blockaae Piping Pressure Galvanized Raw water (int)

Wall thinning -

boundarv steel erosion Piping Pressure Gray cast iron Air-indoor Loss of material boundary uncontrolled (ext)

Aging Management NUREG-2191 Program Item Bl:lFieEI anEI VII.I.A 425 UnEleFgFOl:lnEI Piping anEI +anks (B.2.J.27)

Bl:lFieEI anEI VII.I.AP 198 UnEleFgFOl:lnEI Piping anEI +anks (B.2.J.27)

Selecti*,<e Leaching VII.G.A G2

,...,.,,,,.,~,

External Surfaces VII.I.A-77 Monitoring of Mechanical Components (B.2.3.23)

Inspection of Internal V.A.E-29 Surfaces in Miscellaneous Piping and Ducting Components (B.2.3.24)

One-Time Inspection VII.G.A-532 (B.2.3.20)

Fire Water System VII.G.A-33 (B.2.3.16)

Fire Water System VII.C1.A-409 m.2.3.16)

External Surfaces VII.I.A-77 Monitoring of Mechanical Components (B.2.3.23)

L-2025-184 Page 29 of66 Table 1 Notes Item

~ A8 444

~ A8 00

~ A G72 3.3-1,

A 078 3.2-1,

A 044 3.3-1,

A 193 3.3-1,

A 064 3.3-1,

E, 1 126 3.3-1,

A 078

St. Lucie Nuclear Plant Units 1 and 2 Dockets 50-335 and 50-389 SLRA Table 3.3.2-5, page 3.3-148 (cont'd) is revised as follows:

Table 3.3.2-5: Fire Protection/ Service Water - Summarv of A!:lin!:I Mana!~ement Evaluation Component Type Intended Material Environment Aging Effect Function Requiring Management Piping Pressure Gray cast ironi Air-outdoor (ext)

Loss of material boundary ductile iron Aging Management NUREG-2191 Program Item External Surfaces Vll.1.A-77 Monitoring of Mechanical Components (B.2.3.23)

Table 1 Item 3.3-1,

078 L-2025-184 Page 30 of66 Notes A

St. Lucie Nuclear Plant Units I and 2 Dockets 50-335 and 50-389 SLRA Table 3.3.2-5, page 3.3-149 is revised as follows:

Table 3.3.2-5: Fire Protection/ Service Water-Summary of Aging Management Evaluation Component Type Intended Material Environment Aging Effect Function Requiring Management Piping Pressure Gray cast ironi Concrete (ext)

Loss of material boundary ductile iron Piping Pressure Gray cast ironi Raw water (int)

Long-term loss boundary ductile iron of material Piping Pressure Gray cast ironi Raw water (int)

Loss of material boundary ductile iron Piping Pressure Gray cast ironi Raw water (int)

Loss of material boundary ductile iron Flow blockage Piping Pressure Gray cast ironi Raw water (int)

Wall thinning -

boundary ductile iron erosion Piping Pressure Gray cast ironi Soil (ext)

Cracking boundary ductile iron Piping Pressure Gray cast ironi Soil (ext)

Loss of material boundary ductile iron

~

Piping Pressure Gray cast ironi Soil (ext)

Loss of material boundary ductile iron Piping Pressure PVC/CPVC Air-indoor None boundary uncontrolled (ext)

Piping Pressure PVC/CPVC Air-indoor None boundary uncontrolled (int)

Piping Pressure Stainless steel Air-indoor Cracking boundary uncontrolled (ext)

Piping Pressure Stainless steel Air-indoor Loss of material boundary uncontrolled ( ext)

Aging Management NUREG-2191 Program Item Buried and VII.I.AP-198 Underground Piping and Tanks (B.2.3.27)

One-Time Inspection VII.G.A-532 (B.2.3.20)

Selective Leaching VII.G.A-51 (B.2.3.21 )

Fire Water System VII.G.A-33 (B.2.3.16)

Fire Water System VI I. C 1.A-409 (B.2.3.16)

Buried and VI I. I.A-425 Underground Piping and Tanks (B.2.3.27)

Buried and VII.I.AP-198 Underground Piping and Tanks (B.2.3.27)

Selective Leaching VII.G.A-02 (B.2.3.21 )

None VII.J.AP-268 None VII.J.AP-268 External Surfaces VII.G.AP-209b Monitoring of Mechanical Components (B.2.3.23)

External Surfaces VII.G.AP-221 b Monitoring of Mechanical Components (B.2.3.23)

L-2025-184 Page 31 of 66 Table 1 Notes Item 3.3-1, 8

109 3.3-1,

A 193 3.3-1, A

072 3.3-1, A

064 3.3-1, E, 1 126 3.3-1,

8 144 3.3-1,

8 109 3.3-1,

A 072 3.3-1,

A 119 3.3-1, A

119 3.3-1,

A 004 3.3-1,

A 006

St. Lucie Nuclear Plant Units 1 and 2 Dockets 50-335 and 50-389 SLRA Table 3.3.2-5, page 3.3-157 is revised as follows:

Table 3.3.2-5: Fire Protection / Service Water - Summary of Aging Management Evaluation Component Type Intended Material Environment Aging Effect Function Requiring Management

+aAk (City V\/ateF

~Fess~Fe CmboA steel Raw wateF (iAt) bOA§ teFA'l loss StoFa§e +aAks) bo~AElaFY of ffiateFial Tank (City Water Pressure Carbon steel Raw water (int)

Loss of material Storage Tanks) boundary with internal coating/lining Tank (City Water Pressure CoatiA§ Air - outdoor (int)

Loss of coating Storage Tanks) boundary Carbon steel or lining integrity with internal coating/lining Aging Management NUREG-2191 Program Item OAe +iffie IAspeotioA VII.G.A 532 (B.2.3.2Q) i;;iFe lJVateF Systeffi VII.G.A 412 (B.2.3.16)

VII.G.A-414 Internal Coatings/Linings for ln-ScoQe PiQing 1 PiQing ComQonents 1 Heat Exchangers 1 and Tanks {B.2.3.28}

Internal VII.D.A-416 Coatings/Linings for In-Scope Piping, Piping Components, Heat Exchangers, and Tanks (B.2.3.28)

L-2025-184 Page 32 of66 Table 1 Notes Item

~ A 493 3.3-1,

A

~

139 3.3-1, A

138

St. Lucie Nuclear Plant Units 1 and 2 Dockets 50-335 and 50-389 SLRA Table 3.3.2-5, page 3.3-158 is revised as follows:

Table 3.3.2-5: Fire Protection I Service Water - Summary of Aging Management Evaluation Component Type Intended Material Environment Aging Effect Function Requiring Management Tank {Cit)!'. Water Pressure Carbon steel Air - outdoor {int}

Loss of material Storage Tanks}

boundart with internal coating/lining Tank (City Water Pressure Coating Raw water (int)

Loss of coating Storage Tanks) boundary Carbon steel or lining integrity with internal coating/lining Tank Pressure Carbon steel Air-outdoor (ext)

Loss of material (Hydropneumatic boundary Tank)

Tank Pressure Carbon steel Air - outdoor (int)

Loss of material (Hydropneumatic boundary Tank)

Tank Pressure Carbon steel Raw water (int)

Long-term loss (Hydropneumatic boundary of material Tank)

Tank Pressure Carbon steel Raw water (int)

Loss of material (Hydropneumatic boundary Flow blockage Tank)

Aging Management Program Internal Coatings/linings for ln-SCOQe PiQing, PiQing ComQonents, Heat Exchanaers. and Tanks {B.2.3.28}

Internal Coatings/Linings for In-Scope Piping, Piping Components, Heat Exchangers, and Tanks (B.2.3.28)

External Surfaces Monitoring of Mechanical Components (B.2.3.23)

Inspection of Internal Surfaces in Miscellaneous Piping and Ducting Components (B.2.3.24)

One-Time Inspection (B.2.3.20)

Fire Water System (B.2.3.16)

NUREG-2191 Item VII.D.A-414 VII.G.A-416 Vll.l.A-77 V.A.E-29 Vll.G.A-532 VII.G.A-33 L-2025-184 Page 33 of 66 Table 1 Notes Item 3.3-1, A

139 3.3-1,

C 138 3.3-1,

A 078 3.2-1, A

044 3.3-1,

A 193 3.3-1, A

064

St. Lucie Nuclear Plant Units 1 and 2 Dockets 50-335 and 50-389 SLRA Table 3.3.2-5, page 3.3-162 is revised as follows:

Table 3.3.2-5: Fire Protection/ Service Water - Summary of Aging Management Evaluation Component Type Intended Material Environment Aging Effect Function Requiring Management Valve body PFeSSUFe Ductile irnn AiF outdooF (ext)

Loss of mateFial boundary Valve body PFeSSUFe Ductile iFon Raw wateF (int)

Long teFm loss L..-

,_ -'-.n of mateFial Valve body PFeSSUFe Ductile imn Raw watOF (int)

Loss of matOFial l- -

Valve body PFeSSUFe Ductile iFon Rav,i 1NateF (int)

Loss of mateFial

'--,-.J--

r:-1-.

Valve body PFeSSUFO Ductile iFon Raw wateF (int)

Wall thinning ernsion Valve body Pressure Gray cast iron Air-indoor Loss of material boundary uncontrolled (ext)

Valve body Pressure Gray cast ironi Air - outdoor (ext)

Loss of material boundary ductile iron Valve body Pressure Gray cast ironi Raw water (int)

Long-term loss boundary ductile iron of material Valve body Pressure Gray cast ironi Raw water (int)

Loss of material boundary ductile iron Valve body Pressure Gray cast ironi Raw water (int)

Loss of material boundary ductile iron Flow blockage Valve body Pressure Gray cast ironi Raw water (int)

Wall thinning -

boundary ductile iron erosion Valve body Pressure Gray cast iron Soil (ext)

Cracking boundary Aging Management Program exteFAal SuFfaces MonitOFing of Mechanical Components (B.~.a.~a)

Gne +ime Inspection I I"> '"I '> '"I()\

Selective Leaching

/ C '"l 'l '"l~ \

\ -

FiFe VVateF System I I">,-, '> ~,:, \

Firn WateF System l l">'"I'>~'"

External Surfaces Monitoring of Mechanical Components (B.2.3.23)

One-Time Inspection (B.2.3.20)

Selective Leaching (B.2.3.21 )

Fire Water System (B.2.3.16)

Buried and Underground Piping and Tanks (B.2.3.27)

NUREG-2191 Item VII.I.A 77 VII.G.A ea~

VII.G.A §1 VII.G.A aa VII.C1./\ 409 VII.I.A-77 VII.I.A-77 VII.G.A-532 VII.G.A-51 VII.G.A-33 VII.C1.A-409 VII.I.A-425 L-2025-184 Page 34 of66 Table 1 Notes Item

~ A G+8

~ A 493

~ A

~

~ A 004

~ e,--4

~

3.3-1,

A 078 3.3-1,

A 193 3.3-1,

A 072 3.3-1, A

064 3.3-1,

E, 1 126 3.3-1,

B 144

St. Lucie Nuclear Plant Units 1 and 2 Dockets 50-335 and 50-389 SLRA Table 3.3.2-8, page 3.3-189 is revised as follows:

Table 3.3.2-8: Intake Cooling Water/ Emergency Cooling Canal - Summary of Aging Management Evaluation Component Type Intended Material Environment Aging Effect Aging Management Function Requiring Program Management Piping Pressure Carbon steel Concrete ( ext)

Loss of material Buried and boundary Underground Piping and Tanks (B.2.3.27)

~

PFessl:lFe GaFl3eR steel Rav; wateF (e*t) beR§ teFFR less ef GRe +iFRe IRSfleGtieR FRateFial

/ D

'"> '> ~~

Piping Pressure Carbon steel Raw water ( ext)

Loss of material Open-Cycle Cooling boundary with external Water System coating (B.2.3.11 )

Piping Pressure Carbon steel Raw water ( ext)

Loss of material Gf)eR Gysle GeeliR§ boundary with internal WateF SysteFR coating/lining (B.2.3.11 ) Internal Coatings/Linings for In-Scope PipingI Piping ComponentsI Heat ExchangersI and Tanks {B.2.3.28}

Piping Pressure Carbon steel Raw water { ext}

Loss of coating Internal bounda!Y with external or lining integrit)l Coatings/Linings coating for In-Scope PipingI Piping ComponentsI Heat Exchangers 1 and Tanks {B.2.3.28}

PePif)iR§ PFessl:lFe GaFl3eR steel Ra>N ',!,'ateF (iRt) beR§ teFm less ef GRe +ime IRSfleGtieR L-mateFial

/ 0 ') ') ')(\\\\

Piping Pressure Carbon steel Raw water (int)

Loss of material Open-Cycle Cooling boundary with internal Water System coating/lining (B.2.3.11 )

Piping Pressure Carbon steel Raw water (int) bess ef mateFial Open-Cycle Cooling boundary with internal Flow blockage Water System coating/lining (B.2.3.11 )

~

PFessl:lFe GaFseR steel Ra1N wateF (iRt)

'MIii thiRRiR§ Gf)eR Gysle GeeliR§ 13el:lRdary emsieR WateF SysteFR (B.2.3.11 )

NUREG-2191 Item VII.I.AP-198 VII.G1.A §32 VII.C1.A-400a VII.G1.AP 194 VII.C1.A-414 VII.C1.A-416 VII.G1.,t:,, §32 VI I. C 1.A-400a VII.C1.AP-194 VII.G1.A 409 L-2025-184 Page 35 of66 Table 1 Notes Item 3.3-1,

8 109

~

49d 3.3-1,

A 127 a.a 1, oa7 A

3.3-11 139 3.3-11 138

~

~ A 49d 3.3-1,

A 127 3.3-1,

AJ__d 037

~ e;-4 429

St. Lucie Nuclear Plant Units 1 and 2 Dockets 50-335 and 50-389 SLRA Table 3.3.2-8, page 3.3-189 (cont'd) is revised as follows:

Table 3.3.2-8: Intake Cooling Water/ Emergency Cooling Canal - Summary of Aging Mana 1ement Evaluation Component Type Intended Material Environment Aging Effect Aging Function Requiring Management Management Program Piping Pressure Carbon steel Soil (ext)

Cracking Buried and boundary Underground Piping and Tanks (B.2.3.27)

Piping Pressure Carbon steel Soil (ext)

Loss of material Buried and boundary Underground Piping and Tanks (B.2.3.27)

Piping Pressure Coating Raw water (int)

Loss of coating or Internal boundary Carbon steel lining integrity Coatings/Linings for with internal In-Scope Piping, coating/lining Piping Components, Heat Exchangers, and Tanks (B.2.3.28)

NUREG-2191 Item VII.I.A-425 VII.I.AP-198 VII.C1.A-416 Table 1 Item 3.3-1, 144 3.3-1, 109 3.3-1,

138 L-2025-184 Page 36 of66 Notes AB AB A

St. Lucie Nuclear Plant Units 1 and 2 Dockets 50-335 and 50-389 SLRA Table 3.3.2-8, page 3.3-190 is revised as follows:

Table 3.3.2-8: Intake Cooling Water/ Emergency Cooling Canal - Summary of Aging Management Evaluation Component Type Intended Material Environment Aging Effect Aging Management Function Requiring Program Manaciement Piping Pressure Carbon steel Raw water {int}

Loss of material Internal boundaiy with internal Coatings/Linings coating/lining for In-Scope Piping, Piping Components, Heat Exchangers, and Tanks {B.2.3.28}

Piping Pressure Coating Raw water (int)

Loss of coating or Internal boundary Carbon steel lining integrity..Q!

Coatings/Linings for with internal loss of material In-Scope Piping, coating/lining or cracking Piping Components, (cementitious)

( cementitious)

Heat Exchangers, and Tanks (B.2.3.28)

Piping Pressure Carbon steel Raw water {int}

Loss of material Internal boundaiy with internal Coatings/Linings coating/lining for In-Scope

{ cem entitious}

Piping, Piping Components, Heat Exchangers, and Tanks {B.2.3.28}

Piping Pressure Carbon steel Raw water {int}

Loss of material Open-C)lcle boundaiy with internal Cooling Water coating/lining S)lstem {B.2.3.11}

{cementitious}

Piping Pressure Carbon steel Raw water {int}

Flow blockage Open-C)lcle boundarv with internal Cooling Water coating/lining S)lstem {B.2.3.11}

{ cementitious}

Piping Pressure Copper alloy Air-outdoor None None boundary (ext)

Piping Pressure Copper alloy Air-outdoor None None boundarv (int)

NUREG-2191 Item VII.C1.A-414 VII.G.A 4~1 VII.C1.A-416 VII.C1.A-414 VII.C1.A-400a VII.C1.AP-194 VII.J.AP-144 VII.J.AP-144 L-2025-184 Page 37 of66 Table 1 Notes Item 3.3-1, A

139 3.3-1, A

138 3.3-1, A

139 3.3-1, 127 A 3.3-1, J,4 037 3.3-1,

A 114 3.3-1,

A 114

St. Lucie Nuclear Plant Units I and 2 Dockets 50-335 and 50-389 SLRA Table 3.3.2-8, page 3.3-191 is revised as follows:

Table 3.3.2-8: Intake Cooling Water/ Emergency Cooling Canal - Summary of Aging Management Evaluation Component Type Intended Material Environment Aging Effect Aging Management Function Requiring Program Management Piping (ECC)

Pressure Copper alloy >

Raw water ( ext)

Cracking Open-Cycle Cooling boundary 8%AI Water System (B.2.3.11 )

Piping (ECC)

Pressure Copper alloy >

Raw water ( ext)

Loss of material Open-Cycle Cooling boundary 8%AI Water System (B.2.3.11)

Piping (ECC)

Pressure Copper alloy >

Raw water ( ext)

Loss of material Selective Leaching boundary 8%AI (B.2.3.21 )

Piping Pressure Copper alloy >

Raw water (int)

Cracking Open-Cycle Cooling boundary 8%AI Water System (B.2.3.11 )

Piping Pressure Copper alloy >

Raw water (int)

Loss of material Selective Leaching boundary 8%AI (B.2.3.21 )

Piping Pressure Copper alloy >

Raw water (int)

Loss of material Open-Cycle Cooling boundary 8%AI Flow blockage Water System (B.2.3.11 )

Piping Pressure Copper alloy >

Raw water (int)

Wall thinning -

Open-Cycle Cooling boundary 8%AI erosion Water System (B.2.3.11 )

Piping Pressure Monel Air-indoor Loss of material External Surfaces boundary uncontrolled Monitoring of (ext)

Mechanical Components (B.2.3.23)

Piping Pressure Monel Air-outdoor Loss of material External Surfaces boundary (ext)

Monitoring of Mechanical Components (B.2.3.23)

Piping Pressure Monel Raw water (int)

Loss of material Open-Cycle Cooling boundary Flow blockage Water System (B.2.3.11 )

Piping Pressure Monel Raw water (int)

Wall thinning -

Open-Cycle Cooling boundary erosion Water System (B.2.3.11 )

NUREG-2191 Item VII.C1.A-473b VII.C1.AP-196 VII.C1.A-47 VII.C1.A-473b VII.C1.A-47 VII.C1.AP-196 VII.C1.A-409 VII.C1.AP-221b VII.C1.AP-221b VII.C1.AP-206 VII.C1.A-409 L-2025-184 Page 38 of66 Table 1 Notes Item 3.3-1,

A 160 3.3-1,

A 034 3.3-1,

A 072 3.3-1, A

160 3.3-1,

A 072 3.3-1, A

034 3.3-1, E, 1 126 3.3-1,

A 006 3.3-1, A

006 3.3-1,

A 034 3.3-1, E, 1 126

St. Lucie Nuclear Plant Units 1 and 2 Dockets 50-335 and 50-389 SLRA Table 3.3.2-8, page 3.3-194 is revised as follows:

Table 3.3.2-8: Intake Cooling Water I Emergency Cooling Canal - Summary of Aging Management Evaluation Component Type Intended Material Environment Aging Effect Aging Management Function Requiring Program Mana~ement Piping (Unit 2 only)

Pressure Carbon steel Air-indoor Loss of material Inspection of Internal boundary uncontrolled (int)

Surfaces in Miscellaneous Piping and Ducting Components (B.2.3.24)

Piping (Unit 2 only)

Pressure Fiberglass Air-indoor Loss of material External Surfaces boundary uncontrolled (ext)

Monitoring of Mechanical Components (B.2.3.23)

Piping (Unit 2 only)

Pressure Fiberglass Raw water (int)

Cracking Open-Cycle Cooling boundary Loss of material Water System Flow blockaae (B.2.3.11 )

Piping and piping Structural Carbon steel Air-outdoor Loss of material External Surfaces components integrity (ext)

Monitoring of (attached)

Mechanical Components (B.2.3.23)

Pi13iAg aAEl J3iJ3iAg Structural CarboA steel Raw water (iAt)

LoAg term loss of OAe Time IAs13ectioA com130AeAts iAtegrity material (B.2.3.20)

(attacl=leEI)

Piping and piping Structural Carbon steel Raw water (int)

Loss of material IAs13ectioA of IAtemal components integrity with internal Surfaces iA (attached) coating/lining MiscellaAeous Pi13iAg aAEI QuctiAg Com130AeAts (B.2.3.24) Internal Coatings/Linings for ln-ScoQe PiQing 1 PiQing ComQonents1 Heat Exchangers1 and Tanks {B.2.3.28}

NUREG-2191 Item V.A.E-29 VII.I.A-719 VII.C1.AP-238 VII.I.A-77 VII.C1./\ 532 VII.C1./\ 727 VII.C1.A-414 L-2025-184 Page 39 of66 Table 1 Notes Item 3.2-1, A

044 3.3-1,

A 082 3.3-1, A

030a 3.3-1, A

078

~ A 4W 3.3-1,

A 4a4139

St. Lucie Nuclear Plant Units I and 2 Dockets 50-335 and 50-389 SLRA Table 3.3.2-8, page 3.3-194 (cont'd) is revised as follows:

Table 3.3.2-8: Intake Cooling Water/ Emergency Cooling Canal - Summary of Aging Management Evaluation Component Type Intended Material Environment Aging Effect Aging Management Function Requiring Program Management Pi12ing and 12i12ing Structural Carbon steel Raw water {int}

Loss of coating Internal com12onents integrit~

with internal or lining integrit~

Coatings/Linings for

{attached}

coating/lining ln-Sco12e Pi12ing 1 Pi12ing Com12onents 1 Heat Exchangers, and Tanks {B.2.3.28}

PipiA§! aAEI pipiA§ Struotural CarboA steel Ra>.'l water (iAt)

Wall thiAAiA§ IAspeotioA of IAtemal oompoAeAts iAte§rity erosioA Surfaoes iA (attaoheEI)

MisoellaAeous PipiA§ aAEI QuotiA§ CompoAeAts (B.~.3.~4 )

NUREG-2191 Item VII.C1.A-416 VII.C1.A 409 L-2025-184 Page 40 of66 Table 1 Notes Item 3.3-1, A

138

~ ~

~

St. Lucie Nuclear Plant Units 1 and 2 Dockets 50-335 and 50-389 SLRA Table 3.3.2-8, page 3.3-198 is revised as follows:

Table 3.3.2-8: Intake Cooling Water/ Emergency Cooling Canal - Summary of Aging Management Evaluation Component Type Intended Material Environment Aging Effect Aging Management Function Requiring Program Manaaement Thermowell Pressure Monel Air-outdoor Loss of material External Surfaces boundary (ext)

Monitoring of Mechanical Components (B.2.3.23)

Thermowell Pressure Monel Raw water (int)

Loss of material Open-Cycle Cooling boundary Flow blockage Water System (B.2.3.11 )

Valve body Pressure Carbon steel Air-indoor Loss of material External Surfaces boundary uncontrolled Monitoring of (ext)

Mechanical Components (B.2.3.23)

Valve body Pressure Carbon steel Air-outdoor Loss of material External Surfaces boundary (ext)

Monitoring of Mechanical Components (B.2.3.23)

Valve body FlFessuFe GaFbOR steel Raw wateF (iRt) bOR§l teFFR loss of GRe +iFRe IRspeGtioR FRateFial

, n,., -, rirn J

Valve body Pressure Carbon steel Raw water (int)

Loss of material Open-Cycle Cooling boundary with internal Water System coating/lining (B.2.3.11 )

Valve body Pressure Carbon steel Raw water (int) boss of FRateFial Open-Cycle Cooling boundary with internal Flow blockage Water System coating/lining (B.2.3.11 )

Valve body FlFeSSUFe GaFbOR steel Raw wateF (iRt)

\'Vall thiRRiR§!

GpeR GyGle GooliR§!

bouRdary erosioR VVateF SysteFR (B.2.J.11 )

Valve body FlFeSSUFe GoatiR§!

Raw wateF (iRt) boss of GoatiR§! OF IRteFRal bouRdary liRiR§! iRte§!Fity GoatiR§!SlbiRiR§!S foF IA SGope FlipiR§!,

Pi13iR§! GOFRf30ReRtS, Heat ExGhaR§leFs,

-*,,J T I D

'"I ') '"I 0 \

NUREG-2191 Item VII.C1.AP-221b VI I. C 1.AP-206 Vll.1.A-77 VII.I.A-77 VII.G1.A §J2 VII.C1.A-400a VII.C1.AP-194 VII.GU\ 409 VII.GU\ 416 L-2025-184 Page 41 of66 Table 1 Notes Item 3.3-1,

A 006 3.3-1,

A 034 3.3-1,

A 078 3.3-1,

A 078

~ A 4-93 3.3-1, A

127 3.3-1,

A 037

~ e,-4 42a

~ A 438

St. Lucie Nuclear Plant Units 1 and 2 Dockets 50-335 and 50-389 SLRA Table 3.3.2-8, page 3.3-199 is revised as follows:

Table 3.3.2-8: Intake Cooling Water/ Emergency Cooling Canal - Summary of Aging Management Evaluation Component Type Intended Material Environment Aging Effect Aging Management Function Requiring Program Mana~ement Valve bod:1£ Pressure Carbon steel Raw water {int}

Loss of coating Internal boundarv with internal or lining integrit:ll Coatings/Linings for coatings/

ln-SCOQe PiQing, lining PiQing ComQonents, Heat Exchangers, and Tanks {B.2.3.28}

Valve bod:1£ Pressure Carbon steel Raw water {int}

Loss of material Internal bounda!Y with internal Coatings/Linings for coatings/

ln-SCOQe PiQing, linings PiQing ComQonents, Heat Exchangers, and Tanks {B.2.3.28}

Valve body Pressure Copper alloy Air-indoor None None boundary uncontrolled (ext)

Valve body Pressure Copper alloy Air-outdoor None None boundary (ext)

Valve body Pressure Copper alloy Raw water (int)

Loss of material Open-Cycle Cooling boundary Flow blockage Water System (B.2.3.11 )

Valve body Pressure Copper alloy >

Air-indoor Cracking External Surfaces boundary 8%AI uncontrolled Monitoring of (ext)

Mechanical Components (B.2.3.23)

Valve body {ECC}

Pressure Copper alloy >

Raw water ( ext)

Cracking Open-Cycle Cooling boundary 8%AI Water System (B.2.3.11 )

Valve body {ECC}

Pressure Copper alloy >

Raw water ( ext)

Loss of material Open-Cycle Cooling boundary 8%AI Water System (B.2.3.11 )

Valve body {ECC}

Pressure Copper alloy >

Raw water ( ext)

Loss of material Selective Leaching boundary 8%AI (B.2.3.21 )

NUREG-2191 Item VII.C1.A-416 VII.C1.A-414 VII.J.AP-144 VII.J.AP-144 VII.C1.AP-196 VIII.H.S-454 VII.C1.A-473b VII.C1.AP-196 VII.C1.A-47 L-2025-184 Page 42 of66 Table 1 Notes Item 3.3-1, 138 A 3.3-1, 139 A 3.3-1, A

114 3.3-1, A

034 3.4-1, A

106 3.3-1, A

160 3.3-1, A

034 3.3-1, A

072

St. Lucie Nuclear Plant Units 1 and 2 Dockets 50-335 and 50-389 SLRA Table 3.3.2-8, page 3.3-199 (cont'd) is revised as follows:

Table 3.3.2-8: Intake Cooling Water/ Emergency Cooling Canal - Summary of Aging Management Evaluation Component Type Intended Material Environment Aging Effect Aging Management Function Requiring Program Management Valve body Pressure Copper alloy >

Raw water (int)

Cracking Open-Cycle Cooling

{Includes ECC}

boundary 8%AI Water System (B.2.3.11 )

NUREG-2191 Item VII.C1.A-473b L-2025-184 Page 43 of66 Table 1 Notes Item 3.3-1,

A 160

St. Lucie Nuclear Plant Units 1 and 2 Dockets 50-335 and 50-389 SLRA Table 3.3.2-8, page 3.3-201 is revised as follows:

Table 3.3.2-8: Intake Cooling Water/ Emergency Cooling Canal - Summary of Aging Management Evaluation Component Type Intended Material Environment Aging Effect Aging Management Function Requiring Program Management Valve body Pressure Stainless steel Raw water (int)

Loss of material Inspection of Internal boundary Flow blockage Surfaces in Miscellaneous Piping and Ducting Components (B.2.3.24)

Valve body Pressure Stainless steel Raw water (int)

Loss of material Open-Cycle Cooling boundary Flow blockage Water System (B.2.3.11 )

Valve body Pressure Stainless steel Raw water (int)

Wall thinning-Inspection of Internal boundary erosion Surfaces in Miscellaneous Piping and Ducting Components (B.2.3.24)

Valve body Pressure Stainless steel Raw water (int)

Wall thinning -

Open-Cycle Cooling boundary erosion Water System (B.2.3.11 )

Valve body (Unit 1 Pressure Gray cast iron Air-outdoor Loss of material External Surfaces only) boundary (ext)

Monitoring of Mechanical Components (B.2.3.23)

Valve 13eEly (l::JAit 1 PFeSS!:lFe GFay east iFeA RaiA< 1,,,ateF (iAt) beA§ teFm less ef GAe +ime IAs13eetieA 0ffilf1

,__ --.J--

mateFial

/ 0 Valve 13eEly (l::JAit 1 PFeSS!:lFe Gray east ireA Raw wateF (iAt) bess ef material Seleetive beaehiA§ 0ffilf1

-.J--

I I"> "I '> "I~ \

Valve body (Unit 1 Pressure Gray cast iron Raw water (int) bess ef rnateFial Open-Cycle Cooling only) boundary with internal Flow blockage Water System coatings/linings (B.2.3.11 )

Valve seEly (l::JAit 1 Press1:1Fe Gray east ireA Raw 1NateF (iAt)

VVall thiAAiA§ G13eA Gyele GeeliA§ 0ffiY1 13e1:1AElary eresieA

\AJater Systern IC') ':i ~~ \

I NUREG-2191 Item VII.C1.A-727 VII.C1.A-54 VI I. C 1.A-409 VI I. C 1.A-409 VII.I.A-77 VII.G1.,A, §d2 VII.G1.A §1 VII.C1.AP-194 VII.G1.A 409 L-2025-184 Page 44 of66 Table 1 Notes Item 3.3-1, A

134 3.3-1, A

040 3.3-1, E, 2 126 3.3-1,

E, 1 126 3.3-1, A

078

~ A 4W

~ A G+2 3.3-1,

AJ_d 037

~ e,--4 42G

St. Lucie Nuclear Plant Units 1 and 2 Dockets 50-335 and 50-389 SLRA Table 3.3.2-8, page 3.3-201 (cont'd) is revised as follows:

Table 3.3.2-8: Intake Cooling Water/ Emergency Cooling Canal - Summary of Aging Management Evaluation Component Intended Material Environment Aging Effect Aging Management Type Function Requiring Program ManaQement Valve body Pressure Gray cast iron Raw water Loss of coating Internal Coatings (Unit 1 only}

boundarv with internal

{int}

or lining integrity /Linings for In-coatings/linings SCOQe PiQing, PiQing ComQonents, Heat Exchangers, and Tanks (B.2.3.28}

Valve body Pressure Gray cast iron Raw water Loss of material Internal Coatings (Unit 1 only) boundary with internal

{int)

/Linings for In-SCOQe PiQing, coatings/linings PiQing ComQonents, Heat Exchangers, and Tanks (B.2.3.28}

Valve body Pressure Gray cast iron Raw water Loss of material Internal Coatings (Unit 1 only}

boundary with internal (int)

(selective

/Linings for In-SCOQe PiQing, coatings/linings leaching)

PiQing ComQonents, Heat Exchangers, and Tanks (B.2.3.28}

NUREG-2191 Table 1 Item Item VII.C1.A-416 3.3-1, 138 VII.C1.A-414 3.3-1, 139 VII.C1.A-415 3.3-1, 140 L-2025-184 Page 45 of66 Notes A

A A

St. Lucie Nuclear Plant Units 1 and 2 Dockets 50-335 and 50-389 SLRA Table 3.3.2-8 notes, page 3.3-202 is revised as follows:

General Notes L-2025-184 Page 46 of66 A. Consistent with component, material, environment, aging effect, and AMP listed for NUREG-2191 line item. AMP is consistent with NUREG-2191 AMP description.

B. Consistent with component, material, environment, aging effect, and aging management program listed for NUREG-2191 line item. AMP has exceptions to NUREG-2191 AMP description.

E. Consistent with NUREG-2191 material, environment, and aging effect but a different AMP is credited or NUREG-2191 identifies a plant-specific AMP.

H.

Aging effect not in NUREG-2191 for this component, material, and environment combination.

J.

The material for this component is not explicitly listed in NUREG-2191 for this environment and aging effect; but a differentAMP is credited or NUREG~2191 identifies a plant-specific AMP.

Plant Specific Notes

1.

The Open-Cycle Cooling Water AMP is used to manage wall thinning due to erosion for the interior surfaces of components within the service water system exposed to raw water within the scope of the GL 89-13 program.

2. The Inspection of Internal Surfaces in Miscellaneous Piping and Ducting Components AMP is used to manage wall thinning due to erosion for the interior surfaces of components within the intake cooling water system exposed to raw water not within the scope of the GL 89-13 program.

3.

Based on plant-specific operating experience discussed in SLRA Section B.2.3.21, a one-time inspection of a representative sample of components using the elements of the Selective Leaching AMP will be performed to determine if this aging effect is present in the air-outdoor (ext) environment.

4. The Open-Cycle Cooling Water System AMP is used to manage flow blockage due to fouling.

St. Lucie Nuclear Plant Units I and 2 Dockets 50-335 and 50-389 SLRA Table 3.3.2-9, page 3.3-209 is revised as follows:

Table 3.3.2-9: Primary Makeup Water - Summary of Aging Management Evaluation Component Type Intended Material Environment Aging Effect Function Requiring Manaciement Strainer Filter Stainless steel Treated water Loss of material (int)

Strainer Pressure Stainless steel Air-indoor Cracking boundary uncontrolled (ext)

Strainer Pressure Stainless steel Air-indoor Loss of material boundary uncontrolled (ext)

Strainer Pressure Stainless steel Treated water Loss of material boundary (int)

Tank (primary water Pressure Carbon steel Air-outdoor Loss of material storage) (Unit 2 boundary (ext) only)

+aRk (13FiFflaf3/ wateF PFeSSl:lFe CaFbOR steel I\.

nlF 01:ltdooF (iRt)

Loss of Ff!ateFial stomge) (UR it 2 bOl:lRdaFy oolyJ Tank (primary water Pressure Carbon steel Concrete ( ext)

Loss of material storage) (Unit 2 boundary only)

+aRk (13FiFflaf3/ wateF PreSSl:lFe CaFbOR steel

+mated wateF Loss of FflateFial stomge) (UR it 2 bOl:lRdaFy fiRt}

oolyJ Aging Management Program Water Chemistry (B.2.3.2)

One-Time Inspection (B.2.3.20)

External Surfaces Monitoring of Mechanical Components (B.2.3.23)

Water Chemistry (B.2.3.2)

One-Time Inspection (B.2.3.20)

Outdoor and Large Atmospheric Metallic Storage Tanks (B.2.3.17)

Gl:ltdOOF aRd LaFge

,A,tFflOSJ3ReFiG MetalliG StOFage +aRks (B.2.3.17)

Outdoor and Large Atmospheric Metallic Storage Tanks (B.2.3.17)

Gl:ltdooF aRd LaFge

/\tFf!OSJ3ReFiG MetalliG StoFage +aRkS I "l '2 ~7 \

-LJ. -

I NUREG-2191 Item Vlll.81.SP-87 VII.E1.AP-209b VII.E1.AP-221b Vlll.81.SP-87 VII.C3.A-401 VII.C3.A 401 VII.C3.A-401 VII.C3.A 413 L-2025-184 Page 47 of66 Table 1 Notes Item 3.4-1, 085 A

3.3-1, 004 A

3.3-1, 006 A

3.4-1, 085 A

3.3-1, 128 B

3.3 1, 128 g

3.3-1, 128 B

3.3 1, 137 g

St. Lucie Nuclear Plant Units 1 and 2 Dockets 50-335 and 50-389 SLRA Table 3.3.2-9, page 3.3-210 is revised as follows:

Table 3.3.2-9: Primary Makeup Water - Summary of Aging Management Evaluation Component Type Intended Material Environment Aging Effect Function Requiring Management Tank (primary water Pressure Coating Air - outdoor (int)

Loss of coating or storage) (Unit 2 boundary Carbon steel lining integrity only) with internal coating/lining Tank {Qrima!Jl Pressure Carbon steel Air - outdoor Loss of material water storage}

bounda!Jl with internal

{int}

{Unit 2 onllf'.}

coating/lining Tank (primary water Pressure Coating Treated water Loss of coating or storage) (Unit 2 boundary Carbon steel (int) lining integrity only) with internal coating/lining Tank {Qrima!Jl water Pressure Carbon steel Treated water Loss of material storage} {Unit 2 bounda!Jl with internal

{int}

.Q!l!y1 coating/lining Tank (treated water Pressure Carbon steel Air-outdoor Loss of material storage) boundary (ext)

Tank (treated water Presstlre Carbon steel Air Otltdoor (int)

Loss of material storage) botlndary Aging Management Program Internal Coatings/Linings for In-Scope Piping, Piping Components, Heat Exchangers, and Tanks (B.2.3.28)

Internal Coatings/Linings for ln-SCOQe PiQing1 PiQing ComQonents1 Heat Exchangers1 and Tanks {B.2.3.28}

Internal Coatings/Linings for In-Scope Piping, Piping Components, Heat Exchangers, and Tanks (B.2.3.28)

Internal Coatings/Linings for ln-ScoQe PiQing1 PiQing ComQonents1 Heat Exchangers1 and Tanks {B.2.3.28}

Outdoor and Large Atmospheric Metallic Storage Tanks (B.2.3.17)

Gtltdoor and Large Atmos13l=leriG MetalliG Storage Tanks (B.2.3.17)

NUREG-2191 Item VII.D.A-416 VII.D.A-414 VII.F1.A-416 VII.F1.A-414 VII.C3.A-401 VII.C3./\ 401 L-2025-184 Page 48 of 66 Table 1 Notes Item 3.3-1, 138 A

3.3-1 1 139 A 3.3-1, 138 A

3.3-11 139 A 3.3-1, 128 B

3.3 1, 128 g

St. Lucie Nuclear Plant Units 1 and 2 Dockets 50-335 and 50-389 SLRA Table 3.3.2-9, page 3.3-210 (cont'd) is revised as follows:

Table 3.3.2-9: Primary Makeup Water - Summary of Aging Management Evaluation Tank (treated water Pressure Carbon steel Concrete ( ext)

Loss of material storage) boundary Tank (treated water Press1:1re Carbon steel Treated 111ater Loss of material stora§e) bo1:1ndary tiRit Tank (treated water Pressure Coatin§ Air - outdoor (int)

Loss of coating or storage) boundary Carbon steel lining integrity with internal coating/lining Tank {treated water Pressure Carbon steel Air - outdoor Loss of material storage) boundaQ'.

with internal

{int) coating/lining Outdoor and Large Atmospheric Metallic Storage Tanks (B.2.3.17)

G1:1tdoor and Lar§e Atmos131=!eris Metallis Stora§e Tanks (B.~.3.17)

Internal

Coatings/Linings for In-Scope Piping, Piping Components, Heat Exchangers, and Tanks (B.2.3.28)

Internal Coatings/Linings for ln-Sco12e Pi12ingI PiQing Com12onentsI Heat ExchangersI and Tanks lB.2.3.28)

VII.C3.A-401 VII.C3.A 413 VII.D.A-416 VII.D.A-414 L-2025-184 Page 49 of66 3.3-1, 128 B

3.3 1, 137 g

3.3-1, 138 A

3.3-11 138 A

St. Lucie Nuclear Plant Units 1 and 2 Dockets 50-335 and 50-389 SLRA Table 3.3.2-9, page 3.3-211 is revised as follows:

Table 3.3.2-9: Primary Makeup Water - Summary of Aging Management Evaluation Component Type Intended Material Environment Aging Effect Function Requiring Management Tank (treated water Pressure Coating Treated water Loss of coating or storage) boundary Carbon steel (int) lining integrity with internal coating/lining Tank {treated water Pressure Carbon steel Treated water Loss of material storage) bounda!l'.

with internal

{int) coating/lining Valve body Pressure Copper alloy Air-indoor None boundary uncontrolled (ext)

Valve body Pressure Copper alloy Treated water Loss of material boundary (int)

Valve body Pressure Stainless steel Air-indoor Cracking boundary uncontrolled (ext)

Valve body Pressure Stainless steel Air-indoor Loss of material boundary uncontrolled ( ext)

Valve body Pressure Stainless steel Air-outdoor Cracking boundary (ext)

Aging Management Program Internal Coatings/Linings for In-Scope Piping, Piping Components, Heat Exchangers, and Tanks (B.2.3.28)

Internal Coatings/Linings for ln-ScoRe PiRingI PiRing ComRonentsI Heat ExchangersI and Tanks {B.2.3.28)

None Water Chemistry (B.2.3.2)

One-Time Inspection (B.2.3.20)

External Surfaces Monitoring of Mechanical Components (B.2.3.23)

NUREG-2191 Item VII.F1.A-416 VII.F1.A-414 VII.J.AP-144 VIII.F.SP-101 VII.E1.AP-209b VII.E1.AP-221b VI I. E 1.AP-209b L-2025-184 Page 50 of 66 Table 1 Notes Item 3.3-1, 138 A

3.3-11 139 8.

3.3-1, 114 A

3.4-1, 016 A

3.3-1, 004 A

3.3-1, 006 A

3.3-1, 004 A

St. Lucie Nuclear Plant Units 1 and 2 Dockets 50-335 and 50-389 SLRA Table 3.3.2-11, page 3.3-220 is revised as follows:

Table 3.3.2-11: Turbine Cooling Water - Summary of Aging Management Evaluation Component Type Intended Material Environment Aging Effect Function Requiring Management

+aAk (iAStFl:HfleAt aiF PFeSSl::IFe CaFbOA steel

/1.

,,IF iASOOF Loss of mateFial oompFessoF oooliA§ bOl::IAElary l::IAGOAtFOlleEl (iAt) wateF heaEl)

+aAk (iAStF1::1meAt aiF PFeSSl::IFe CaFbOA steel

+FeateEl 111ateF Loss of mateFial oompFessoF oooliA§ bo1::1AElary Bmt wateF heaEl)

Tank (instrument air Pressure CoatiA§ Air-indoor Loss of coating or compressor cooling boundary Carbon steel uncontrolled (int) lining integrity water head) with internal coating/lining Tank {instrument Pressure Carbon steel Air-indoor Loss of material air com~ressor boundarv with internal uncontrolled cooling water coating/lining

{int) head)

Tank (instrument air Pressure CoatiA§ Treated water Loss of coating or compressor cooling boundary Carbon steel (int) lining integrity water head) with internal coating/lining Aging Management Program IAspeotioA of IAtemal S1::1Ffaoes iA MisoellaAeo1::1s PipiA§ aAEl (;)1::1otiA§ Compo Re Ats (B.2.3.24)

Closes +FeateEl VVateF Systems (B.2.3.12)

Internal Coatings/Linings for In-Scope Piping, Piping Components, Heat Exchangers, and Tanks (B.2.3.28)

Internal Coatings/Linings for ln-Sco~e Pi~ing1 Pi~ing Com~onents1 Heat ExchangersI and Tanks {B.2.3.28)

Internal Coatings/Linings for In-Scope Piping, Piping Components, Heat Exchangers, and Tanks (B.2.3.28)

NUREG-2191 Item V.A.E 29 VII.C2.AP 202 VII.D.A-416 VII.D.A-414 VII.C2.A-416 L-2025-184 Page 51 of66 Table 1 Notes Item 3.2 1,044 A

3.3 1, 045 A

3.3-1, 138 A

3.3-11 139

~

3.3-1, 138 A

St. Lucie Nuclear Plant Units 1 and 2 Dockets 50-335 and 50-389 L-2025-184 Page 52 of66 SLRA Table 3.3.2-11, page 3.3-221 is revised as follows:

Table 3.3.2-11: Turbine Cooling Water-Summary of Aging Management Evaluation Component Type Intended Material Environment Aging Effect Aging Management NUREG-2191 Table 1 Function Requiring Program Item Item Management Tank {instrument Pressure Carbon steel Treated water Loss of material Internal VII.C2.A-414 3.3-1, 139 air comQressor bounda!Y with internal

{int)

Coatings/Linings for cooling water coating/lining ln-ScoQe PiQing, head)

PiQing ComQonents, Heat Exchangers, and Tanks {B.2.3.28)

Thermowell Pressure Stainless steel Air-indoor Cracking External Surfaces VII.C2.AP-209b 3.3-1, 004 boundary uncontrolled (ext)

Monitoring of Mechanical Components (B.2.3.23)

Thermowell Pressure Stainless steel Air-indoor Loss of material External Surfaces VII.C2.AP-221b 3.3-1, 006 boundary uncontrolled (ext)

Monitoring of Mechanical Components (B.2.3.23)

Thermowell Pressure Stainless steel Treated water Loss of material Closed Treated VII.C2.A-52 3.3-1, 049 boundary (int)

Water Systems (B.2.3.12)

Valve body Pressure Carbon steel Air-indoor Loss of material External Surfaces VII.I.A-77 3.3-1, 078 boundary uncontrolled ( ext)

Monitoring of Mechanical Components (B.2.3.23)

Valve body Pressure Carbon steel Treated water Loss of material Closed Treated VII.C2.AP-202 3.3-1 I 045 boundary (int)

Water Systems (B.2.3.12)

General Notes A. Consistent with component, material, environment, aging effect, and AMP listed for NUREG-2191 line item. AMP is consistent with NUREG-2191 AMP description.

C. Component is different, but consistent with material, environment, aging effect, and AMP listed for NUREG-2191 line item. AMP is consistent with NUREG-2191 AMP description.

Notes A

A A

A

St. Lucie Nuclear Plant Units I and 2 Dockets 50-335 and 50-389 SLRA Section 3.4.2.1.1, page 3.4-2 is revised as follows:

Gas Steam Treated water >140°F Treated water Aging Effects Requiring Management L-2025-184 Page 53 of68 The following aging effects associated with the main steam, auxiliary steam, and turbine systems require management:

Cracking Cumulative fatigue damage Loss of material Loss of preload Wall thinning - erosion Wall thinning - FAC Aging Management Programs The following AMPs manage the aging effects for the main steam, auxiliary steam, and turbine system components:

Bolting Integrity (B.2.3.9)

Boric Acid Corrosion (B.2.3.4)

Compressed Air Monitoring (B.2.3.14)

External Surfaces Monitoring of Mechanical Components (B.2.3.23)

Flow-Accelerated Corrosion (B.2.3.8)

One-Time Inspection (B.2.3.20)

Water Chemistry (B.2.3.2)

Selective Leaching (B.2.3.21) 3.4.2.1.2 Main Feedwater and Steam Generator Slowdown Materials The materials of construction for the feedwater and blowdown system components are:

Aluminum Carbon steel Gray cast iron Low-alloy steel Stainless steel Steel

St. Lucie Nuclear Plant Units I and 2 Dockets 50-335 and 50-389 SLRA Section 3.4.2.1.3, page 3.4-3 is revised as follows:

Environments L-2025-184 Page 54 of66 The feedwater and blowdown system components are exposed to the following environments:

Air-dry Air - indoor uncontrolled Air - outdoor Air with borated water leakage Gas Treated water >140°F Treated water Aging Effects Requiring Management The following aging effects associated with the feedwater and blowdown systems require management:

Cracking Cumulative fatigue damage Loss of material Loss of preload Wall thinning - erosion Wall thinning - FAC Aging Management Programs The following AMPs manage the aging effects for the feedwater and blowdown system components:

Bolting Integrity (8.2.3.9)

Boric Acid Corrosion (8.2.3.4)

Compressed Air Monitoring (B.2.3.14)

External Surfaces Monitoring of Mechanical Components (B.2.3.23)

Flow-Accelerated Corrosion (B.2.3.8)

One-Time Inspection (B.2.3.20)

Selective Leaching (B.2.3.21 )

Water Chemistry (8.2.3.2) 3.4.2.1.3 Auxiliary Feedwater and Condensate Materials The materials of construction for the auxiliary feedwater and condensate system components are:

Carbon steel CoatingCarbon steel with internal coating/lining Glass Stainless steel

St. Lucie Nuclear Plant Units I and 2 Dockets 50-335 and 50-389 SLRA Section 3.4.2.1.3, page 3.4-4 is revised as follows:

Environments The auxiliary feedwater and condensate system components are exposed to the following environments:

Air - indoor uncontrolled Air - outdoor Concrete Gas Lubricating oil Soil Steam Treated water >140°F Treated water Underground Aging Effects Requiring Management L-2025-184 Page 55 of 68 The following aging effects associated with the auxiliary feedwater and condensate systems require management:

Cracking Cumulative fatigue damage Loss of coating or lining integrity Loss of material Loss of preload Reduction of heat transfer Wall thinning - erosion Wall thinning - FAC Aging Management Programs The following AMPs manage the aging effects for the auxiliary feedwater and condensate system components:

Bolting Integrity (B.2.3.9)

Buried and Underground Piping and Tanks (B.2.3.27)

External Surfaces Monitoring of Mechanical Components (B.2.3.23)

Flow-Accelerated Corrosion (B.2.3.8)

Inspection of Internal Surfaces of Miscellaneous Piping and Ducting Components (B.2.3.24)

Internal Coatings/Linings for In-Scope Piping, Piping components, Heat Exchangers, and Tanks (B.2.3.28)

Lubricating Oil Analysis (B.2.3.25)

One-Time Inspection (B.2.3.20)

Outdoor and Large Atmospheric Metallic Storage Tanks (B.2.3.17)

Water Chemistry (B.2.3.2)

St. Lucie Nuclear Plant Units 1 and 2 Dockets 50-335 and 50-389 SLRA Table 3.4-1, page 3.4-26 is revised as follows:

Table 3.4-1: Summary of the Aging Management Evaluations for the Steam and Power Conversion Systems Item Component Aging Effect/

Aging Management Further Number Mechanism Programs Evaluation Recommended 3.4-1, Steel, stainless steel or Loss of material due to AMP XI.M29, No 062 aluminum tanks (within general (steel only),

"Outdoor and Large the scope of AMP pitting, crevice Atmospheric Metallic XI.M29, "Outdoor and corrosion, MIC (steel, Storage Tanks" Large Atmospheric stainless steel only)

Metallic Storage Tanks") exposed to treated water 3.4-1, Insulated steel, copper Loss of material due to AMP XI.M36, No 063 alloy (>15% Zn or >8%

general, pitting, crevice "External Surfaces Al), piping, piping corrosion (steel only);

Monitoring of components, tanks, cracking due to sec Mechanical tanks (within the scope (copper alloy (>15% Zn Components" or of or >8% Al) only)

AMP XI.M29, AMP XI.M29, "Outdoor and Large "Outdoor and Large Atmospheric Metallic Atmospheric Metallic Storage Tanks" Storage Tanks")

exposed to air,

condensation 3.4-1, Non-metallic thermal Reduced thermal AMP XI.M36, No 064 insulation exposed to insulation resistance "External Surfaces air, condensation due to moisture Monitoring of intrusion Mechanical Components" Discussion L-2025-184 Page 56 of68 Not am;~licable. GeRsisteRt witA NldR~G 2~ 9~

1NitA e:x:eef:)tieR. +Ae Gl::ltEleeF aREl baF§e Atffi0Sl=)AeFiG MetalliG ~teFa§e +aRks AMP is l::lseEl te ffiaRa§e less ef R'lateFial feF tt:ie steel G0RdeRsate St0Fa§e taRkS. The steel condensate storage tanks are internalll£ coated and addressed bl£ line 3.4-1 1 067.

Consistent with NUREG-2191.

The External Surfaces Monitoring of Mechanical Components AMP is used to manage loss of material of insulated steel, low-alloy steel piping and piping components exposed to air.

Consistent with NUREG-2191.

Aging effect not applicable. Insulation for main steam and feedwater penetrations are fully encased in the multiple flued head and guard pipes and there are no plausible moisture, contaminants, or exposures that could degrade the (calcium silicate) insulation.

Aging effects for non type-1 hot penetrations is addressed by line item 3.2-1, 087.

St. Lucie Nuclear Plant Units 1 and 2 Dockets 50-335 and 50-389 SLRA Table 3.4-1, page 3.4-27 is revised as follows:

Table 3.4-1: Summary of the Aging Management Evaluations for the Steam and Power Conversion Systems Item Component Aging Effect/

Aging Management Further Number Mechanism Programs Evaluation Recommended 3.4-1, Any material piping, Loss of material due to AMP XI.M42, "Internal No 067 piping components, general, pitting, crevice Coatings/Linings for heat exchangers, tanks corrosion, MIC In-Scope Piping, Piping with internal Components, Heat coatings/linings Exchangers, and Tanks" exposed to closed-cycle cooling water, raw water, treated water, lubricating oil Discussion L-2025-184 Page 57 of66 Net af:)f:)lisaele.Consistent with NUREG-2191.

The Internal Coatings/Linings for In-Scope Piping, Piping Components, Heat Exchangers, and Tanks AMP is flet-used to manage loss of material for the internally coated condensate storage tanks

St. Lucie Nuclear Plant Units 1 and 2 Dockets 50-335 and 50-389 SLRA Table 3.4.2-3, page 3.4-75 is revised as follows:

Table 3.4.2-3: Auxiliary Feedwater and Condensate - Summary of Aging Management Evaluation Component Type Intended Material Environment Aging Effect Aging Management Function Requiring Program Management Tank (condensate Pressure Carbon Gas (int)

None None storage tank) boundary steel with internal coating/lining Tank Pressure Carbon steel Treated water Loss of coating or Internal Coatings/Linings

{condensate bounda!Jl with internal

{int) lining integritv for ln-Sco12e PiQing, PiQing storage tank}

coating/lining Com12onents, Heat Exchangers, and Tanks

{B.2.3.28}

NUREG-2191 Item Vlll.l.~P 4 N/A VIII.E.S-401 L-2025-184 Page 58 of66 Table 1 Notes Item M-4,-

A G,5 Ga9 N/A 3.4-1,

~

066

St. Lucie Nuclear Plant Units 1 and 2 Dockets 50-335 and 50-389 SLRA Table 3.4.2-3, page 3.4-76 is revised as follows:

Table 3.4.2-3: Auxiliary Feedwater and Condensate - Summary of Aging Management Evaluation Component Type Intended Material Environment Aging Effect Aging Management Program Function Requiring ManaQement Tank (condensate Pressure Carbon Treated water Loss of material Gl:ltEleeF aREl baF§le AtFR9S1:)R8FiG storage tank) boundary steel with (int)

MetalliG St9Fa§l8 TaRkS (B.2.3.17) internal Internal Coatings/Linings for coating/

ln-Sco!;!e Pi!;!ing 1 Pi!;!ing lining Com!;!onents 1 Heat Exchangers 1 and Tanks

{B.2.3.28}

TaRk (GeREleRsate PFeSSl:lF8 CeatiR§l TmateEl wateF bess ef GeatiR§l eF IRteFRal CeatiR§lSlbiRiR§lS feF IA steFa§le taRk) bel:lRElary fiRB liRiR§l iRt8§lFity SG91=)8 Pil=)iR§l, Pil=)iR§l C9FRJ:)9R8Rts, Fleat E*GA3R§l8FS, aREl TaRks (B.2.3.2g)

Tank (condensate Pressure Carbon Air - outdoor Loss of material Outdoor and Large Atmospheric storage tank) (Unit 1 boundary steel (ext)

Metallic Storage Tanks only)

(B.2.3.17)

Tank (condensate Pressure Carbon Concrete ( ext)

Loss of material Outdoor and Large Atmospheric storage tank) (Unit 1 boundary steel Metallic Storage Tanks only)

(B.2.3.17)

Tank (condensate Pressure Carbon Air-indoor Loss of material Outdoor and Large Atmospheric storage tank) (Unit 2 boundary steel uncontrolled Metallic Storage Tanks only)

(ext)

(B.2.3.17)

Tank (condensate Pressure Carbon Concrete ( ext)

None None storage tank) (Unit 2 boundary steel only)

Tank (lube oil Pressure Carbon Air - outdoor Loss of material External Surfaces Monitoring of reservoir) (Unit 2 boundary steel (ext)

Mechanical Components only)

(B.2.3.23)

Tank (lube oil Pressure Carbon Lubricating oil Loss of material Lubricating Oil Analysis reservoir) (Unit 2 boundary steel (int)

(B.2.3.25) only)

One-Time Inspection (B.2.3.20)

Turbine casing Pressure Carbon Air - outdoor Loss of material External Surfaces Monitoring of boundary steel (ext)

Mechanical Components (B.2.3.23)

NUREG-2191 Item VIII.E.S-4G-a414 VIII.E.S 401 VIII.E.SP-115 VIII.E.SP-115 VIII.E.SP-115 VIII.I.SP-154 VIII.H.S-29 VIII.G.SP-91 VIII.H.S-29 L-2025-184 Page 59 of66 Table Notes 1 Item 3.4-1,

BA 002 067 M--1, g

Gee 3.4-1, B, 3 030 3.4-1,

B, 3 030 3.4-1,

A 051 3.4-1,

A, 1 034 3.4-1,

A, 1 040 3.4-1,

A, 2 034

St. Lucie Nuclear Plant Units 1 and 2 Dockets 50-335 and 50-389 SLRA Table 3.4.2-3, page 3.4-79 is revised as follows:

G. Environment not in NUREG-2191 for this component and material.

Plant Specific Notes L-2025-184 Page 60 of66

1.

Unit 1 does not have an external lube oil cooler. Cooling water is provided to the bearings by water from the condensate system. Heat is dissipated through externally mounted fins.

2. During standby, steam to the Unit 1 auxiliary feedwater turbine is isolated, and the turbine is open to the atmosphere with an internal environment of air. During standby, the Unit 2 auxiliary feedwater turbine receives steam continuously to maintain turbine warm-up conditions.

3.

The Unit 1 condensate storage tank is partially enclosed in a concrete missile barrier. The Unit 2 condensate storage tank is completely enclosed in a concrete missile barrier.

4. The filtering component is not long lived and the filtering function is therefore not included.

5. Carbon steel does not have any aging effects when exposed to a gas environment (nitrogen). Therefore, carbon steel with internal coating/lining exposed to a gas environment (nitrogen) does not have aging effects that are expected to degrade the ability of the component to perform its intended function.

St. Lucie Nuclear Plant Units I and 2 Dockets 50-335 and 50-389 SLRA Appendix A 1, Section 19.2.2.28, page A 1-32 is revised as follows:

L-2025-184 Page 61 of66 19.2.2.28 Internal Coatings/Linings for In-Scope Piping, Piping Components, Heat Exchangers, and Tanks The PSL Internal Coatings/Linings for In-Scope Piping, Piping Components, Heat Exchangers, and Tanks AMP is a new AMP that will manage degradation of internal coatings/linings exposed to closed-cycle cooling water, raw water, treated water, fuel oil, and air that can lead to loss of material of base materials or downstream effects such as reduction in flow, reduction in pressure or reduction of heat transfer when coatings/linings become debris. Portions of the program were previously part of the Intake Cooling Water System Inspection Program and the Periodic Surveillance and Preventive Maintenance (PSPM) Program. The PSL Internal Coatings/Linings for In Scope Piping, Piping Components, Heat Exchangers, and Tanks AMP will Ret-be used to manage loss of coating integrity for external coatings. The PSL Internal Coatings/Linings for In-Scope Piping, Piping Components, Heat Exchangers, and Tanks AMP will perform inspections of coatings/linings applied to components that will also be managed by the PSL Outdoor and Large Atmospheric Metallic Storage Tanks AMP, the PSL Open-Cycle Cooling Water AMP, PSL Closed Treated Water Systems AMP, PSL Inspection of Internal Surfaces in Miscellaneous Piping and Ducting Components AMP, PSL Fuel Oil Chemistry AMP, and the PSL Fire Water System AMP. For components where the aging effects of internally coated/lined surfaces are managed by PSL Internal Coatings/Linings for In-Scope Piping, Piping Components, Heat Exchangers, and Tanks AMP, loss of material, cracking, and loss of material due to selective leaching need not be managed for these components by another program.

The PSL Internal Coatings/Linings for In-Scope Piping, Piping Components, Heat Exchangers, and Tanks AMP will manage these aging effects for internal coatings by conducting opportunistic and periodic visual inspections of coatings/linings applied to the internal surfaces of in-scope components where loss of coating or lining integrity could impact the component's or downstream component's CLB intended function(s). Where visual inspection of the coated/lined internal surfaces determines the

St. Lucie Nuclear Plant Units I and 2 Dockets 50-335 and 50-389 SLRA Appendix A1, Table 19-3, Commitment No. 18(c) on page A1-76 is revised as follows:

Table 19-3 List of Unit 1 SLR Commitments and Implementation Schedule No.

Aging Management NUREG-2191 Commitment Program or Activity Section (Section) 18 Fire Protection (19.2.2.15)

XI.M26 Continue the existing PSL Fire Protection AMP, including enhancement to:

a)

Enhance plant procedures to specify that penetration seals will be inspected for indications of increased hardness and loss of strength such as cracking, seal separation from walls and components, separation of layers of material, rupture, and puncture of seals.

b)

Enhance plant procedures to specify that subliming, cementitious, and silicate materials used in fireproofing and fire barriers will be inspected for loss of material, separation, change in material properties, and cracking/delamination.

c)

Enhance plant procedures to specify that any loss of material (e.g., general, pitting, or crevice corrosion to the fire damper housings assembly is unacceptable.

d)

Enhance plant procedures to require projection of identified degradation to the next scheduled inspection for all monitored fire protection SSCs, where practical.

e)

Enhance plant procedures to require that projections are evaluated against acceptance criteria to confirm that the timing of subsequent inspections will maintain the components' intended functions throughout the subsequent period of extended operation based on the projected rate of degradation.

L-2025-184 Page 62 of66 Implementation Schedule No later than 6 months prior to the SPEO, or no later than the last refueling outage prior to the SPEO i.e.:

PSL 1: 09/01/2035

St. Lucie Nuclear Plant Units I and 2 Dockets 50-335 and 50-389 SLRA Appendix A2, Section 19.2.2.28, page A2-32 is revised as follows:

19.2.2.28 Internal Coatings/Linings for In-Scope Piping, Piping Components, Heat Exchangers, and Tanks L-2025-184 Page 63 of66 The PSL Internal Coatings/Linings for In-Scope Piping, Piping Components, Heat Exchangers, and Tanks AMP is a new AMP that will manage degradation of internal coatings/linings exposed to closed-cycle cooling water, raw water, treated water, fuel oil, and air that can lead to loss of material of base materials or downstream effects such as reduction in flow, reduction in pressure or reduction of heat transfer when coatings/linings become debris. Portions of the program were previously part of the Intake Cooling Water System Inspection Program and the Periodic Surveillance and Preventive Maintenance (PSPM) Program. The PSL Internal Coatings/Linings for In Scope Piping, Piping Components, Heat Exchangers, and Tanks AMP will oot-be used to manage loss of coating integrity for external coatings. The PSL Internal Coatings/Linings for In-Scope Piping, Piping Components, Heat Exchangers, and Tanks AMP will perform inspections of coatings/linings applied to components that will also be managed by the PSL Outdoor and Large Atmospheric Metallic Storage.Tanks AMP, the PSL Open-Cycle Cooling Water AMP, PSL Closed Treated Water Systems AMP, PSL Inspection of Internal Surfaces in Miscellaneous Piping and Ducting Components AMP, PSL Fuel Oil Chemistry AMP, and the PSL Fire Water System AMP. For components where the aging effects of internally coated/lined surfaces are managed by PSL Internal Coatings/Linings for In-Scope Piping, Piping Components, Heat Exchangers, and Tanks AMP, loss of material, cracking, and loss of material due to selective leaching need not be managed for these components by another program. The PSL Internal Coatings/Linings for In-Scope Piping, Piping Components, Heat Exchangers, and Tanks AMP will manage these aging effects for internal coatings by conducting opportunistic and periodic visual inspections of coatings/linings applied to the internal surfaces of in-scope components where loss of coating or lining integrity could impact the component's or downstream component's CLB intended function(s). Where visual inspection of the coated/lined internal surfaces determines the coating/lining is deficient or degraded, physical tests will be performed, where physically possible, in conjunction with the visual inspection. For tanks and heat exchangers, all accessible surfaces will be inspected. Piping inspections will be sampling-based. The training and qualification of individuals involved in coating/lining inspections of non-cementitious coatings/linings will be conducted in accordance with ASTM International Standards endorsed in RG 1.54 including guidance from the staff associated with a particular standard. For cementitious coatings/linings inspectors should have a minimum of 5 years of experience inspecting or testing concrete structures or cementitious coatings/linings or a degree in the civil/structural discipline and a minimum of 1 year of experience. Peeling and delamination will not be acceptable. Blisters will be evaluated by a coatings specialist to confirm the surrounding material is sound and the blister size and frequency is not increasing. Minor cracks in cementitious coatings will be acceptable provided there is no evidence of debonding. All other degraded conditions will be evaluated by a coatings specialist. For coated/lined surfaces determined to not meet the acceptance criteria, physical testing will be performed where possible (i.e., sufficient room to conduct testing) in conjunction with repair or replacement of the coating/lining. Additional inspections will be conducted if one of the inspections does not meet acceptance criteria due to current or projected

St. Lucie Nuclear Plant Units I and 2 Dockets 50-335 and 50-389 SLRA Appendix B, Section B.2.3.11, page B-106 is revised as follows:

L-2025-184 Page 64 of66 recommended. As evaluated above, internal corrosion has occurred within multiple outages during the evaluated 10-year period in piping that includes coatings or linings, and several of these occurrences involved a wall reduction of greater than 50 percent. Therefore, the PSL Open-Cycle Cooling Water AMP will need to manage recurring internal corrosion for carbon steel components with internal coatings and linings. Due to a section of carbon steel piping in the intake cooling water system that is externally coated and exposed to raw water, the PSL Open-Cycle Cooling Water AMP will also manage recurring external corrosion for that section of piping. One proactive action to reduce the number of internal corrosion issues is to replace the above-ground main line and strainer bypass line portions of the SR ICW piping with AL6XN SS piping. For the piping that is not replaced, the PSL Open-Cycle Cooling Water System AMP meets the recurring internal corrosion management recommendations from NUREG-2192 as follows:

a) The existing examination methods are sufficient to detect recurring internal corrosion before affecting the ability of a component to perform its intended function. These methods primarily include an internal visual inspection of 100 percent of the large-bore ICW header piping length. The visual inspections are currently augmented with brushing, scraping, and hammer testing as applicable to provide assurance that all internal piping degradation is identified. An enhancement will be created to perform volumetric inspections as applicable for areas where visual inspection alone is not adequate or as needed to determine the extent of degradation b) The existing ICW header inspections are 100 percent visual and are performed at an interval of every 2 refueling outages. When degradation is identified, it is repaired during the same refueling outage. This provides reasonable assurance that all degradation is identified along the ICW header length and that pressure boundary integrity will be maintained until the next inspection.

c) The existing inspection specification provides instructions for documenting inspection results within an Inspector's Report attached to an AR. The specification also provides instructions for the system engineer to map and trend the locations of patches, epoxy, or cement, within the ICW piping. The trending of the inspection parameters/results (e.g.,

repair locations) provides reasonable assurance that recurring internal corrosion will remain adequately managed.

d) Inspections of components that are buried, underground, or submerged are conducted per the same inspection specification, procedure, and preventive maintenance activities and personnel have been able to perform internal inspections of these sections of ICW piping.

The implementation of the existing inspection activities provides reasonable assurance that recurring internal corrosion of the buried, underground, or submerged ICW system components will be adequately managed.

e) The PSL Open-Cycle Cooling Water System AMP uses system instrumentation and/or performance monitoring to identify leaks in involved buried, underground, or submerged ICW piping components. When leaks are identified, an AR is initiated to determine the cause, extent of degradation, and initiate corrective actions. Using instrumentation and/or performance monitoring to identify leaks and adjusting inspections to proactively identify leaks on other susceptible piping provides reasonable

St. Lucie Nuclear Plant Units I and 2 Dockets 50-335 and 50-389 SLRA Appendix 8, Section B.2.3.28, page 8-220 is revised as follows:

B.2.3.28 Internal Coatings/Linings for In-Scope Piping, Piping Components, Heat Exchangers, and Tanks Program Description The PSL Internal Coatings/Linings for In-Scope Piping, Piping Components, Heat L-2025-184 Page 65 of66 Exchangers, and Tanks AMP is a new AMP that will have the principal objective to manage the aging effect of loss of coating/lining integrity.

The PSL Internal Coatings/Linings for In-Scope Piping, Piping Components, Heat Exchangers, and Tanks AMP will be a condition monitoring AMP that will manage degradation of internal coatings/linings exposed to closed cycle cooling water, raw water, treated water, fuel oil, and air that can lead to loss of material of base materials or downstream effects such as reduction in flow, reduction in pressure or reduction of heat transfer when coatings/linings become debris. The PSL Internal Coatings/Linings for In-Scope Piping, Piping Components, Heat Exchangers, and Tanks AMP will Mt-be used to manage loss of coating integrity for external coatings. The PSL Internal Coatings/Linings for In-Scope Piping, Piping Components, Heat Exchangers, and Tanks AMP performs inspections of coatings/linings applied to components which will be managed by the PSL Outdoor and Large Atmospheric Metallic Storage Tanks AMP (Section 8.2.3.17), the PSL Inspection of Internal Surfaces in Miscellaneous Piping and Ducting Components AMP (Section B.2.3.24), the PSL Open-Cycle Cooling Water AMP (Section B.2.3.11 ), the PSL Closed Treated Water Systems AMP (Section 8.2.3.12), the PSL Fuel Oil Chemistry AMP (Section 8.2.3.18) and the PSL Fire Water System AMP (Section 8.2.3.16). For components where the aging effects of internally coated/lined surfaces are managed by PSL Internal Coatings/Linings for In-Scope Piping, Piping Components, Heat Exchangers, and Tanks AMP, loss of material, cracking, and loss of material due to selective leaching need not be managed for these components by another program.

The PSL Internal Coatings/Linings for In-Scope Piping, Piping Components, Heat Exchangers, and Tanks AMP will manage these aging effects for internal coatings by conducting opportunistic and periodic visual inspections of coatings/linings applied to the internal surfaces of in-scope components where loss of coating or lining integrity could impact the component's or a downstream component's current licensing basis intended function(s). Where visual inspection of the coated/lined internal surfaces determines the coating/lining is deficient or degraded, physical tests will be performed, where physically possible, in conjunction with the visual inspection. The PSL Internal Coatings/Linings for In-Scope Piping, Piping Components, Heat Exchangers, and Tanks AMP will use the following acceptance criteria:

There are no indications of peeling or delamination.

Blisters are evaluated by a coatings specialist qualified in accordance with an ASTM International standard endorsed in RG 1.54 (Reference 1.6.44) including staff limitations associated with use of a particular standard. Blisters should be limited to a few intact small blisters that are completely surrounded by sound coating/lining bonded to the substrate. Blister size or frequency should not be increasing between inspections (e.g., ASTM D714-02, "Standard Test Method for Evaluating Degree of Blistering of Paints").

St. Lucie Nuclear Plant Units I and 2 Dockets 50-335 and 50-389 SLRA Appendix 8, Section B.2.3.28, page 8-224 is revised as follows:

L-2025-184 Page 66 of66 The PSL Internal Coatings/Linings for In-Scope Piping, Piping Components, Heat Exchangers, and Tanks AMP is informed and enhanced when necessary through the systematic and ongoing review of both plant-specific and industry OE including research and development such that the effectiveness of the AMP is evaluated consistent with the discussion in Appendix B of the GALL-SLR Report.

Plant Specific Operating Experience The following summary of site-specific OE (which includes review of corrective actions and NRC inspections) provides examples of how PSL is managing aging effects associated with the PSL Internal Coatings/Linings for In-Scope Piping, Piping Components, Heat Exchangers, and Tanks AMP.

In August 2011, the U2 PWST interior was inspected. No degradation issues were identified within the normally wetted interior of U2 PWST, however, the inspection of the non-wetted area between the floating roof seal and the tank top identified several minor areas (approximately eight) of corrosion within previous Belzona repaired areas. These areas were approximately 1/2 inch in diameter and in all cases the carbon steel substrate was corroding. The minor corrosion identified did not affect the ability of the tank to perform its design function; therefore, no corrective action was required. A follow up tank inspection is scheduled for the refueling outage in Spring 2023.

In March 2018, during a Unit 1 Refueling VVater Tank internal floor lining remote inspection, three areas v.1ith 6 inch stress cracks vvere discovered on the fiberglass reinforced vinyl ester epoxy lining material (Dudick Protecto Line 800). An evaluation 1Nas performed as part of the AR and as a corrective measure, a follow up inspection was scheduled for the next outage. Repairs 1.vere performed under a *.vork order.

The City Water Storage Tank 1A tank internals were visually inspected and ultrasonic testing of the tank bottom was performed under the License Renewal FP Program in October 2020. In general, ultrasonic testing results showed tank floor thickness within nominal thickness -1 O percent. Internal coatings had failed in some locations in the tank floor resulting in several locations of localized pitting. Some of these locations were below the minimum wall thickness for the tank floor. There were also other tank components that were corroded due to localized coatings failures. Using engineering judgement, none of the corroded areas or floor pitting below minimum wall thickness impacted tank structural integrity or functionality. Internal City Water Storage Tank recoating is scheduled to be implemented in 2022 as part of the City Water Storage Tank Repair Capital Project.

The City Water Storage Tank 18 tank internals were visually inspected and ultrasonic testing of the tank bottom was performed under the License Renewal FP Program in October 2020. In general, ultrasonic testing results showed tank floor thickness within nominal thickness -10 percent. Internal coatings had failed in some locations in the tank floor, which resulted in a few locations of localized pitting. Some of these locations were below the minimum wall thickness for the tank floor. There were also other tank components that were corroded due to localized coatings failures. By engineering judgement, none of the corroded areas or floor pitting below

L-2025-184, Subsequent License Renewal Application - Fourth Annual Update

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ML25324A217
Site:	Saint Lucie (DPR-067, NPF-016)
Issue date:	11/20/2025
From:	Mack K Florida Power & Light Co
To:	Office of Nuclear Reactor Regulation, Document Control Desk
References
L-2025-184
Download: ML25324A217 (1)
v • d • e

L-2025-184, Subsequent License Renewal Application - Fourth Annual Update

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