IR 05000458/2025012

License Renewal Inspection Report 05000458/2025012

ML25190A405
Person / Time
Site:	River Bend
Issue date:	07/10/2025
From:	Greg Warnick NRC/RGN-IV/DORS/EB2
To:	Hansett P Entergy Operations
References
IR 2025012
Download: ML25190A405 (55)

Text

July 10, 2025

SUBJECT:

RIVER BEND STATION - LICENSE RENEWAL INSPECTION REPORT 05000458/2025012

Dear Phil Hansett:

On May 29, 2025, the U.S. Nuclear Regulatory Commission (NRC) completed an inspection at River Bend Station and discussed the results of this inspection with you and other members of your staff. The results of this inspection are documented in the enclosed report.

No findings or violations of more than minor significance were identified during this inspection.

This letter, its enclosure, and your response (if any) will be made available for public inspection and copying at http://www.nrc.gov/reading-rm/adams.html and at the NRC Public Document Room in accordance with Title 10 of the Code of Federal Regulations 2.390, Public Inspections, Exemptions, Requests for Withholding.

Sincerely, Gregory G. Warnick, Chief Engineering Branch 2 Division of Operating Reactor Safety Docket No. 05000458 License No. NPF-47

Enclosure:

As stated

Inspection Report

Docket Number:

05000458

License Number:

NPF-47

Report Number:

05000458/2025012

Enterprise Identifier:

I-2025-012-0000

Licensee:

Entergy Operations, Inc

Facility:

River Bend Station

Location:

St. Francisville, LA

Inspection Dates:

May 5, 2025 to May 29, 2025

Inspectors:

S. Campbell, Senior Reactor Systems Engineer

S. Graves, Senior Reactor Inspector

S. Makor, Senior Reactor Inspector

A. Saunders, Reactor Inspector

Approved By:

Gregory G. Warnick, Chief

Engineering Branch 2

Division of Operating Reactor Safety

SUMMARY

The U.S. Nuclear Regulatory Commission (NRC) continued monitoring the licensees performance by conducting a license renewal Phase 2 inspection at River Bend Station, in accordance with the Reactor Oversight Process. The Reactor Oversight Process is the NRCs program for overseeing the safe operation of commercial nuclear power reactors. Refer to https://www.nrc.gov/reactors/operating/oversight.html for more information.

List of Findings and Violations

No findings or violations of more than minor significance were identified.

Additional Tracking Items

None.

INSPECTION SCOPES

Inspections were conducted using the appropriate portions of the inspection procedures (IPs) in effect at the beginning of the inspection unless otherwise noted. Currently approved IPs with their attached revision histories are located on the public website at http://www.nrc.gov/reading-rm/doc-collections/insp-manual/inspection-procedure/index.html. Samples were declared complete when the IP requirements most appropriate to the inspection activity were met consistent with Inspection Manual Chapter (IMC) 2516, Policy and Guidance for the License Renewal Inspection Programs. The inspectors reviewed selected procedures and records, observed activities, and interviewed personnel to assess licensee performance and compliance with Commission rules and regulations, license conditions, site procedures, and standards.

OTHER ACTIVITIES

- TEMPORARY INSTRUCTIONS, INFREQUENT AND ABNORMAL

===71003 - Post-Approval Site Inspection for License Renewal Inspection Procedure 71003, Post-Approval Site Inspection for License Renewal, recommended that the inspection be conducted shortly before the period of extended operation.

The period of extended operation is the additional 20 years beyond the original 40-year licensed term. The period of extended operation for River Bend Station, will begin after midnight on August 29, 2025.

The inspectors evaluated whether the licensee:

(1) completed actions required to comply with the license renewal license condition and commitments;

(2) implemented the aging management programs that agreed with those approved in the safety evaluation report and described in the safety analysis report;

(3) followed the guidance in Nuclear Energy Institute (NEI) 99-04, Guidelines for Managing NRC Commitment Changes, for changing license renewal commitments and followed the guidance in 10 CFR 50.59 when making changes to the license renewal supplement;

(4) identified, evaluated, and incorporated newly identified structures, systems, and components into their aging management programs; and (5)implemented operating experience review and corrective action programs that account for aging effects.

The Safety Evaluation Report Related to the License Renewal of River Bend Station

[ML18212A151], lists 44 aging management programs. The NRC previously completed reviews for several aging management programs as documented in Inspection Report 5000485/2023011 [ML23102A294]. As detailed in this report, the inspectors reviewed 36 aging management programs and associated commitments during this inspection. The inspectors completed all aging management program reviews with the exception of the Aboveground Metallic Tank Program. This program will be reviewed in a future inspection.

For each aging management program reviewed, the inspectors reviewed program documents, license renewal documents, the safety analysis report, and the safety evaluation report.

Supporting documents reviewed included implementing procedures, work orders, inspection reports, engineering evaluations, calculations, database entries, and condition reports. The inspectors interviewed program owners and license renewal program personnel.

The inspectors walked down the following areas of the plant to inspect for signs of aging:

9. standby diesel generator fuel oil storage tanks

10. standby diesel generator fuel oil waste tanks 11. containment penetrations 12. control building 13. standby cooling tower 14. cat 1 building b - electrical tunnel 15. warehouse, storage location for reactor head closure replacement studs 16. spent fuel pool The inspectors determined that the licensee described their aging management programs and commitments in the Updated Safety Analysis Report (USAR), Appendix A. The inspectors paraphrased most of the commitments listed in the aging management program reviews. For the actual wording refer to the safety evaluation report and any license basis changes. The inspectors listed specific documents reviewed in the enclosure.

Post-Approval Site Inspection for License Renewal===

(1) A.1.1 Aboveground Metallic Tanks Program The Aboveground Metallic Tanks Program (AMTP) is a new program that will manage loss of material for the nonsafety-related aluminum condensate storage tank (CST),which is located outdoors on sand and concrete. Preventive measures to mitigate corrosion were applied during construction, such as using the appropriate materials and use of a protective multi-layer vapor barrier beneath the tank. The inner volume of the concrete ring foundation is filled with clean dry sand, which is sloped downward from the tank center to the tank exterior. The protective multi-layer vapor barrier beneath the tank serves as a seal at the concrete-to-tank interface. There are no indoor tanks included in this program. Inspection includes periodic visual inspection of the seal between the tank bottom and concrete foundation at least once per refueling cycle.

Commitment 1 specified:

Implement the Aboveground Metallic Tanks Program as described in License Renewal Application (LRA) Section A.1.1.

The inspectors reviewed the USAR supplement for aging management, including the aging management program (AMP) basis documents, implementing procedures, and records of completed inspection activities. The inspectors also examined corrective actions, reviewed work orders, and conducted walkdowns around the CST. In addition, the inspectors met with the AMTP owner to discuss inspection activities, program health, and any emerging trends.

The inspectors also reviewed License Basis Document Change Request (LBDCR) 01A.00-017, which proposes a revision to USAR Section A.1.1 to permit CST level monitoring in lieu of internal visual and volumetric inspections. The licensee performed a 10 CFR 50.59 screening in accordance with procedure EN-LI-100, Attachment 1, Process Applicability Determination,Section VI.A, 10 CFR 50.59 Screening, and concluded that a full 10 CFR 50.59 evaluation was not required for the proposed change.

Based on the review of procedures, records, and discussions with licensee personnel and NRC License Renewal technical staff, the inspectors did not identify any findings or violations of more than minor significance, but did identify an observation for this aging management program that will require additional review.

(2) A.1.3 Neutron Absorbing Material Monitoring The Neutron Absorbing Material Monitoring Program is a new program, consistent with Section XI.M40, "Monitoring of Neutron-Absorbing Materials Other Than BORAFLEX," of the Generic Aging Lessons Learned (GALL) report, credited with managing changes in material properties, loss of material, and reduction of neutron absorption capacity of the neutron absorbing inserts used in the spent fuel storage facility to ensure the Boron-10 areal density is consistent with the assumptions in the spent fuel pool criticality analysis, as required by plant Technical Specification 5.5.15, "Spent Fuel Storage Rack Neutron Absorber Monitoring Program."

The licensee submitted surveillance coupons to a laboratory facility for dimensional testing and the results of the testing were categorized in report NET-28096-010-01, "Inspection and Testing of Boralcan' Surveillance Coupons from River Bend Power Station." The report compared the pre-characterization data taken before the coupons were placed in the fuel pool and utility acceptance criteria. Boron-10 areal density neutron attenuation testing was conducted at the Pennsylvania State University Radiation Science and Engineering Center using the Breazeale TRIGA Reactor. The report concludes that all coupons satisfy all acceptance criteria. The results of the dimensional and material properties tests are indicative of satisfactory coupon performance.

Commitment 3 and 32 specified:

• Implement the Neutron Absorbing Material Monitoring Program as described in LRA Section A.1.3.

• Install aluminum boron-carbide neutron absorbing material before the period of extended operation so that the Boraflex material in the spent fuel pool will not be credited to perform a neutron absorption function.

• Entergy shall submit a letter to the NRC, within 60 days following installation of the new neutron absorbing material, confirming that the Boraflex material is no longer credited for neutron absorption.

• Installation of boron carbide aluminum metal matrix composite inserts into the spent fuel pool fuel storage racks was completed under engineering change EC-73497 and letter RBG-48003 was submitted to the NRC on February 24, 2020, confirming that the Boraflex material is no longer credited for neutron absorption.

The inspectors reviewed the aging management program basis document, inspection procedures, work orders, examination data, and corrective action program documents. The inspectors interviewed plant and implementing personnel.

Based on the review of the procedures, records and discussion with licensee personnel, the inspectors did not identify any findings or violation of more than minor significance associated with the commitments, and the associated aging management program.

(3) A.1.4 Buried and Underground Piping and Tanks Inspection This existing program manages the effects of aging on external surfaces of buried piping components and tanks subject to aging. The program will manage loss of material and cracking through preventive and mitigative features (e.g., coatings, backfill quality, and cathodic protection) and periodic inspection activities during opportunistic and directed excavations. The number of inspections is based on the availability and effectiveness of preventive and mitigative actions as specified in Appendix B of License Renewal-Interim Staff Guidance (LR-ISG) -2015-01.

The buried stainless steel piping inspection recommended by LR-ISG-2015-01, one additional inspection of buried stainless steel piping with silicon-based coating will be conducted during each 10-year period unless the soil is demonstrated non-corrosive and the backfill is in accordance closed with the recommendations of LR-ISG-2015-01. Preventive action category F of LR-ISG-2015-01 will be used in determining the number of inspections for portions of the in-scope buried steel piping where the cathodic protection system is not meeting performance goals (i.e.,

operational time period, effectiveness) or where the piping is not protected by a cathodic protection system unless all the requirements of moving to another preventive action category are met. A visual examination of buried carbon steel piping surfaces for evidence of cracking is performed whenever carbon steel piping surfaces are exposed. Annual cathodic protection surveys are conducted. For steel components, where the acceptance criteria for effectiveness of cathodic protection is other than -850 millivolts (mV) instant off, loss of material rates are measured.

The criterion for determining piping inspection locations will include in-scope piping protected by cathodic protection that is in areas exceeding the limiting critical potential of -1200 mV. The number of times and the magnitude by which the criterion is exceeded at specific locations are evaluated when determining inspection locations.

This program is implemented prior to the period of extended operation.

Commitment 4 specified:

Implement the Buried and Underground Piping and Tanks Inspection Program as described in LRA Section A.1.4.

The inspectors reviewed the soil analysis provided by the site and performed walkdowns of cathodic protection piping. The licensee has placed all the buried pipe into category F due to fire protection piping found with pitting on the pipe that was almost through wall.

The inspectors confirmed the licensee completed the required commitments and implemented the procedures associated with this program prior to the period of extended operation. Based on the review of the procedures, work-orders, work control program documents, and discussions with licensee personnel, the inspectors did not identify any findings or violations of more than minor significance for this aging management program.

(4) A.1.5 Control Rod Drive Return Line Nozzle Program (Rolled into ISI)

This program manages the effects of aging on control rod drive return line nozzle (CRDRLN) components and was rolled into the Inservice inspection (ISI)program since the program includes only American Society of Mechanical Engineers (ASME) Code Class 1 components.

The program will manage loss of material and cracking through preventive and mitigative features (e.g., coatings, backfill quality, and cathodic protection) and periodic inspection activities during opportunistic and directed excavations. The number of inspections is based on the availability and effectiveness of preventive and mitigative actions as specified in Appendix B of LR-ISG-2015-01. In addition to the buried stainless steel piping inspection recommended by LR-ISG-2015-01, one additional inspection of buried stainless steel piping with silicon-based coating will be conducted during each 10-year period unless the soil is demonstrated non-corrosive and the backfill is in accordance with the recommendations of LR-ISG-2015-01.

The CRDRLN program credits volumetric examinations to monitor the effects of crack in in accordance with the ASME Case,Section XI as part of the ISI program.

The inspectors reviewed the aging management program basis document, inspection procedures, work orders, examination data, and corrective action program documents. Based on the review of the procedures and records and discussion with licensee personnel, the inspectors did not identify any findings or violations of more than minor significance associated with this aging management program.

(5) A.1.6 BWR Feedwater Nozzle Program This existing program manages cracking due to cyclic loading on the reactor vessel feedwater nozzles in accordance with (ASME)Section XI and NRC augmented requirements. The program consists of enhanced in-service inspections, implemented by station procedures and performed in accordance with the requirements of the ASME Code,Section XI, Subsection IWB, the recommendations of General Electric (GE) NE-523-A71-0594-A, and the requirements of NUREG-0619. This program will be continued for the period of extended operation.

Each inspection interval, RBS performs inservice inspections on all four feedwater nozzles using volumetric examinations. This inspection is described in Section 5.1.2 of SEP-ISI-RBS-001, Revision 3, Program Section for ASME Section XI Division 1 RBS Inservice Inspection Program, and inspections are listed under Table 7.1 of SEP-IS-RBS-001.

This program had no additional commitments.

The inspectors reviewed the aging management program basis document, inspection procedures, work orders, examination data, and corrective action program documents. Based on the review of the procedures and records and discussion with licensee personnel, the inspectors did not identify any findings or violations of more than minor significance associated with this aging management program.

(6) A1.7 BWR Penetrations Program This existing program that manages cracking due to cyclic loading or stress corrosion cracking (SCC) and intergranular stress corrosion cracking (IGSCC) of BWR instrument penetrations, control rod drive (CRD) housing and incore housing penetrations, and core plate differential pressure standby liquid control penetrations.

The program is implemented by station procedures and performed in accordance with the guidelines of NRC approved BWRVIP-49-A, BWRVIP-47-A and BWRVIP-27-A.

Inspections include volumetric examination methods (ultrasonic testing or radiography testing), surface examination methods (liquid penetrant testing or magnetic particle testing), and VT-2 visual examination methods as appropriate, and are implemented in accordance with the requirements in the ASME Code,Section XI.

This program will be continued for the period of extended operation.

This program had no additional commitments.

The inspectors reviewed the aging management program basis document, analysis, inspection procedures, work orders, examination data, and corrective action program documents. Based on the review of the program guidance documents, procedures and records, the inspectors did not identify any findings or violation of more than minor significance associated with this aging management program.

(7) A.1.8 BWR Stress Corrosion Cracking Program This existing program manages IGSCC in stainless steel, cast austenitic stainless steel (CASS), and nickel alloy reactor coolant pressure boundary piping and piping welds.

The program manages welds classified as Category C in accordance with the recommendations provided in the staff-approved BWRVIP-75-A. Welds classified as Category A are subsumed into the risk-informed inservice inspection (RI-ISI) program in accordance with the June 30, 2010, NRC safety evaluation that approved RI-ISI at RBS. During the period of extended operation, at least 10 percent of the Category A welds are inspected during each ISI interval. RBS has only Category A and C welds.

The program includes preventive measures including the mechanical stress improvement process to minimize stress corrosion cracking.

The program includes reactor coolant piping and piping welds 4 inches or larger in nominal diameter containing reactor coolant at a temperature above 93°C (200°F)during power operation regardless of code classification.

The program had no enhancements.

The inspectors reviewed the aging management program basis document, analysis, inspection procedures, work orders, examination data, and corrective action program documents. Based on the review of the program guidance documents, procedures and records, the inspectors did not identify any findings or violations of more than minor significance associated with this aging management program.

(8) A.1.9 BWR Vessel ID Attachment Welds Program This existing program manages cracking in structural welds for BWR reactor vessel internal integral attachments and will continue through the period of extended operation, which begins on August 29, 2025. There are no enhancements identified for this program.

The program is implemented through station procedures, manages cracking of reactor vessel internal components through control of reactor water chemistry as described in the Water Chemistry Control - BWR Program (Section A.1.42) and condition monitoring through in-vessel examinations of the reactor vessel internal attachment welds. The program uses inspections, acceptance criteria, and flaw evaluation in conformance with BWRVIP guidelines, including BWRVIP-48-A.

The program includes welds between the vessel wall and vessel inner diameter brackets that attach components to the vessel. The internal attachment weld can be a simple weld or a weld build-up pad on the vessel.

The inspectors reviewed the aging management program basis document, analysis, inspection procedures, work orders, examination data, and corrective action program documents. Based on the review of the program guidance documents, procedures and records the inspectors did not identify any findings or violations of more than minor significance associated with this aging management program.

(9) A.1.10 BWR Vessel Internals This existing program manages cracking, loss of preload, loss of material, and reduction in fracture toughness for BWR vessel internal components in a reactor coolant environment. The program performs inspections and flaw evaluation in conformance with the guidelines of applicable BWR vessel internals program (VIP)reports. The program also mitigates the aging effects by controlling water chemistry with the Water Chemistry Control - BWR Program (Section A.1.42).

The program includes

(1) determining the susceptibility of cast austenitic stainless steel components to thermal embrittlement,

(2) accounting for the synergistic effect of thermal aging and neutron irradiation, and

(3) implementing a supplemental examination program, as necessary.

Commitment 5 specified:

Implement the Neutron Absorbing Material Monitoring Program as described in LRA Section A.1.3 and enhance the BWR Vessels Internals program as follows:

• Revise BWR VIP procedures to state that for core shroud repairs or other IGSCC repairs, the program will maintain operating tensile stresses below a threshold limit that precludes IGSCC of X-750 material.

• The susceptibility to neutron or thermal embrittlement for reactor vessel internal components composed of CASS and X-750 alloy will be evaluated.

• Revise BWR VIP procedures as follows: Portions of the susceptible components determined to be limiting from the standpoint of thermal aging susceptibility, neutron fluence, and cracking susceptibility (i.e., applied stress, operating temperature, and environmental conditions) will be inspected using an inspection technique capable of detecting the critical flaw size with adequate margin. The critical flaw size will be determined based on the service loading condition and service-degraded material properties. The initial inspection will be performed either prior to or within five years after entering the period of extended operation.

If cracking is detected after the initial inspection, the frequency of re-inspection will be justified based on fracture toughness properties appropriate for the condition of the component. The sample size for the initial inspection of susceptible components will be 100 percent of the accessible component population, excluding components that may be in compression during normal operations.

The inspectors reviewed the aging management program basis document, revised implementing procedures, completed inspection activities, corrective action program evaluation of related issues, and commitment closure documents. The inspectors confirmed the licensee implemented the commitment associated with this program prior to the period of extended operation. Based on the review of the procedures and records, the inspectors did not identify any findings or violations of more than minor significance for this aging management program.

(10) A.1.12 Compressed Air Monitoring The Compressed Air Monitoring Program manages loss of material in compressed air systems by periodically monitoring the air for moisture and contaminants and by inspecting system internal surfaces. Air quality is maintained in accordance with limits based on consideration of manufacturer recommendations as well as guidelines in EPRI NP-7079, EPRI TR-108147, ASME OM-S/G-1998 (Part 17), and ANSI/ISA-S7.0.01-1996. Periodic and opportunistic internal visual inspections of components (accumulators, flex hoses, tubing, etc.) are performed to monitor for signs of corrosion.

Commitment 7 specified:

Enhance the compressed air monitoring program to:

• Apply consideration of the guidance of ASME OM-S/G-1998 (Part 17), EPRI NP-7079, and EPRI TR-108147 to the limits specified for the air system contaminants.

• Include periodic and opportunistic visual inspections of accessible internal surfaces of system components.

The licensee revised the USAR through LBDCR 0A.01-002 to update Section A.1.12, the Compressed Air Monitoring program description, by removing the requirement for periodic inspections and eliminating references to specific frequencies for inspections performed in accordance with guidance from O/M-S/G-1998, Part 17. The inspectors had no concerns with this change.

The inspectors reviewed high-definition images of pneumatic components for main steam isolation valve A in the drywell to assess their material condition and found no issues. The inspectors also examined the aging management program basis document, implementing procedures, completed work activities, and corrective action records. The inspectors confirmed the licensee met all required commitments and implemented the program procedures prior to the period of extended operation.

Based on the review of the procedures, records, and discussions with licensee personnel, the inspectors did not identify any findings or violations of more than minor significance for this aging management program.

(11) A.1.13 Containment Inservice Inspection - IWE This existing aging management program manages loss of material for the steel containment vessel (SCV) and its integral attachments, containment equipment hatches, airlocks, and pressure-retaining bolting. The Program provides confirmation that the effects of aging on the SCV will not prevent the performance of intended functions consistent with the current licensing basis.

Commitment 8 specified:

Enhance the CII-IWE Program as described in LRA Section A.1.13.

• The primary inspection method for the SCV and its integral attachments is visual examination. The Containment Inservice Inspection - IWE Program specifies acceptance criteria, corrective actions, supplemental inspections as required, and provisions for expansion of the inspection scope when identified degradation exceeds the acceptance criteria in accordance with ASME Code,Section XI, as mandated and modified by 10 CFR 50.55a.

The inspectors confirmed the licensee completed the required commitment and implemented the procedures associated with this program. Based on the review of the procedures, work orders, work control program documents, and discussions with licensee personnel, the inspectors did not identify any findings or violations of more than minor significance for this aging management program.

(12) A.1.14 Containment Leak Rate Program This existing aging management program consists of tests performed in accordance with the regulations and guidance provided in 10 CFR Part 50, Appendix J, Primary Reactor Containment Leakage Testing for Water-Cooled Power Reactors, Option B; RG 1.163, "Performance -Based Containment Leak-Testing Program; NEI 94-01, Industry Guideline for Implementing Performance-Based Options of 10 CFR Part 50, Appendix J; and the conditions and limitations specified in NEI 94-01, Revision 2-A, Section 4.1, dated October 2008. The program provides for detection of pressure boundary degradation due to aging effects such as loss of leak tightness, loss of material, cracking, or loss of sealing in various systems penetrating containment. The program also provides for detection of age-related degradation in material properties of gaskets, O-rings, and packing materials for the containment pressure boundary access points.

Three types of tests are performed under Option B. Types A, B, and C leakage rate testing will be implemented in accordance with the criteria set forth in Regulatory Guide (RG) 1.163, NEI 94-01, Revision 3-A, and the conditions and limitations specified in NEI 94-01, Revision 2-A, Section 4.1, dated October 2008. Type A tests are performed to determine the overall primary containment integrated leakage rate at the loss of coolant accident peak containment pressure. Performance of the integrated leakage rate test (ILRT) demonstrates the leak-tightness and structural integrity of the containment. Types B and C containment local leakage rate tests (LLRTs) are intended to detect local leaks and to measure leakage across each pressure containing or leakage-limiting boundary of containment penetrations.

Corrective actions are taken if leakage rates exceed acceptance criteria.

Based on the review of the procedures, work orders, work control program documents, and discussions with licensee personnel, the inspectors did not identify any findings or violations of more than minor significance for this aging management program.

(13) A.1.15 Diesel Fuel Monitoring The Diesel Fuel Monitoring Program manages loss of material in piping, tanks, and other components in an environment of diesel fuel oil by verifying the quality of the fuel oil source.

Commitment 9 specified:

Enhance the diesel fuel monitoring program to:

• Monitor levels of microbiological organisms in the standby diesel generator and high pressure core spray (HPCS) diesel generator fuel oil storage and day tanks, and diesel-driven fire pump fuel oil storage tanks.

• Include periodic multi-level sampling of tanks within the scope of the program.

Include provisions to obtain a representative sample from the lowest point in the tank, if tank design does not allow for multi-level sampling.

• Include a periodic cleaning and internal visual inspection of the tanks within the program. In the areas of any degradation identified during the internal inspection, a volumetric inspection shall be performed. In the event that an internal inspection cannot be performed due to design limitations, a volumetric examination shall be performed. Perform cleanings and internal inspections at least once during the 10-year period prior to the period of extended operation and at succeeding 10-year intervals.

• Monitor biological activity (revised to microbiological organisms) and particulate concentrations in the diesel-driven fire pump fuel oil storage tanks at least quarterly, and monitor levels of microbiological organisms in the SDG and HPCS diesel fuel oil storage and day tanks at least quarterly.

• Sample for water and sediment in accordance with ASTM Standard D2709.

The licensee revised USAR Section A.1.15 through LBDCR 0A.01-004, substituting the term biological activity with levels of microbiological organisms to clarify terminology in alignment with NUREG-1801,Section XI.M30. The inspectors raised no concerns regarding this change.

The NRC evaluated this commitment during a Phase 1 inspection conducted in accordance with Inspection Procedure 71003, "Post-Approval Site Inspection for License Renewal." Consequently, the commitment was left open pending cleaning and inspecting of the diesel-driven fire pump fuel oil storage tanks FOF-TK1A and FOF-TK1B. The inspection results were documented in Inspection Report 05000458/2023011, issued on April 12, 2023 (Agencywide Document Access and Management Systems (ADAMS) Accession No. ML23102A294).

The inspectors reviewed the aging management program basis document, implementing procedures, and records of completed program activities, and held discussions with site personnel and fleet program owners. The inspectors verified fuel quality chemistry analyses for newly received diesel fuel, examined diesel tank inspection results and trends, and conducted walkdowns of accessible areas of the standby diesel generator fuel oil storage, fuel oil day tanks, and diesel-driven fire pump fuel oil storage tanks. During these activities, the inspectors observed the licensee collect a sample from fire protection diesel fuel oil tank FOF-TK-1A. No concerns were identified.

The inspectors reviewed work orders 53037843-06 and 53037817-01, used for cleaning and inspecting tanks FOF-TK1B and FOF-TK1A on April 9 and 8, 2025, respectively. Condition reports CR-RBS-2025-03085 and CR-RBS-2025-02336 were issued by the licensee for sludge and algae found in the tanks. An extent-of-condition review found no similar issues in the fuel oil day tanks for safety-related emergency and HPCS diesel systems. Since the issue was documented in the corrective action program and the tanks were cleaned and inspected, the inspectors identified no aging management concerns.

Based on the review of the procedures, records, and discussions with licensee personnel, the inspectors did not identify any findings or violations of more than minor significance for this aging management program.

(14) A.1.16 Environmental Qualification (EQ) of Electrical Components Program This is a new aging management program that manages the effects of thermal, radiation, and cyclic aging through the use of aging evaluations based on 10 CFR 50.49(f) qualification methods. As required by 10 CFR 50.49, EQ components are refurbished, replaced, or their qualification is extended prior to reaching the aging limits established in the evaluation. Reanalysis of an aging evaluation addresses attributes of analytical methods, data collection and reduction methods, underlying assumptions, acceptance criteria, and corrective actions. Some aging evaluations for EQ components are time-limited aging analyses (TLAAs) for license renewal.

The inspectors confirmed the licensee completed the required actions to ensure EQ components will be able to perform their designed safety function through the life of the facility. The inspectors noted that the licensee identified components that were not properly maintained as per EQ requirements and generated CR-2025-02205. The inspectors determined that the action being taken for license renewal was acceptable.

The licensee created condition reports and are taking the appropriate corrective actions to bring the program into compliance.

Based on the review of the procedures, work orders, work control program documents, and discussions with licensee personnel, the inspectors did not identify any findings or violations of more than minor significance for this aging management program.

(15) A.1.17 External Surfaces Monitoring This new aging management program manages aging effects of components fabricated from metallic, elastomeric, and polymeric materials through periodic visual inspection of external surfaces for evidence of loss of material, cracking, reduced thermal insulation resistance, and change in material properties. When appropriate for the component and material, physical manipulation, such as pressing, flexing and bending, is used to augment visual inspections to confirm the absence of elastomer hardening and loss of strength. The External Surfaces Monitoring Program is also credited for situations where the material and environment combinations are the same for the internal and external surfaces such that the external surfaces are representative of the internal surfaces.

Commitment 10 specified:

Enhance the External Surfaces Monitoring Program as described in LRA Section A.1.17.

The external surfaces monitoring program will be enhanced as follows:

• Revise External Surfaces Monitoring Program procedures to include instructions to perform a visual inspection of accessible flexible polymeric component surfaces. The visual inspection should identify indicators of loss of material due to wear to include dimensional change, surface cracking, crazing, scuffing, and for flexible polymeric materials with internal reinforcement, the exposure of reinforcing fibers, mesh, or underlying metal. In addition, 10 percent of the available flexible polymeric surface area should receive physical manipulation to augment the visual inspection to confirm the absence of hardening and loss of strength (e.g., HVAC flexible connectors).

• Revise External Surfaces Monitoring Program procedures to specify the following for in scope insulated components in a condensation or air - outdoor environment.

o Periodic representative inspections will be conducted during each 10-year period during the period of extended operation.

o For a representative sample of in-scope insulated indoor components with an environment of condensation (because the component is operated below the dew point) and insulated outdoor components, insulation will be removed for visual inspection of the component surface. Inspections include a minimum of 20 percent of the in-scope piping length for each material type (e.g., steel, stainless steel, copper alloy, aluminum), or for components with a configuration which does not conform to a 1-foot axial length determination (e.g., valve, accumulator), 20 percent of the surface area. Alternatively, insulation will be removed and a minimum of 25 inspections performed that can be a combination of 1-foot axial length sections and individual components for each material type.

o Inspection locations will be locations with a higher likelihood of corrosion under insulation (CUI). For example, CUI is more likely for components experiencing alternate wetting and drying in environments where trace contaminants could be present and for components that operate for long periods of time below the dew point. Subsequent inspections will consist of an examination of the exterior surface of the insulation for indications of damage to the jacketing or protective outer layer of the insulation, if the following conditions are verified in the initial inspection.

No loss of material due to general, pitting or crevice corrosion, beyond that which could have been present during initial construction.

No evidence of cracking. If the external visual inspections of the insulation reveal damage to its exterior surface or if there is evidence of water intrusion through the insulation (e.g., water seepage through insulation seams/joints), periodic inspections under the insulation will continue as described above.

o Removal of tightly adhering insulation that is impermeable to moisture is not required unless there is evidence of damage to the moisture barrier. If the moisture barrier is intact, the likelihood of CUI is low for tightly adhering insulation. Tightly adhering insulation is considered a separate population from the remainder of insulation installed on components subject to aging management review. The entire population of accessible piping component surfaces subject to aging management review that have tightly adhering insulation will be visually inspected for damage to the moisture barrier with the same frequency as for other types of insulation inspections. These inspections will not be credited towards the inspection quantities for other types of insulation.

• Revise External Surfaces Monitoring Program procedures to include the following acceptance criteria.

o Stainless steel should have a clean, shiny surface with no discoloration.

There should be no leakage of stainless steel components in an environment of air containing halides.

o Other metals should not have abnormal surface indications.

o Flexible polymeric materials should have a uniform surface texture with the material in a as-new condition with no cracks, crazing, scuffing, discoloration, dimensional change, exposure of internal reinforcement for reinforced elastomers, hardening as evidenced by a loss of suppleness during manipulation where the component and material are appropriate for manipulation, and no shrinkage or loss of strength.

o Rigid polymeric materials should have no erosion, cracking, checking, or chalking.

These enhancements will be implemented prior to the period of extended operation.

The inspectors performed walkdowns of the fire water system, fire pumps, fire piping, condensate storage tanks, and safety-related air conditioning system to understand material condition of the external systems. The inspectors reviewed condition reports, procedures, performed walkdowns of several external surfaces to verify material condition, and conducted discussions with licensee personnel.

Based on the review of the procedures, work orders, work control program documents, and discussions with licensee personnel, the inspectors did not identify any findings or violations of more than minor significance for this aging management program.

(16) A.1.18 Fatigue Monitoring This existing program ensures that fatigue usage remains within allowable limits for components identified to have a fatigue TLAA by

(a) tracking the number of critical thermal and pressure transients for selected components,

(b) verifying that the severity of monitored transients is bounded by the design transient definitions for which they are classified, and

(c) assessing the impact of the reactor coolant environment on a set of sample critical components including those from NUREG/CR-6260 and those components identified to be more limiting than the components specified in NUREG/CR-6260, and

(d) addressing applicable fatigue exemptions.

Commitment 11 and 11a specified:

Enhance the fatigue monitoring program to:

• Monitor and track critical thermal and pressure transients for components with a fatigue TLAA.

• Develop a set of fatigue usage calculations that consider the effects of the reactor water environment for a set of sample reactor coolant system components. This sample shall include the locations identified in NUREG/CR-6260, and additional plant-specific component locations in the reactor coolant pressure boundary if they are found more limiting than those considered in NUREG/CR-6260.

Environmental correction factors (Fen) shall be determined using the formulae recommended in NUREG-1801, X.M1. Stress analysis methods used as inputs to fatigue analyses will consider all six stress components. An environmentally assisted fatigue analysis using NUREG/CR-6909 will not use average temperature for complex transients. For simple transients that use average temperature, when the minimum temperature is below the threshold temperature, the maximum and threshold temperature will be used to calculate the average temperature.

• Provide updates of the fatigue usage calculations on an as-needed basis if an allowable cycle limit is approached, or in a case where a transient definition has been changed, an unanticipated new thermal event is discovered, or the geometry of a component has been modified.

All actions are complete, and all fatigue locations have been identified. The inspectors reviewed Fatigue Usage Calculation 1500837.312, Revision 0, Recalculation of Cumulative Usage Factor for RPV Closure Studs Including Consideration of 60-Year Projected Cycles, verifying that the current and 60-year Cumulative Usage Factors are below 1.0 per ASME Code. The inspectors also examined FP-RBS-403, Revision 0, Cycle-Based Fatigue Report for the Transient and Fatigue Monitoring System for River Bend Station, confirming no uncounted cycles or fatigue from uncounted transients at nine locations.

Based on the review of the procedures, work orders, work control program documents, and discussions with licensee personnel, the inspectors did not identify any findings or violations of more than minor significance for this aging management program.

(17) A.1.19 Fire Protection Program This is an existing aging management program that manages the fire barrier intended function, carbon steel(loss of material), concrete (cracking and loss of material),masonry walls (cracking and loss of material), fire resistant materials (loss of material, change in material properties, cracking/delamination, and separation), and elastomers through following periodic visual inspection of components and structures The program manages aging effects for components that serve a fire barrier function.

Fire barriers include assemblies such as penetration fire seals, walls, floors, ceilings, fire-rated doors, cable tray enclosures, cable or conduit wraps, fire stops, junction boxes, and other fire-resistant materials that serve a fire barrier intended function.

Fire barrier inspections are performed frequently in accordance with the NRC-approved fire protection program and the Technical Requirements Manual.

The periodic visual inspection and functional test of the Halon fire suppression system associated with the power generation control complex is performed to examine for signs of corrosion and degradation that may lead to the loss of material of the Halon fire suppression system. The frequency of the periodic functional test is in accordance with the NRC-approved fire protection program and the Technical Requirements Manual.

The inspectors reviewed condition reports, procedures, performed walkdowns of fire protection doors and walls in air conditioning rooms, switchgear rooms, and fire water pump house to verify material condition of fire barriers and doors Based on the review of the procedures, work orders, work control program documents, and discussions with licensee personnel, the inspectors did not identify any findings or violations of more than minor significance for this aging management program.

(18) A.1.20 Fire Water System This existing aging management program manages loss of material, and flow blockage due to fouling for in-scope, long-lived, passive, water-based fire suppression system components using periodic flow testing and visual inspections in accordance with NFPA 25 (2011 Edition). In addition, the fire water system pressure is monitored such that a loss of system pressure is immediately detected and corrective action initiated. When visual inspections are used to detect loss of material and fouling, the inspection technique is capable of detecting surface irregularities that could indicate wall loss due to corrosion, corrosion product deposition, and flow blockage due to fouling. The program also manages loss of coating integrity for the firewater tanks.

Commitment 12 specified:

Enhance the Fire Water System Program as described in LRA Section A.1.20.

Commitment 12a specified:

Remove existing coating, perform bottom thickness measurements and recoat the fire water storage tanks.

Enhancements:

• Testing or replacement of sprinkler heads that have been in service for 50 years is performed in accordance with the 2011 Edition of NFPA 25. Portions of the water-based fire water system that

(a) are normally dry, but periodically subject to flow (e.g., downstream of the deluge valve in a deluge system) and

(b) allow water to collect are subject to augmented examination beyond that specified in NFPA 25. The augmented examinations for the portions of normally dry piping that are periodically wet include

(a) periodic full flow tests at the design pressure and flow rate, or internal inspections, and

(b) volumetric wall thickness evaluations. Augmented examinations for the system include periodic volumetric wall thickness evaluations, at a minimum rate of five inspections in each refueling cycle.

• The training and qualifications of individuals involved in fire water storage tank coating inspections are in accordance with ASTM International standards endorsed in RG 1.54, including limitations, if any, identified in RG 1.54 on a particular standard.

• Program acceptance criteria include

(a) the water-based fire protection system can maintain required pressure, and

(b) no unacceptable signs of degradation or fouling are observed during non-intrusive or visual inspections.

• In the event surface irregularities are identified, testing is performed to ensure minimum design pipe wall thickness is maintained. In the event the fire water tank fails to meet the acceptance criteria for coating or tank surface condition (e.g.,

peeling, delamination, blistering, flaking, cracking, or rust), the program specifies an evaluation to ensure the tank can perform its intended function until the next inspection and that downstream flow blockage is not a concern.

• Revise Fire Water System Program procedures to perform an internal inspection of the auxiliary building and diesel generator building pre-action systems dry piping for loss of material every five years. Perform an inspection by removing a sprinkler from the branch line most remote from the source of water or using an inspector's test valve. In the event foreign material is found in a pre-action system that could result in flow obstructions or blockage of a sprinkler head in a building, each in-scope pre-action system in that building shall have an internal inspection.

• Revise Fire Water System Program procedures to perform an internal inspection every five years of the dry piping downstream of the deluge valves for the control building cable vaults (WS-6A, WS-6B and WS-6C), cable tunnel spray system (WS-8D), tunnels (WS-8E, WS-8F, WS-8G, WS-8H, WS-8K, WS-8L, WS-8M and WS-8N), and auxiliary building water curtains (WS-19 and WS-20) at 70-foot elevation and 141-foot elevation. The inspection shall be performed by opening a flushing connection, removing the most remote sprinkler head, and using a method capable of detecting surface irregularities that could indicate wall loss below nominal pipe wall thickness due to corrosion product deposition and flow blockage due to fouling. In the event foreign material is found in an in-scope deluge system in a building during the five-year internal inspection of piping, the dry piping of each in-scope deluge system in that building shall have an internal inspection.

• Revise Fire Water System Program procedures to perform an internal piping inspection of every other wet fire water system every five years by opening a flushing connection at the end of one main and by removing a closed sprinkler head toward the end of one branch line for the purpose of inspecting the interior for evidence of loss of material and the presence of foreign material that could result in flow obstructions or blockage of sprinkler head or nozzles. The inspection method used shall be capable of detecting surface irregularities that could indicate wall loss below nominal pipe wall thickness due to corrosion, corrosion product deposition, and flow blockage due to fouling. Ensure procedures require a follow-up volumetric wall thickness evaluation where irregularities are detected. In the event foreign material is found, all wet pipe systems in that building shall have an internal inspection before returning to service.

• Revise Fire Water System Program procedures to perform flow testing of underground piping in accordance with NFPA 291.

• Revise Fire Water System Program procedures to inspect fire water sprinkler heads in accordance with NFPA 25, Section 5.2.1.1, except for sprinkler orientation, foreign material, physical damage, and loading due to dust or debris.

• Revise Fire Water System Program procedures to inspect the interior of the fire water tanks in accordance with NFPA 25 (2011 Edition), Sections 9.2.6 and 9.2.7, including sub-steps, using the guidance of SSPC-SP2, Hand Tool Cleaning; SSPC-SP3, Power Tool Cleaning; SSPC-SP11, Cleaning of Bare Metal; and SSPC-SP WJ-1, 2, 3 and 4, Water Jet Cleaning. Perform the interior inspection with the tank completely drained.

• Revise Fire Water System Program procedures to remove mainline strainers, inspect for damage and corroded parts, clean every five years, and add a requirement to flush mainline strainers (basket or screen) until they clear at least once per refueling cycle if a fire water system actuation occurred or flow testing occurred during that refueling cycle.

• Revise Fire Water System Program procedures to specify that sprinkler heads are tested or replaced in accordance with NFPA 25 (2011 Edition), Section 5.3.1.

• Revise Fire Water System Program procedures to specify a flow test or flush sufficient to detect potential flow blockage or conduct a visual inspection of 100 percent of the internal surface of piping segments that allow water to collect in each five-year interval, beginning five years prior to the period of extended operation.

• Revise Fire Water System Program procedures to specify volumetric wall thickness inspections of 20 percent of the length of piping segments that allow water to collect in each five-year interval of the period of extended operation.

Measurement points shall be obtained to the extent that each potential degraded condition can be identified (e.g., general corrosion, microbiologically induced corrosion [MIC]). The 20 percent piping that is inspected in each 5-year interval is in different locations than previously inspected piping.

• Revise Fire Water System Program procedures to perform main drain tests on 20 percent of the standpipes and risers in accordance with NFPA 25 (2011 Edition), Sections 6.3.1.5 and 13.2.5.

• Revise Fire Water System Program procedures to specify an annual air flow test of the charcoal filter units that are in scope for license renewal. If obstructions are found, the system shall be cleaned and retested.

• Revise Fire Water System Program procedures to verify the hydrants drain within 60minutes after flushing or flow testing.

• Revise Fire Water System Program procedures to ensure the training and qualification of the individual performing the evaluation of fire water storage tank coating degradation is in accordance with ASTM International standards endorsed in RG 1.54 guidance, including limitations, if any, identified in RG 1.54 on a particular standard.

• Revise the Fire Water System Program procedures to ensure a fire water tank is not returned to service after identifying interior coating blistering, delamination or peeling unless there are only a few small intact blisters that are not growing in size or number and are surrounded by coating bonded to the substrate as determined by a qualified coating specialist, or the following actions are performed:

o Blistering in excess of a few small intact blisters that are not growing in size or number or blistering not completely surrounded by coating bonded to the substrate is removed.

o Delaminated or peeled coating is removed. The exposed underlying coating is verified securely bonded to the substrate as determined by an adhesion test endorsed by RG 1.54 at a minimum of three locations.

o The outermost coating is feathered, and the remaining outermost coating is determined securely bonded to the coating below at a minimum of three locations adjacent to the defective area via an adhesion test endorsed by RG 1.54.

o Ultrasonic testing is performed where there is evidence of pitting or corrosion to ensure the tank meets minimum wall thickness requirements. An evaluation is performed to ensure that downstream flow blockage is not a concern. A follow-up inspection is scheduled within 2-years and every 2-years after that until the coating is repaired, replaced, or removed.

o Adhesion testing in accordance with ASTM D3359, ASTM D4541, or equivalent testing endorsed by RG 1.54 at a minimum of three locations.

o Ultrasonic testing where there is evidence of pitting or corrosion to determine if the o

tank thickness meets the minimum thickness criteria.

• Revise Fire Water System Program procedures to determine the extent of coating defects on the interior of the fire water tanks by using one or more of the following methods when conditions such as cracking, peeling, blistering, delamination, rust, or flaking are identified during visual examination.

o Lightly tapping and scraping the coating to determine the coating integrity.

o Dry film thickness measurements at random locations to determine overall thickness of the coating.

o Wet-sponge testing or dry film testing to identify holidays in the coating.

o Adhesion testing in accordance with ASTM D3359, ASTM D4541, or equivalent testing endorsed by RG 1.54 at a minimum of three locations.

o Ultrasonic testing where there is evidence of pitting or corrosion to determine if the tank thickness meets the minimum thickness criteria.

• Revise Fire Water System Program procedures to include acceptance criteria of no abnormal debris (i.e., no corrosion products that could impede flow or cause downstream components to become clogged). Signs of abnormal corrosion or blockage will be removed, and its source and extent of condition determined and corrected. The condition will be entered into the corrective action program.

• Revise Fire Water System Program procedures to include the following acceptance criteria for the fire water tanks' interior coating:

o Indications of peeling and delamination are not acceptable.

o Blisters are evaluated by a coatings specialist qualified in accordance with an ASTM International standard endorsed in RG 1.54 including limitations, if any, identified in RG 1.54 associated with use of a particular standard.

Blisters should be limited to a few intact small blisters that are not growing in number or size and are completely surrounded by sound coating/lining bonded to the substrate. Blister size and frequency should not be increasing between inspections (e.g., reference ASTM D714-02, "Standard Test Method for Evaluating Degree of Blistering of Paints").

o Indications such as cracking, flaking, and rusting are evaluated by a coatings specialist qualified in accordance with an ASTM International standard endorsed in RG 1.54 including limitations, if any, identified in RG 1.54 associated with use of a particular standard.

o As applicable, wall thickness measurements, projected to the next inspection, meet design minimum wall requirements.

o Coating meets the plant-specific design requirements for the coating/lining and substrate, including the required degree of adhesion when performing adhesion testing.

o Revise Fire Water System Program procedures to specify replacement of sprinkler heads that show signs of leakage, excessive loading, or corrosion.

• Revise Fire Water System Program procedures to perform an obstruction evaluation if any of the following conditions exist:

o There is an obstructive discharge of material during routine flow tests.

o An inspector's test valve is clogged during routine testing.

o Foreign material is identified during internal inspections.

o Sprinkler heads are found clogged during removal or testing.

o Pin-hole leaks are identified in fire water piping.

o After an extended fire water system shutdown (greater than one year).

• Revise Fire Water System Program procedures to evaluate for MIC if tubercules or slime are identified during internal inspections of fire water piping.

• Revise Fire Water System Program procedures to conduct augmented volumetric wall thickness examinations of fire water system piping. Inspections will be performed during the period of extended operation as long as the frequency of occurrence of loss of material meets the criteria for recurring internal corrosion.

Procedures shall specify wall thickness measurements at a minimum of five selected locations per refueling cycle. The number of augmented examinations will be increased if substantial corrosion is detected during inspections. Corrosion will be considered substantial if the component does not meet plant specific acceptance criteria (such as the minimum wall thickness required by the design code) or experiences a reduction in wall thickness greater than 50 percent of nominal wall thickness. For through-wall leaks and material loss greater than 50 percent of nominal wall thickness, four additional locations will be examined during the next refueling cycle. Where the identified material loss is 30 percent to 50 percent of nominal wall thickness and the calculated remaining life is less than two years, two additional locations will be examined during the next refueling cycle.

• Revise Fire Water System Program procedures to perform a full flow test on hose rack HR96, Control Building 135'0" elevation stairwell in accordance with Section 6.3.1 of NFPA 25 (2011 edition).

• Revise Fire Water System Program procedures to test hydrants FHY9. FHY10 and FHY11 annually in accordance with Section 7.3.2 of NFPA 25 (2011 Edition)and test FHY13 with the hydrant valve partially open until any foreign material has cleared.

• Revise Fire Water System Program procedures to conduct examinations of the fire water storage tank floors. The first examination shall be performed prior to the period of extended operation following removal of the existing coating and the subsequent examination will be performed during the first 10 years of the period of extended operation. The examinations shall consist of a low-frequency electromagnetic test (LFET) scan, or equivalent, and ultrasonic testing (UT) where there is indication of potential thinning of the floor plates. In place of the LFET scan, or equivalent, 25 UT thickness measurements may be performed on the tank floor (at least four measurements in each quadrant, at least three of which will examine the area within six inches of where the wall meets the floor).

Enhancements will be implemented prior to the period of extended operation.

The inspectors reviewed the program basis documents, administrative procedures, and implemented procedures to verify that the licensee developed the program as described in the license renewal application. The inspectors confirmed the licensee completed the commitment requirements and implemented the procedures/administrative controls associated with this program prior to the period of extended operation. The inspectors interviewed plant personnel and walked down fire water system equipment, including the fire pumps and jockey pumps, fire water storage tanks, fire water deluge system, fire brigade hoses, sprinkler systems in the turbine building, transformer deluge sprinklers, and associated piping and valves.

The inspectors verified that fire protection procedures and work orders accounted for the license renewal commitments and incorporated Commitment 12a. The inspectors verified that procedures were updated to look for and take the following actions with regards to the fire water storage tanks: training and qualifications for inspecting the inside of the tanks, procedures are updated to inspect the interior if conditions do not meet acceptance qualifications, procedures are updated if deviations are found.

The inspectors determined that the licensee has a plan for the 50-year sprinkler testing and/or replacement. It was noted by inspectors that the licensee missed the internal inspection every five years of dry piping downstream of the deluge valves for the control building. The licensee created CR-2025-02879 to address the issue. The inspectors determined that the licensee is taking acceptable corrective actions.

Based on the review of the procedures and records, and discussions with licensee personnel, the inspectors did not identify any findings or violations of significance associated with the aging management program.

(19) A.1.21 Flow-Accelerated Corrosion This is an existing program consistent with GALL Report AMP XI.M17, Flow-Accelerated Corrosion, as modified by LR-ISG-2012-01, Wall Thinning Due to Erosion Mechanisms after an exception and enhancement, credited with managing wall thinning caused by flow accelerated corrosion and various erosion mechanisms.

This program includes performing

(a) an analysis to determine critical locations, (b)limited baseline inspections to determine the extent of thinning at these locations, and

(c) follow-up inspections to confirm the predictions or repairing or replacing components as necessary. The licensee uses the computer program CHECKWORKS to model susceptible piping for predictive analysis, performs inspections and non-destructive exams (to baseline and monitor wall-thinning), evaluates industry experience, and uses engineering judgment to monitor and predict flow accelerated corrosion (FAC) wear rates.

Commitment 13 specified:

Enhance the Flow-Accelerated Corrosion Program as described in LRA Section A.1.21.

Enhancements:

• Revise FAC Program procedures to manage wall thinning due to erosion mechanisms such as cavitation, flashing, liquid droplet impingement, and solid particle impingement.

• Revise FAC Program procedures to include susceptible locations based on the extent of condition reviews in response to plant-specific or industry operating experience.

• Revise FAC Program procedures to

(1) evaluate wall thinning due to erosion from cavitation, flashing, liquid droplet impingement, and solid particle impingement when determining a replacement type of material, and

(2) ensure piping and components replaced with FAC-resistant material and subject to erosive conditions are not excluded from inspections until effectiveness of piping replacement or other corrective action has been confirmed.

• Revise procedures to ensure that error reporting continues to be performed for RBS FAC software during the period of extended operation.

Exception:

• The licensee implemented the recommendations provided in NSAC-202L, Recommendations for an Effective Flow-Accelerated Corrosion Program, Revision 4, which was endorsed by the subsequent license renewal GALL rather than the revisions endorsed by LR-ISG-2012-01, Wall Thinning due to Erosion Mechanisms. The inspectors identified no concerns with the licensee utilizing the most current versions of industry monitoring software since NRC endorsed it in the subsequent license renewal GALL.

• The inspectors reviewed the program basis documents, administrative and implementing procedures, and corrective action documents to verify that the licensee developed the program as described in the license renewal application.

The inspectors verified that implementing procedures accomplished the actions described in the commitments or that the licensee established administrative controls to accomplish the activities described. The inspectors confirmed the licensee completed the required commitments and

• implemented the procedures associated with this program prior to the period of extended operation.

Based on the review of the procedures, records, and discussions with licensee personnel, the inspectors did not identify any findings or violations of more than minor significance for this aging management program.

(20) A.1.22 Inservice Inspection This existing program manages cracking, wear, loss of mechanical closure integrity, and loss of material of reactor coolant system piping and components, including reactor coolant pump items and austenitic stainless steel small-bore piping.

The program implements the applicable requirements of ASME Section XI, Subsections IWA, IWB, IWC, IWD, and IWF, and other requirements specified in 10CFR50.55a with approved NRC alternatives and relief requests. The Inservice Inspection Program is updated every 10 years to the latest ASME Section XI code edition and addendum approved by the NRC in 10CFR50.55a.

The program uses nondestructive examination techniques to detect and characterize flaws. Volumetric examinations are the most extensive, using methods such as radiographic, ultrasonic or eddy current examinations to locate surface and subsurface flaws. Surface examinations, such as magnetic particles or dye penetrant testing, are used to locate surface flaws. Visual examinations (VT-1) are conducted to assess the condition of the surface of the part being examined, looking for cracks and symptoms of wear, corrosion, erosion or physical damage. Visual examinations (VT-2) are conducted specifically to locate evidence of leakage from pressure retaining components (period pressure tests). While the system is under pressure for a leakage test, visual examinations are conducted to detect direct or indirect indications of leakage. Visual examinations (VT-3) are conducted to determine the general mechanical and structural condition of components and supports and to detect discontinuities and imperfections.

Based on the review of the procedures, records, and discussions with licensee personnel, the inspectors did not identify any findings or violations of more than minor significance for this aging management program.

(21)1.23 Inservice Inspection - IWF This existing program manages aging effects on supports for ASME Classes 1, 2, and 3 piping and components. The scope of inspection for supports is a sampling of piping supports, and 100 percent of other component supports as specified in Table IWF-2500-1 of ASME Section XI. The program implements the applicable requirements of ASME Section XI, Subsection IWF.

The program uses nondestructive examination techniques to detect and characterize component degradation. The parameters monitored or inspected include corrosion; deformation; misalignment of supports; missing, detached, or loosened support items; improper clearances of guides and stops; and improper hot or cold settings of spring supports, and constant load supports. Accessible areas of sliding surfaces are monitored for debris, dirt, or indications of excessive loss of material due to wear that could prevent or restrict sliding as intended in the design basis of the support.

Structural bolts are monitored for corrosion and loss of integrity of bolted connections due to self-loosening and material conditions that can affect structural integrity. High-strength structural bolting (actual measured yield strength greater than or equal to 150 ksi in sizes greater than 1-inch nominal diameter) susceptible to stress corrosion cracking (SCC) is monitored for SCC. Inspection populations per inspection interval are specified by ASME Code.

Commitment 14 specified:

Enhance the Inservice Inspection - IWF Program as described in LRA Section A.1.23.

Enhancements:

• Revise plant procedures to include the preventive actions for storage of ASTM A325, ASTM F1852, and ASTM A490 bolting from Section 2 of the Research Council on Structural Connections publication, "Specification for Structural Joints Using ASTM A325 or A490 Bolts."

• Revise plant procedures to specify that detection of aging effects will include monitoring anchor bolts for loss of material, loose or missing nuts and bolts, and cracking of concrete around the anchor bolts.

• Revise plant procedures to include an assessment of the impact on the inspection sample, in terms of sample size and representativeness, if components that are part of the sample population are re-worked.

• Revise plant procedures to specify the following conditions as unacceptable:

o Loss of material due to corrosion or wear that reduces the load bearing capacity of the component support.

o Debris, dirt, or excessive wear that could prevent or restrict sliding of the sliding surfaces as intended in the design basis of the support.

Based on the review of the procedures, records, and discussions with licensee personnel, the inspectors did not identify any findings or violations of more than minor significance for this aging management program.

(22) A.1.24 Inspection of Overhead Heavy Load and Light Load (Related to Refueling)

Handling Systems This is an existing aging management program that manages the loss of material due to corrosion, loose bolting or rivets, and rail wear of cranes and hoists, based on industry standards and guidance documents. The program includes structural components, including structural bolting, that make up the bridge, the trolley, lifting devices, and crane rails and includes cranes and hoists within the scope of license renewal and subject to aging management review. The activities entail visual examinations and functional testing to ensure that cranes and hoists can sustain their rated loads. The number and the magnitude of lifts made by the hoist or crane are also reviewed.

Commitment 15 specified:

Enhance the Inspection of Overhead Heavy Load and Light Load (Related to Refueling) Handling Systems Program as described in LRA Section A.1.24.

Enhancements:

• Revise plant procedures to ensure that the program manages loss of material due to wear for the crane rails; manages deformation, cracking, and loss of material due to corrosion for bridge, trolley and hoists structural components; and manages loss of bolting integrity for structural connections by monitoring for loose or missing bolts, nuts, pins or rivets and any other conditions indicative of loss of bolting integrity.

• Revise plant procedures to specify inspection frequency will be in accordance with ASME B30.2 or other appropriate standard in the ASME B30 series. The inaccessible or infrequently used cranes and hoists will be inspected prior to use.

Bolted connections will be visually inspected for loose or missing bolts, nuts, pins or rivets at the same frequency as crane rails and structural components.

• Revise plant procedures to specify the acceptance criteria for any visual indication of loss of material due to corrosion or wear and any visual sign of loss of bolting preload is evaluated according to ASME B30.2 or other applicable industry standard in the ASME B30 series.

• Revise plant procedures to specify that maintenance and repair activities will utilize the guidance provided in ASME B30.2 or other appropriate standard in the ASME B30 series.

These enhancements are implemented prior to the period of extended operation.

The inspectors reviewed the aging management program basis document, implementing procedures, nondestructive evaluation reports, crane inspection reports, completed work orders, and commitment closure documentation. It was observed that the licensee missed adding the requirement to evaluate as per ASME B30.2 into the work orders. The licensee has created CR-RBS-2025-03159 and the inspectors found the actions taken acceptable.

Based on the review of the procedures, records, and discussions with licensee personnel, the inspectors did not identify any findings or violations of more than minor significance for this aging management program.

(23) A.1.25 Internal Surfaces in Miscellaneous Piping and Ducting Components This new program manages the effects of aging due to loss of material and change in material properties using representative sampling and opportunistic visual inspections of the internal surfaces of metallic and elastomeric components in environments of air

- indoor, air - outdoor, condensation, exhaust gas, raw water, and wastewater, and of fiberglass in treated water. Internal inspections will be performed during periodic system and component surveillances or during the performance of maintenance activities when the surfaces are accessible for visual inspection.

For metallic components, visual inspection will be used to detect evidence of loss of material. For fiberglass, visual inspection will be used to detect surface irregularities, which are evidence of change in material properties and cracking. For elastomeric components, visual inspections will be used to detect loss of material due to wear.

Specific acceptance criteria are as follows:

• Stainless steel: clean surfaces, shiny, no abnormal surface condition.

• Metals: no abnormal surface condition.

• Fiberglass: no cracking, blistering, or other abnormal surface conditions.

• Elastomers: a uniform surface texture and color with no cracks, no unanticipated dimensional change, and no abnormal surface conditions.

Conditions that do not meet the acceptance criteria are entered into the corrective action program for evaluation. Indications of relevant degradation will be evaluated using design standards, procedural requirements, current licensing basis, and industry codes or standards.

This program will be implemented prior to the period of extended operation.

Commitment 16 specified:

Implement the Internal Surfaces in Miscellaneous Piping and Ducting Components Program as described in LRA Section A.1.25.

The inspectors reviewed procedures SEP-AMP-RBS-001, RBS Opportunistic Inspections for Aging Management Programs, Revision 0, and observed that the licensee did not include acceptance criteria for fiberglass components acceptance criteria. The licensee created CR-RBS-2025-03091 and the inspectors found the corrective actions to be acceptable. The inspectors performed walkdowns of the fire water system, safety-related air conditioning system.

Based on the review of the procedures, records, and discussions with licensee personnel, the inspectors did not identify any findings or violations of more than minor significance for this aging management program.

(24) A.1.31 Oil Analysis This existing program manages loss of material and reduction of heat transfer by maintaining the quality of the lubricating oil. The program ensures that contaminants (primarily water) and particulates are within acceptable limits.

Analyses are performed to monitor the condition of lubricating oils. Periodic sampling detects evidence of abnormal wear rates, contamination by moisture, excessive corrosion, and oil degradation. Water and particle concentrations are maintained within acceptance criteria based on equipment manufactures recommendations or industry standards. This manages the aging effects of loss of material and reduction of heat transfer.

Procedure SEP-LUB-RBS-001 provides direction for the RBS Oil Analysis Program. It includes instructions for selecting components to be included in the program.

2 of SEP-LUB-RBS-001 is a list of equipment included in the program.

Components that are subject to aging management review for license renewal are indicated by a note in Attachment 2.

Analysis is performed to monitor the condition of lubricating oils. The sample results are compared to predetermined limits to assess the need for corrective action and results are tracked in a program database.

Based on the review of the procedures, records, and discussions with licensee personnel, the inspectors did not identify any findings or violations of more than minor significance for this aging management program.

(25) A.1.32 One-Time Inspection This one-time aging management program, consistent with GALL Report AMP XI.M30, One-Time Inspection, is credited with conducting a series of examinations of components in the water chemistry, fuel oil chemistry, and lubricating oil analysis programs to establish and verify the effectiveness of the aging management activities performed by those programs. The scope of the program was expanded by commitment to include other components and materials where the environment in the period of extended operation is expected to be equivalent to that in the prior 40 years and for which no aging effects have been observed.

The licensee selected representative sample of 20 percent of the identified population (defined as components having the same material, environment, and aging effect combination) or a maximum of 25 components. The sample selection was based on criteria such as the longest service period, most severe operating conditions, lowest design margins, lowest or stagnant flow conditions, high flow conditions, and highest temperature. The licensee created an implementation procedure for the One-Time Inspection Program, EN-FAP-LR-024, One-Time Inspection," which provided guidance for program implementation including sample selection, inspection instructions, inspector qualifications and documentation requirements. Inspections were performed using visual techniques capable of detecting discontinuities and imperfections on the surface of components, including cracks and surface irregularities caused by wear, corrosion, or erosion.

The visual inspections were conducted in accordance with VT-1 and VT-3 inspection guidance for inspection parameters such as lighting, presence of protective coatings, cleaning processes, and the use of visual aids. When volumetric inspections were performed, ultrasonic thickness measurements were compared to predetermined limits and any indication of degradation was evaluated. The licensee documented the results of their inspections in report RBS-EP-25-00001, "License Renewal One-time Inspection Program Report," which contains tables of results. The report documents two anomalies identified during inspections, and both were entered into the site corrective action program for correction. One anomaly was identified as erosion/steam cutting damage to a valve body and seat damage and not an aging mechanism, the other was a rupture of a stainless steel hose due to loss of material and cracking which led the licensee to determine that this and similar hoses will be periodically replaced.

Commitment 22 specified:

Implement the One-Time Inspection Program as described in LRA Section A.1.32.

The commitment included the following elements:

• Components where aging effects are managed by the Diesel Fuel Monitoring, Oil Analysis, and Water Chemistry Control - BWR programs

• Reactor vessel flange leak detection components

• Representative sample of internal and external surfaces of piping passing through the waterline region of the suppression pool in the residual heat removal (RHR), reactor core isolation cooling, and nuclear pressure relief systems for loss of material

• Representative sample of stainless steel component external surfaces exposed to outdoor air for cracking and loss of material

• Representative sample of aluminum component external surfaces exposed to outdoor air for loss of material

• Representative sample of service water system containment and auxiliary building vacuum release piping that cannot be vented between the check valves and the treated water source for loss of material

• Establish an informal process to trigger opportunistic inspections in conjunction with plant modification and maintenance activities prior to the period of extended operation.

The inspectors reviewed the aging management program basis document, implementing procedures, examination sheets, destructive examination reports, engineering evaluations, and corrective action documents. The inspectors reviewed the sampling plan and technical basis document that established the sample populations and evaluation samples for each material and environment combination.

The inspectors determined that the licensee had appropriately selected the components and environments and completed all required examinations.

Based on the review of the procedures, records, and discussions with licensee personnel, the inspectors did not identify any findings or violations of more than minor significance for this aging management program.

(26) A.1.33 One-Time Inspection - Small-Bore Piping This new one-time inspection program, consistent with GALL Report AMP XI.M35, One-Time Inspection of ASME Code Class 1 Small-Bore Piping, credited with conducting a series of volumetric examinations of ASME Code Class 1 small-bore piping to provide reasonable assurance that aging is not occurring, or that the aging effects are not significant, such that a plant-specific aging management program is not warranted. The program required volumetric examination of 3 percent, with a maximum of 10, of the socket welds and 3 percent, with a maximum of 10, of the butt welds within the population of ASME Class 1 small-bore piping welds. A determination of the number of Class 1 small bore welds was performed, and the review determined that two socket welds and 14 butt welds required inspection. The results of the examinations are documented in RBS-EP-23-00004, "License Renewal One-time Inspection - Small-Bore Piping Welds Program Report."

Commitment 23 specified:

Implement the One-Time Inspection - Small-Bore Piping Program as described in LRA Section A.1.33.

The inspectors reviewed the program basis documents, revised administrative and implementing procedures, and corrective action documents to verify that the licensee developed the program as described in the license renewal application. The inspectors verified work orders evaluated and examined small bore butt and socket welds in accordance with implementing procedures. The inspectors confirmed the licensee completed the commitment inspections and implemented the revised procedures associated with this program prior to the period of extended operation.

Based on the review of the procedures, records, and discussions with licensee personnel, the inspectors did not identify any findings or violations of more than minor significance for this aging management program.

(27) A.1.34 Periodic Surveillance and Preventive Maintenance This is an existing program credited with periodic inspections and tests to manage aging effects including cracking, loss of material, reduction of heat transfer in cases where no NUREG-1801 (GALL) program was found appropriate to manage the particular aging effects for specific components.

The program requires at a minimum in each 10-year period during the period of extended operation, a representative sample of 20 percent of the population (defined as components having the same combination of material, environment, and aging effect) or a maximum of 25 components per population is inspected. The program credits the following activities:

• Visually inspect the surface of the high-pressure core spray, residual heat removal, low pressure core spray, and reactor core isolation cooling suppression pool suction strainers for debris.

• In the plant drains system, visually inspect the internal and external surface of pump casings and piping components within sumps to manage loss of material and cracking. Visually inspect the external surface of the pump suction strainer within sumps to manage loss of material.

• In the service water system, visually inspect the external surfaces of pump casings to manage loss of material.

• For the standby diesel generators, visually inspect the external surface of heat exchanger (intercooler) tube fins to manage reduction of heat transfer at least once every eight years.

• Additional inspections of internal surfaces of abandoned equipment in nonsafety-related systems that could affect safety-related systems are also performed, as well as for metallic components, visually inspect components to detect evidence of reduction of heat transfer.

Commitment 24 specified:

Enhance the Periodic Surveillance and Preventive Maintenance Program as described in LRA Section A.1.34.

The Periodic Surveillance and Preventive Maintenance Program was enhanced to revise program procedures as necessary to incorporate the activities identified above, and to revise program procedures to specify acceptance criterion as no indication of relevant degradation and that such indications will be evaluated.

The licensee modified the original amendment request to remove two inflatable elastomer seals in the spent fuel pool upper containment gate and the pool storage gate because the seals are frequently replaced. LBDCR 01A.00-010 was created to document this change.

The licensee modified the original amendment request to move the inspection of the service water pump casing to the Service Water Integrity Program. LBDCR 01A.00-019 was created to document this change.

The licensee modified the original amendment request to remove the enhancement for inspection of abandoned reactor water cleanup system components because it has been confirmed through evaluations that the only abandoned equipment is pipe supports and could not affect safety-related components. LDDCR 01A.00-020 was created to document this change.

Based on the review of the procedures, records, and discussions with licensee personnel, the inspectors did not identify any findings or violations of more than minor significance for this aging management program for the samples reviewed.

(28) A.1.36 Reactor Head Closure Studs The program manages cracking and loss of material due to wear or corrosion for reactor head closure studs bolting (studs, washers, nuts, and flange threads) using inservice inspection and preventive measures to mitigate the effects of aging. The licensee performs visual, surface, and volumetric examinations to detect cracks, loss of material, and leakage. The licensee uses stable lubricants, bolting materials with low susceptibility to SCC, and avoidance of the use of metal-plated stud bolting as preventative action.

Commitment 25 specified:

Enhance the Reactor Closure Studs Program to ensure replacement studs are fabricated from bolting material with actual measured yield strength less than 150 ksi.

The inspectors reviewed the aging management program basis document, implementing procedures, and documentation of completed program activities, and engaged in discussions with site personnel. The inspectors conducted walkdowns of the warehouse where the spare studs are stored and assessed the associated storage procedures. The inspectors verified that the licensee had implemented the program procedures prior to the period of extended operation.

Based on the review of the procedures, records, and discussions with licensee personnel, the inspectors did not identify any findings or violations of more than minor significance for this aging management program.

(29) A.1.37 Reactor Vessel Surveillance Program The program manages reduction of fracture toughness and long-term operating conditions for reactor vessel beltline materials as defined by 10 CFR 50, Appendix G, Section II.F using material data and dosimetry. The program ensures that the specimen exposure, capsule withdrawal, sample testing, and capsule storage meet the requirements of 10 CFR 50, Appendix H, for vessel material surveillance and American Society for Testing and Materials (ASTM) E 185.

The objective of Reactor Vessel Surveillance Program is to provide sufficient material data and dosimetry to

(a) monitor irradiation embrittlement at the end of the period of extended operation and

(b) establish operating restrictions on the inlet temperature, neutron spectrum, and neutron flux after a surveillance capsule is withdrawn for testing. Surveillance capsule testing and reporting, to the extent practicable, is performed in accordance with the requirements of ASTM E 185 Standard. This program required no enhancements or exceptions.

When specific changes are made to the testing matrix, withdrawal schedule, or the testing and reporting of individual capsule results, these modifications are submitted promptly to the NRC to ensure appropriate implementation arrangements. The surveillance program outlined in ASTM E 185 is based on plant operation during the current license term; therefore, additional surveillance capsules may be required to support the period of extended operation. Alternatively, an integrated surveillance program covering the extended operation period may be established for reactors with similar design and operating characteristics, in accordance with 10 CFR Part 50, Appendix H, Paragraph III.C. In either case, additional surveillance capsules may be necessary to support the period of extended operation.

The inspectors confirmed the licensee completed the required commitments and revised the procedures associated with this program prior to the period of extended operation.

Based on the review of the procedures, records, and discussions with licensee personnel, the inspectors did not identify any findings or violations of more than minor significance for this aging management program.

(30) A.1.38 RG 1.127, Inspection of Water-Control Structures Associated with Nuclear Power Plants This is an existing program that is associated with the Nuclear Power Plants Program and performed under the Structures Monitoring Program to manage the effects of aging on structures in the scope of license renewal through periodic visual inspections.

Commitment 26 specified:

Enhance the RG 1.127, Inspection of Water-Control Structures Associated with Nuclear Power Plants Program as described in LRA Section A.1.38.

The program entails visual inspections of water-control components and structures within the scope of license renewal. For each structure/aging effect combination, the specific parameters monitored or inspected were selected to ensure that aging degradation leading to loss of intended functions is detected and the extent of degradation is determined.

The program monitors and inspects structures credited for emergency cooling service and flood protection. Structural components and commodities include reinforced concrete members, structural steel, structural bolting, and earthen material.

The water-control structures do not include embankment structures, spillway structures and outlet work, reservoirs, cooling water channels and canals, an intake pumping structure, and intake and discharge canals often associated with emergency cooling water systems. Therefore, steel or wood piles and sheeting required for the stability of embankments and channel slopes, and miscellaneous items, such as sluice gates and trash racks are not applicable.

Based on the review of the procedures, records, and discussions with licensee personnel, the inspectors did not identify any findings or violations of more than minor significance for this aging management program.

(31) A.1.39 Selective Leaching The program includes a one-time visual inspection of selected components coupled with other mechanical examination techniques to determine whether loss of material is occurring due to selective leaching that may affect the ability of a component to perform its intended function through the period of extended operation. Either destructive testing or laboratory analysis is necessary to identify selective leaching in certain materials.

Commitment 27 specified:

Implement the Selective Leaching Program as described in LRA Section A.1.39.

The licensee revised the USAR information using LBDCR 01A.00-021 to reflect that the Selective Leaching Program will continue in the period of extended operation for gray cast iron components in raw water and soil and copper alloy components in treated water. This is needed to address selective leaching being identified in these material and environment combinations during inspections prior to the period of extended operation. The inspectors had no concerns with this change.

The inspectors reviewed inspection results, engineering reports, work activities, implementing procedures and interviewed license renewal project personnel. The program was implemented within the last 5 years of the period of extended operation per the LRA. The inspectors determined that the licensee used the aging management program guidelines in NUREG-2191,Section XI.M33, Selective Leaching, for implementing the one-time selective leaching sample sizes and for developing the periodic program that will be implemented during the period of extended operation. Specifically, the program sample size included selected components (20 percent of the population with a maximum of 25 components)fabricated from gray cast iron and certain copper/zinc alloys that were in an environment of raw water, wastewater, treated water, or soil. The sample population focused on components most susceptible to aging due to time in service, severity of operating condition, and lowest design margin.

The inspectors confirmed that the licensee fulfilled all required commitments and implemented the associated procedures prior to the period of extended operation.

Disassembled components were not available for inspection during this review. The program identified selective leaching, highlighting the need for continued inspections throughout the extended period of operation. The inspectors concluded that the licensee completed the necessary actions and developed the Selective Leaching Program in accordance with NRC guidance.

Based on the review of the procedures, records, and discussion with licensee personnel, the inspectors did not identify any findings or violations of more than minor significance for this aging management program.

(32) A.1.40 Service Water Integrity This existing program manages the aging effects of loss of material, cracking and fouling due to micro-or macro-organisms and various corrosion mechanisms on standby service water (SSW) system components and components cooled by standby service water.

The Service Water Integrity Program, in accordance with NRC Generic Letter 89-13 commitments, includes condition and performance monitoring, which inspects components for erosion, corrosion and blockage and verifies the heat transfer capability of the safety-related heat exchangers cooled by SSW. Chemical treatment using biocides and chlorine and periodic cleaning and flushing of redundant or infrequently used loops are the methods used to control or prevent fouling within the heat exchangers and loss of material in safety-related SSW components.

Commitment 31 specified:

Enhance the Service Water Integrity Program as described in LRA Section A.1.40.

The Service Water Integrity Program manages loss of material and reduction of heat transfer for service water system components fabricated from carbon steel, carbon steel with copper cladding, stainless steel, and copper alloy in an environment of treated water. The program includes periodic

(a) testing of the RHR heat exchangers to verify heat transfer capability,

(b) inspection and maintenance of the auxiliary building unit coolers,

(c) routine maintenance (cleaning) of the RHR heat exchanger radiation monitor coolers, and

(d) routine maintenance (cleaning) of the penetration valve leakage control system compressor aftercoolers. The program includes inspecting the safety-related carbon steel piping in the standby service water cooling tower exposed to raw water. Inspections will include submerged piping and distribution piping in the tower at locations with an air-to-water interface. The nozzles on the standby service water distribution piping are inspected.

Based on the review of the procedures, records, and discussion with licensee personnel, the inspectors did not identify any findings or violations of more than minor significance for this aging management program.

(33) A.1.41 Structures Monitoring The Structures Monitoring Program manages the effects of aging on structures and structural components, including structural bolting, within the scope of license renewal. The program was developed based on guidance in RG 1.160, Revision 2, "Monitoring the Effectiveness of Maintenance at Nuclear Power Plants," and NUMARC 93-01, Revision 2, "Industry Guidelines for Monitoring the Effectiveness of Maintenance at Nuclear Power Plants," to satisfy the requirement of 10 CFR 50.65.

Commitment 28 specified:

Enhance the Structures Monitoring Program as described in the LRA Section A.1.41.

Enhancements:

• Include the following in-scope structures:

o auxiliary control building o

circulating water switchgear house number 1 o

condensate storage tank foundation o

electrical tunnels and piping tunnels o

fire protection storage tanks foundation o

fuel oil storage tank foundation o

manholes, handholes and duct banks o

transformer and switchyard support structures and foundations

• Include a list of structural components and commodities within the scope of license renewal.

• Include periodic sampling and chemical analysis of ground water.

• Procure bolting greater than one inch in diameter to only procure bolting material with actual measured yield strength less than 150 ksi.

• Include the preventive actions for storage of ASTM A325, ASTM F1852, and ASTM A490 bolting from Section 2 of Research Council on Structural Connections publication, "Specification for Structural Joints Using ASTM A325 or A490 Bolts."

• Include the following parameters to be monitored or inspected:

o For concrete structures and components, include loss of material, loss of bond, increase in porosity and permeability, loss of strength, and reduction in concrete anchor capacity due to local concrete degradation.

o For chemical analysis of ground water, monitor pH, chlorides and sulfates.

• Include the following components to be monitored for the associated parameters:

o Anchor bolts (nuts and bolts) for loss of material, and loose or missing nuts and bolts.

o Elastomeric vibration isolators and structural sealants for cracking, loss of material, loss of sealing, and change in material properties (e.g.,

hardening).

• Include the following:

o Visual inspection of elastomeric material should be supplemented by feel or touch to detect hardening if the intended function of the elastomeric material is suspected. Include instructions to augment the visual examination of elastomeric material with physical manipulation of at least 10 percent of available surface area.

o Inspection of submerged structures at the same inspection interval and limitations as the other structures in the program.

o Sampling and chemical analysis of ground water at least once every five years. The program owner will review the results and evaluate any anomalies and perform trending of the results.

o Inspections of the service water cooling system cooling tower fill material.

A sample coupon of similar material shall be provided that will indicate potential fouling. The periodic visual inspection at a frequency of once every five years is intended to detect whether fouling is occurring.

• Including acceptance criteria for the inspection of cooling tower fill will be the absence of fouling.

• Include conditions of cooling tower fill that do not meet the acceptance criteria will be entered into the corrective action program for evaluation.

The licensee revised the USAR through LBDCR 01A.00-008 to clarify that inspection of the service water cooling tower fill material is not required, as it has a limited service life and is periodically replaced. Consequently, aging management in accordance with 10 CFR 54.21(a)(1)(ii) is not applicable to this material. The inspectors had no concerns with this change.

The inspectors conducted walkdowns of the control building, diesel generator building, standby cooling tower, and the category B electrical tunnel. During the inspection, the inspectors noted that water seepage through a service water pipe penetration in the B tunnel, which had been previously documented in condition reports CR-RBS-2021-00128 and CR-RBS-2021-00566. Repairs for this leak are scheduled by implementing work order 00557250-01 and the condition reports were closed. The inspectors reviewed the aging management program basis document, implementing procedures, work orders, and results from completed inspections. The inspectors also interviewed the program owner and reviewed license renewal documents, drawings, and related procedures.

The inspectors confirmed that procedure EN-DC-150, "Condition Monitoring of Maintenance Rule Structures," Revision 18, established structural inspection intervals of five years for High-Risk Significant structures and ten years for Low-Risk Significant structures. The procedure also includes provisions for identifying nonconforming conditions and expands the structural monitoring program to include additional inspection areas. For certain normally inaccessible areas within High-Risk Significant structures, the inspection interval may be extended to ten years due to the potential risks and the extensive effort required to perform the inspections. The inspectors verified that the licensee had fulfilled the required commitments and implemented the procedures associated with this program prior to the period of extended operation.

Based on the review of the procedures, records, and discussions with licensee personnel, the inspectors did not identify any findings or violations of more than minor significance for this aging management program.

(34) A.1.42 Water Chemistry Control BWR Program This existing program manages loss of material, cracking, change in material properties, and reduction of heat transfer in components in an environment of treated water through periodic monitoring and control of water chemistry.

The program monitors and controls chemical species and water quality to keep levels of various contaminants below system-specific limits based on EPRI BWR water chemistry guidelines.

The One-Time Inspection Program (Section A.1.32) uses inspections or non-destructive examinations of representative samples to verify that the Water Chemistry Control BWR Program has been effective at managing aging effects. The representative sample includes low flow and stagnant areas.

Procedure CSP-0006, Chemistry Surveillance and Scheduling System, describes the process used to complete and document chemistry surveillances. Attachments to the procedure include surveillance schedules for applicable systems and components.

Based on the review of the procedures, records, and discussion with licensee personnel, the inspectors did not identify any findings or violations of more than minor significance for this aging management program.

(35) A.1.43 Water Chemistry Control - Closed Treated Water Systems This existing program manages internal aging effects in the following closed, treated water systems.

• normal service water system (SWP, 118)

• reactor plant component cooling water (CCP, 115)

• turbine plant component cooling water system (CCS, 116)

• control building chilled water systems (HVK, 410)

• ventilation chilled water (HVN, 410: turbine building and radwaste)

• diesel engine jacket cooling water (Divisions I, II & III) (309)

• firewater diesel engine jacket cooling water (FPW, 251)

Commitment 29 specified:

Enhance the Water Chemistry Control - Closed Treated Water System Program as described in LRA Section A.1.43.

Inspection of select components is undertaken to verify the effectiveness of the chemistry control program and to ensure that significant degradation is not occurring, and the component intended function is maintained during the period of extended operation.

Components inspected will be those with the highest likelihood of corrosion or cracking. A representative sample is 20 percent of the population (defined as components having the same material, environment, and aging effect combination)with a maximum of 25 components. The inspection methods will be in accordance with applicable ASME Code requirements, industry standards, or other plant-specific inspection and personnel qualification procedures that ensure the capability of detecting cracking and loss of material caused by corrosion.

Based on the review of the procedures, records, and discussion with licensee personnel, the inspectors did not identify any findings or violations of more than minor significance for this aging management program.

(36) A.1.44 Metal-Enclosed Bus This is a new aging management program not originally credited in the license renewal amendment request. Subsequent review determined that the power supply paths from the preferred station transformers RTX-XSR1E and RTX-XSR1F to 13.8 kV switchgear NPS-SWG1A and NPS-SWG1B perform a license renewal intended function and include metal-enclosed bus, RTX-BD1A and RTX-BD1B. While not an original commitment, the licensee has established the aging management program following the guidance in the GALL,Section XI.E4, "Metal Enclosed Bus,"

including adding the program to the USAR Appendix A, Section 1.44 as a commitment to implement and maintain.

The bus enclosure internal surfaces are visually inspected for evidence of loss of material, aging degradation of the insulating supports, cracks, corrosion, foreign debris, excessive dust buildup, and evidence of moisture intrusion. Bus insulation is visually inspected for signs of embrittlement, cracking, melting, swelling, surface contamination, and discoloration. The internal bus insulating supports, or insulators are inspected for structural integrity, signs of cracks, and loose or damaged mounting hardware. External surfaces are visually inspected for loss of material. Accessible elastomers (e.g., gaskets, boots, and sealants) are inspected for indications of change in material properties, such as surface cracks. A sample of accessible bolted electrical connections are tested for increased connection resistance by thermography or by measuring connection resistance. A representative sample is 20 percent of the population with a maximum sample of 25. Inspections in the period of extended operation, including sampling of accessible bolted connections, are performed at least once every 8 years to coordinate with existing scheduled bus divisional outages. LBDCR 0A.01-007 was written to document this change.

Entergy procedure EN-DC-349, Metal Enclosed Bus Inspection Procedure, provides direction for implementation of the program.

Based on the review of the procedures, records, and discussions with licensee personnel, the inspectors did not identify any findings or violations of more than minor significance for this aging management program for the samples reviewed.

INSPECTION RESULTS

Observation: Aboveground Metallic Tank 71003 In 2014, an internal inspection of the condensate storage tank (CST) CNS-TK1 was completed per work order (WO) 397884, CNS-TK1 Internal Tank Inspection, and the results documented in BOP-VE-14-041, Internal Inspection Report. No signs of material loss were found during inspections, and the licensee concluded there is reasonable assurance that the tank interior is not experiencing material loss. As part of the license renewal application process, the licensee issued letter RBG-47818, Response to License Renewal Application NRC Request for Additional Information - Set 7, dated February 7, 2018, (ADAMS Accession No. ML18087A164) and committed to inspecting the CSTs interior and exterior surfaces, including visual inspections of the multi-layer vapor barrier sealing the tank-to-foundation interface, and ultrasonic testing (UT) of the tank bottom to measure thickness whenever the tank is drained and every 10 years beginning 10 years prior to the period of extended operation. Tank bottom thickness is checked using either UT on select areas or full low-frequency electromagnetic testing scanning around the outer 18 inches and that suspect areas were to be confirmed with UT.

On December 6, 2022, an internal inspection of CNS-TK1 was performed under WO 00564391 and only 60 to 70 percent of the tank was cleaned, preventing inspection of the tank bottom. WTRBS-2019-00339 CA-24 was initiated to plan further cleaning, but following an engineering evaluation, CA-24 concluded that no additional internal inspections of the CST were necessary. The licensee noted that the only license renewal intended function of the CST is to provide a 4-hour coping time for station blackout.

The licensee initiated a Licensing Basis Document Change Request (LBDCR) to revise the RBS commitment and updated the Process Applicability Document (PAD) to support the change. The licensee evaluated the change using the corporate 10 CFR 50.59 process, starting with the PAD. The PAD concluded that eliminating periodic visual and UT exams of the CST bottom does not adversely affect the CSTs license renewal intended function. Per procedure EN-LI-100, Process Applicability Determination, the licensee concluded that no 10 CFR 50.59 evaluation was needed, and thus no license amendment was required. On February 22, 2024, the licensee approved LBDCR 01A.00-017 to change to USAR Section A.1.1 to allow CST level monitoring in lieu of CST internal visual and volumetric inspections.

The licensee credits the concrete foundation filled with clean, dry sand that is sloped to direct moisture away from the tank, along with a multi-layer vapor barrier sealing the tank-to-concrete interface, as key measures to control corrosion of the tank bottom. The vapor barrier beneath the CST is not externally visible. To prevent moisture intrusion, the licensee applied for Thiokol 2235M/2282 Polysulfide Sealant per engineering change EC 87382 and WO 563529. The licensee concluded that corrosion is mitigated through this sealed tank-to-foundation interface, inspected under PM0002566002, with additional exterior checks during outages.

The licensee concluded that CSTs robust moisture barrier, corrosion-resistant aluminum alloy 5454, and favorable industry experience support its reliability and that even with leakage, operating margins ensure it meets safety functions. The licensee determined that the UT exam, added during license renewal per NRC guidance, was not part of the original license. After unsuccessful UT attempts, the licensee found inspections and design features provided adequate assurance that the CST will perform its license renewal intended function.

The inspectors evaluated whether the use of CST level monitors was an acceptable alternative to managing CST aging and degradation that could lead to tank leakage. The water makeup volume to the CST is not constant. Condensate storage tank transfers can occur to and from the condenser, the control rod drive system, and the spent fuel pool cooling system. Makeup to the CST can be from the makeup water system and from treated liquid radwaste tanks. The total makeup volume varies daily with plant operations, including transfers to/from the condenser, control rod drive system, and spent fuel pool, and makeup from water systems or treated radwaste.

Condensate storage tank level is checked once per shift from the auxiliary control room.

Condensate storage tank level is typically maintained between 23 and 28 feet using 330 gallons per minute (gpm) demineralizer makeup pumps, within an allowable range of 15 to 36 feet. For the week of May 5, 2025, usage averaged about 1 foot per shift. The inspectors reviewed historical data that showed weekly level fluctuations between 30.4 and 27.9 feet, and annual fluctuations between 30 and 21 feet. The licensee determined that leaks over 250 gpm for 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> (approximately 1 inch drop every 5 minutes) are considered detectable. The level monitoring system has an accuracy of +/-0.75 feet, per calibration report 1.ILCMS.021.

The inspectors reviewed procedures associated with monitoring CST level: CST annunciator response procedure, Alarm No. 0083, Condensate Storage Tank Level High/Low, OPS-0032, Revision 355, Data Sheet 2, Auxiliary Control Room Rounds, STP-000-0001, Revision 98, Data Sheet 1, Daily Operating Logs, and SOP-0008, Revision 029, Condensate Storage, Makeup and Transfer (SYSTEM #106). These procedures provided instructions for the operation of the condensate storage, makeup, and transfer system. None of these procedures identified a leak of over 250 gpm for 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> as criterion for a possible CST leak.

In the PAD, the licensee stated that an operating experience (OpE) review found no instances of loss of material on aluminum tanks exposed to soil. The inspectors conducted an OpE review and found corrosion of aluminum tank bottoms from the underside at LaSalle, which resulted in increasing tritium values, providing evidence of an active tank leak, and at Dresden. The LaSalle event document references similar events at St. Lucie in 1993, Braidwood and Oyster Creek (mid-1990s). The inspectors also identified OpE involving weld cracking of aluminum tank floor-mounted nozzle welds, due to voids in the sand below the tank creating an unsupported condition. The inspectors noted that WO 52525716-01, CNS-TK1 External Inspection, included as OpE the same events listed above.

Based on the erratic CST level trends during operations, the ability of the demineralizer makeup pumps to exceed the 250 gpm leak detection threshold, the absence of CST leak response actions in level monitoring procedures, and operating experience (OpE) highlighting corrosion risks for aluminum tanks in soilparticularly the LaSalle event involving a tritium leakthe inspectors concluded that the alternative to rely on CST level indicators to manage tank aging and degradation in place of the previously committed UT examinations was not adequate.

Additionally, the licensee missed a key opportunity to establish a baseline condition of the CST bottom in 2022, when the UT exam could not be completed due to insufficient tank cleaning.

This program will remain open and be reviewed by the NRC in a future inspection.

Observation: Diesel Fuel Monitoring 71003 The inspectors identified multiple instances where the licensee did not initiate condition reports (CRs) for out-of-spec diesel fuel oil in the fuel oil forwarding (FOF) tanks as follows:

1. On April 9, 2025, sludge and algae were discovered during cleaning and inspection of

tank FOF-TK1B under WO 53037843-06, but no CR was initiated until the NRC inspectors identified the issue. The licensee initiated CR-RBS-2025-03085.

2. The inspectors requested chemistry data to review, and the licensees review

revealed that both FOF-TK1A and FOF-TK1B had been out of specification for water and sediment per CSP-0100, Chemistry Required Surveillance, Revision 33, since January 14, 2025, yet no CR had been written until identified during the inspection.

The licensee initiated CR-RBS-2025-02914.

3. The inspectors also noted that there was a potential ongoing chemistry-related issues

associated with the FOF tanks, including earlier sludge and algae identification in FOF-TK1A on April 8, 2025, in WO 53037817-01 and documented in CR-RBS-2025-02336.

EXIT MEETINGS AND DEBRIEFS

The inspectors verified that no proprietary information was retained or documented in this report.

• On May 29, 2025, the inspectors presented the License Renewal inspection results to Phil Hansett, Site Vice President, and other members of the licensee staff.

DOCUMENTS REVIEWED

Inspection

Procedure

Type

Designation

Description or Title

Revision or

Date

CR-RBS-YYYY-NNNN

25-00714, 2010-00931, 2010-00932, 2014-

01338,

2016-00656, 2017-08166, 2019-00339, 2021-

00128,

21-00566, 2021-04418, 2022-06907, 2022-

06909,

23-01661, 2024-04840, 2025-02336, 2025-

03159

AR21004323

WT-WT-RBS-2019-00348-

CA-7

WT-WTHQN-2021-00044-

00148

WT-WTRBS-2019-00348-

00009

WT-WTRBS-2019-00348-

00010

WT-WTRBS-2019-00348-CA-

WTHQN-2021-00044 CA 148

WTRBS-2019-00348 CA 10

WTRBS-2019-00348 CA 11

Corrective

Action

Documents

WTRBS-2019-00348 CA 9

Corrective

Action

Documents

Resulting from

Inspection

CR-RBS-YYYY-NNNN

25-02881, 2025-02882, 2025-02891, 2025-

2914,

25-03085, 2025-03136, 2025-02884

26D9370

Metal-Enclosed Bus Duct 15 kV 3/8 X 6 CU

005

26D9370

Metal-Enclosed Bus 15 kV - 3/8 X 6 CU

006

D-76-630

Standby Diesel Gen Fuel Oil Storage Tank

71003

Drawings

EE-001AC

Start Up Electrical Distribution Chart

063

Inspection

Procedure

Type

Designation

Description or Title

Revision or

Date

EE-032A

Arrangement Ductline Plan & Detail

011

Engineering

Changes

RBS-EC-0000087382

237.300 SPEC UPDATE TO INCLUDE CHIME

REPAIR METHOD

11/16/2020

1500837.312

Recalculation of Cumulative Usage Factor for RPV

Closure Studs Including Consideration of 60-Year

Projected Cycles

000

FP-RBS-306

Fatigue Update for River Bend Nuclear Station

using SI: FatiguePro 4 Software

306

FP-RBS-403

Cycle-Based Fatigue Report for the Transient and

Fatigue Monitoring System for River Bend Station

2/31/2021

PQE - RBS - General Atomic -

E-254-960

RADIATION DETECTOR

000

PQE - RBS - General Atomic -

E-255-1047

RADIATION DETECTOR

000

PQE - RBS - General Atomic -

E-255-1081

RADIATION DETECTOR

001

PQE - RBS - Magnetrol -

NEDC-30378

LEVEL SWITCH

000

PQE - RBS - Okonite -

NQRN-3

SPLICE TAPE

000

PQE - RBS - Raychem -

EDR-5336

Raychem Splice

000

PQE - RBS - Rosemount -

108026

TRANSMITTER

000

PQE - RBS - Rosemount -

D8300152

CONDUIT SEAL

000

PQE - RBS - Southern

Transformer - RBS-242.132-

290

TRANSFORMER

000

PQE - RBS - Square D -

20016

PANEL

000

PQE - RBS - Static-O-Ring -

17344-82N-D

PRESSURE SWITCH

000

Engineering

Evaluations

PQE - RBS - Static-O-Ring -

TEMPERATURE SWITCH

000

Inspection

Procedure

Type

Designation

Description or Title

Revision or

Date

9058-102

RBS-EP-1.9-00014

Review of the Compressed Air Monitoring Program

for License Renewal lmplementation

000

RBS-EP-15-00007

Aging Management Program Evaluation Results

Non-Class 1 Mechanical (Partial) - Neutron

Absorbing Material Monitoring Program

001

RBS-EP-17-00005

Review of Past Cycle Counts for Accuracy

000

RBS-EP-19-00004

Review of the Aboveground Metallic Tanks

Program for License Renewal Implementation

000

RBS-EP-19-00006

Review of the Neutron Absorbing Material

Monitoring Program for License Renewal

Implementation

000

RBS-EP-19-00009

Review of the BWR Feedwater Nozzle Program for

License Renewal Implementation

000

RBS-EP-19-00010

Review of the BWR Penetrations Program for

License Renewal Implementation

000

RBS-EP-19-00014

Review of the Compressed Air Monitoring Program

for License Renewal Implementation

000

RBS-EP-19-00018

Review of the Compressed Air Monitoring Program

for License Renewal Implementation

000

RBS-EP-19-00021

Review of the Fatigue Monitoring Program for

License Renewal Implementation

06/04/2020

RBS-EP-19-00024

Review of the Flow-Accelerated Corrosion

Program for License Renewal Implementation

000

RBS-EP-19-00035

Review of the One-Time Inspection Program for

License Renewal Implementation

000

RBS-EP-19-00036

Review of the One-Time Inspection - Small-Bore

Piping Program for License Renewal

Implementation

000

RBS-EP-19-00037

Review of the Periodic Surveillance and

Preventive Maintenance Program for License

Renewal Implementation

000

RBS-EP-19-00039

Review of the Reactor Head Closure Studs

Program for License Renewal Implementation

Inspection

Procedure

Type

Designation

Description or Title

Revision or

Date

RBS-EP-19-00040

Review of the Reactor Vessel Surveillance

Program for License Renewal Implementation

05/07/2020

RBS-EP-19-00042

Selective Leaching Program for License Renewal

Implementation

2/02/2019

RBS-EP-19-00044

Structures Monitoring Program for LR

Implementation

04/15/2020

RBS-EP-19-00052

Review of the Metal Enclosed Bus Inspection

Program

000

RBS-EP-22-00006

Fitness for Service Evaluation for FPW-12-001-4

per License Renewal Commitment for Buried Pipe,

Deep Pit replacement

001

RBS-EP-23-00004

License Renewal One-time Inspection - Small-

Bore Piping Welds Program Report

000

RBS-EP-23-

00009REV000EC0054130459

Analysis of a Pitted Cast Gray Iron Pipe Section

01/2024

RBS-EP-23-

00010EC0054130459

METALLURGICAL ANALYSIS OF PIPING WITH

A 13 FOOT-9 INCH LONGITUDINAL CRACK

(EXCAVATION #3)

RBS-EP-24-00006

Analysis of a Damaged Heat Exchanger

01/23/2025

RBS-EP-25-00001

License Renewal One-time Inspection Program

Report

000

RBS-EP-25-00003

Selective Leaching Program Inspection Report

2/03/2025

SEP-AMP-RBS-003

RBS Selective Leaching Program

03/04/2025

Instruction Manual - 13.8kV Metal-Clad Switchgear

and Bus Ducts

07/09/1979

Letter from C Billings to C Johnston, RE:

Inspection and Testing of Boralcan Surveillance

Coupons

from River Bend Power Station Review

01/08/2025

LBDCR 01A.00-008

Clarify Inspection of Service Water Cooling Tower

Fill Material Not Required

05/17/2022

Miscellaneous

DRN-21-0649

Perform editorial change at next revision to correct

commitment identified in Step 2.3.6

to read "36186" and change A.1.2 to read A.1.3.

05/26/2021

Inspection

Procedure

Type

Designation

Description or Title

Revision or

Date

Att 9.3 should be Att 3

LBDCR - 01A.00.017

Allow CST level monitoring in lieu of CST internal

visual and volumetric inspections. See additional

pages for discussion

2/15/2024

LBDCR 01A.00-010

Commitment Change to Periodic Surveillance and

Preventive Maintenance Aging Management

Program

08/29/2022

LBDCR 01A.00-017

Change to USAR Section A.1.1 to delete the aging

management program activities of performing

periodic visual inspection of condensate storage

tank (CST) internals and periodic volumetric

examination of the CST bottom.

10/20/2023

LBDCR 01A.00-019

Commitment Change to Periodic Surveillance and

Preventive Maintenance Aging Management

Program to transfer inspection of SWP casing

08/13/2024

LBDCR 01A.00-020

Revise USAR Section A.1.34 to remove the

enhancement for inspection of abandoned reactor

water cleanup system components

11/27/2024

LBDCR 01A.00-021

Revise Section A.1.39 of the USAR to reflect that

the Selective Leaching program will continue

during the period of extended operation.

2/05/2024

LBDCR 0A.01-002

Revision to USAR section A.1.12 Compressed Air

Monitoring

01/05/2021

LBDCR 0A.01-004

Editorial corrections in accordance with EN-LI-113

LBDCR-01A.00-008

Structures Monitoring Program enhancement

description in USAR Section A.1.41 needs revision

05/04/2022

LR-LAR-2018-00201

License Renewal Application Update - Neutron

Absorbing Material Monitoring Program

2/27/2020

MRR 78-2452

Reactor Vessel Studs Receipt Inspection Report

11/17/1978

NET-28096-010-01

Inspection and Testing of Boralcan' Surveillance

Coupons from River Bend Power Station

000

PMC-046441

Inspect Carbon Steel Submerged Bolting

Assemblies in the Standby Service Water Clg Twr,

SWP-TWR1

04/11/2024

Inspection

Procedure

Type

Designation

Description or Title

Revision or

Date

PMC-046447

Inspect Threaded Studs and Nuts on SWC-EJ11A

2/13/2025

PMC-051353

Change Tolerance for New PMs per PMC-24-

046440 & PM 24-046441

01/29/2025

PMC-23-046440

Inspect DFR-PSA and DFR-PSB carbon steel

submerged bolting

01/31/2025

PMC-23-046446

B21-RVF041F - REPLACE MAIN STEAM

SAFETY RELIEF VALVE

04/19/2024

PMCR-2021-21006568

Change task frequency from 3650 days +/- 25% to

once every Cycle.

2/21/2023

RBG-47830

License Renewal Application Update - Neutron

Absorbing Material Monitoring Program

2/15/18

RBS-EP-25-00001

License Renewal One-time Inspection Program

Report

000

WT-WTRBS-2016-00068-

00012

Pursue an alternate solution of using OSI PI to

retrieve missing cycle 18 fatigue (Collect) data

between November 2012 to September 2013

000

WT-WTRBS-2019-00370

Work Tracker for implementation of added scope

to One-Time Inspection aging management

program

WT-WTRBS-2019-00372

Work Tracker for implementation of Periodic

Surveillance and Preventive Maintenance aging

management program

WT-WTRBS-2019-271, CA-74

Work Tracker for implementation of One-Time

Inspection program potential discrepancy actions

EN-DC-130

Entergy Reactor Vessel Internals Management

(RVIM) Program

010

ISI-UT-19-021

Feedwater Nozzle N4 (B13-D001-N04A-0) UT

Examination Report

04/17/2019

ISI-UT-19-022

Feedwater Nozzle N4 (B13-D001-N04B-0) UT

Examination Report

04/17/2019

RBS RF-20

Reactor Vessel Internals Management Program

Post-Outage Report

000

NDE Reports

RBS-EP-21-00002

River Bend Station RF-21 In-Vessel Visual

Inspection (IVVI) Final Report

06/17/2021

Inspection

Procedure

Type

Designation

Description or Title

Revision or

Date

RBS-EP-21-00002

RBS RF-21 In-Vessel Visual Inspection (IVVI)

Final Report

000

RBS-EP-21-00003

RBS RF-21 Reactor Vessel Internals Management

(RVIM) Program Post-Outage Report

000

RBS-EP-23-00002

River Bend Station RF-22 In-vessel Visual

Inspection (IVVI) Final Report

03/11/2023

RBS-EP-23-00003

RBS RF-22 Reactor Vessel Internals Management

(RVIM) Program Post-Outage Report

05/31/2023

SEP-RVI-003

RIVER BEND STATION REACTOR VESSEL

INTERNALS (RVI) INSPECTION PROGRAM

PLAN

2

EN-DC-313

Procurement Engineering Process

23

AOP-0029

Severe Weather Operation

049

CEP-PT-001

ASME SECTION XI PRESSURE TEST (PT)

PROGRAM

10/12/2022

CEP-RR-001

ASME SECTION XI REPAIR/REPLACEMENT

PROGRAM

20

CEP-RVI-001

REACTOR VESSEL INTERNALS MANAGEMENT

(RVIM) PROGRAM PLAN

013

COP-0043

SAMPLING INSTRUMENT AIR SYSTEMS FOR

PARTICULATE AND OIL ANALYSES

005

CSP-0100

CHEMISTRY - REQUIRED SURVEILLANCES

AND ACTIONS

033

CSP-0131

Receipt, Storage, and Handling of Diesel Fuel

used in Standby Diesel Engines

308

EN-DC-141

Design Inputs

019

EN-DC-150

Condition Monitoring of Maintenance Rule

Structures

018

EN-DC-159

System and Component Monitoring

23

EN-DC-164

Environmental Qualification (EQ) Program

008

EN-DC-178

System Walkdowns

017

EN-DC-315

Flow Accelerated Corrosion Program

019

Procedures

EN-DC-334

Primary Containment Leakage Rate Testing

Appendix J)

005

Inspection

Procedure

Type

Designation

Description or Title

Revision or

Date

EN-DC-342

Entergy Repair/Replacement Program

004

EN-DC-346

Cable Reliability Program

009

EN-DC-349

Metal Enclosed Bus Inspection Procedure 005

EN-DC-360

Erosion Program

007

EN-DC-362

Conduct of Plant Engineering

005

EN-EV-112

Chemical Control Program

25

EN-FAP-LR-024

One-Time Inspection

010

EN-FAP-LR-025

Selective Leaching Inspection

007

EN-LI-100

Process Applicability Determination

035

EN-LI-110

Commitment Management Program

015

EN-MA-119-01

Control, Storage, and Inspection of Lifting

Equipment

2

EN-MA-121

Fluid Leak Prevention and Management Program

008

EN-MA-138

VLF Tan Delta Withstand Testing of Electrical

Power Cables

008

EN-MA-145

Maintenance Standard for Torque Applications

011

EN-MP-125

Control of Material

21

EN-MS-S-011-MULTI

Conduct of System & Components Engineering

2

EN-P-S-002-MULTI

Underground Piping and Tanks General Visual

Inspection

005

FPP-0101

Fire Suppression System Inspection

018

FPP-0102

Internal Visual Inspection of Fire water piping

systems

000

FPP-0116

Hose Rack HR96 Full Flow Test

000

FPP-0117

Standpipe Hose Main Drain Test (FPW)

000

FPP-0118

Internal Visual Inspection of Auxiliary Building and

Diesel Generator Building Pre-Action System's

Piping

001

FPP-0122

Internal Visual Inspection of Fire Water Piping

Systems WS-6A, WS-6B, WS-6C, WS-8D, WS-

8E, WS-8F, WS-8G, WS-8H, WS-8K, WS-8L, WS-

8M, WS-8N, WS-19, AND

WS-20

000

Inspection

Procedure

Type

Designation

Description or Title

Revision or

Date

FPP-0123

Internal Visual Inspection of Fire Water Wet Piping

Systems AS-5, AS-12, AS-6A, AS-6B, AND AS-6C

000

GMP-0102

Reactor Vessel Disassembly

28

GMP-0103

Reactor Vessel Assembly

RBS EC-82967

LLRT Frequency Determination NEI 94-01

000

RBS-CS-24-00001

24 Maintenance Rule Structures Periodic

Assessment

RBS-EE-15-00001

Electrical Screening and Aging management

Review

2

RBS-EP-19-00005

Review of the Bolting Integrity Program for License

Renewal Implementation

000

RBS-EP-19-00013

Review of the BWR Vessel Internals Program for

License Renewal Implementation

000

RBS-EP-19-00019

Review of the Environmental Qualification (EQ) of

Electric Components Program for License

Renewal

000

RBS-EP-19-00020

Review of the External Surfaces Monitoring

Program for License Renewal Implementation.

000

RBS-EP-19-00020

Review of the External Surfaces Monitoring

Program for

License Renewal Implementation

000

RBS-EP-19-00022

Review of the Fire Protection Program for License

Renewal Implementation.

000

RBS-EP-19-00023

Review of the Fire Water System Program for

License Renewal Implementation

001

RBS-EP-19-00025

Review of the Inservice Inspection Program for

License Renewal Implementation

000

RBS-EP-19-00027

Review of the Inspection of Overhead Heavy Load

and Light Load (Related to Refueling) Handling

Systems Program for License Renewal

Implementation

000

RBS-EP-19-00028

Review of the Internal Surfaces in Miscellaneous

Piping and Ducting Components Program for

License Renewal Implementation

000

Inspection

Procedure

Type

Designation

Description or Title

Revision or

Date

RBS-EP-19-00031

Review of the Non-EQ Inaccessible Power Cables

(> or = to 400 V) Program for License Renewal

Implementation

000

RBS-EP-19-0017

Review of the Containment Leak Rate Program for

License Renewal Implementation

000

RBS-EP-21-0004

RBS License Renewal Site Soil Sample Results

000

REP-0007

• Spent Fuel Pool Snap-In(R) Insert Surveillance

Program

008

SEP-AMP-RBS-001

RBS Opportunistic Inspections for Aging

Management Programs

000

SEP-AMP-RBS-001

RBS Opportunistic Inspections for Aging

Management Programs

7/29/2024

SEP-AMP-RBS-001

RBS Opportunistic Inspections for Aging

Management Programs

000

SEP-AMP-RBS-001-01

In-Scope Components for RBS Opportunistic

Inspections for Aging Management Programs

000

SEP-AMP-RBS-001-01

In-Scope Components for RBS Opportunistic

Inspections for Aging Management Programs

10/07/2024

SEP-AMP-RBS-001-01

In-Scope Components for RBS Opportunistic

Inspections for Aging Management Programs

000

SEP-AMP-RBS-002

External Surfaces Monitoring (Corrosion Under

Insulation) Inspection Program

000

SEP-AMT-RBS-001

Aboveground Metallic Tank Program

2

SEP-FTP-RBS

Entergy Nuclear South Engineering Programs

SEP-ISI-104

PROGRAM SECTION FOR ASME SECTION XI,

DIVISION 1 WF3 INSERVICE INSPECTION

PROGRAM

017

SEP-ISI-RBS-001

PROGRAM SECTION FOR ASME SECTION XI,

DIVISION 1 RBS INSERVICE INSPECTION

PROGRAM

2

SEP-PT-RBS-OO1

Inservice Inspection Ppressure Testing (PT)

001

SEP-RVI-003

River Bend Station Reactor Vessel Internals (RVI)

Inspection Program Plan

2

STP-000-3602

Fire Barrier Visual Inspection

018

Inspection

Procedure

Type

Designation

Description or Title

Revision or

Date

STP-057-3703

Primary Reactor Containment Integrated Leak

Rate

309

STP-251-3601

Fire Protection Sprinkler Header/Nozzle Inpsection

014

STP-251-3700

Fire System Yard Water Suppression Loop Flow

Test

018

STP-251-3700

Fire System Water Suppression Loop Flow Test

018

SUP-UIP-RBS

Underground Components Inspection Plan Non-

Rad and Rad Piping

008

TR-108147

Compressor and Instrument Air System

Maintenance Guide

03/1998

TSP-0028

Periodic Sampling of Plant Compressed Air

Systems

307

Work Orders

00555566, 00592244, 52715412, 52823928,

2930067, 52937283, 52990961, 53037323,

00563529, 52462311, 53027300, 00570119,

2864860, 52901382, 52906023, 52969290,

00524854, 52882578, 52737654, 00534419,

00534422, 00446646, 00558664, 53037843,

00446646, 00558664, 53037838, 00572206,

2962619, 52962620, 52718349, 00524854,

5035513, 552737654, 52882578, 52737654,

55725001, 00557250, 53037817, 54034457,

243727, 00257682, 52974691, 589397,

54148874-03, 53023920, 461114, 462215,

53026657, 54025785, 569078, 572760, 593361,

2991603, 53016944, 53016945, 53016946,

53019631, 53032603, 53032604, 53032605,

53032606, 53032607