ML25356A370
| ML25356A370 | |
| Person / Time | |
|---|---|
| Site: | South Texas  |
| Issue date: | 12/30/2025 |
| From: | Wes Cullum NRC/RGN-IV/DORS/EB2 |
| To: | Kharrl C South Texas |
| References | |
| IR 2025010 | |
| Download: ML25356A370 (0) | |
Text
December 30, 2025 Charles Kharrl, President CEO and CNO STP Nuclear Operating Company P.O. Box 289 Wadsworth, TX 77483
SUBJECT:
SOUTH TEXAS PROJECT STEAM ELECTRIC STATION, UNIT 2 - LICENSE RENEWAL INSPECTION REPORT 05000499/2025010
Dear Charles Kharrl:
On December 15, 2025, the U.S. Nuclear Regulatory Commission (NRC) completed an inspection at South Texas Project Steam Electric Station, Unit 2 and discussed the results of this inspection with Chris Georgeson, General Manager, Strategic Project & Engineering Design 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, Wes L. Cullum, Chief Engineering Branch 1 Division of Operating Reactor Safety Docket No. 05000499 License No. NPF-80
Enclosure:
As stated cc w/ encl: Distribution via LISTSERV Signed by Cullum, Wes on 12/30/25
SUNSI Review By: GAP
Non-Sensitive
Sensitive
Publicly Available
Non-Publicly Available OFFICE SRI:DORS/EB2 RI:DORS/EB2 BC:DORS/EB1 NAME GPick ARowe WCullum SIGNATURE
/RA/
/RA/
/RA/
DATE 12/22/25 12/23/25 12/30/25
Enclosure U.S. NUCLEAR REGULATORY COMMISSION Inspection Report Docket Number:
05000499 License Number:
NPF-80 Report Number:
05000499/2025010 Enterprise Identifier:
I-2025-010-0020 Licensee:
STP Nuclear Operating Company Facility:
South Texas Project Steam Electric Station, Units 1 and 2 Location:
Wadsworth, TX 77483 Inspection Dates:
December 8 - 15, 2025 Inspectors:
G. Pick, Senior Reactor Inspector A. Rowe, Reactor Inspector Approved By:
Wes L. Cullum, Chief Engineering Branch 1 Division of Operating Reactor Safety
2
SUMMARY
The U.S. Nuclear Regulatory Commission (NRC) continued monitoring the licensees performance by conducting a license renewal inspection at South Texas Project Steam Electric Station, Unit 2, 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.
3 INSPECTION SCOPES Inspections were conducted using the appropriate portions of the inspection procedures in effect at the beginning of the inspection unless otherwise noted. Currently approved inspection procedures 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 inspection procedure requirements most appropriate to the inspection activity were met consistent with Inspection Manual Chapter 2515, Light-Water Reactor Inspection Program - Operations Phase. 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 The inspectors performed an in-office Phase 1 inspection to review aging management programs and documentation. The planned onsite inspection to evaluate the material condition of South Texas Project, Unit 2, prior to the unit entering the period of extended operation, could not be completed because of the lapse in government activities. The period of extended operation is an additional 20 years beyond the original 40-year licensed term and begins after midnight on December 15, 2028.
During this in-office inspection, the inspectors evaluated whether the licensee: (1) completed the necessary actions to comply with the license condition and commitments related to aging management; and (2) implemented programs that agreed with those approved in the safety evaluation report and described in the updated final safety analysis report. NRC issued the safety evaluation report, Safety Evaluation Report Related to the License Renewal of South Texas Project, Units 1 and 2 (ML17146B242) in June 2017. Specific activities evaluated during this inspection are described in the following paragraphs.
Post-Approval Site Inspection for License Renewal (9 Samples)
(1)
Plant Condition Monitoring Walkdowns As described above, the inspectors did not complete the planned condition monitoring walk downs of normally inaccessible areas of the facility (i.e., containment). The walk downs allow inspectors to evaluate structures, systems, and components for signs of aging, such as corrosion on piping and supports, corrosion of cable trays, water intrusion, cracking, and spalling of concrete.
This aspect of the inspection will have another opportunity to be conducted during the next Unit 2 refueling outage estimated Spring 2027.
(2) 19A.1.4 Boric Acid Corrosion and Commitment 2 This existing program manages aging effects for loss of material and corrosion of mechanical connector contact surfaces caused by boric acid leakage. The program monitors nearby mechanical, electrical, and structural components that could be affected by boric acid corrosion from systems that contain treated borated water.
4 Commitment 2 specified:
Enhance the procedures to state that susceptible components adjacent to potential leakage sources include electrical components and connectors. The program will also state that it is applicable to other materials (such as aluminum and copper alloy).
The inspectors reviewed the aging management program basis document, work orders, condition reports, and implementing procedures, as well as interviewed the program owner. The inspectors determined that procedure 0PGP03-ZE-0133, Boric Acid Corrosion Control Program, specifically includes aluminum and copper alloy materials and electrical components and connectors, as specified in commitment 2.
The inspectors reviewed several corrective action documents that evaluated and documented the actions taken to resolve boric acid leakage. The inspectors determined that the licensee walked down the reactor containment building during each refueling outage and walked down the electrical auxiliary building and mechanical auxiliary building areas on each unit in areas containing reactor coolant system fluid looking for boric acid leaks.
Based on the review of the documents and discussions with licensee personnel, the inspectors did not identify any findings or violations of more than minor significance associated with this aging management program.
(3) 19A.1.6 Flow-Accelerated Corrosion This existing program manages aging effects related to wall thinning caused by flow-accelerated corrosion on the internal surfaces of carbon or low alloy steel piping and system components that contain high energy fluids (both single and two phase). The program also manages wall thinning caused by erosion/corrosion, cavitation, flashing, and impingement damage.
The inspectors reviewed the aging management program basis document, work orders, examination reports, engineering evaluations, condition reports, and implementing procedures, as well as interviewed the program owner. The inspectors determined that the program owner was knowledgeable of both flow-accelerated corrosion and erosion that resulted from erosion/corrosion, cavitation, flashing, and impingement damage. Procedure 0PGP04-ZA-0012, Flow Accelerated Corrosion Program, revision 8, utilized the electric power research institute CHECKWORKS program to manage flow-accelerated corrosion affecting carbon steel piping.
Procedure 0PGP04-ZA-0608, Erosion Program, revision 1, utilized FAC Manager web edition to manage erosion caused by erosion/corrosion, cavitation, flashing, and impingement damage on piping and components.
During discussions related to the basis for ongoing piping replacement, some confusion occurred related to which aging management program identified erosion/corrosion of ongoing essential cooling water piping replacements. Erosion had occurred on the essential cooling water piping, and two separate aging management programs discussed managing erosion of the piping (i.e., the open cycle cooling water and the flow-accelerated corrosion programs). The inspectors determined that the implementing procedures for each aging management program
5 provided a clear delineation related to the purpose of each program. The licensee initiated condition report 25-11388 to ensure that they have alignment between the aging management programs and the implementing procedures.
Based on the review of the documents and discussions with licensee personnel, the inspectors did not identify any findings or violations of more than minor significance associated with this aging management program.
(4) 19A.1.8 Steam Generator Tubing Integrity and Commitment 48 This existing program manages aging effects on steam generator tubes, plugs, sleeves, divider plate assemblies, tube-to-tubesheet welds, primary head (interior surfaces), tubesheet(s) (primary side), and secondary side components contained within the steam generator (i.e., secondary side internals).
Commitment 48 specified:
Enhance the steam generator tubing integrity program procedures to:
Visually inspect steam generator head internal areas (head interior surfaces, divider plate assemblies, tubesheets (primary side) and tube-to-tubesheet welds for signs of cracking or loss of material.
Conduct inspections at least every 72 effective full power months or every third refueling outage whichever results in more frequent inspections.
Evaluate the acceptability of any degraded conditions of the divider plate assemblies, tubesheets (primary side), tube-to-tubesheet welds, and primary head (interior surfaces) on a case-by-case basis.
The inspectors reviewed the aging management program basis document, implementing procedures, condition reports, work orders, inspection results, and license amendment, as well as interviewed the program owner. The inspectors determined that procedures 0PGP03-ZO-0044, Steam Generator Management Program, and 0PSP11-RC-0014, Steam Generator Inspection, required inspecting the listed steam generator internals and welds for signs of cracking or loss of material, evaluating the acceptability of degraded conditions on a case-by-case basis, and performing the inspections at the required frequency.
On December 9, 2021, NRC approved license amendment No. 209 implementing TSTF-577, Revised Frequencies for Steam Generator Tube Inspections. This amendment changed the steam generator inspection frequency from 72 to 96 effective full power months and from every third to every fifth refueling outage for thermally treated Alloy 690 steam generator tubing. The inspectors determined that the licensee appropriately changed the technical specifications and implementing procedures 0PGP03-ZO-0044 and 0PSP11-RC-0014. The inspectors determined the licensee had revised updated final safety analysis report table 19A.4-1, License Renewal Commitments, commitment 48 to reflect 96 effective full power months but had not changed updated final safety analysis report section 19A.1.8 Steam Generator Tube Integrity. The licensee initiated condition report 25-11389 to correct the updated final safety analysis report section. The inspectors determined the licensee implemented commitment 48.
6 Based on the review of the documents and discussions with licensee personnel, the inspectors did not identify any findings or violations of more than minor significance associated with this aging management program.
(5) 19A.1.23 Lubricating Oil Analysis and Commitment 18 This existing program manages aging effects related to loss of material, and reduction of heat transfer for components exposed to lubricating and hydraulic oil.
Commitment 18 specified:
Enhance the lubricating oil analysis program procedures to analyze the particle count of the lubricating oil for the centrifugal charging pumps and require evaluating and trending the sample analysis data results, for which no acceptance criteria is specified, against baseline data and data from previous samples to determine the acceptability of oil for continued use.
The inspectors reviewed the aging management program basis document, implementing procedures, work orders, and analysis results, as well as interviewed the program owner. The inspectors verified procedure 0PGP03-ZM-0004, Lubrication Program, revision 22, step 8.3.1 implemented commitment 18. In addition, the licensee had required the particle count and trending of lubricating oil for the reactor coolant pump motors and the various diesel generators.
Based on the review of the documents and discussions with licensee personnel, the inspectors did not identify any findings or violations of more than minor significance associated with this aging management program.
(6) 19A.1.30 10 CFR Part 50, Appendix J and Commitment 24 This existing program manages aging effects related to leakage from the containment, containment isolation valves, and containment penetrations for systems and components penetrating the primary containment. This program must meet the allowable leakage rate limits specified in the technical specifications.
Commitment 24 specified:
Establishing a surveillance frequency of 15 years following a successful type A test.
The inspectors reviewed the aging management program basis document, implementing procedures, work orders, and completed inspection results, as well as interviewed the program owner. The inspectors confirmed that procedure 0PSP11-ZA-0005, Local Leakage Rate Test Calculations, Guidelines, and Program, revision 22, specified the requirements to conduct integrated leak rate tests (type A) every 15 years and met commitment 24. The inspectors determined that the surveillance activities for the integrated leak rate tests had a 12-year frequency to ensure that the 15-year interval would not be exceeded since it does not allow for a grace period. The inspectors reviewed local leak rate testing results, as well as the last performance of the integrated leak rate test results for each unit, that demonstrated the licensee remained well with technical specification limits.
7 Based on the review of the documents and discussions with licensee personnel, the inspectors did not identify any findings or violations of more than minor significance associated with this aging management program.
(7) 19A.1.34 Nickel Alloy Aging Management and Commitment 31 (part A, reactor coolant system components)
This existing program manages aging effects by using various visual, surface, and volumetric examination techniques for early detection of primary water stress corrosion cracking in Nickel-Alloy 600 nozzle components and nickel-alloy penetration nozzles welded to the reactor pressure vessel closure heads exposed to reactor coolant.
Commitment 31, part A specified:
For reactor coolant system nickel-alloy pressure boundary components:
Implement applicable NRC orders, bulletins and generic letters associated with nickel-alloys, Implement staff-accepted industry guidelines, Participate in industry initiatives, such as owners group programs and the Electric Power Research Institute materials reliability program, for managing aging effects associated with nickel-alloys, and Not less than 24 months before entering the period of extended operation, submit an inspection plan for reactor coolant system nickel-alloy pressure boundary components to the NRC for review and approval.
The inspectors reviewed the aging management program basis document, implementing procedures, condition reports and completed inspection results, as well as interviewed the program owner. The inspectors confirmed that procedures 0PGP04-ZE-0006, Alloy Materials Management Program, and 0PGP04-ZA-0013, Reactor Coolant System Materials Management Program, incorporated applicable NRC orders, code cases, industry guidelines and industry initiatives as expected. The inspectors determined the program owner participated in the PWR owners group programs and Electric Power Research Institute materials reliability program, by serving on several materials reliability program focus groups. The inspectors verified the licensee submitted the nickel-alloy pressure boundary components inspection plan to the NRC as specified in letter NOC-AE-25004119 Nickel Alloy Inspection Plan, dated July 17, 2025. The inspectors determined the licensee implemented commitment 31, part A.
Based on the review of the documents and discussions with licensee personnel, the inspectors did not identify any findings or violations of more than minor significance associated with this aging management program.
8 (8) 19A.1.39 Protective Coating Monitoring and Maintenance Program and Commitment 40 This existing program manages aging effects related to degradation of accessible service level 1 coatings inside containment, as defined in regulatory guide 1.54, Service Level I, II, and III Protective Coatings Applied to Nuclear Power Plants, revision 2.
Commitment 40 specified:
Enhance the protective coating monitoring and maintenance program procedures to include:
Parameters monitored or inspected include visible defects, such as blistering, cracking, flaking, peeling, rusting, and physical damage, as specified in ASTM D 5163-08, Inspection frequencies, personnel qualifications, and inspection plans, methods and equipment meet the requirements of ASTM D 5163-08, Performing a pre-inspection review of the previous two monitoring report results to identify areas needing repair during the same outage, during the next available outage, or re-evaluated in next available outage, Establishing a standardized coating condition assessment report form that will list identified coatings found intact with no defects identified and coatings not inspected that includes the basis why the inspection cannot be conducted, Establishing a standardized coating condition assessment report that will include written and/or photographic documentation of coating inspection areas, failures, and defects, and Performing destructive/non-destructive tests by individuals trained in the applicable referenced standards.
The inspectors reviewed the aging management program basis document, implementing procedures, work orders, and completed inspection results, as well as interviewed the program owner. The inspectors confirmed that procedure 0PMP06-ZD-0001, Paints and Coatings, revision 16, generally, incorporated the requirements described in commitment 40. Specifically, step 6.11.2.4 required documenting and inspecting for blistering, cracking, flaking, peeling, rusting and physical damage. Step 6.13 specified the frequency for conducting the inspections, required a pre-inspection review of the previous two inspection reports, and required performing destructive and non-destructive tests by qualified individuals.
While reviewing the personnel qualification requirements, the inspectors determined that the licensee referenced ASTM D 7108, Standard Guide for Establishing Qualifications for a Nuclear Coatings Specialist, and ASTM D 5428, Standard Guide for Developing a Training Program for Personnel Performing Coating Work Inspection for Nuclear Facilities, but did not reference ASTM D 5163, Standard Guide for Establishing a Program for Condition Assessment of Coating Service Level I Coating Systems in Nuclear Power Plants, as specified in the commitment in procedure 0PMP06-ZD-0001. In addition, the inspectors determined that the licensee had a standardized inspection form that established criteria for the coating conditions (repair during the same outage, during the next available outage, or re-evaluated in
9 next available outage). During interviews, the inspectors learned that the program owner completed an excel spreadsheet coating form and pasted it into the inspection report. However, procedure 0PMP06-ZD-0001 did not have a model of the standardized coatings assessment report that discussed the acceptance criteria and required photographs. The licensee initiated condition report 25-11327 to clarify the reference to ASTM D5163 listed in the commitment and to incorporate the standardized assessment form formally into the procedure. With these changes the inspectors determined the licensee met commitment 40.
Based on the review of the documents and discussions with licensee personnel, the inspectors did not identify any findings or violations of more than minor significance associated with this aging management program.
(9)
Standalone Commitments The updated final safety analysis report, chapter 19A, License Renewal, table 19A.4-1 included several commitments that the licensee identified as standalone. The inspectors reviewed the condition reports associated with the commitments, referenced correspondence, associated procedures or other implementing documents, and interviewed the license renewal implementation coordinator. The inspectors reviewed any applicable inspection results.
Commitment 29 and 41 - Operating Experience These commitments provided specific guidelines related to incorporating industry operating experience beginning 10 years prior to the units entering the period of extended operation and required enhancing the existing operating experience program.
Commitment 29 specified:
Within 10 years prior to entering the period of extended operation, evaluate and incorporate into each aging management program any additional industry and plant-specific applicable operating experience as it becomes available.
Also, if new aging effects are identified, develop a new aging management program, if necessary, so that the aging effects will be managed during the period of extended operation.
Commitment 41 specified:
Enhance the operating experience program and corrective action program for managing the effects of aging to:
Add license renewal interim staff guidance and revisions to NUREG-1801, Generic Aging Lessons Learned (GALL) Report, to the operating experience program procedure as sources of information, Revise the operating experience procedure to include aging effects to the list of characteristics for determining applicability of operating experience that may require further evaluation. A screened-in evaluation should consider (a) systems, structures, or components, (b) materials, (c) environments, (d) aging
10 effects, (e) aging mechanisms, and (f) aging management programs, Review the corrective action program event codes to determine if additional codes are needed to ensure age-related degradation effects are identified, Perform a training needs analysis for those plant personnel, including aging management program owners, who screen, assign, evaluate, implement, and submit plant-specific and industry operating experience information for age related effects. Include in the analysis a requirement that individuals complete training before performing tasks, and a determination of the periodicity of the training.
Revise the operating experience program procedure to provide criteria for reporting plant-specific operating experience of age-related degradation.
The inspectors determined procedure 0PGP03-ZE-0083, License Renewal Implementation & Operating Experience Review, revision 4 included NUREG-1801 and interim staff guidance documents as sources of information, listed aging effects
((a) systems, structures, or components, (b) materials, (c) environments, (d) aging effects, (e) aging mechanisms, and (f) aging management programs), and established operating experience reporting criteria. The procedure described the responsibilities for reviewing aging related operating experience and the codes required to be applied to condition reports. The inspectors determined that the training needs analysis required personnel dealing with age-related degradation and review of operating experience read procedure 0PGP03-ZE-0083 during their qualifications. The inspectors verified that the licensee established computer based training for their aging management program owners.
Commitment 33 - Transmission Conductors This commitment related to the components in the recovery path for loss of offsite power following a station blackout.
Commitment 33 specified:
Continue the periodic inspection of a sample of transmission conductor connections for loose connections using thermography as part of the preventive maintenance activities into the period of extended operation.
The inspectors verified that the licensee continued to perform thermography for electrical connections related to components required to recover from a station blackout.
Commitment 37 - Groundwater Samples The licensee agreed to take additional ground water samples at multiple locations and analyze them for pH, sulfates, and chlorides to confirm the ground water remained nonaggressive for underground structures.
11 Commitment 37 specified:
Beginning no later than September 2012, take groundwater samples at multiple locations around the site every three months for at least 24 consecutive months. Analyze the samples for pH, sulfates, and chlorides.
The inspectors verified that the licensee took the required groundwater samples for at least 24 consecutive months and had taken additional samples as part of their structures monitoring program. The completed samples demonstrated that the soil remained nonaggressive for concrete structures.
Commitment 42 - Reactor Head Closure Stud This standalone commitment detailed an additional visual inspection applicable only to Unit 2.
Commitment 42 specified:
Enhance the reactor head closure studs program procedures to perform a remote VT-1 of stud insert #30 (Unit 2 only) concurrent with the volumetric examination once every 10 years to verify no additional loss of bearing surface area.
The inspectors reviewed the inservice inspection program plan, revision 11 and confirmed the licensee incorporated a visual inspection of reactor pressure vessel stud Insert #30 once every 10 years. The inspectors reviewed VT 1/3-2019-093 inspection report and verified the 2019 inspection yielded acceptable results.
Commitment 43 - Seal Caps The licensee agreed to remove the seal caps and evaluate the check valve bolts for intergranular stress corrosion cracking.
Commitment 43 specified:
Remove the seal cap enclosures from the Unit 2 safety injection system check Valve SI0010A and from the Unit 1 and Unit 2 chemical volume control system check Valves CV0001, CV0002, CV0004, and CV0005 will be permanently removed. After removal of the seal cap enclosures, replace or inspect the component bolting for intergranular stress corrosion cracking.
The inspectors verified that the licensee had removed the seal caps from the identified check valves, tested the bolting for intergranular stress corrosion cracking, replaced the valve internals and reassembled the valves without seal caps to allow for future access to the check valves.
Commitment 46 - Essential Cooling Water Flaw Leakage Although the licensee had operating experience that leakage from a flaw progresses slowly and would be detected and repaired prior to significant leakage, this
12 commitment required the licensee to identify maximum flaw sizes that would allow the piping to remain operable.
Commitment 46 specified:
Identify leak rates that could occur upstream of components supplied by the essential cooling water system to validate the maximum size flaw that would still allow the piping to perform its intended function. Provide the summary of this evaluation to the NRC for review.
The inspectors determined that the licensee completed the evaluation of maximum size flaws in different essential cooling water system piping diameters and submitted the evaluation to NRC in letter NOC-AE-14003135, Response to Requests for Additional Information for the Review of the South Texas Project, Units 1 and 2, License Renewal Application - Set 26 (TAC Nos. ME4936 and ME4937),
enclosure E, Commitment No. 46, in response to RAI B2.1.37-4 Issue 5, Summary of the Results of the Leak Rate Analysis.
The inspectors determined from the material provided by the licensee that the licensee met standalone commitments 29, 33, 37, 41, 42, 43, and 46.
Based on the review of the documents and discussions with licensee personnel, the inspectors did not identify any findings or violations of more than minor significance associated with this aging management program.
INSPECTION RESULTS No findings were identified.
EXIT MEETINGS AND DEBRIEFS The inspectors verified no proprietary information was retained or documented in this report.
On December 15, 2025, the inspectors presented the license renewal inspection results to Chris Georgeson, General Manager Strategic Project & Engineering Design and other members of the licensee staff.
13 The inspectors closed commitments 1, 6, 9, 16, 22, and 36 in Inspection Report 05000498/2024011.
The inspectors closed the following commitments during this inspection: 2, 18, 24, 29, 31 part A, 33, 37, 40, 41, 42, 43, 46, and 48.
The following commitments remain open: 3, 4, 5, 7, 8, 10, 11, 12, 13, 14, 15, 17, 19, 20, 21, 23, 25, 26, 27, 28, 30, 31 part B, 32, 34, 35, 38, 39, 44, 45, and 47.
DOCUMENTS REVIEWED Inspection Procedure Type Designation Description or Title Revision or Date 71003 Calculations 4302-03 South Texas Project Unit 1 FAC System Susceptibility Evaluation (SSE) 0 71003 Corrective Action Documents CR 09-12611, 10-23276, 10-23604, 10-23606, 10-23608, 11-20856, 12-15170, 12-21155, 12-27257, 12-8955, 12-8990, 14-4793,15-848, 16-15866, 16-2406, 21-1850, 22-9889, 23-7647, 23-7655, 24-10830,24-174, 24-3176, 24-9485, 24-9489, 24-9602, 25-3172, 25-8849 71003 Corrective Action Documents Resulting from Inspection CR 25-11327, 25-11388, 25-11389, 24-11424 71003 Engineering Evaluations 15-0230-TR-001 Erosion Program - Basis Document South Texas Project Units 1 and 2 0
71003 Engineering Evaluations CREE 15-848-4 Question Related to Rising Unit 2 ILRT Results 3/22/2015 71003 Engineering Evaluations CREE 22-9889 2023 Structures Monitoring Program inspection 12/17/2024 71003 Engineering Evaluations CREE 24-48-17 1RE25 Service Level I Coatings Conditions Assessment Report 1/15/2025 71003 Engineering Evaluations CREE 24-48-7 2RE23 Service Level I Coatings Conditions Assessment Report 1/14/2025 71003 Engineering Evaluations CREE 25-8733-4 CETNA evaluation 10/23/2025 71003 Miscellaneous 2022 Flow Accelerated Corrosion Examination Plan/Summary Report for 2RE22 South Texas Project 11/2022
14 Inspection Procedure Type Designation Description or Title Revision or Date Electrical Generating Station, Unit 2 71003 Miscellaneous 2024 Flow Accelerated Corrosion Examination Plan/Summary Report for 2RE23 South Texas Project Electrical Generating Station, Unit 2 4/2024 71003 Miscellaneous 2023 Flow Accelerated Corrosion Examination Plan/Summary Report for 1RE24 South Texas Project Electrical Generating Station, Unit 1 4/2023 71003 Miscellaneous Structure Monitoring Program, Ground Water Element 3/12/2014 71003 Miscellaneous Unit 1 Integrated Leak Rate Test 11/4/2024 71003 Miscellaneous Unit 2 Integrated Leak Rate Test 4/12/2021 71003 Miscellaneous Inservice Inspection Program Plan 11 71003 Miscellaneous South Texas Project, Unit 1 and 2 - Issuance of License Amendment Nos. 224 and 209 to adopt TSTF-577, Rev 1 12/09/2021 71003 Miscellaneous AE-NOC-16002840 South Texas Project, Units 1 and 2 - Issuance of Amendments Re: Request to Extend the 10 Year Containment Integrated Leak Rate Test Frequency To 15 Years (CAC Nos. Mf6176 and MF6177) 4/29/2016 71003 Miscellaneous CN-3402 Changes to Licensing Basis Documents and Amendments to the Operating License to adopt TSTF-577 9/30/2025 71003 Miscellaneous Generic Letter 89-08 Erosion/Corrosion-Induced Pipe Wall Thinning 5/2/1989 71003 Miscellaneous LRI.19A.1.23 Lubricating Oil Analysis Aging Management Program 2
71003 Miscellaneous LRI.19A.1.30 10 CFR Part 50, Appendix J Aging Management Program 1
71003 Miscellaneous LRI.19A.1.39 Protective Coating Monitoring and Maintenance Aging Management Program 2
71003 Miscellaneous LRI.19A.1.4 Boric Acid Corrosion Aging Management Program 1
71003 Miscellaneous LRI.19A.1.5 &
LRI.19A.1.34 Nickel-Alloy Aging Management Program 1
71003 Miscellaneous LRI.19A.1.6 Flow-Accelerated Corrosion Aging Management Program 1
71003 Miscellaneous LRI.19A.1.8 Steam Generator Tubing Integrity Aging Management Program 1
71003 Miscellaneous LRI.19A.1.9 Open-Cycle Cooling Water System Aging Management Program 1
71003 Miscellaneous NEI 94-01 Industry Guideline for Implementing Performance-Based 2A
15 Inspection Procedure Type Designation Description or Title Revision or Date Option of 10 CFR Part 50, Appendix J 71003 Miscellaneous NOC-AE-11002683 Response to Request for Additional Information 6/23/2011 71003 Miscellaneous NOC-AE-11002683 Response to Request for Additional Information for the South Texas Project License Renewal Application (TAC Nos.
ME4936 and ME4937) 6/23/2011 71003 Miscellaneous NOC-AE-11002737 Supplement to the South Texas Project License Renewal Application (TAC NOS. ME4936 and ME4937) 10/18/2011 71003 Miscellaneous NOC-AE-13003041 2013 Annual Update to the South Texas Project License Renewal Application (TAG NOS. ME4936 and ME4937) 10/28/2013 71003 Miscellaneous NOC-AE-14003135 Response to Requests for Additional Information for the Review of the South Texas Project, Units 1 and 2, License Renewal Application - Set 26 (TAC Nos. ME4936 and ME4937) 7/31/2014 71003 Miscellaneous NOC-AE-15003227 South Texas Project (STP), Units 1 and 2 License Amendment Request for Extending the 10 year ILRT to 15 years 4/29/2015 71003 Miscellaneous NOC-AE-24004031 Unit 2 Relief Request for RVH Penetration 75 4/6/2024 71003 Miscellaneous NOC-AE-25004119 Nickel Alloy Inspection Plan for License Renewal 0
71003 Miscellaneous WCAP-15988-NP Generic Guidance for an Effective Boric Acid Inspection Program for Pressurized Water Reactors 2
71003 NDE Reports VE-2024-002 Reactor Vessel Closure Head Visual Penetration Nozzles, misc nozzles and general head area 4/2/2024 71003 NDE Reports VE-2024-003 Reactor Vessel Closure Head Penetration Nozzles visual examination of previously inaccessible areas 4/2/2024 71003 NDE Reports VE-2024-004 Reactor Vessel Closure Head Visual Penetration #75 4/1/2024 71003 NDE Reports VE-2024-005 Reactor Vessel Closure Head Visual Penetration #75 as left 4/5/2024 71003 NDE Reports VT-1-3-2019-093 Remote VT-1 of Flange Bushing Stud Insert #30 10/21/2019 71003 Procedures 0PEP06-ZG-0013 Infrared Thermography Data Collection 10 71003 Procedures 0PGP03-ZA-0506 Tests or Evolutions Requiring Additional Controls 11 71003 Procedures 0PGP03-ZE-0080 Essential Cooling Water System Reliability Program 7
71003 Procedures 0PGP03-ZE-0083 License Renewal Implementation & Operating Experience 4
16 Inspection Procedure Type Designation Description or Title Revision or Date Review 71003 Procedures 0PGP03-ZE-0133 Boric Acid Corrosion Control Program 13 71003 Procedures 0PGP03-ZM-0004 Lubrication Program 22 71003 Procedures 0PGP03-ZO-0044 Steam Generator Management Program 12 71003 Procedures 0PGP03-ZO-0049 Conduct of Tests or Evolutions Requiring Additional Controls 5
71003 Procedures 0PGP04-ZA-0012 Flow Accelerated Corrosion Program 8
71003 Procedures 0PGP04-ZA-0013 Reactor Coolant System Materials Management Program 6
71003 Procedures 0PGP04-ZA-0608 Erosion Program 1
71003 Procedures 0PGP04-ZE-0006 Alloy 600 Materials Management Program 3
71003 Procedures 0PMP06-ZD-0001 Paints and Coatings 16 71003 Procedures 0PSP11-IL-0007 Reactor Containment Building Integrated Leakage Rate Test 9
71003 Procedures 0PSP11-IL-0009 Reactor Containment Building Visual Inspection 2
71003 Procedures 0PSP11-RC-0014 Steam Generator Inspection 25 71003 Procedures 0PSP11-ZA-0005 Local Leakage Rate Test Calculations, Guidelines, and Program 22 71003 Work Orders WAN 338416, 338417, 489939, 527995, 698490, 698491, 702413, 702461, 716903, 716904 71003 Work Orders WO 497442, 497444, 497445, 535574