IR 05000458/2023011

NRC License Renewal Phase 1 Inspection Report 05000458/2023011

ML23102A294
Person / Time
Site:	River Bend
Issue date:	04/12/2023
From:	Nick Taylor NRC/RGN-IV/DORS/EB2
To:	Karenina Scott Entergy Operations
References
IR 2023011
Download: ML23102A294 (17)

Text

April 12, 2023

SUBJECT:

RIVER BEND STATION - NRC LICENSE RENEWAL PHASE 1 INSPECTION REPORT 05000458/2023011

Dear Kent Scott:

On March 2, 2023, the U.S. Nuclear Regulatory Commission (NRC) completed an inspection at River Bend Station and discussed the results of this inspection with Robert Franssen, Site Vice President, 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, Nicholas H. Taylor, 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: 05000458/2023011

Licensee: Entergy Operations, Inc.

Facility: River Bend Station

Location: St. Francisville, LA

Inspection Dates: February 27, 2023 to March 02, 2023

Inspectors: J. Lee, Reactor Inspector N. Okonkwo, Reactor Inspector C. Smith, Senior Reactor Inspector

Approved By: Nicholas H. Taylor, Chief Engineering Branch 2 Division of Operating Reactor Safety

Enclosure

SUMMARY

The U.S. Nuclear Regulatory Commission (NRC) continued monitoring the licensees performance by conducting a NRC 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) 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 evaluated the material condition of River Bend Station the first week of March 2023 while the plant was shut down for Refueling Outage R22. This allowed the inspectors to evaluate the material condition of inaccessible areas prior to entry into the period of extended operation and to evaluate the licensees implementation of aging management activities. The period of extended operation is the additional 20 years beyond the original 40-year licensed term and begins after midnight on August 29, 2025.

In addition, 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 in NUREG-1915, Safety Evaluation Report Related to the License Renewal of River Bend Station, Unit 1 (ML18212A151). Specific activities evaluated during this inspection are described in the following paragraphs.

Post-Approval Site Inspection for License Renewal===

1.) The inspectors evaluated the aging management programs (AMPs) and commitments described below and walked down selected areas of the facility while performing this phase 1 license renewal inspection.

A.1.15 Diesel Fuel Monitoring and Commitment A-17336 This AMP 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. This is performed by receipt inspection, sampling, and limiting the quantities of contaminants before allowing it to enter the fuel oil storage tanks. Parameters monitored include water and sediment content, total particulates, and levels of microbiological organisms in the fuel oil.

Monitoring and control are performed in accordance with ASTM standards D4057, D2274, D2276, and D2709. The program includes multi-level sampling of fuel oil storage tanks. Where multi-level sampling cannot be performed due to design, a representative sample is taken from the lowest part of the tank. A stabilizer/biocide is added to new fuel.

The Diesel Fuel Monitoring Program includes periodic inspections of low flow areas where contaminants may collect such as in the bottom of tanks. The fuel oil storage tanks are periodically sampled, drained, inspected, and cleaned.

Commitment A-17336 specified:

This commitment required that the Diesel Fuel Monitoring AMP will be enhanced as described in LRA Section A.1.15 period of extended operation.

For clarity, those enhancements are described below:

Revise Diesel Fuel Monitoring Program procedures to monitor levels of microbiological organisms in the standby diesel generator (SDG) and HPCS diesel generator fuel oil storage and day tanks, and diesel-driven fire pump fuel oil storage tanks.

Revise Diesel Fuel Monitoring Program procedures to 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.

Revise Diesel Fuel Monitoring Program procedures to 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 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.

Revise Diesel Fuel Monitoring Program procedures to

(a) monitor levels of microbiological organisms and particulate concentrations in the diesel-driven fire pump fuel oil storage tanks at least quarterly, and

(b) monitor levels of microbiological organisms in the SDG and HPCS diesel fuel oil storage and day tanks at least quarterly.

Revise Diesel Fuel Monitoring Program procedures to specify sampling for water and sediment in accordance with ASTM Standard D2709.

While a majority of the actions associated with the diesel fuel monitoring AMP were verified to be complete, the licensee had not cleaned and inspected the diesel-driven fire pump fuel oil storage tanks FOF-TK1A and FOF-TK1B by the time of the inspection. This commitment remains open until those actions are complete, and the inspectors plan to review this item during the Inspection Procedure 71003 Phase 2 inspection.

A.1.26 Masonry Wall Program and Commitment A-17344 This AMPs objective is to manage aging effects established for masonry walls through the period of extended operation. The program includes periodic visual inspection of masonry walls in the scope of license renewal to detect loss of material and cracking of masonry units and mortar. The aging effects that could impact a masonry walls intended function or potentially invalidate its evaluation basis are entered in the corrective action program for further analysis, repair, or replacement.

The structures monitoring program manages the effects of aging on structural steel components, such as steel edge supports and steel bracing of masonry walls.

Masonry walls are inspected as part of the structure monitoring program, on a frequency of at least once every five years to ensure there is no loss of intended function.

Commitment A-17344 specified:

This commitment required the masonry wall program to continue through the period of extended operation and the following items:

Revise plant procedures to ensure masonry walls located in in-scope structures are included in the scope of the masonry wall program.

Revise plant procedures to include monitoring gaps between the structural steel supports and masonry walls that could potentially affect wall qualification.

Revise plant procedures to specify that masonry walls will be inspected at least once every five years with provisions for more frequent inspections in areas where significant aging effects (missing blocks, cracking, etc.) are observed to ensure there is no loss of intended function between inspections.

Revise plant procedures to include acceptance criteria for masonry wall inspections that ensure observed aging effects (cracking, loss of material, or gaps between the structural steel supports and masonry walls) do not invalidate the wall's evaluation basis or impact its intended function.

The inspectors reviewed the licensees revised plant procedures to determine if the changes noted above had been made. The inspectors reviewed records and conducted independent plant walkdowns to determine if the structures monitoring program and masonry wall program was identifying and correcting any deficiencies with in-scope masonry walls.

Based on the review of the procedures and records, and discussions with licensee personnel, the inspectors did not identify any findings or violations of more than minor significance associated with commitment A-17344 and its associated AMP.

A1.27 Electrical Cable Connections Not Subject to 10 CFR 50.49 Environmental Qualification Requirements and Commitment A-17345 This AMP manages aging effects of cable connections that would be affected by increased resistance of connection due to thermal cycling, ohmic heating, electrical transients, vibration, chemical contamination, corrosion, or oxidation.

This program requires a one-time inspection program to provide reasonable assurance that the intended functions of the metallic parts of electrical cable connections are maintained consistent with the current licensing basis through the period of extended operation. A representative sample size of the connection population with a maximum sample were selected and tested.

Commitment 17345 specified:

The Non-EQ Electrical Cable Connections Program commitment must be completed prior to February 28, 2025, or the end of the last refueling outage prior to August 29, 2025, whichever is later.

The licensee verified the samples for the non-EQ electrical cable connections, verified the licensee incorporated cable connection testing steps into existing work order instructions and performed the one-time inspections on the identified samples of non-EQ electrical cable connections.

The inspectors reviewed procedures, work orders, and corrective actions related to the performance of thermographic scans and the measurement of cable resistance of the metallic connections.

Based on the review of the procedures and records, and discussions with licensee personnel, the inspectors did not identify any findings or violations of more than minor significance associated with commitment A-17345, and its associated AMP.

A.1.28 Implement the Non-EQ Inaccessible Power Cables (>= 400 V) Program and Commitment 17346 This AMP will manage the effects of aging of energized, nonenvironmentally qualified power cables, with voltages greater than or equal to 400 volts, with the potential for exposure to significant moisture. Energized power cables exposed to standing water or condensation are vulnerable to loss of dielectric strength and water treeing. The aging management program applies to all inaccessible or underground (e.g., in conduit, duct bank, or direct buried) power cables. This is a condition monitoring program that performs periodic testing and manhole inspections for the identified in scope cables.

The licensee will conduct the first tests of the cables and first inspections of the manholes prior to entering the period of extended operation. These cables will be tested prior to the period of extended operation and at least once every 6 years thereafter to provide an indication of the condition of the conductor insulation.

Periodic inspections for water accumulation in manholes are performed at least once every year (annually) to ensure the insulation of the cable within the scope are not subjected to significant moisture and submergence, to prevent premature cable failure. In addition to the periodic manhole inspections, manhole inspections for water after event-driven occurrences, such as flooding, will be performed. RBS identified manhole EHM30, equipped with a solar powered sump pump, for inspection and dewatering.

Commitment 17346 specified:

These commitments are to be implemented prior to February 28, 2025, or the end of the last refueling outage prior to August 29, 2025, whichever is later.

The inspectors interviewed license renewal personnel, the program owner, and reviewed program documents, completed work orders, and some of the available test results. The inspectors determined that the licensee had established the program requirements related to testing of the cables and inspection of the identified manhole (EMH30). The inspectors confirmed that the licensee had inspected the manhole, which is equipped with solar powered sump pump that is alarmed for failure and monitor daily. The inspectors determined cable inspection and testing are performed in accordance with RBS procedure EN-DC-346, Cable Reliability Program. This procedure has been revised to include the testing and inspection requirement for the commitment.

Commitment 17346 and non-EQ inaccessible power cables aging management program remains open because most of the cables were not tested by the time of this inspection.

A.1.29 Electrical Cables and Connections Not Subject to 10 CFR 50.49 Environmental Qualification Requirements Used in Instrumentation Circuits and Commitment 17347 This AMP manages the aging effect of insulated cables and connections exposed to adverse localized environments caused by heat, radiation, and moisture, to provide reasonable assurance the intended functions of insulated cables and connections exposed to adverse localized environments caused by heat, radiation, and moisture can be maintained consistent with the current licensing basis through the period of extended operation. An adverse localized environment is a condition in a limited plant area that is significantly more severe than the plant design environment for the cable or connection insulation materials.

Commitment 17347 specified:

This program visually inspects accessible cables located in an adverse environment at least once every 10 years, with the first inspection prior to the period of extended operation.

The licensee will perform visual inspections of a representative sample of accessible insulated cables and connections for cable and connection jacket surface anomalies such as embrittlement, discoloration, cracking or surface contamination. This is to assure that these accessible cables and connections in the affected zone of Adverse Localized Equipment Environment (ALEEs) are devoid of these physical characteristics that are indications of insulation or jacket degradation.

The inspectors reviewed program documents, completed work orders, selected cables and connectors. The inspectors interviewed license renewal personnel and the program owner and determined that the licensee had established the program requirements related to electrical cables and connections in selected ALEEs. The inspectors did not identify any issues during the review of this aging management program.

Based on the review of the procedures and records, and discussions with licensee personnel, the inspectors did not identify any findings or violations of more than minor significance associated with commitment A-17347, and its associated AMP.

A.1.30 Non-EQ Sensitive Instrumentation Circuits Test Review and Commitment 17348

This AMP manages the aging effects of the cables in the neutron monitoring and process radiation monitoring systems or sub-systems, to provide assurance that the intended functions of these sensitive, high-voltage, low-signal cables, exposed to ALEEs caused by heat, radiation and moisture (i.e., neutron flux monitoring instrumentation and process radiation monitoring), can be maintained consistent with the current licensing basis through the period of extended operation.

The inspectors determined that the following components in the RBS process radiation monitoring system were within the scope of this program:

Fuel building ventilation exhaust monitors (RMS-RE5A, RMS-RE5B)

Main control room local air intake monitors (RMS-RE13A, RMS-REIBB)

Main control room remote air intake monitors (RMS-14A, RMS-RE14B)

Containment atmosphere monitor (RMS-RE111)

Drywell atmosphere monitor (RMS-RE112)

Most sensitive instrumentation circuit cables and connections were included in the instrumentation loop calibration at the normal calibration frequency, which provides sufficient indication of the need for corrective actions based on acceptance criteria related to instrumentation loop performance.

For sensitive instrumentation circuit cables that are disconnected during instrument calibrations, testing using a proven method for detecting deterioration for the insulation system (such as insulation resistance tests or time domain reflectometry)will occur at least once every 10 years, with the first test occurring before the period of extended operation. Applicable industry standards and guidance documents are used to delineate the program.

Commitment 17348 specified:

These commitments are to be implemented prior to February 28, 2025, or the end of the last refueling outage prior to August 29, 2025, whichever is later.

The licensee procedures RBS-EE-15-00001 & RBS-EP-15-00009 to state the intermediate range monitors (IRMs), local power range monitors (LPRMs), average power range monitors (APRMs), and process radiation monitor instrumentation circuits identified as environmental qualification (EQ) related are not included in the Non-EQ Sensitive Instrumentation Circuits Test Review Program.

The licensee prepared a procedure to review and document the results obtained from normal calibrations of the process radiation monitors at least once every 10 years after the completion. The inspectors determined that the instrumentation circuits test review is performed in accordance with RBS procedure RBS-EP-22-00002, Non-EQ Sensitive Instrumentation Circuits Test Review Program Report; at a frequency of 10 years. In addition, when cables were disconnected during calibration testing, the licensee used insulation resistance tests or time domain reflectometry methods to detect deterioration. This review is also performed at a frequency of at least once every 10 years.

Based on the review of the procedures and records, and discussions with licensee personnel the inspectors did not identify any findings or violations of more than minor significance associated with commitment A-17348, and its associated AMP.

A.1.40 Service Water Integrity

This AMP implements the recommendations of Generic Letter 89-13, Service Water System Problems Affecting Safety-Related Equipment. Because the NRC routinely inspects the heat sinks (Inspection Procedure 71111.07(T), Heat Sink Inspection and Inspection Procedure 71111.21M, Comprehensive Engineering Team Inspection) and reviews the flow testing, periodic cleaning, and heat transfer capability testing of heat exchangers cooled by service water, the inspectors did not review these aspects of program implementation.

Commitment 17373 states:

The service water integrity program will be enhanced for LRA commitment #31, from RAI response set #9, prior to February 28, 2025. For simplicity, this commitment is to inspect the safety-related carbon steel piping in the standby service water cooling tower exposed to raw water, including visual inspection of accessible submerged piping at least once every 10 years, and five volumetric inspections per 10-year period of the period of extended operation.

During this inspection, the inspectors conducted a walkdown of the standby service water cooling tower, reviewed corrective action and work order documentation, and reviewed the enhancements made to the program in accordance with commitment A-17373. The inspectors verified that the licensee had revised service water integrity program documents to inspect the safety-related carbon steel piping in the standby service water cooling tower exposed to raw water to include visual inspection of accessible submerged piping at least once every 10 years, and five volumetric inspections per 10-year period of the period of extended operation. The volumetric inspections will determine wall thickness of the horizontal distribution piping in the tower at locations with an air-to-water interface.

While the inspectors determined that the licensee had effectively made changes to the Service Water Integrity Program to meet commitment A-17373 prior to entering the period of extended operation, the inspectors were unable to assess the effectiveness of the aging management program for the sparger nozzles in the standby service water tower. Specifically, the inspectors reviewed corrective action records (CRs) CR-RBS-2019-1016, CR-RBS-2020-4162, CR-RBS-2022-2632, CR-RBS-2022-6072, and CR-RBS-2023-1451 that documented instances where nozzles, pipe nipples and elbows were falling off the distribution headers in the standby service water cooling tower, affecting both divisions, since 2019. The failures of these components in the standby service water cooling tower were attributed to system-wide corrosion. While the CRs documented a basis for the service water operability, the licensee was focused on the heat removal capability of the service water system, whereas the service water aging management program did not appear to address the management of the corrosion and aging in the system.

Discussions with the relevant licensee personnel revealed that although the system remained operable from a heat transfer perspective, the corrosion rates within the sparger nozzles were unknown. Further, until prompted by the inspectors, the licensee had not identified an acceptable amount of corrosion or a minimum acceptable wall thickness for the degraded sparger nozzles. Due to these open questions, and that there were only preliminary plans to address the aging affects due to the corrosion, this AMP and commitment remains open. The inspectors plan to review the final corrective actions for the standby service water tower in a future inspection. The licensee captured the inspectors concerns in CR-RBS-2023-2215.

A.1.35 Protective Coating Monitoring and Maintenance

This existing program manages the effects of aging on Service Level I coatings applied to external surfaces of carbon steel and concrete inside containment (e.g.,

steel containment vessel shell, structural steel, supports, penetrations, and concrete walls and floors). The program is implemented using the guidance provided in Regulatory Guidance 1.54 and ASTM D 5163-08. The program provides an effective method to assess coating condition through visual inspections by identifying degraded or damaged coatings and providing a means for repair of identified problem areas.

Service Level I protective coatings are not credited to manage the effects of aging.

Proper monitoring and maintenance of protective coatings inside containment ensures operability of post-accident safety systems that rely on water recycled through the containment. The proper monitoring and maintenance of Service Level I coatings ensures there is no coating degradation that would impact safety functions, for example, by clogging emergency core cooling system suction strainers.

The inspectors reviewed program documents, personnel qualifications, work orders, inspection reports and corrective action documents. A containment walkdown was performed by the NRC inspectors and accompanied by the safety related coatings program owner.

The inspectors determined that the licensee has a program to manage the effects of aging of Service Level I coatings applied to external surfaces of carbon steel and concrete inside containment as part of their Protective Coating Monitoring and Maintenance program.

The inspectors reviewed the changes made by the licensee to this aging management program. Based on the review of the procedures and records, and discussions with licensee personnel, the inspectors did not identify any findings or violations of more than minor significance associated with this AMP.

Plant Condition Monitoring Walkdowns The inspectors walked down normally inaccessible areas of the facility looking at the structures, systems, and components for signs of aging, such as corrosion on piping, component supports, and cable trays, water intrusion, structural cracking, and spalling of concrete.

Specific structures, systems, and components walked down and evaluated during this inspection included:

Containment - multiple elevations o Drywell liner coating o Containment cooling units Shield building Diesel generator building C tunnel area Standby service water cooling tower

During the walk downs of the areas, the inspectors did not identify any signs of aging that affected the structures, systems, or components, with the exception of the standby service water cooling tower sparger nozzles described above.

INSPECTION RESULTS

No findings were identified.

EXIT MEETINGS AND DEBRIEFS

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

On March 2, 2023, the inspectors presented the License Renewal Phase 1 inspection results to Robert Franssen, Site Vice President, and other members of the licensee staff.

DOCUMENTS REVIEWED

Inspection Type Designation Description or Title Revision or

Procedure Date

71003 Corrective Action CR-RBS-2021-

Documents 01755, CR-RBS-

22-05287, CR-

RBS-2023-01284,

LO-RLO-2022-

00091, CR-RBS-

21-01184, CR-

RBS-2021-01186,

CR-RBS-

21-05727, CR-

RBS-2021-05728

Miscellaneous Licensing Commitment Report

A-17345 Implement the Non-EQ Electrical Cable connections Program 0

and described in LRA Section A.1.27

A-17347 Tab 3.2 - A-17347 commitment Closed 1/12/2023

A-17348 Implement the Non-EQ Sensitive Instrumentation Circuits Test 5/25/2017

Review Program as Described in LRA Section A.1.30

A-17373 Enhance the Service Water Integrity Program as described in 03/08/2018

LRA Section A.1.40.

AR 21005951 PM change request to Implement the RBS Non-EQ Insulated 11/16/2021

Cables and Connections Program (Non-Outage)

AR 21005951 pt 3 PM change request to Implement the RBS Non-EQ Insulated 11/16/2021

Cables and Connections Program (Outage)

FTK-ESPP-Entergy Nuclear Engineering Qualification Card - Safety 8

G00064 Related Coatings Program Owner

LO-RLO-2022-Phase 1 IP 71003 NRC Inspection Focused Self-Assessment September

00091 15, 2022

N/A RBS Aging Management Program (AMP) Assignments 1/1/2023

N/A Program Population for Non-EQ Inaccessible Power Cable (= 3/02/2023

400 V)

N/A Non-EQ Cable Termination Population 3/02/2023

Inspection Type Designation Description or Title Revision or

Procedure Date

N/A List of routed cables in EMH30 & WO for MH30 Inspection N/A

PMID 50036669 PMID for Standby Service Water post PEO maintenance.

RBS-CS-21-RF-21 Drywell Coatings Inspection Report 0

00001

SDC-118, 130, & RBS System Design Criteria for Normal Service Water, 6

256 Standby Service Water, and Service Water Cooling, system

numbers 118, 256, and 130 respectively.

USAR A.1.26 / A-Masonry Wall Program 0

17344

USAR A.1.40 / A-Service Water Integrity Program Notebook 0

17373

USAR A.1.41 / A-Structures Monitoring Program Notebook 0

17355

WTRBS-2019-LR Commitment Action Items by Program: Diesel Fuel

00353/A-17336 Monitoring Program

WTRBS-2019-Commitment action for Non-EQ Electrical Cable Connections 1/09/2023

00365

WTRBS-2019-Commitment action for Non-EQ Electrical Cable Connections 1/09/2023

00365

WTRBS-2019-Commitment Action for Non-EQ Insulated Cables and 1/09/2023

00367 Connections

WTRBS-2019-Commitment Action Non-EQ Sensitive Instrumentation Circuits1/09/2023

00368

WTRBS-2019-LR Commitment Action Items for Protective Coatings

00522

Procedures EN-DC-141 Design Inputs 18

EN-DC-150 Condition Monitoring of Maintenance Rule Structures 15

EN-DC-220 Safety-Related Coatings Program 6

EN-DC-346 Cable Reliability Program 9

EN-DC-363 Sensitive Instrumentation Circuits Review 0

EN-FAP-LR-024 One-Time Inspection 9

EN-FAP-LR-026 License Renewal Non-EQ Electrical Cable Connection AMP 5

EN-FAP-LR-027 License Renewal Sensitive Instrumentation Circuits Review 3

EN-MA-138 VLF Tan Delta and Withstand Testing of Electrical Power 6

Inspection Type Designation Description or Title Revision or

Procedure Date

Cables

RBS-CS-15-Aging Management Review of the Reactor Building 2

00001

RBS-EE-15-Electrical Screening and Aging Management Review 2

00001

RBS-EE-15-Aging Management Program Evaluation Results-Electrical 2

00009

RBS-EP-15-Aging Management Program Evaluation Results - Civil / 1

00008 Structural

RBS-EP-19-Review of the Masonry Wall Program for License Renewal 0

00029 Implementation

RBS-EP-19-Review of the Non-EQ Electrical Cable Connections Program 0

00030 for License Renewal Implementation

RBS-EP-19-Review of the Non-EQ Insulated Cables and Connections 0

00033 Program for License Renewal Implementation

RBS-EP-19-Review of the Protective Coating Monitoring and Maintenance 0

00038 Program for License Renewal Implementation

RBS-EP-19-0003l Review of the NonEQ inaccessible Power Cables (= 400 V) 0

Program for License Renewal Implementation

RBS-EP-21-Non-EQ Insulated Cable and Connection Inspection Report 0

00006

RBS-EP-22-Non-EQ Sensitive Instrumentation Circuits Test Review 0

00002 Program Report

RBS-EP-I5-00008 River Bend Station License Renewal Project Aging 1

Management Program Evaluation Report Civil/Structural

RBS-ME-15-Aging Management Review of the Service Water System 1

00012

Self-Assessments RBS-CS-19-2019 Maintenance Rule Structures Periodic Assessment- 0

00004 Masonry Wall Only

Work Orders 00234831,

00483629,

00547723,

00547722,

Inspection Type Designation Description or Title Revision or

Procedure Date

53016946,

2824422,

00556659,

00569078,

2980193,

2991603,

53016944

15