LR-N24-0039, Steam Generator Tube Inspection Report - Twenty-ninth Refueling Outage

Steam Generator Tube Inspection Report - Twenty-ninth Refueling Outage

ML24128A048
Person / Time
Site:	Salem
Issue date:	05/06/2024
From:	Jennings J Public Service Enterprise Group
To:	Office of Nuclear Reactor Regulation, Document Control Desk
References
LR-N24-0039
Download: ML24128A048 (1)

Text

Jason Jennings Director, Site Regulatory Compliance, PSEG Nuclear LLC PO Box 236 Hancocks Bridge, New Jersey 08038-0221 Technical Specification 6.9.1.10 LR-N24-0039 May 6, 2024 U.S. Nuclear Regulatory Commission ATTN: Document Control Desk Washington, DC 20555-0001 Salem Generating Station, Unit 1 Renewed Facility Operating License No. DPR-70 Docket No. 50-272

Subject:

Steam Generator Tube Inspection Report - Twenty-ninth Refueling Outage PSEG Nuclear, LLC (PSEG) submits an updated steam generator (SG) tube inspection report consistent with the requirements of technical specification 6.9.1.10. Salem Unit 1 entered HOT SHUTDOWN (Mode 4) on November 9, 2023, following completion of its twenty-ninth refueling outage.

The following attachments are included in this letter:

Steam Generator Tube Inspection Report TS 6.9.1.10 Explanation of Terms (acronyms)

Salem Unit 1 Model F SG Tube Support Arrangement and Terminology 1R29 Tubes Plugged for Each Degradation Mechanism Total Number and Percentage of Tubes Plugged to Date 1R29 Nondestructive Examination Techniques Anti-Vibration Bar (AVB) Wear Foreign Object Wear Summary of Condition Monitoring 0 Summary of Loose Parts 1 Summary of Upper Internal Secondary Side Repairs 2 Summary of Predicted Tube Integrity Conditions o PSEG I NUCLEAR

May 6, 2024 Page 2 LR-N24-0039 There are no regulatory commitments contained in this letter.

Please contact Mr. Harry Balian at (856) 339 - 2173 if you have questions.

Sincerely, Jason Jennings Director, Site Regulatory Compliance Attachments (12) cc:

USNRC Regional Administrator Region 1 USNRC NRR Project Manager - Salem USNRC Senior Resident Inspector - Salem NJ Department of Environmental Protection, Bureau of Nuclear Engineering NJ Occupational Safety and Health Bureau of Boiler and Pressure Vessel Compliance SIGN

Jennings, Jason Digitally signed by Jennings, Jason Date: 2024.05.06 19:20:13 -04'00'

LR-N24-0039 Steam Generator Tube Inspection Report TS 6.9.1.10

LR-N24-0039 STEAM GENERATOR TUBE INSPECTION REPORT TS 6.9.1.10 Page 1 of 7 PSEG Nuclear LLC Salem Unit 1 Design and Operating Parameters Salem Unit 1 is a four (4) loop Westinghouse Pressurized Water Reactor (PWR) with Westinghouse Model F SGs that incorporate thermally treated Inconel 600 U-tubes. These SGs were placed into service in 1998 which was the start of operating cycle 13. The tube bundle consists of 5,626 tubes per SG with an outside diameter (OD) of 0.688 inches and a nominal tube wall thickness of 0.040 inches. During SG fabrication, the tubes were hydraulically expanded over the full tubesheet depth and the first ten tube rows were thermally stress relieved after U-bend formation. The seven (7) tube support plates (TSP) are fabricated from 405 stainless steel (SS) and have broached quatrefoil tube holes. A flow distribution baffle (FDB) plate, also 405SS, between the secondary face of the tubesheet and the first tube support plate, provides top-of-tubesheet (TTS) sludge pile control. Tube support within the U-bend region is provided by three V-shaped chrome-plated Inconel 600 anti-vibration bars (AVBs). Refer to Attachment 2 for Explanation of Terms (acronyms) and Attachment 3 for steam generator Salem Unit 1 Model F SG Tube Support Arrangement and Terminology.

At the time of the Fall 2023 SG inspection outage (1R29), the SGs accumulated a total of approximately 22.6 Effective Full Power Years (EFPY) of operation. Prior to Fall 2023, all 4 SGs were also inspected in Spring 2020. Between spring 2020 and fall 2023 the SGs were operated approximately 38.34 Effective Full Power Months (EFPM), with a reactor coolant hot leg temperature of approximately 607 degrees Fahrenheit. Screening for higher stress tubes provides 167 tubes potentially with higher stress.

PSEG Nuclear LLC has no deviations for Salem Unit 1 of Mandatory or Needed (shall) requirements important to tube integrity from the EPRI Guidelines referenced by NEI 97-06.

SG inspections were performed in accordance with TS 6.8.4.i, Steam Generator Program, during Salem Unit 1 Fall 2023 steam generator inspection outage. Each reporting requirement of TS 6.9.1.10 is addressed below (items a through i).

a.

The scope of inspections performed on each SG,

b.

The nondestructive examination techniques utilized for tubes with increased degradation susceptibility,

c.

For each degradation mechanism found:

1.

The nondestructive examination techniques utilized;

2.

The location, orientation (if linear), measured size (if available), and voltage response for each indication. For tube wear at support structures less than 20 percent through-wall, only the total number of indications needs to be reported;

LR-N24-0039 STEAM GENERATOR TUBE INSPECTION REPORT TS 6.9.1.10 Page 2 of 7

3.

A description of the condition monitoring assessment and results, including the margin to the tube integrity performance criteria and comparison with the margin predicted to exist at the inspection by the previous forward-looking tube integrity assessment;

4.

The number of tubes plugged during the inspection outage; and

d.

An analysis summary of the tube integrity conditions predicted to exist at the next scheduled inspection (the forward-looking tube integrity assessment) relative to the applicable performance criteria, including the analysis methodology, inputs, and results.

e.

The number and percentage of tubes plugged to date, and the effective plugging percentage in each SG,

f.

The results of any SG secondary side inspections;

g.

The primary to secondary leakage rate observed in each SG (if it is not practical to assign the leakage to an individual SG, the entire primary to secondary leakage should be conservatively assumed to be from one SG) during the cycle preceding the inspection which is the subject of the report,

h.

The calculated accident induced leakage rate from the portion of the tubes below 15.21 inches from the top of the tubesheet for the most limiting accident in the most limiting SG. In addition, if the calculated accident induced leakage rate from the most limiting accident is less than 2.16 times the maximum operational primary to secondary leakage rate, the report should describe how it was determined,

i.

The results of monitoring for tube axial displacement (slippage). If slippage is discovered, the implications of the discovery and corrective action shall be provided.

a. Technical Specification 6.9.1.10.a, The scope of inspections performed on each SG Eddy Current Tube Inspections All four steam generators were inspected as follows:

Array Probe and Bobbin Probe

1. All in-service tubes full length with exception of rows 1 and 2 which were limited to straight sections of tube up to 07H and 07C Note: Consistent with Salem Unit 1 Technical Specification 6.8.4.i.d the portion of the tube below 15.21 inches from the top of the tubesheet is excluded.

LR-N24-0039 STEAM GENERATOR TUBE INSPECTION REPORT TS 6.9.1.10 Page 3 of 7 Rotating Coil (+Point Probe)

1. All In-service row 1 and row 2 tubes U-bends (07H to 07C)

Tube Plug Visual Inspections All four steam generators tube plugs (installed prior to fall 2023) were visually inspected from within the channel head, hot and cold leg side. No conditions adverse to quality were identified.

Primary Side Channel Head Visual Inspections All four steam generators channel head primary side clad surfaces (i.e. - internal channel head bowl and tubesheet surfaces) and divider plates were visually inspected, from the hot and cold leg side. No conditions adverse to quality were identified.

Secondary Side Inspections See response provided for 6.9.1.10.f.

b. Technical Specification 6.9.1.10.b, The nondestructive examination techniques utilized for tubes with increased degradation susceptibility As stated in response to 6.9.1.10.a, robust eddy current tube inspections were completed full tube length with enhanced probes (i.e. - Array, Rotating Coil). These inspections are consistent with Salem Unit 1 Technical Specification 6.8.4.i.d.2 Enhanced probes have a capability to detect flaws of any type equivalent to or better than array probe technology.

Rotating Coil (+Point Probe) inspections also include special interest, such as tube locations with greater than or equal to (>=) 5 volt DNG and DNT, and loose part wear. See Attachment

6.

c. Technical Specification 6.9.1.10.c, For each degradation mechanism found:

1.

The nondestructive examination techniques utilized; See 6.9.10.b and Attachment 6.

LR-N24-0039 STEAM GENERATOR TUBE INSPECTION REPORT TS 6.9.1.10 Page 4 of 7

2.

The location, orientation (if linear), measured size (if available), and voltage response for each indication. For tube wear at support structures less than 20 percent through-wall, only the total number of indications needs to be reported; During outage 1R29 there were a total of 1616 AVB wear indications, 21 TSP wear indications, 9 FBP wear indications, and 1 loose part wear (LPW) indication from eddy current inspections in all 4 steam generators. None of the wear indications exceeded 39% through-wall (TW), and only AVB wear was 20% TW or greater (i.e. - TSP, FBP, and LPW were all less than 20% TW).

See Attachment 7 for AVB wear equal to or greater than 20% TW. Attachment 8 provides detail for the LPW indication.

3.

A description of the condition monitoring assessment and results, including the margin to the tube integrity performance criteria and comparison with the margin predicted to exist at the inspection by the previous forward-looking tube integrity assessment; As noted in response to 6.9.1.10.c.2 all tube wear indications were 39% TW or less, which is below Technical Specification 6.8.4.i.c provisions for tube plugging criteria for flaws with a depth equal to or exceeding 40% of the nominal tube wall thickness. Furthermore, all tube wear was below condition monitoring limits, see Attachment 9 for additional information.

4.

The number of tubes plugged during the inspection outage; and See Attachment 4.

d. Technical Specification 6.9.1.10.d, An analysis summary of the tube integrity conditions predicted to exist at the next scheduled inspection (the forward-looking tube integrity assessment) relative to the applicable performance criteria, including the analysis methodology, inputs, and results.

The Operational Assessment from the Fall 2023 1R29 outage tube inspections allows continued operation up to refueling outage 1R33 (Fall 2029), conservatively assuming 5.7 EFPY of plant operation (~68.4 EFPM). Probabilistic and Deterministic methods of analysis were performed. Attachment 12 provides a summary of analysis for each degradation mechanisms evaluated (existing and potential), applicable performance criteria limits, and

LR-N24-0039 STEAM GENERATOR TUBE INSPECTION REPORT TS 6.9.1.10 Page 5 of 7 1R33 projection in terms of Probability of Burst (POB) for full bundle probabilistic evaluations or end-of cycle depths for deterministic evaluations. For the deterministic evaluations, growth rates of 4%TW/EFPY were used compared to maximum observed growth/wear rates for TSP and FBP at outage 1R29 of 1.25%TW/EFPY and 0.3%TW/EFPY respectively (i.e. - the wear rates used in the calculations are conservative to actual estimates). Conservatism with operating duration also estimated EFPY between start of cycle 30 to outage 1R33 is closer to 5.55 EFPY, however 5.7 EFPY was assumed. Response to 6.9.1.10.f also provides discussion of loose parts (i.e. - Foreign material), concluding known foreign material not able to be removed from the SGs was evaluated as having no significant consequence to tube integrity and continued plant operation. In summary, these results provide reasonable assurance the performance criteria will not be challenged for 4 cycles of plant operation prior to next SG inspections planned in outage 1R33.

e. Technical Specification 6.9.1.10.e, The number and percentage of tubes plugged to date, and the effective plugging percentage in each SG.

See Attachment 5.

f. Technical Specification 6.9.1.10.f, The results of any SG secondary side inspections In each steam generator, following top of tubesheet (TTS) and flow distribution baffle (FDB) plate water lancing, visual inspections and Foreign Object Search and Retrieval (FOSAR) were performed. These inspections included the full length of the no tube lane (area between row 1 tubes), a minimum of three inner bundle passes (hot leg and cold leg), and completely around the annulus tube areas (shell-to-tube bundle region, including periphery tubes). The annulus

/ periphery tubes inspection included view into the bundle (from the annulus region) allowing inspection between the periphery tubes into the bundle. The purpose of these inspections was to identify and remove foreign material and to assess the effectiveness of the water lancing.

Approximately 56 pounds of sludge was removed from all four SGs (total). During the water lance process, a strainer is used to separate material removed from the SGs. Generally, all of the SGs had several small metallic pieces and foil like materials. Some benign tube scale deposits and sludge material are also typically observed during secondary side inspections.

FOSAR was performed (as-possible) at tube locations identified by ECT for potential loose parts (PLP), and these tube locations and tubes in immediate proximity (bounding) to PLP/foreign material were also further reviewed with bobbin and array probe inspections. A summary of known foreign material, other than sludge rocks / scale / sediment, identified by FOSAR is provided in Attachment 10. Attachment 10 also provide summary of the eddy current detected LPW described in response for 6.9.1.10.c.2. Foreign material identified in the SGs and not able to be removed was evaluated as having no significant consequence to tube integrity with continued plant operation for at least 4 cycles of operation.

LR-N24-0039 STEAM GENERATOR TUBE INSPECTION REPORT TS 6.9.1.10 Page 6 of 7 Secondary side inspections of the upper internal steam drum components in all 4 steam generators included visual and ultrasonic testing (UT). General area internals visual inspections reviewed all accessible surfaces and components for degradation (erosion, corrosion, cracking, etc). Focused inspections were performed on all 16 primary moisture separators and subcomponents (e.g. - riser barrel, downcomer barrel, tangential nozzles, swirl vane blades, spacer tabs, orifice rings) and feedwater rings. In summary, many primary moisture separators subcomponents have indications of erosion including some with small holes, while the feedwater rings were in generally good condition with little to no erosion.

PSEG prepared contingency plans prior to outage 1R29 to make repairs (as-needed) and at the conclusion of the inspections and evaluations, 24 localized repairs were made to primary moisture separator subcomponents as summarized in Attachment 11. Evaluations of the secondary side conditions considering repairs made in outage 1R29 provide at least 4 cycles of continued operation until the next planned SG inspections in outage 1R33.

g. Technical Specification 6.9.1.10.g, The primary to secondary leakage rate observed in each SG (if it is not practical to assign the leakage to an individual SG, the entire primary to secondary leakage should be conservatively assumed to be from one SG) during the cycle preceding the inspection which is the subject of the report PSEG did not observe any primary to secondary leakage at or greater than the detection threshold of approximately one (1) gallon per day in operating interval after spring 2020 SG inspections to the end of cycle 29 (start of refueling outage 1R29).

h. Technical Specification 6.9.1.10.h, The calculated accident induced leakage rate from the portion of the tubes below 15.21 inches from the top of the tubesheet for the most limiting accident in the most limiting SG. In addition, if the calculated accident induced leakage rate from the most limiting accident is less than 2.16 times the maximum operational primary to secondary leakage rate, the report should describe how it was determined Since PSEG did not observe any measurable SG primary to secondary operational leakage, the calculated accident induced leakage rate from the most limiting accident would not be significant.

LR-N24-0039 STEAM GENERATOR TUBE INSPECTION REPORT TS 6.9.1.10 Page 7 of 7

i. Technical Specification 6.9.1.10.i, The results of monitoring for tube axial displacement (slippage). If slippage is discovered, the implications of the discovery and corrective action shall be provided 100% of all in-service tubes within the tubesheet, both HL and CL, were monitored for tube axial displacement (slippage) using Bobbin coil inspections. No indications of slippage were detected.

LR-N24-0039 Explanation of Terms

LR-N24-0039 Explanation of Terms (acronyms)

Page 1 of 2 1R29:

Salem Unit 1 Refueling Outage 29 (i.e. - the 29th refueling outage)

AVB:

Anti-Vibration Bar BET:

Bottom Expansion Transition (synonymous with BHT)

BHT:

Bottom Hydraulic Transition (synonymous with BET)

BLG:

Bulge (typically within the hydraulically expanded tubesheet per PSEG reporting requirements)

CL:

Cold Leg CM:

Condition Monitoring DNG:

Ding (Freespan region of the tube per PSEG reporting requirements)

DNT:

Dent (At support structures per PSEG reporting requirements)

EPRI:

Electric Power Research Institute ETL:

Expansion Transition Location (PSEG reporting requirements)

ETSS:

Examination Technique Specification Sheet FBC:

Flow Baffle Coldleg (designates the Flow Distribution Baffle Plate on the Cold Leg)

FBH:

Flow Baffle Hotleg (designates the Flow Distribution Baffle Plate on the Hot leg)

FBP:

Flow Distribution Baffle Plate (synonymous with FDB)

FDB:

Flow Distribution Baffle Plate (synonymous with FBP)

FOSAR:

Foreign Object Search and Retrieval HL:

Hot Leg LPW:

Loose Part Wear NDE:

Non-Destructive Examination NDD:

No Degradation Detected OA:

Operational Assessment OD:

Outside Diameter OEX:

Over Expansion (localized variation in tube diameter within the hydraulically expanded tubesheet)

OXP:

Over Expansion (a hydraulic expansion occurring above the top of tubesheet)

PLP:

Possible Loose Part POB:

Probability of Burst PWR:

Pressurized Water Reactor SIPC:

Structural Integrity Performance Criteria SG:

Steam Generator TEC:

Tube End Coldleg TEH:

Tube End Hotleg TS:

Technical Specification TSC:

Tubesheet Cold Leg TSH:

Tubesheet Hot Leg

LR-N24-0039 Explanation of Terms (acronyms)

Page 2 of 2 TTS:

Top of Tubesheet TSP:

Tube Support Plate TW:

Through-Wall Vpp:

Volts Peak to Peak Note: Acronyms provided above are similar as provided in previous reports to the NRC and may not be needed/used in every report.

LR-N24-0039 SALEM UNIT 1 MODEL F SG TUBE SUPPORT ARRANGEMENT AND TERMINOLOGY

LR-N24-0039 SALEM UNIT 1 MODEL F SG TUBE SUPPORT ARRANGEMENT AND TERMINOLOGY Page 1 of 1 Tube Support -------.

Number 05H 02H TSC lEC Tubesheet

LR-N24-0039 1R29 TUBES PLUGGED FOR EACH DEGRADATION MECHANISM

LR-N24-0039 1R29 TUBES PLUGGED FOR EACH DEGRADATION MECHANISM Page 1 of 1 Tube Degradation Steam Generator Total 11 12 13 14 AVB Wear 0

0 3

0 3

TSP Wear 0

0 0

0 0

FBP Wear 0

0 0

0 0

Foreign Object Wear 0

0 1

0 1

Total Tube Plugged 0

0 4

0 4

LR-N24-0039 TOTAL NUMBER AND PERCENTAGE OF TUBES PLUGGED TO DATE

LR-N24-0039 TOTAL NUMBER AND PERCENTAGE OF TUBES PLUGGED TO DATE Page 1 of 1 Salem Unit 1 Steam Generator Tube Plugging Status SG 11 SG 12 SG 13 SG 14 Total Tubes Plugged Prior to Outage 1R29 63 65 129 48 305 Tubes Plugged in Outage 1R29 0

0 4

0 4

Total Tubes Plugged 63 65 133 48 309 Total Percentage 1.12%

1.16%

2.36%

0.85%

1.37%

I I

I I

I I

I

LR-N24-0039 1R29 NONDESTRUCTIVE EXAMINATION TECHNIQUES

LR-N24-0039 1R29 NONDESTRUCTIVE EXAMINATION TECHNIQUES Page 1 of 1 Degradation Mechanism Detection Technique Depth Sizing Technique AVB Wear Bobbin / Array Bobbin TSP Wear Bobbin / Array Bobbin FBP Wear Bobbin / Array Bobbin Foreign Object Wear Bobbin / Array

+Point Axial ODSCC at TSPs Bobbin / Array N/A(1)

Axial ODSCCs at Dents/Dings <5 Volts Bobbin / Array N/A(1)

Axial ODSCCs at Dents/Dings 5 Volts Bobbin / +Point N/A(1)

Circumferential ODSCC at TTS Bobbin / Array N/A(1)

Notes:

1. No SCC indications were identified/found at 1R29 and therefore depth sizing was not performed.

LR-N24-0039 ANTI-VIBRATION BAR (AVB) WEAR

LR-N24-0039 ANTI-VIBRATION BAR (AVB) WEAR Page 1 of 9 SG Row Column Location

%TW Voltage 11 30 48 AV2 +0.22 20 0.49 11 38 51 AV5 +0.22 20 0.47 11 39 69 AV2 -0.18 20 0.50 11 39 69 AV4 -0.18 20 0.50 11 41 103 AV5 -0.05 20 0.51 11 43 100 AV2 -0.07 20 0.47 11 44 68 AV3 +0.07 20 0.50 11 49 39 AV2 +0.05 20 0.49 11 27 44 AV6 +0.51 21 0.53 11 29 114 AV1 +0.19 21 0.53 11 40 20 AV3 +0.02 21 0.54 11 40 79 AV2 +0.05 21 0.55 11 40 79 AV5 -0.16 21 0.54 11 40 84 AV4 +0.16 21 0.53 11 43 20 AV5 -0.12 21 0.53 11 43 25 AV4 +0.26 21 0.55 11 43 38 AV1 +0.06 21 0.56 11 44 59 AV3 -0.05 21 0.55 11 49 85 AV2 -0.02 21 0.54 11 37 73 AV2 +0.23 22 0.56 11 37 79 AV4 +0.13 22 0.58 11 38 105 AV3 -0.12 22 0.59 11 39 61 AV5 +0.37 22 0.59 11 40 58 AV6 +0.14 22 0.59 11 43 43 AV3 +0.14 22 0.59 11 43 75 AV1 -0.25 22 0.57 11 43 75 AV3 -0.44 22 0.60 11 32 72 AV4 -0.10 23 0.61 11 34 109 AV2 -0.20 23 0.64 11 38 105 AV2 +0.16 23 0.61 11 39 61 AV4 -0.24 23 0.63 11 40 43 AV4 +0.46 23 0.65 11 40 89 AV3 +0.18 23 0.64 11 44 41 AV4 -0.02 23 0.63 11 27 44 AV2 -0.02 24 0.67 11 29 112 AV2 +0.39 24 0.68 11 38 66 AV6 +0.23 24 0.67 11 39 72 AV2 +0.02 24 0.67

LR-N24-0039 ANTI-VIBRATION BAR (AVB) WEAR Page 2 of 9 SG Row Column Location

%TW Voltage 11 40 20 AV4 -0.02 24 0.67 11 43 43 AV5 -0.02 24 0.69 11 43 46 AV6 +0.23 24 0.71 11 44 59 AV2 +0.09 24 0.69 11 28 114 AV6 -0.23 25 0.71 11 38 49 AV4 +0.10 25 0.73 11 38 66 AV2 +0.39 25 0.74 11 40 85 AV2 +0.08 25 0.72 11 41 86 AV4 -0.07 25 0.71 11 42 33 AV2 +0.16 25 0.74 11 43 49 AV4 -0.23 25 0.74 11 29 9

AV5 -0.12 26 0.81 11 35 44 AV5 +0.28 26 0.79 11 38 105 AV5 +0.09 26 0.83 11 40 89 AV4 -0.02 26 0.77 11 40 98 AV5 -0.21 26 0.80 11 44 45 AV4 +0.04 26 0.82 11 40 58 AV3 +0.23 27 0.84 11 43 46 AV4 -0.02 27 0.86 11 44 22 AV5 +0.02 27 0.88 11 49 29 AV5 +0.02 27 0.88 11 40 43 AV3 +0.31 28 0.94 11 40 104 AV4 -0.15 28 0.92 11 43 25 AV5 +0.19 28 0.91 11 43 38 AV2 -0.16 28 0.98 11 43 43 AV2 -0.02 28 0.98 11 44 45 AV3 -0.07 28 0.93 11 44 74 AV3 +0.02 28 0.93 11 40 43 AV2 -0.27 29 1.05 11 40 104 AV5 +0.19 29 0.99 11 29 114 AV6 +0.21 30 1.11 11 40 79 AV3 -0.05 30 1.16 11 49 85 AV3 +0.21 30 1.09 11 43 38 AV3 +0.09 31 1.24 11 43 46 AV5 -0.03 31 1.24 11 43 83 AV4 -0.02 31 1.22 11 43 100 AV3 +0.16 31 1.24 11 49 85 AV4 +0.18 32 1.37 11 39 72 AV3 +0.02 33 1.45

LR-N24-0039 ANTI-VIBRATION BAR (AVB) WEAR Page 3 of 9 SG Row Column Location

%TW Voltage 11 39 72 AV4 +0.05 33 1.38 11 39 99 AV2 -0.14 33 1.49 11 44 58 AV4 +0.51 33 1.45 11 43 22 AV4 -0.02 34 1.63 11 44 100 AV5 -0.02 34 1.64 11 38 66 AV5 -0.29 35 1.70 11 44 58 AV3 +0.19 35 1.68 11 44 68 AV5 -0.22 36 1.98 11 49 85 AV5 -0.02 36 1.94 11 44 68 AV6 -0.35 39 2.70 12 25 115 AV1 +0.32 20 0.47 12 39 72 AV2 +0.25 20 0.49 12 39 96 AV5 -0.31 20 0.50 12 40 75 AV2 -0.30 20 0.51 12 40 88 AV2 +0.02 20 0.49 12 40 95 AV1 -0.23 20 0.48 12 41 82 AV1 -0.20 20 0.48 12 41 82 AV2 -0.64 20 0.51 12 41 85 AV4 +0.19 20 0.48 12 41 98 AV3 +0.03 20 0.51 12 42 46 AV3 +0.39 20 0.48 12 49 95 AV5 +0.09 20 0.47 12 53 34 AV6 +0.02 20 0.50 12 23 89 AV6 -0.27 21 0.52 12 26 83 AV2 +0.39 21 0.53 12 29 109 AV2 +0.05 21 0.52 12 30 13 AV2 -0.07 21 0.55 12 40 80 AV5 +0.11 21 0.52 12 40 95 AV4 +0.03 21 0.55 12 42 51 AV4 -0.27 21 0.55 12 47 95 AV4 -0.05 21 0.54 12 40 24 AV4 +0.07 22 0.59 12 40 24 AV5 -0.05 22 0.58 12 40 87 AV2 +0.20 22 0.60 12 40 88 AV5 +0.23 22 0.58 12 45 67 AV1 -0.14 22 0.59 12 48 98 AV4 +0.02 22 0.57 12 52 80 AV1 -0.23 22 0.59 12 29 39 AV5 +0.07 23 0.63

LR-N24-0039 ANTI-VIBRATION BAR (AVB) WEAR Page 4 of 9 SG Row Column Location

%TW Voltage 12 29 54 AV5 -0.07 23 0.60 12 29 108 AV5 +0.02 23 0.62 12 38 104 AV2 -0.02 23 0.61 12 40 95 AV3 +0.03 23 0.64 12 41 85 AV2 +0.20 23 0.61 12 41 90 AV2 +0.13 23 0.62 12 41 97 AV4 +0.02 23 0.64 12 41 98 AV6 +0.11 23 0.62 12 41 102 AV5 +0.07 23 0.64 12 51 67 AV1 -0.09 23 0.64 12 27 112 AV2 -0.41 24 0.71 12 32 109 AV4 -0.05 24 0.66 12 33 108 AV3 +0.08 24 0.67 12 40 87 AV3 +0.21 24 0.67 12 41 97 AV3 -0.02 24 0.68 12 42 51 AV6 +0.12 24 0.66 12 51 82 AV1 -0.18 24 0.67 12 51 85 AV2 +0.02 24 0.68 12 26 74 AV2 -0.18 25 0.72 12 27 8

AV6 +0.12 25 0.75 12 29 39 AV2 +0.09 25 0.75 12 39 48 AV6 +0.33 25 0.71 12 39 54 AV6 +0.06 25 0.76 12 39 65 AV3 -0.04 25 0.73 12 41 56 AV2 -0.14 25 0.72 12 27 8

AV1 -0.19 26 0.81 12 27 8

AV1 +0.18 26 0.78 12 33 108 AV5 -0.07 26 0.79 12 40 87 AV5 +0.17 26 0.77 12 46 97 AV5 +0.18 26 0.81 12 38 107 AV3 -0.02 27 0.89 12 40 69 AV2 -0.12 27 0.84 12 40 80 AV2 +0.14 27 0.85 12 40 95 AV5 +0.16 27 0.83 12 41 100 AV3 +0.03 27 0.86 12 42 46 AV5 -0.07 27 0.90 12 52 80 AV2 +0.22 27 0.84 12 38 107 AV2 +0.07 28 0.95 12 41 85 AV3 +0.38 28 0.91

LR-N24-0039 ANTI-VIBRATION BAR (AVB) WEAR Page 5 of 9 SG Row Column Location

%TW Voltage 12 41 98 AV2 +0.23 28 0.96 12 40 88 AV1 +0.02 29 1.04 12 40 88 AV3 -0.02 29 1.04 12 40 95 AV2 -0.05 29 1.06 12 49 96 AV5 -0.02 29 0.99 12 41 56 AV3 -0.02 30 1.14 12 41 87 AV4 -0.20 30 1.08 12 41 100 AV2 +0.21 31 1.16 12 41 87 AV5 +0.02 33 1.40 12 40 80 AV3 +0.24 34 1.62 12 40 80 AV4 +0.27 39 2.56 13 24 7

AV6 -0.08 20 0.49 13 36 88 AV1 +0.12 20 0.50 13 36 88 AV3 +0.05 20 0.49 13 38 53 AV4 -0.13 20 0.48 13 38 81 AV6 -0.02 20 0.49 13 38 98 AV2 +0.22 20 0.49 13 39 65 AV1 -0.02 20 0.48 13 39 80 AV2 -0.17 20 0.51 13 39 80 AV4 +0.23 20 0.49 13 41 96 AV2 -0.05 20 0.48 13 43 69 AV4 +0.02 20 0.48 13 43 71 AV5 +0.55 20 0.48 13 44 60 AV3 +0.31 20 0.49 13 44 76 AV3 -0.46 20 0.49 13 46 66 AV6 -0.09 20 0.47 13 25 7

AV6 +0.62 21 0.54 13 31 32 AV5 -0.20 21 0.52 13 34 48 AV3 +0.13 21 0.54 13 36 88 AV2 +0.28 21 0.53 13 36 89 AV4 +0.11 21 0.55 13 38 28 AV3 -0.02 21 0.55 13 38 69 AV2 -0.05 21 0.55 13 38 85 AV3 +0.11 21 0.55 13 38 92 AV4 -0.17 21 0.54 13 38 101 AV4 +0.30 21 0.51 13 43 47 AV3 +0.16 21 0.52 13 43 62 AV4 -0.05 21 0.52 13 43 75 AV5 +0.18 21 0.54

LR-N24-0039 ANTI-VIBRATION BAR (AVB) WEAR Page 6 of 9 SG Row Column Location

%TW Voltage 13 43 85 AV2 +0.17 21 0.54 13 48 25 AV2 -0.04 21 0.52 13 54 37 AV5 -0.07 21 0.54 13 23 117 AV1 +0.51 22 0.59 13 36 87 AV6 -0.18 22 0.60 13 37 60 AV3 +0.05 22 0.58 13 38 58 AV5 -0.24 22 0.57 13 38 98 AV3 +0.02 22 0.59 13 39 59 AV2 -0.02 22 0.57 13 43 72 AV6 +0.14 22 0.57 13 43 73 AV5 +0.65 22 0.58 13 43 91 AV3 +0.02 22 0.59 13 44 68 AV5 +0.26 22 0.60 13 46 73 AV2 -0.05 22 0.57 13 47 25 AV5 +0.05 22 0.56 13 51 92 AV2 -0.23 22 0.59 13 54 37 AV4 -0.09 22 0.60 13 22 5

AV6 -0.12 23 0.65 13 34 48 AV2 +0.19 23 0.63 13 36 43 AV4 +0.19 23 0.63 13 36 87 AV3 -0.18 23 0.61 13 38 53 AV5 +0.36 23 0.64 13 38 92 AV5 +0.06 23 0.65 13 38 98 AV6 +0.09 23 0.64 13 39 35 AV3 +0.02 23 0.64 13 41 31 AV5 +0.05 23 0.64 13 43 69 AV5 +0.54 23 0.65 13 52 34 AV6 -0.03 23 0.61 13 53 57 AV3 +0.40 23 0.64 13 30 46 AV2 +0.43 24 0.69 13 32 16 AV2 +0.07 24 0.66 13 34 48 AV1 +0.02 24 0.71 13 36 88 AV6 -0.05 24 0.66 13 37 60 AV5 +0.67 24 0.66 13 44 68 AV4 +0.02 24 0.70 13 46 24 AV5 -0.13 24 0.70 13 49 94 AV5 +0.20 24 0.68 13 54 37 AV3 -0.18 24 0.67 13 38 53 AV3 -0.07 25 0.71

LR-N24-0039 ANTI-VIBRATION BAR (AVB) WEAR Page 7 of 9 SG Row Column Location

%TW Voltage 13 38 101 AV5 +0.24 25 0.74 13 39 54 AV4 +0.38 25 0.73 13 39 65 AV4 -0.05 25 0.74 13 43 96 AV6 -0.05 25 0.73 13 44 68 AV1 +0.19 25 0.74 13 51 50 AV5 -0.07 25 0.75 13 19 80 AV6 -0.15 26 0.82 13 32 15 AV2 -0.04 26 0.81 13 36 87 AV2 -0.02 26 0.78 13 41 31 AV4 -0.10 26 0.80 13 44 68 AV3 +0.16 26 0.79 13 45 97 AV4 -0.16 26 0.82 13 49 95 AV4 -0.05 26 0.80 13 51 92 AV4 +0.01 26 0.77 13 38 88 AV3 -0.02 27 0.89 13 39 54 AV3 +0.18 27 0.88 13 39 64 AV3 +0.12 27 0.83 13 44 68 AV2 +0.02 27 0.85 13 50 94 AV2 +0.20 27 0.86 13 53 72 AV4 +0.29 27 0.88 13 36 80 AV3 -0.05 28 0.94 13 38 85 AV4 +0.08 28 0.96 13 38 91 AV2 +0.23 28 0.96 13 43 80 AV5 +0.02 28 0.97 13 43 91 AV4 +0.60 28 0.95 13 44 71 AV2 +0.26 28 0.95 13 36 88 AV5 +0.02 29 0.98 13 38 72 AV3 +0.14 29 1.02 13 38 81 AV2 +0.05 29 1.01 13 38 81 AV3 -0.10 29 0.98 13 38 91 AV5 -0.22 29 1.06 13 39 46 AV2 -0.35 29 1.05 13 39 35 AV5 +0.27 30 1.12 13 43 64 AV4 +0.05 30 1.06 13 43 80 AV4 -0.33 30 1.15 13 50 93 AV5 -0.20 30 1.09 13 34 48 AV4 -0.24 31 1.17 13 41 96 AV3 +0.10 31 1.21 13 51 55 AV5 +0.17 31 1.21

LR-N24-0039 ANTI-VIBRATION BAR (AVB) WEAR Page 8 of 9 SG Row Column Location

%TW Voltage 13 38 72 AV2 -0.23 32 1.37 13 38 72 AV4 +0.34 32 1.35 13 39 65 AV2 -0.26 32 1.35 13 43 62 AV5 -0.02 32 1.35 13 53 88 AV5 +0.16 32 1.27 13 36 88 AV4 +0.25 33 1.42 13 51 92 AV5 -0.11 33 1.43 13 53 89 AV5 -0.02 33 1.41 13 49 94 AV6 +0.15 35 1.75 13 38 53 AV2 -0.34 36 1.94 13 43 80 AV2 +0.17 38 2.31 13 43 80 AV3 -0.02 39 2.52 14 26 115 AV6 +0.02 20 0.50 14 28 38 AV2 +0.20 20 0.50 14 34 108 AV3 +0.05 20 0.49 14 38 101 AV5 +0.07 20 0.49 14 39 100 AV2 +0.02 20 0.51 14 50 28 AV5 -0.02 20 0.48 14 25 7

AV1 -0.19 21 0.55 14 25 7

AV6 -0.32 21 0.55 14 25 44 AV5 +0.03 21 0.52 14 39 56 AV4 +0.08 21 0.53 14 39 78 AV3 -0.71 21 0.52 14 39 97 AV3 +0.02 21 0.54 14 53 38 AV6 -0.19 21 0.51 14 30 72 AV2 +0.49 22 0.56 14 32 84 AV4 +0.15 22 0.59 14 38 103 AV4 +0.12 22 0.56 14 39 78 AV2 -0.05 22 0.57 14 39 78 AV4 -0.22 22 0.57 14 39 100 AV3 +0.10 22 0.57 14 40 60 AV3 -0.20 22 0.58 14 40 87 AV6 +0.02 22 0.59 14 53 38 AV3 -0.05 22 0.59 14 27 8

AV6 -0.19 23 0.64 14 32 84 AV2 +0.13 23 0.65 14 32 84 AV5 -0.07 23 0.62 14 26 7

AV1 -0.23 24 0.70 14 34 108 AV4 -0.14 24 0.68

LR-N24-0039 ANTI-VIBRATION BAR (AVB) WEAR Page 9 of 9 SG Row Column Location

%TW Voltage 14 38 101 AV2 -0.04 24 0.68 14 39 77 AV3 -0.02 24 0.70 14 40 58 AV2 -0.21 24 0.66 14 55 83 AV6 +0.05 24 0.67 14 39 56 AV3 +0.11 25 0.72 14 39 77 AV4 -0.06 25 0.72 14 24 6

AV1 -0.02 26 0.79 14 27 79 AV2 +0.02 26 0.80 14 32 12 AV4 +0.12 26 0.77 14 38 101 AV4 +0.07 26 0.81 14 24 116 AV1 -0.12 27 0.87 14 27 79 AV5 +0.05 27 0.89 14 39 96 AV3 +0.05 27 0.86 14 50 28 AV6 -0.05 27 0.89 14 53 33 AV5 +0.10 27 0.86 14 53 38 AV4 -0.02 27 0.85 14 25 115 AV6 +0.09 29 1.06 14 28 9

AV2 +0.35 29 1.00 14 32 12 AV5 +0.02 29 1.02 14 40 87 AV3 -0.21 29 1.04 14 40 87 AV4 +0.19 29 1.03 14 47 43 AV3 +0.21 29 1.00 14 39 96 AV2 +0.15 30 1.13 14 26 115 AV1 +0.07 31 1.20 14 27 8

AV1 -0.11 31 1.19 14 25 8

AV1 -0.05 32 1.36 14 42 21 AV3 +0.01 32 1.38 14 28 9

AV5 -0.05 33 1.43 14 38 101 AV3 -0.10 34 1.53 14 40 87 AV5 -0.22 34 1.54

LR-N24-0039 FOREIGN OBJECT WEAR

LR-N24-0039 FOREIGN OBJECT WEAR Page 1 of 1 SG Row Column Location Axial Length (inches)

Circumferential Extent (Degrees)

%TW

+Point Voltage 13 5

26 05C -0.69 0.21 38.30 12 0.21

LR-N24-0039

SUMMARY

OF CONDITION MONITORING

LR-N24-0039

SUMMARY

OF CONDITION MONITORING Page 1 of 1 Degradation Mechanism Max Depth

%TW 1R29 CM Limit 1

%TW 1R29 Projected 2 Depth %TW From spring 2020 to 1R29 AVB Wear 39 58 Note 3 TSP Wear 18 57 42.6 FBP Wear 10 58 51 Loose Part Wear 12 70 24 Note 1 - Approximate and conservative limit based on eddy current technique and flaw geometry/model for flaw lengths of 1.0 for AVB, TSP, and FBP and 0.29 for loose part wear.

Note 2 - Conservative deterministic projection provided by Operational Assessment from prior inspection outage in spring 2020. Operational Assessment for AVB wear is a Probabilistic methodology.

Note 3 - AVB Wear Full Bundle Probabilistic model for cycles of operation provides probability of burst (POB) projected to be 0.3% or less for all SGs, which is well below the requirement of 5%.

LR-N24-0039 0

SUMMARY

OF LOOSE PARTS

LR-N24-0039 0

SUMMARY

OF LOOSE PARTS Page 1 of 1 Description (Length x Width x Depth)

Location Comment Steam Generator 11 Potential Sludge Object 42-63, 43-64 TSH Potential sludge object visually identified inner bundle in a low flow velocity zone.

All affected and bounding tubes were No Degradation Detected (NDD) with Bobbin and Array.

The object is conservatively assumed to be a non-sludge object and remains in SG.

Steam Generator 12 Metal object from 1R20 (1.0 L x 0.50 W) 20-42, 21-41, 21-42, 20-43 TSH Object is observed in the same location and unchanged since prior inspection.

All bounding in-service tubes were NDD with Bobbin and Array and remains in the SG.

Steam Generator 13 Unknown 5-26 05C Eddy Current (Array) detected wear near TSP 05C, 12%TW wear sized with +Point. No loose parts detected by eddy current in the affected or bounding tubes. Visual inspection not readily possible in this location, tube was preventatively plugged.

Steam Generator 14 None N/A N/A

LR-N24-0039 1

SUMMARY

OF UPPER INTERNALS SECONDARY SIDE REPAIRS

LR-N24-0039 1

SUMMARY

OF UPPER INTERNALS SECONDARY SIDE REPAIRS Page 1 of 1 Tangential Nozzle Downcomer Barrel Spacer Tab Swirl Vane Riser Barrel SG 11 1

4 0

0 0

SG 12 1

4 0

0 0

SG 13 4

3 0

0 0

SG 14 0

7 0

0 0

Total:

6 18 0

0 0

LR-N24-0039 2

SUMMARY

OF PREDICTED TUBE INTEGRITY CONDITIONS

LR-N24-0039 2

SUMMARY

OF PREDICTED TUBE INTEGRITY CONDITIONS Page 1 of 1 Degradation Mechanism Analysis Methodology SIPC Limit 1R33 Projection AVB Wear Probabilistic 0.05 POB 0.002 POB TSP Wear Deterministic 60%TW (1.4 Length) 49.4%TW FDB Wear Deterministic 57%TW (1.4 Length) 37.4%TW FO Wear Deterministic 60%TW (1.4 Length) 27%TW Axial ODSCC at TSPs Probabilistic 0.05 POB 0.0241 POB Axial ODSCC at Dents/Dings 5 Volts Probabilistic 0.05 POB 0.0093 POB Axial ODSCC at TSP Dents 2 to 5 Volts Probabilistic 0.05 POB 0.0041 POB Combined Axial ODSCC SCC at Dents Probabilistic 0.05 POB 0.0372 POB Circumferential ODSCC at TTS Probabilistic 0.05 POB 0.0001 POB