ML12230A226

Braidwood Station, Unit 1, Inservice Inspection Summary Report

ML12230A226
Person / Time
Site:	Braidwood
Issue date:	08/17/2012
From:	Enright D J Exelon Generation Co
To:	Office of Nuclear Reactor Regulation, Document Control Desk
References
BW120081
Download: ML12230A226 (13)

Text

August 17, 2012 BW120081 U.S.Nuclear Regulatory Commission ATTN: Document Control Desk Washington, DC 20555-0001 Braidwood Station, Unit 1 Facility Operating License No.NPF-72 NRC Docket No.STN 50-456 SUbject: Braidwood Station, Unit 1InserviceInspection Summary Report Enclosed please find the post-outage summary report (Le., 90 day report)for inservice inspection (lSI)examinations conducted during Braidwood Station, Unit 1 Refueling Outage 16 (A 1 R16).This report is submitted in accordance with the requirements of the American Society of Mechanical Engineers (ASME)Boiler and Pressure Vessel Code,Section XI,"Rules for the Inservice Inspection of Nuclear Power Plant Components," and ASME Code Case N-532-4,"Repair/Replacement Activity Documentation Requirements and Inservice Summary Report Preparation Submission

-Section XI, Division 1." Attachment 1 provides the Owner's Activity Report (OAR)for lSI activities conducted duringA1 R16 including a list of items with flaws or relevant conditions that required evaluation for continued service and an abstract of repair/replacements activities required for continued service.In addition, Attachment 2 provides the results of Containment lSI activities performed in accordance with ASME Section XI, Subsection IWE,"Requirements for Class MC and Metallic Liners of Class CC Components of Light-Water Cooled Power Plants," and Subsection IWL,"ReqUirements of Class CC Components of Light-Water Cooled Power Plants," with specified modifications and limitations in 10 CFR 50.55a,"Codes and standards." Please direct any questions you may have regarding this submittal to Mr.Chris VanDenburgh, Regulatory Assurance Manager, at (815)417-2800.Daniel J.Enright Site Vice President Braidwood Station Attachments:

1.Owner's Activity Report (OAR)for A1R16 2.A1 R16 Containment lSI (IWElIWL)Results cc: Regional Administrator

-NRC Region III NRC Senior Resident Inspector-Braidwood Station NRR Project Manager-Braidwood Station Illinois Emergency Management Agency-Division of Nuclear Safety ATTACHMENT 1 FORM OAR-1 OWNER'S ACTIVITY REPORT TABLE 1, ITEMS WITH FLAWS OR RELEVANT CONDITIONS THAT REQUIRED EVALUATION FOR CONTINUED SERVICE TABLE 2, ABSTRACT OF REPAIR/REPLACEMENT ACTIVITIES REQURIED FOR CONTINUED SERVICE ATTACHMENT 1 FORM OAR-l OWNER'S ACTIVITY REPORT Report Number A1R16...:..;=..:..;.::.;;..-------------------------------------

Plant Braidwood Generating Station, 35100 South Route 53, Suite 84, Braceville, Illinois 60407 Third Inspection Interval (lSI), Second Inspection Interval (Containment lSI)Refueling Outage Number AlR16-'-c=.:.:::=-

_Commercial Service Date--.:;.Ju;::.:l

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_Unit No.1-=-----,-,-,---(if applicable)

Current Inspection Interval Current Inspection Period Edition and Addenda of Section XI applicable to the Inspection Plans (IS', 2 nd , 3 rd)ASME Section XI 2001 Edition through 2003 Addenda Edition and Addenda of Section XI applicable to repair/replacement activities, if different than the inspection plans Same as above Code Cases used: N-460, N-508-3, N-513-3, N-532-4, N-566-2,N-586-1,N-597-2,N-613-1,N-624,N-639, N-648-1, N-652-1, N-661-1, N-685,N-695,N-696, N-700, N-706-1,N-722-1,N-729-1, N-731, N-739,N-751,N-753, N-770-1 CERTIFICATE OF CONFORMANCE I certify that (a)the statements made in this report are correct;(b)the examinations and tests, meet the Inspection Plan as required by the ASME Code,Section XI;and (c)the repair/replacement activities and evaluations supporting the completion of A1R16-"'--"-'-------

conform to the requirements of Section XI (refueling outage number)Signed

__esignee.Title)Date CERTIFICATE OF INSERVICE INSPECTION I, the undersigned, holding a valid commission issued by the National Board of Boiler and Pressure Vessel Inspectors and the State or Province of Illinois and employed by HSBCT of-.:..H;,;;;a.;.:rt11::.;o;.:r..;:dL.'

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_have inspected the items described in this Owner's ActiVity Report, and state that to the best of my knowledge and belief, the Owner has performed all activities represented by this report in accordance with the requirements of Section XI National Board, State, PrOVince, and Endorsements (Inspector's Signature)

By signing this certificate neither the Inspector nor his employer makes any warranty expressed or implied concerning the repair/replacement activities and evaluation described in this report.Furthermore, neither the Inspector nor his employer shall be liable in any manner for any personal injury or property damage or a loss of any kind arising from or connected with this inspectionDate Page 1 of 3 ATTACHMENT 1 TABLE 1 ITEMS WITH FLAWS OR RELEVANT CONDITIONS THAT REQUIRED EVALUATION FOR CONTINUED SERVICE Examination Examination Item Cateaorv Number Item Description Evaluation Description D-B D2.10 1DG5045A Crack observed visually inside valve body was evaluated under EC 385798 (IR 1256964)D-B D2.10 1AB8458 BOdy-to-bonnet leak evaluation completed under ATI 1261575-02 C-H C7.10 1 CS01 SA Eductor Flange Flange bolting evaluation completed under AT11326453-02 C-H C7.10 1CV8119 Inlet flange bolting evaluation com pleted under A TI 1334556-02 C-H C7.10 1CV128 Body-to-bonnet bolting evaluation completed under AT11334971-02 D-B D2.10 1 FC8762B Body-to-bonnet bolting evaluation completed under IR 1335573 D-B D2.10 1 FC01 P Discharge Flange Flange bolting evaluation completed under AT11341352-02 D-B D2.10 OAB8575B Bonnet bolting evaluation completed under ATI 1346996-02 D-B D2.10 1FC013 Body-to-bonnet bolting evaluation completed under AT11357587-03 C-H C7.10 1CV8444 Body-to-bonnet bolting evaluation completed under AT11207169-02 D-B D2.10 OSXA5AA Minimum wall evaluation completed under EC 385472/Calculation BRW-11-0135-M (IR 1249027)D-B D2.10 1 FC8762A Body-to-bonnet bolting evaluation completed under ATI 1110373-02 Page 2 of 3 ATIACHMENT1 TABLE 2 ABSTRACT OF REPAIR/REPLACEMENT ACTIVITIES REQUIRED FOR CONTINUED SERVICE Code Item Description Date Repair/Replacement Class Description Of Work Completed Plan Number21 SI03AA Through-Replace Existing 3/3/2011 WO#1413529-01 Wall Leak (lR Pipe with New Pipe (1-11-005) 1180138)2 In-Process Weld Repair Welds That 3/3/2011 WO#1413529-01 Repair of 1SI03AA Failed Radiography (1-11-005)

OR 1181689)2 In-Process Weld Repair Welds That 3/3/2011 WO#1413529-01 Repair of 1 SI03AA Failed Radiography (1-11-005)(IR 1182629)3 1 VP01 D Tube Leak Install mechanical 3/6/2011 WO#1415197-04 OR 1183482)tube pluqs 3 Support 1 SX72009R Tighten Loose Lock 4/5/2012 WR 398107 Loose Lock Nut (IR Nut 1349032)3 OFC004 Hinge Pin Clean and tighten 4/18/2012 WR 397911 Leak (IR 1347425)hinge pin11 RC01 BA Tube Plug tube based on 4/28/2012 WO#1231322-02 R19-C138 eddy current results (1-11-018)11 RC8042B Rebuilt valve 4/27/2012 WO#1354708-01 Diaphragm Leak (IR 1354708)21 CV81 08 Body-to-Replaced bonnet 5/3/2012 WO#1531828 Bonnet Leak (IR gasket 1353632)2 In-Process Weld Repair Weld That 5/4/2012 WO#1450740-03 Repair Line 1 SI08CA Failed Preservice (1-12-030)(IR 1354639)Ultrasonic Exam 2 In-Process Weld Repair Weld That 5/4/2012 WO#1450740-03 Repair Line 1 SI08CA Failed Visual (1-12-030)(IR 1360099)Examination of Weld Root 1 Reactor Upper Head Perform Embedded 5/8/2012 WO#1534769-03 Penetration

1. 69 (IR Flaw Repair of (1-12-024) 1357298)Penetration 69 1 In-Process Repair on Remove Liquid 5/8/2012 WO#1534769-03 Reactor Upper Head Penetrant Indications (1-12-024)

Penetration

1. 69 (IR From Embedded 1363159)Flaw Repair21 CV8382A Body-to-Replaced bonnet 5/9/2012 WO#1539047-01 Bonnet Leak (IR gasket 1363840)Page 3 of 3 ATTACHMENT 2 A1R16 CONTAINMENT lSI (IWE/lWL)RESULTS ATTACHMENT 2 A 1 R16 Containment 151 (IWElIWL)Results REPORT OF CONTAINMENT DEGRADATION Containment inspections are performed in accordance with Subsection IWE (Requirements for Class MC and Metallic Liners of Class CC Components of Light-Water Cooled Power Plants)and IWL (Requirements for Class CC Components of Light-Water Cooled Power Plants)of ASME Section XI, Division 1, with specified modifications and limitations in 10CFR 50.55a.A limited scope of IWE inspections was completed duringA1 R16.The completed surveillances for IWE contain all the examination details along with indications recorded and their associated evaluations required by ASME Section XI.The 25 th Year Inservice Inspection of Class CC Concrete Surfaces and Post Tensioning Systems were completed for Braidwood Unit 1 (and Unit 2)priorto Refuel Outage A1R16.The completed surveillances for IWL contain all the examination and testing details along with their associated evaluations required by ASME Section XI.The results of the Unit 2 surveillance will be included in the A2R16 Inservice Summary Report.ASME IWE REPORT OF CONTAINMENT DEGRADATION Augmented Section XI IWE examinations of the Class CC liner examinations for the third interval were performed in accordance with the requirements of ASME Section XI, Table IWE-2500-1, Category E-C, Containment Surfaces Requiring Augmented Examination.

The scope of the examinations included areas of the liner below the moisture barrier.Exelon Procedures ER-AA-330-007,"Visual Examination of ASME Section XI Class MC Surfaces and Class CC Liners", ER-AA-335-018"Visual Examination of ASME IWE Class MC and Metallic Liners of CC Components':

and ER-AA-335-004"Ultrasonic Measurement of Material Thickness and Interfering Conditions" were used toperformthe examinations.

A description of the type and estimated extent of the conditions that led to the degradation

[10CFR 50.55a(b)(2)(ix)(A)(1>>:

The most notable type of degradation was liner pitting just below the moisture barrier resulting in metal loss of varying depths.Maximum pit depth identified was 8/64" (this was found at only one location).

Extent of Condition:

The maximum pit depth was measured at 8/64" and had occurred only at one location based on Detail Visual (VT-1)examinations of the areas inspected.

These examinations also indicated that the liner plate contained numerous pits in the areas below the MB with pit depth averages to less than or equal to 3/64" and pits with larger depths occurring less frequently.

This pattern is typical of the entire liner plate surfaces below the moisture barrier.Approximately 115'of liner plate directly below the moisture barrier that was not exam ined previously inA1R 14 orA1R 15 was examined after the moisture barrier was removed.This completed the VT examination of the entire containment liner plate directly below the moisture barrier.Description of the Conditions That Led to the Degradation:

Based on the examination results the condition is attributed to corrosion.

The liner plate surface below the moisture barrier was coated with Carbo Zinc CZ11 in year 2000 which does not tolerate improper surface preparation.

This coating product is not recommended for use unless white metal conditions with contoured surface profile is achieved.Since this strip of liner plate below the moisture barrier is not easily accessible, it is unlikely that the proper surface preparation was Page 1 of 7 ATTACHMENT 2 A 1 R16 Containment lSI (IWElIWL)Results attained.Furthermore, the liner plate surface may not have been completely dried (Le., some moisture left in the wall from the wet Cerafibre resting against it)when the moisture barrier was replaced in 2000.In the year 2000 the Cerefibre was found wet and adhering to the metal liner.The liner most likely experienced a slow chronic corrosion rate prior to 2000.The bulk of the liner corrosion probably occurred in the early years after the year 2000 when the moisture barrier was replaced.Thenewcoating applied in A1R16 was Keeler and Long 9600 Series used for Service Level I coating in containment which does not require white metal surface conditions.

Evaluation of each area, and the result of the evaluation

[10CFR SO.SSa(b)(2)(ix)(A)(3)]:

One engineering evaluation was performed to address all the indications since the corrosion leading to the degraded condition is the same contributor affecting the same component (liner plate).The evaluation determined that the liner plate with the highest degraded condition (8/64")bounds all newly documented degraded surfaces and the containment will remain operational and meet its intended design function during the upcoming operating cycle through Refuel Outage A1 R17 where additional examinations and repairs are scheduled.

Description of Necessary Corrective Actions Completed[10CFR SO.SSa(b)(2)(ix)(A)(3)]:

1)Approximately 115'of liner plate directly below the MB that was not exam ined previously inA1R 14 orA1R 15 was exam ined after the MB was removed.This completed the VT examination of the entire containment liner plate directly below the moisture barrier.2)Selected areas determined as augmented in A1 R14 or A1 R15 were further examined using the Ultrasonic examination method to document actual liner plate thicknesses in the vicinity of these pitted areas.3)This evaluation was completed to provide justification for the acceptability of the liner plate at its thinnest location and operation of the Unit 1 untilA1 R17 without repair or replacement activities on the containment liner plate.4)The liner surfaces at all the exposed locations where the moisture barrier had been removed were prepared for Keeler and Long 9600 series coating (used for Level I coating in containment) that was applied duringA1 R16 along with a new Cerafibre and new moisture barrier.5)A new moisture barrier was installed at all areas where it was removed.AService VT-3 exam was performed after all repairs were made on the entire moisture barrier.No conditions which would allow water intrusion were identified.

6)Portions of Class CC liner below the moisture barrier have been categorized as Category E-C in the lSI schedule.Proposed Corrective Actions for A1 R17: Liner repairs shall be performed in the areas exceeding 4/64" prior to performance of the Containment Integrated Leak Rate Test (ILRT), scheduled inA1 R17.In addition to the repairs, additional examinations are scheduled forA1 R17.This scope includes locations that showed thickness loss greater than 1/64" as identified duringA1 R14,A1 R15 andA1 R16.Page 2 of 7 ATTACHMENT 2 A 1 R16 Containment 151 (IWE/lWL)Results Conclusions/Findings:

The liner plate is acceptable and capable of performing its intended design function until A1R17 where a combination of augmented examinations and liner plate weld repairs are scheduled for completion.

ASME IWL REPORT OF CONTAINMENT DEGRADATION The 25 th Year ASME Class CC examinations and tests for Unit 1 (and Unit 2)containment surfaces were completed during 2011 prior toA1 R16.Additionally, the 25 th year examinations and tests for the Units 1 (and Unit 2)ASME Class CC Post Tensioning Systems were completed.

As permitted by ASME Section XI IWL-2421 , the examination requirements were modified.The Braidwood Units are identical in design, the post tensioning system operations were completed not more than two years apart.The requirements specified in ASME IWL-2524 and IWL-2525 were met for the Unit 1 Post Tensioning System during the 25 th Year Surveillance.

The requirements specified in ASME IWL-2523, IWL-2524, and IWL-2525 were met for the Unit 2 Post Tensioning System during the 20 th Year Surveillance.

NRC Regulatory Guide 1.35.1 1990)was used to determine predicted forces.The Exelon procedure implemented for the 25 t Year Post Tensioning Surveillance was ER-AA-330-006,"In-service Inspection and Testing of the Pre-Stressed Concrete Post Tensioning Systems".In addition to the tendons selected in accordance with IWL-2521, an augmented sample of tendon grease caps were removed for free water inspection.

This sample included grease caps installed on vertical tendons located below grade elevation (401'), grease caps from horizontal tendons located below grade elevation (401')and grease caps from dome tendons.For those locations where the presence of free water was detected, samples of the sheathing filler grease and water (if sufficient quantities were collected to allow for analysis)were obtained and chemically analyzed in accordance with IWL-2525 and examination of the anchorage components and surrounding concrete were performed in accordance with IWL-2524.During grease cap examinations, there was no evidence ofdeformationobserved which was indicative of deterioration of anchorage hardware.With regard to pre-stress forces and elongation measurements, all acceptance standards were met.Additionally,the Regression Analysis as specified in NRC Information Notice 99-10 was completed.

The results of the regression analysis concludes the projectedoff forces for each group of tendons for the next surveillance and beyond the 40 year life of the plant is higher than the minimum post tensioning force for all three tendon groups.As required by 10CFR 50.55(a)the applicant orlicenseeshall report the following conditions, if they occur, in the lSI Summary Report required by IW A-6000: (1)The sampled sheathing filler grease contains chemically combined water exceeding 10 percent by weight or the presence of free water: Discussion as applicable to the 25 th Year Post Tensioning Surveillance:

There was no instance where the chemically combined water exceeded ten percent by weight.However the presence of free water was detected.The anchorage components for all tendons are accessible for inspection for the presence of free water when the grease caps are removed.A total of 38 Unit 1 grease caps were removed for presence of free water during the 2011 surveillance.

Of these 38 locations, eleven were locations selected in addition to those to meet the requirements of Table IWL-2525-1.

The grease caps from these eleven locations were removed for the purpose of examination for the presence of free water.The basis for selection of these eleven locations was history of free water and other locations which may be suspect for free water intrusion.

Of the Page 3 of 7 ATTACHMENT 2 A 1 R16 Containment 151 (.WE/IWl)Results eleven locations, free water was collected from seven.The majority of the eleven locations were those with a history of the presence of free water during past examinations.

The presence of free water at specific locations is managed through additional examinations in conjunction with the post tensioning surveillance activities required by ASME Section XI on a five year frequency.

The following table provides a summary of the free water collected:

Unit Tendon IR Tendon auantity.Reason For Selection EPN Number End Collected (Oz.)1 0-1-37 1247483 Shop 2 Augmented (Free Water Exam)1 0-1-40 1247480 Shop 17 25th Yr.lSI 1 H-01-AC 1234002 Field 3 Augmented (Free Water Exam)1 H-02-AC 1234000 Field 1 Augmented (Free Water Exam)1 H-02-BA 1238029 Shop 6 Augmented (Free Water Exam)1 H-02-BA 1239892 Field 7 Augmented (Free Water Exam)1 V-142 1231835 Field 11 25th Yr.lSI Although free water was collected from these locations, no active corrosion or other physical degradation due to the presence of free water was identified and all chemical analysis acceptance standards were met.(2)The absolute difference between the amount removed and the amount replaced exceeds 10 percent of the tendon net duct volume;Discussion as applicable to the 25 th Year Post Tensioning Surveillance:

There was no instance where the amount of sheathing filler grease removed and the amount replaced exceeded 10 percent of the tendon net duct volume.(3)Grease leakage is detected during general visual examination of the containment surface.Discussion as applicable to the 25 th Year Containment Concrete Surface Exams: Five indications of grease leakage through the surface were observed.Three indications are new and have developed since the previous examination in 2006.The following table provides descriptions of the indications:

Page 4 of 7 ATTACHMENT 2 A1 R16 Containment lSI (IWElIWL)Results UNIT DESCRIPTION OF CONDITION I INDICATION NEW INDICATION SINCE 2006 EXAM: Grease Leakage (Containment Surface): Location: Outdoors, Northeast Face, first horizontal joint 1 down.Leakage is at a previously placed form tie patch, minor shrinkage crack extends down.Surfaceare of grease is approximately 8" high x 6" wide.Grease accumulation is conservatively estimated at 1 pint.No evidence of exposed reinforcinQ steel or structural distress was observed.NEW INDICATION SINCE 2006 EXAM: Grease Leakage (Containment Surface): Location: Outdoors, East Face of Containment, Location: upper left hand corner of the patch that was placed in support of closure of the steam generator replacement (SGR)project opening.Degradation in the form of pattern cracking (surface area approximately 3'-0" x 3'-0"), a single crack 1 exists (approximately 5'-0" long with minimal width)from a form tie patch down to the edge of the SGR opening patch.Efflorescence exists in localized areas in the pattern cracking, and evidence of grease leakage/staining (no significant accumulation) exists in the vicinity of the crack adjacent to the form tie patch.There is no evidence of structural degradation such as deflection of concrete, significant cracking, settlement, shifting, or exposed reinforcing steel.CHANGE IN INDICATION SINCE 2006 EXAM: Grease Leakage (Containment Surface): Location: Outdoors, East Face of Containment, Location: upper right hand corner of the patch that was placed in support of closure of the steam generator replacement project opening.The 1 characteristics of the indication have not changed significantly but additional cracking further up, extending from previously identified cracking (tight widths and approximately 2'-0" in length)and additional minor grease staining/leakage within the new cracked area was observed.There are additional localized areas of pattern cracking in the panel adjacent to the indication.

No evidence of structural distress or exposed reinforcinQ steel was identified.

MINOR CHANGE IN INDICATION SINCE 2006 EXAM: Grease Leakage (Containment Surface): Location: Outdoors, Location: Horizontal construction joint approximately 30'to the left (south)of the 18/1 C MainSteamIsolation Valve Rooms and approximately 35'above ground level.The 1 only change from the previous inspection is as expected the quantity of grease accumulation has slightly increased, estimated to be a maximum of one quart.There are no significant changes in the characteristics of the previously identified small void/crack.No evidence of structural distress or exposed reinforcing steel was identified.

NEW INDICATION SINCE 2006 EXAM: Grease Leakage (Containment Surface): Location: Outdoors, Northwest Face of Containment, Location: Above (approximately 1')the second horizontal joint down from the dome access grating approximately 20'to the left of the permanent/vertical ground 1 cable that runs fromthetop to the bottom of the containment exterior.The leakage starts approximately l'up from the joint and extends down to the horizontal joint.The source of the leakage is through a minor shrinkage crack/void.The leakage does not appear to be significant or active.The quantity of the grease accumulation is estimated to be a maximum of 1 pint.There is no evidence of structural distress or exposed reinforcing steel.Page 5 of 7 ATTACHMENT 2 A 1 R16 Containment lSI (IWElIWL)Results As required by 10CFR 50.55(a), for Class CC applications, the applicant or licensee shall evaluate the acceptability of inaccessible areas when conditions exist in accessible areas that could indicate the presence of or result in degradation to such inaccessible areas.For each inaccessible area identified, the applicant or licensee shall provide the following in the lSI Summary Report required by IWA-6000: (1)A description of the type and estimated extent of degradation, and the conditions that led to the degradation:

(2)An evaluation of each area, and the result of the evaluation, and;(3)A description of necessary corrective actions.Discussion as applicable to the 25 th Year Containment Concrete Surface Exams: (1)Description of the type and estimated extent of degradation, and the conditions that led to the degradation:

The type of degradation is evidence of grease leakage through the concrete surface.The estimated extent of degradation in the inaccessible area is negligible if any exists.The primary inaccessible area is the containment surface below grade level.During the post tensioning surveillance activities there has been no significant differences in the quantity of sheathing filler grease removed versus installed.

Additionally, no degradation has been identified during visual examination or physical testing of the tendons located below grade level.The conditions that led to the degradation is grease seepage I leakage through minor cracks in the structure between the surface and the tendon sheathing.

(2)Evaluation of each area and the result of the evaluation:

Based on RPE review I evaluation the conditions do not warrant repair as it has negligible impact on the structure.

With regard to the post tensioning system the quantity of grease leakage is small when compared to the volume (>100 gallons)in each tendon duct.The condition will not result in post tensioning components becoming uncoveredorsusceptible to corrosion.

(3)Description of Necessary Actions: The conditions will be monitored through annual examinations for significant changes in the grease leakage.At this time all indications have been evaluated as not having any significant impact on the structural integrity of the containments.

Discussion as applicable to the Presence of Free Water (1)Description of the type and estimated extent of degradation, and the conditions that led to the degradation:

The type of degradation is the existence of free water in the post tendon grease caps and ducts.The anchorage components for all tendons are accessible for inspection for the presence of free water when the grease caps are removed.Although undesirable, the presence of free water is not resulting in degradation of the tendon hardware.The condition that led to the presence of free water in the tendons is water infiltration through minor cracks and voids in the outer surface of the structure.

Additionally, a damaged dome drainage system contributed to water intrusion into the dome tendons.The drainage system has been repaired.(2)Evaluation of each area and the result of the evaluation:

The presence of free water inside the sheathing and the resultant potential for corrosion is the condition to be addressed Ievaluated.Althoughundesirable, the potential presence of free water in the tendon ducts I sheathing does not present a Page 6 of 7 ATTACHMENT 2 A 1 R16 Containment lSI (IWElIWL)Results concern with regard to corrosion.

The basis for this conclusion is as follows: No active corrosion or other degradation was identified during any examination of the anchorage hardware.The quantity of grease replaced versus removed did not exceed 10%of the tendon net duct volume during any re-greasing operation.

The moisture content in all grease samples did not exceed ten percent volume by weight.During a past surveillance (2001)a"worse case" tendon from which a significant quantity (nine gallons)of free water was collected was subjected to force measurement, completely de-tensioned, wire removed for examination and testing, and re-tensioning.

The sheathing filler grease ("Visconorusf' 2090-P4)was observed to maintain the film integrity during as found inspections.

The tendon met all visual and physical acceptance standards.

The removed wire showed no evidence of corrosion and met all physical testing acceptance standards.

The free water had accumulated in the tendon from construction (1985)until 1998 when it was selected for initial inspection.

No further evaluation is required.(3)Description of Necessary Actions: Braidwood will continue including selection of additional anchorage locations beyond that required by ASME Section XI for the purpose of inspection for the presence of free water during the 30 th year surveillance and beyond.The scope of the tendons selected will include the 10 anchorage locations with greater than ten ounces of free water collected during the 25 th year surveillance.

Additionally, other anchorage locations located below grade level and dome tendons have been selected for grease cap removal and inspection for evidence of free water.A total of 24 Unit 1 grease caps have been selected for removal for free water inspection during the 30 th Year surveillance (2016).Page 7 of 7