ML103130038
| ML103130038 | |
| Person / Time | |
|---|---|
| Site: | Millstone  |
| Issue date: | 10/28/2010 |
| From: | Jordan A Dominion, Dominion Nuclear Connecticut |
| To: | Document Control Desk, Office of Nuclear Reactor Regulation |
| Shared Package | |
| ML103130038 | List: |
| References | |
| 10-632, FOIA/PA-2011-0115 | |
| Download: ML103130038 (26) | |
Text
Dominion Nuclear Connecticut, Inc.
/i Millstone Power Station
- Dominion, Rope Ferry Road OCT 2 8 2010 Waterford, CT 06385 U.S. Nuclear Regulatory Commission Serial No.10-632 Attention: Document Control Desk NSS&L/MLC RO Washington, DC 20555 Docket No.
50-423 License No.
NPF-49 DOMINION NUCLEAR CONNECTICUT. INC.
MILLSTONE POWER STATION UNIT 3 END OF CYCLE 13 STEAM GENERATOR TUBE INSPECTION REPORT In accordance with the Millstone Power Station Unit 3 Technical Specification (TS)
Section 6.9.1.7, Dominion Nuclear Connecticut, Inc. hereby submits the End of Cycle 13 Steam Generator Tube Inspection Report. The report is submitted within 180 days after initial entry into MODE 4 following completion of an inspection performed in accordance with TS 6.8.4.g, Steam Generator (SG) Program.
The report includes the following:
- a. The scope of inspections performed on each SG,
- b. Active degradation mechanisms found,
- c. Nondestructive examination techniques utilized for each degradation mechanism,
- d. Location, orientation (if linear), and measured sizes.(if available) of service induced indications,
- e. Number of tubes plugged during the inspection outage for each active degradation mechanism,
- f. Total number and percentage of tubes plugged to date,
- g. The results of condition monitoring, including the results of tube pulls and in-situ
- testing,
- h. The effective plugging percentage for all plugging in each SG,
- i. During Refueling Outage 13 and the subsequent operating cycle, 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,
- j. 'During Refueling Outage 13 and the subsequent operating cycle, the calculated accident induced leakage rate from the portion of the tubes' below 13.1 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 2.49 times the maximum operational primary to secondary leakage rate, the report should describe how it was determined;, and Awol
Serial No.10-632 Docket No. 50-423 Page 2 of 2
- k. During Refueling Outage 13 and the subsequent operating cycle, the results of monitoring for tube axial displacement (slippage). If slippage is discovered, the implications of the discovery and corrective action shall be provided.
If you have any questions or require additional information, please contact Mr. William D.
Bartron at (860) 444-4301.
Sincerely, Aj.
Site Vic President - Millstone
Enclosures:
(1)
Commitments made in this letter: None.
cc:
U.S. Nuclear Regulatory Commission Region I 475 Allendale Road King of Prussia, PA 19406-1415 C. J. Sanders NRC Project Manager U.S. Nuclear Regulatory Commission One White Flint North, Mail Stop 08-B3 11555 Rockville Pike Rockville, MD 20852-2738 NRC Senior Resident Inspector Millstone Power Station
Serial No.10-632 Docket No. 50-423 ENCLOSURE Millstone Power Station Unit 3 End of Cycle 13 Steam Generator Tube Inspection Report MILLSTONE POWER STATION UNIT 3 DOMINION NUCLEAR CONNECTICUT, INC.
Serial No.10-632 Docket No. 50-423 Enclosure Page 1 of 20 End of Cycle 13 Steam Generator Tube inspection Report Millstone Power Station Unit 3 (MPS3) is a four loop Westinghouse pressurized water reactor (PWR) with Westinghouse Model F steam generators (SGs). Each SG contains 5626 U-bend thermally treated Inconel 600 tubes. The tubing is nominally 0.688 inches outside diameter with a 0.040-inch nominal wall thickness. During SG fabrication, the tubes were hydraulically expanded over the full depth of the 21.23-inch thick tubesheet. The tubesheet was drilled on a square pitch with 0.98-inch spacing. There are 59 rows and 122 columns in each SG. The radius of the row 1 U-bends is 2.20 inches. U-bends in rows 1 through 10 were stress relieved after being formed. Secondary side tube support structures include a flow distribution baffle, seven plate supports with broached holes on the vertical section of the tubes, and six anti-vibration bars (AVBs) on the U-bend section of the tubes.
The SGs have accrued 17.9 effective full power years (EFPY) of operation as of the End of Cycle (EOC) 13 (April 2010). Prior to the beginning of Cycle 13, MPS3 operated with a hot leg temperature of 617 degrees Fahrenheit. A 7% power uprate was implemented for Cycle 13.
Following the uprate, MPS3 operated with a hot leg temperature of 622 degrees Fahrenheit.
The MPS3 SG eddy current testing (ECT) conducted at the EOC 13 was completed on April 24, 2010. The examinations, personnel, and equipment conformed to the requirements of NEI 97-06, Revision 2, Steam Generator Program Guidelines; Electric Power Research Institute (EPRI)
Pressurized Water Reactor Steam Generator Examination Guidelines: Revision 7; and MPS3 Technical Specifications (TSs). One hundred percent of the operational tubes within SG B and SG D, a total of 10,182 tubes (approximately 50% of the total population of tubes), were inspected full length. The majority of the tubing length was examined with bobbin probes. The U-bends of row 1 and row 2 tubes were examined by a motorized rotating pancake coil (MRPC) technique in addition to the bobbin probe examination of the straight legs of the tubes. An augmented sample, 8,665 tube locations, was inspected with diagnostic rotating coils. The rotating coil inspections were performed in areas of special interest (SI) including hot leg expansion transitions, tube overexpansion locations within the hot leg tubesheet, low row U-bends, and dents, as well as locations where the bobbin probe response was ambiguous. The sample included bounding examinations for possible loose part (PLP) indications and new volumetric (fabrication or foreign object wear) detections. Outside the tubesheet, the only indications of degradation recorded were attributed to mechanically induced wear or fabrication related damage.
Seven tubes were removed from service during 3R13. One tube in SG B was identified with AVB wear, sized at 37% through-wall (TW), and was discretionarily removed from service. One tube with inside diameter chatter (IDC) was discretionarily removed from service in SG D after completing condition monitoring (CM) using the +PointTM examination. One historical volumetric indication with no significant change was removed from service in SG D due to application of the new EPRI Examination Technique Specification Sheet (ETSS) 27901.1 sizing technique for foreign object wear, which produced a depth estimate of 41% TW. Three tubes in SG B were discretionarily removed from service due to probable foreign object wear less than 40% TW since the locations were not accessible for visual confirmation that no foreign object was present for continued wear. One tube in SG D was removed from service due to foreign object wear with a depth of 52% TW.
Serial No.10-632 Docket No. 50-423 Enclosure Page 2 of 20 Two indications of minor wear at a tube support plate (TSP) were reported during 3R13. These indications were sized at 17% and 22% TW.
The following paragraphs provide more information on-foreign objects and foreign object wear identified during 3R13.
Six tubes in SG B were identified with new probable foreign object wear. Three tubes in SG B with shallow probable foreign object wear above the top of the tubesheet cold leg side (TSC) could be examined by Foreign Object Search and Retrieval (FOSAR) to confirm that the foreign object and potential of continued wear was no longer present. These three tubes were retained in service. Three other tubes in SG B had shallow probable foreign object wear in locations that were not accessible by FOSAR. Although there were no eddy current indications of PLPs at any of the SG B wear locations, the three inaccessible tubes were removed from service since the probability of continued wear growth could not be confirmed visually.
Four tubes in SG D were identified with new confirmed or probable foreign object wear. A small nail was found above 01 H adjacent to the deepest wear indication of 52% TW and adjacent to a 26% TW indication in an adjacent tube. The nail was removed from the location and the 52% TW wear tube was removed from service. A second location at 01C had shallow wear (16% TVV and 27% TW) on two adjacent tube3. No PLP was detected at the 01C location. Since FOSAR could access both of these tubes and no foreign object was found, the tubes were retained in service.
Four new metallic foreign object locations were found by ECT or secondary side inspection (SSI) during 3R13. These were: 1) a small metal object found above the TSC in SG A, 2) a 4" metal turning above the top of tubesheet hot leg side (TSH) in SG D, 3) a small nail above 01 H responsible for tube wear in SG D and a small group of two machine curls, and
- 4) a small piece of flex on the outer edge annulus above 01 H in SG D. The first three objects were removed from the SGs. The two machine curls and piece of flex could not be removed. One known foreign object fixed in SG C at R1 C4 in the cold leg was confirmed to be in its 'as found' position.
Tube slippage monitoring was performed during 3R13. No indications of tube slippage were reported.
In accordance with MPS3 TSs, a SG tube inspection report is required. TS Section 6.9.1.7 states:
A report shall be submitted within 180 days after the initial entry into MODE 4 following completion of an inspection performed in accordance with TS 6.8.4.g, Steam Generator (SG) Program. The report shall include:
- a. The scope of inspections performed on each SG, All in-service tubes of SG B and SG D were inspected during the 3R13 outage. The majority of the tubes were inspected from the tube end of the hot leg (TEH) to the tube end of the cold leg (TEC) via the 100% full length bobbin coil examination. The U-bends of row
Serial No.10-632 Docket No. 50-423 Enclosure Page 3 of 20 1 and row 2 tubes were examined by a Motorized Rotating Probe Coil (MRPC) technique in addition to the bobbin probe examination of the straight legs of the tubes. See Attachment 1, "Acronyms," for explanation of acronyms. See Attachment 2, "Millstone Power Station Unit 3 Steam Generator Arrangement," for illustration of steam generator component locations.
Additionally, for both SG B and SG D, the diagnostic rotating coil examinations included a 50% sample of hot leg tubesheet expansion transitions (TSH +3"/-3") and a 732 tube sample in the cold leg tubesheet periphery expansion transitions (TSC +3"7-3").
A secondary side visual examination was performed on all four steam generators.
In total, 8,665 diagnostic examinations were performed. The locations included 3R1 1 historical locations which consisted of previously reported dings (DNG), dents (DNT), non-quantifiable historical indications (NQH), overexpansions above the tubesheet (OVR),
overexpansions within the tubesheet (OXP), PLP, percent through wall indications (%TW),
volumetric indications (VOL) and wear indications (WAR). These locations also included 3R13 bobbin coil special interest (SI) locations such as non-quantifiable indications (NQI),
PLP, and various hot leg and cold leg PLP bounding locations. The inspection summary is documented in Table 1.
Serial No.10-632 Docket No. 50-423 Enclosure Page 4 of 20 Table I MPS3 ECT Summary for 3R13 SG A SG B SG C SG D Total Number of Tubes Inservice 5,588 5,610 5,604 5,543 22,345 Number of Tubes Inspected Full Length w/Bobbin Probe N/A 5,122 N/A 5,060 10,182 Number of Tubes Inspected w/Bobbin Probe Hot Leg N/A 244 N/A 244 488 Straights and Cold Leg Candy Canes (Rows 3 and 4)
Number of Tubes Inspected w/Bobbin Probe Hot and Cold N/A 244 N/A 239 483 Leg Straights and MRPC U-Bends (Rows 1 and 2)
Previously Plugged Tubes 38 16 22 83 159 Number of Tubes Incomplete w/Bobbin Probe due to N/A 0
N/A 0
0 Obstruction Number of Examinations w/MRPC (Total)t N/A 4,258 N/A 4,407 8,665 oHot Leg Tubesheet, OXP (TTS+3 to TSH -15")
N/A 40 N/A 70 110
- Hot Leg Transitions (+3 / -3) - Original Scope +
N/A 2,851 N/A 2,850 5,701 Additional oHot Leg Transitions - Scope Expansion N/A 0
NiA 0
0
- Cold Leg Transitions (+3 / -3) - Original Scope +
N/A 735 N/A 732 1467 Additional
- Cold Leg Transitions - Scope Expansion N/A 0
N/A 0
0 eRow 1 and 2 U-Bends - Original Scope N/A 244 N/A 239 483
- Hot Leg Misc. Special Interest - Diagnostic Exams and N/A 253 N/A 306 559 from Previous History
- Cold Leg Misc. Special Interest -Diagnostic Exams N/A 87 N/A 94 181 and from Previous History 9U-bend. Special Interest - Diagnostic Exams and from N/A 11 N/A 33 44 Previous History ePLP / SVI Bounding Special lnte.iest N/A 37 N/A 83 120 Total Number of Hot Leg OXP/OVR Locations Examined N/A 48 N/A 135 183 Total Number of Cold Leg OXP/OVR Locations Examined N/A 5
N/A 56 61 Tubes w/ Max AVB Wear > 40 %
N/A 0
N/A 0
0 Tubes w/ Max AVB Wear > 37 %
N/A 1
N/A 0
1 Tubes w/ Max AVB Wear >20% but <37%
N/A 15 N/A 19 34 Tubes w/ Max AVB Wear <20%
N/A 33 N/A 53 86 Tubes w/ Max TSP Wear >20% but <40%
N/A 0
N/A 1
1 Tubes w/ Max Non-Structure Vol. Deg, > 40 %
N/A 0
N/A 2
2 Tubes w/ Max Non-Structure Vol. Deg. >20% but <40%
N/A 5
N/A 4
9 Tubes w/ Max Non-Structure Vol. Deg. <20%
N/A 3
N/A 2
5 Total Tubes Plugged as a Result of this Inspection:
N/A 4
N/A 3
7 e Due to AVB Wear >37% (discretionary)
N/A 1
N/A 0
1 e Due to Non-Support Volumetric Degradation > 40 %
N/A 0
N/A 2
2 e Due to Non-Support Volumetric Degradation < 40 %
N/A 3
N/A 0
3 (discretionary) e Due to IDC (discretionary)
N/A 0
N/A 1
1 e Due to an Obstruction N/A 0
N/A 0
0 4 Values provided in the total and the sub-bullets correspond to the number of examinations performed.
Serial No.10-632 Docket No. 50-423 Enclosure Page 5 of 20
- b. Active degradation mechanisms found, The existing degradation mechanisms found during 3R13 included AVB wear, first two indications of tube support plate (TSP) wear and volumetric degradation from foreign object wear.
- c. Nondestructive examination techniques utilized for each degradation mechanism, Table 2 identifies the examination techniques utilized for each identified degradation mechanism.
Serial No.10-632 Docket No. 50-423 Enclosure Page 6 of 20 Table 2 Identified Deqradation Mechanisms and Examination Techniques*
Degradation Location DetectionTechnique, ETSS Mechanism Number Wear Tube at AVB, Tube at FDB Bobbin, 96004.3 Bobbin, Site Spec NU-MP3-AVB-1
+Point, 96910.1 0.115", 96911.1
+Point, 21998.1 Pitting Tube at Secondary Side Sludge /
Bobbin, 96005.2 Deposits
+Point, 21998.1 Thinning Tube at support structures Bobbin, 96001.1 Impingement Tube Bobbin IGA/SCC (OD)
Tube Freespan, Non Dented Bobbin, 96008.1 Volumetric/Axial Support Intersections, Sludge Bobbin, 96007.1 Regions
+Point, 22401.1 Dented TSP Bobbin, 24013.1
<5.00v Dings IGA/SCC (OD)
Freespan Bobbin, 128412 Axial Freespan, Sludge Pile and Bobbin, 128413 Broached TSP
+Point, 128424
+Point, 128425 Wear (foreign Circ. Groove
+Point, 27901.1 object not present) Axial Groove
+Point, 27902.1 (freespan)
Tapered football
+Point, 27903.1 Tapered round hole
+Point, 27904.1 Flat wear
+Point, 27905.1 Tapered wear
+Point, 27906.1 45 deg. Tapered wear
Tube Freespan, Dented and Non
+Point, 21409.1 Circumferential Dented Support Intersections,
+Point, 21410.1 Sludge Regions, Expansion
+point, 22842.1 Transition
+Point, 22842.3 PWSCC (ID)
Tube Expansion Transition, Within +Point, 20510.1 Circumferential Tubesheet, Dents, Near Seal Weld +Point, 96701.1
("tube end cracking"), Plugs PWSCC (ID)
Tube Expansion Transition, Within +Point, 20511.1 Axial Tubesheet, Dents, Near Seal Weld Bobbin, 96012.1
("tube end cracking"), Plugs
+Point, 96703.1
<2.00v Dents @ TSP Ghent 3/4, 20507.1 Ghent 3/4, 20508.1 Degradation Location DetectionTechnique, ETSS Mechanism Number PWSCC (ID)
Det, ext sizing, circ.
UT, 98302.1 Axial Det, ext sizing, axial UT, 98302.3 (continued)
Depth sizing, circ UT, 98303.1 Depth sizing, axial UT, 98303.3 PT PWSCC (ID)
Low Row U-bends
+Point, 96511.3 Axial and/or
+Point, 96511.2 Circumferential Corrosion Induced Support Structures Bobbin, no specific ETSS Tube Denting Plug Installation Piug/Tube Interface Engineeringreview plug Deficiencies, Plug installation parameters and plug IGA/SCC video after Installation; Engineering visual examination (video) of existing plug(s)
Cracking Secondary side structures and Visual Inspection of upper components Internals structures and components in accordance with the EPRI Steam Generator Integrity Assessment Guidelines, Chapter 10.
Flow Assisted Feedring, J-Tube / Feedring Visual and UT Inspection of upper Corrosion Interface, Moisture Separators Internals structures and components In accordance with the EPRI Steam Generator Integrity Assessment Guidelines, Chapter 10.
Foreign Objects, Tubes, TTS, FOB, Blowdown pipes Visual Inspection of structures Sludge, Scale and components, retrieval of foreign objects.
PWSCC Prlmar side 1600 structures and Visual inspection of components components and structures within and adjacent to the SG bowls in accordance with ER-AA-MAT-10, Dominion Reactor Coolant System Materials Degradation Management Program.
- The inspection is directed toward those damage mechanisms with realistic near-term potential for development.
Serial No.10-632 Docket No. 50-423 Enclosure Page 7 of 20
- d. Location, orientation (if linear), and measured sizes (if applicable) of service induced indications, The following tables (Tables 3 through 10) identify the AVB wear, TSP wear, and volumetric indications reported during 3R13.
Table 3 Steam Generator B - Repeat AVB Wear Indications Old New Row Col Elev Old New Old New Change Growth Rate Outage Outage Offset Offset
%TW
%TW 3R11 3R13 30 12 AV2 0
0.05 13 13 0
0.00
%TW/EFPY 3R11 3R13 30 12 AV5 0.2 0.1 16 16 0
0.00
%TW/EFPY 3R11 3R13 32 108 AV4
-0.05
-0.02 13 15 2
0.74
%TW/EFPY 3R1I 3R13 33 12 AV2
-0.05 0
14 16 2
0.74
%TW/EFPY 3R11 3R13 33 12 AV5 0
0 16 17 1
0.37
%TW/EFPY 3R11 3R13 33 39 AV3 0.05 0.1 11 11 0
0.00
%TW/EFPY 3R11 3R13 33 109 AV2
-0.07
-0.1 15 15 0
0.00
%TW/EFPY 3R11 3R13 33 109 AV3
-0.13 0.02 18 20 2
0.74
%TW/EFPY 3R11 3R13 34 18 AV4 0.05 0
10 10 0
0.00
%TW/EFPY 3R1I 3R13 34 109 AV2
-0.06
-0.14 8
10 2
0.74
%TW/EFPY 3R11 3R13 34 109 AV3 0
0 22 24 2
0.74
%TW/EFPY 3R11 3R13 34 109 AV5
-0.16
-0.14 14 14 0
0.00
%TW/EFPY 3R11 3R13 34 109 AV6 0.05
-0.07 9
11 2
0.74
%TW/EFPY 3R11 3R13 35 106 AV3 0.02 0
9 10 1
0.37
%TW/EFPY 3R11 3R13 35 106 AV4 0.07
-0.05 15 17 2
0.74
%TW/EFPY 3R11 3R13 35 106 AV6 0
0 10 10 0
0.00
%TW/EFPY 3Rl1 3R13 36 22 AV6 0.12 0
11 12 1
0.37
%TW/EFPY 3R11 3R13 36 39 AV2 0.24 0.22 12 11
-1
-0.37
%TW/EFPY 3R11 3R13 36 39 AV3 0.02 0
12 12 0
0.00
%TW/EFPY 3R11 3R13 36 39 AV5 0.02 0
19 18
-1
-0.37
%TW/EFPY 3R11 3R13 36 39 AV6 0.22 0.19 15 14
-1
-0.37
%TW/EFPY 3R1I 3R13 37 103 AV2
-0.12 0.05 12 11
-1
-0.37
%TW/EFPY 3R11 3R13 37 104 AV3 0
0 13 14 1
0.37
%TW/EFPY 3R11 3R13 37 104 AV4
-0.07
-0.07 12 10
-2
-0.74
%TW/EFPY 3R1l 3R13 38 104 AV3
-0.05
-0.07 17 16
-1
-0.37
%TW/EFPY 3R11 3R13 38 104 AV4
-0.12
-0.2 28 26
-2
-0.74
%TW/EFPY 3R11 3R13 38 104 AV5
-0.02
-0.22 14 11
-3
-1.10
%TW/EFPY 3R11 3R13 39 30 AV2 0.22 0.19 12 14 2
0.74
%TW/EFPY 3R11 3R13 39 30 AV4 0
-0.05 10 12 2
0.74
%TW/EFPY 3R11 3R13 39 30 AV5
-0.02
-0.1 12 14 2
0.74
%TW/EFPY 3R11 3R13 39 96 AV3 0 -
0 14 12
-2
-0.74
%TW/EFPY 3R11 3R13 40 23 AV2 0.1 0.02 14 13
-1
-0.37
%TW/EFPY 3R11 3R13 40 23 AV3 0.02 0.05 11 11 0
0.00
%TW/EFPY 3R1I 3R13 40 23 AV4
-0.1 0
15 14
-1
-0.37
%TW/EFPY 3R11 3R13 40 23 AV5
-0.05 0
17 16
-1
-0.37
%TW/EFPY 3R11 3R13 40 24 AV3 0.02
-0.05 16 19 3
1.10
%TW/EFPY 3R11 3R13 40 24 AV4 0
0.02 20 22 2
0.74
%TW/EFPY 3R1l 3R13 40 24 AV5
-0.02,
-0.07 14 16 2
0.74
%TW/EFPY 3Rl1 3R13 41 34 AV2 0.46 0.41 15 14
-1
-0.37
%TW/EFPY 3R11 3R13 41 34 AV3 0.15 0.14 18 15
-3
-1.10
%TW/EFPY 3R11 3R13 41 34 AV4 0.29 0.22 33 31
-2
-0.74
%TW/EFPY 3R11 3R13 41 34 AV5 0
-0.07 31 30
-1
-0.37
%TW/EFPY 3R11 3R13 41 34 AV6 0
0 14 10
-4
-1.47
%TW/EFPY 3Rl1 3R13 41 50 AV3
-0.15
-0.15 12 12 0
0.00
%TW/EFPY 3R11 3R13 41 50 AV4
-0.12
-0.12 21 22 1
0.37
%TW/EFPY
Serial No.10-632 Docket No. 50-423 Enclosure Page 8 of 20 Old New Row Col Elev Old New Old New Change Growth Rate Outage Outage Offset Offset
%TW
%TW 3Rl1 3R13 41 69 AV4
-0.12
-0.17 15 16 1
0.37
%TW/EFPY 3Rl1 3R13 41 69 AV5
-0.05
-0.05 27 28 1
0.37
%TW/EFPY 3Rl1 3R13 41 77 AV3 0.2 0.12 18 16
-2
-0.74
%TW/EFPY 3Rl1 3R13 41 77 AV4
-0.15
-0.17 14 15 1
0.37
%TW/EFPY 3Rl1 3R13 41 77 AV5 0
-0.1 21 22 1
0.37
%TW/EFPY 3Rl1 3R13 42 21 AV2 0.1 0.07 14 13
-1
-0.37
%TW/EFPY 3Rl1 3R13 42 21 AV3
-0.12
-0.12 12 11
-1
-0.37
%TW/EFPY 3R11 3R13 42 21 AV4 0.1 0.05 22 23 1
0.37
%TW/EFPY 3R11 3R13 42 21 AV5 0
0 26 24
-2
-0.74
%TW/EFPY 3R11 3R13 42 21 AV6 0.07 0.02 13 13 0
0.00
%TWIEFPY 3R11 3R13 42 33 AV2 0.02 0.02 13
'13 0
0.00
%TW/EFPY 3R11 3R13 42 40 AV2
-0.05
-0.05 21 21 0
0.00
%TW/EFPY 3R1l 3R13 42 40 AV3 0.1 0.1 20 20 0
0.00
%TW/EFPY 3R11 3R13 42 40 AV4 0.02 0.02 35 37 2
0.74
%TW/EFPY 3R11 3R13 42 40 AV5
-C.1
-0.1 13 10
-3
-1.10
%TW/EFPY 3R11 3R13 42 40 AV6 0.07 0.12 12 11
-1
-0.37
%TW/EFPY 3R11 3R13 42 96 AV2 0.14 0.1 22 23 1
0.37
%TW/EFPY 3R11 3R13 42 96 AV3
-0.05 0
13 16 3
1.10
%TW/EFPY 3R1l 3R13 42 96 AV4
-0.07 0
12 14 2
0.74
%TW/EFPY 3R11 3R13 42 96 AV5
-0.23
-0.07 13 19 6
2.21
%TW/EFPY 3Rl1 3R13 42 98 AV2 0.07 0.1 33 30
-3
-1.10
%TW/EFPY 3R11 3R13 42 98 AV3
-0.02 0
29 28
-1
-0.37
%TW/EFPY 3R11 3R13 42 98 AV5
-0.07 0
15 13
-2
-0.74
%TW/EFPY 3R11 3R13 43 100 AV3
-0.02 0
26 25
-1
-0.37
%TW/EFPY 3R11 3R13 43 100 AV4
-0.05 0
30, 29
-1
-0.37
%TW/EFPY 3R1l 3R13 43 100 AV6
-0.12
-0.12 13 15 2
0.74
%T'W/EFPY 3R1I 3R13 45 22 AV6
-0.17
-0.15 12 11
-1
-0.37
%TW/EFPY 3R11 3R13 46 99 AV4 0.02 0.05 10 11 1
0.37
%TW/EFPY 3R11 3R13 48 25 AV6
-0.29
-0.27 10 7
-3
-1.10
%TW/EFPY 3R11 3R13 49 27 AV/5 0.17 0.17 10 11 1
0.37
%TW/EFPY 3Rl1 3R13 50 72 AV3
-0.15
-0.1 14 13
-1
-0.37
%TW/EFPY 3R11 3R13 50 88 AV2 0.09 0.1 19 18
-1
-0.37
%TW/EFPY 3R11 3R13 50 88 AV3 0.05 0.05 22 22 0
0.00
%TW/EFPY 3R11 3R13 50 88 AV4 0.55 0
15 16 1
0.37
%TW/EFPY 3R11 3R13 50 88 AV5
-0.02 0.12 12 12 0
0.00
%TW/EFPY 3R11 3R13 51 91 AV4
-0.12
-0.07 14 15 1
0.37
%TW/EFPY 3R1l 3R13 51 91 AV5 0
0 18 18 0
0.00
%TW/EFPY 3R11 3R13 54 35 AV4 0
-0.05 12 11
-1
-0.37
%TW/EFPY 3R11 3R13 54 35 AV5 0
0.05 16 14
-2
-0.74
%TW/EFPY 3R11 3R13 54 35 AV6 0
0.05 12 11
-1
-0.37
%TW/EFPY 3R11 3R13 54 36 AV5
-0.17
-0.17 29 32 3
1.10
%TW/EFPY 3R11 3R13 54 36 AV6
-0.29
-0.29 14 16 2
0.74
%TW/EFPY 3R11 3R13 54 45 AV2 0.1 0
12 11
-1
-0.37
%TW/EFPY 3R11 3R13 56 41 AV3 0.15 0.15 10 12 2
0.74
%TW/EFPY 3R11 3R13 56 42 AV6 0
0 14 12
-2
-0.74
%TW/EFPY 3R11 3R13 56 81 AV1 0.07 0
12 9
-3
-1.103
%TW/EFPY 3R11 3R13 57 70 AV2
-0.02 0.1 10 10 0
0
%TW/EFPY 3R11 3R13
.58 75 AV5
-0.02 0
22 22 0
0
%TW/EFPY 3R11 3R13 59 65 AV2 0.22 0.63 11 12 1
0.3676
%TW/EFPY
Serial No.10-632 Docket No. 50-423 Enclosure Page 9 of 20 Table 4 Steam Generator B - Newly Reported AVB Wear Indications New Outage Row Col Elev New Offset New %TW 3R13 34 18 AV3
-0.14 10 3R13 34 110 AV3 0.02 12 3R13 35 103 AV6 0.02 11 3R13 36 67 AV6
-0.02 10 3R13 37 100 AV4
-0.07 10 3R13 42 19 AVI
-0.12 10 3R13 43 86 AV4 0
10 3R13 50 88 AV6 0
10
Serial No.10-632 Docket No. 50-423 Enclosure Page 10 of.20 Table 5 Steam Generator D - Repeat AVB Wear Indications Old New Row Col Elev Old New Old New Change Growth Rate Outage Outage Offset Offset
%TW
%TW 3R11 3R13 24 117 AV2 0
0 20 22 2
0.74
%TW/EFPY 3Rl1 3R13 26 8
AV6
-0.05
-0.05 14 15 1
0.37
%T'WEFPY 3R11 3R13 26 115 AVI 0
0.41 15 17 2
0.74
%TW/EFPY 3R11 3R13 27 115 AV2 0
-0.12 17 12
-5
-1.84
%TW/EFPY 3R11 3R13 27 115 AV5 0
0 14 15 1
0.37
%TvV/EFPY 3R11 3R13 28 8
AVI
-0.14
-0.02 12 17 5
1.84
%TW/EFPY 3R11 3R13 28 8
AV6 0.05 0.22 12 14 2
0.74
%TP'/EFPY 3R11 3R13 28 114 AV2 0
-0.1 31 32 1
0.37
%TW/EFPY 3R11 3R13 28 114 AV5 0
0 11 12 1
0.37
%TW/EFPY 3R11 3R13 29 113.
AV2
-0.05
-0.07 16 19 3
1.10
%TW/EFPY 3R11 3R13 29 113 AV5
-0.11 0
15 17 2
0.74
%TW/EFPY 3R11 3R13 30 114 AV6 0
0.05 21 22 1
0.37
%TW/EFPY 3R11 3R13 33 109 AV5 0.05 0
19 20 1
0.37
%TW/EFPY 3R11 3R13 35 99 AV2 0.12 0.1 12 14 2
0.74
%TW/EFPY 3R11 3R13 35 102 AV5 0.12 0.12 15 16 1
0.37
%TW/EFPY 3R11 3R13 35 103 AV5 0.09 0
19 17
.-2
-0.74
%TW/EFPY 3R11 3R13 35 108 AV3 0.05 0
17 17 0
0.00
%TW/EFPY 3R11 3R13 35 108 AV4 0.02 0
10 14 4
1.47
%TW/EFPY 3R11 3R13 35 109 AV4 0.07 0.02 14 17 3
1.10
%TW/EFPY 3R11 3R13 36 97 AV2
-0.02 0
13 15 2
0.74
%TW/EFPY 3R11 3R13 37 93 AV2 0.23 0.19 17 14
-3
-1.10
%TW/EFPY 3R11 3R13 37 93 AV3 0
0.02 20 20 0
0.00
%TW/EFPY 3R11 3R13 37 101 AV2 0.02
-0.07 19 18
-1
-0.37
%TW/EFPY 3R11 3R13 37 101 AV3 0.26
-0.02 14 14 0
0.00
%TW/EFPY 3R11 3R13 37 101 AV4
-0.12
-0.12 13 14 1
0.37
%TWIEFPY 3R11 3R13 37 103 AV5
-0.05
-0.12 12 13 1
0.37
%TW/EFPY 3R11 3R13 37 106 AVM
-0.02
-0.02 12 15 3
1.10
%TW/EFPY 3R11 3R13 37 106 AV3
-0.09 0
22 23 1
0.37
%TW/EFPY 3R11 3R13 37 106 AV4
-0.09
-0.09 31 34 3
1.10
%TW/EFPY 3R11 3R13 37 106 AV5
-0.09
-0.09 24 24 0
0.00
%TW/EFPY 3R11 3R13 37 106 AV6 0.07 0.07 12 15 3
1.10
%TW/EFPY 3R11 3R13 38 21 AV5 0.07 0.12 15 13
-2
-0.74
%TW/EFPY 3R11 3R13 38 98 AV2 0.09 0.12 11 13 2
0.74
%TW/EFPY 3R11 3R13 38 98 AV4 0.05
-0.02 13 16 3
1.10
%TW/EFPY 3R11 3R13 40 99 AV2
-0.05
-0.02 14 15 1
0.37
%TW/EFPY 3R11 3R13 40 99 AV4
-0.09
-0.12 27 29 2
0.74
%TW/EFPY 3R11 3R13 40 99 AV5 0
0 32 34 2
0.74
%TW/EFPY 3R11 3R13 40 100 AV4 0
0 12 15 3
1.10
%TW/EFPY 3R11 3R13 40 100 AV5 0.09 0.09 19 18
-1
-0.37
%TW/EFPY 3R11 3R13 40 100 AV6 0
0 13 15 2
0.74
%TW/EFPY 3R11 3R13 40 102 AV3 0
0 13 13 0
0.00
%TW/EFPY 3R11 3R13 40 102 AV4 0.02 0.02 25 27 2
0.74
%TW/EFPY 3R11 3R13 40 102 AV5 0.09 0.07 18 20 2
0.74
%TW/EFPY 3R11 3R13 40 103 AV1
-0.19
-0.17 14 14 0
0.00
%TW/EFPY 3R11 3R13 40 103 AV2 0
0 23 25 2
0.74
%TW/EFPY 3R11 3R13 40 103 AV3
-0.02
-0.07 27 29 2
0.74
%TW/EFPY 3R11 3R13 40 103 AV4 0.02 0
34 35 1
0.37
%TW/EFPY 3R11 3R13 40 103 AV5 0.05 0
31 31 0
0.00
%TW/EFPY 3R11 3R13 40 103 AV6 0.05
-0.02 18 18 0
0.00
%TW/EFPY 3R11 3R13 41 26 AV2 0
0.07 15 15 0
0.00
%TW/EFPY 3R11 3R13 41 26 AV5
-0.07
-0.17 32 32 0
0.00
%TW/EFPY 3R11 3R13 41 26 AV6
-0.17
-0.22 33 32
-1
-0.37
%TW/EFPY 3R11 3R13 41 30 AV2 0.12 0.14 10 8
-2
-0.74
%0TW/EFPY 3R11 3R13 41 30 AV3 0.2 0.19 15 15 0
0.00
%TW/EFPY 3R11 3R13 41 30 AV4 0
0 21 20
-1
-0.37
%TW/EFPY
Serial No.10-632 Docket No. 50-423 Enclosure Page 11 of 20 Old New Row Col Elev Old New Old New Change Growth Rate Outage Outage Offset Offset
%TW
%TW 3R1I 3R13 41 30 AV5
-0.1
-0.1 16 11
-5
-1.84
%TW/EFPY 3R1l 3R13 41 31 AV2 0.07 0.07 16 14
-2
-0.74
%TW/EFPY 3R11 3R13 41 39 AV2 0.02 0.12 17 19 2
0.74
%TW/EFPY 3R11 3R13 41 39 AV3 0.16 0.22 21 23 2
0.74
%TW/EFPY 3R1I 3R13 41 39 AV4 0.12 0.02 23 24 1
0.37
%TW/EFPY 3R11 3R13 41 39 AV5
-0.02
-0.17 27 29 2
0.74
%TW/EFPY 3R11 3R13 41 39 AV6
-0.02 0.12 11 11 0
0.00.
%TW/EFPY 3R11 3R13 41 78 AV2
-0.05
-0.07 10 5
-5
-1.84
%TW/EFPY 3R11 3R13 41 78 AV3
-0.07
-0.07 24 20
-4
-1.47
%TW/EFPY 3RMl 3R13 41 78 AV4
-0.02
-0.02 21 18
-3
-1.10
%TW/EFPY 3R11 3R13
.41 78
- AV5 0.39 0
14 11
-3
-1.10
%TW/EFPY 3R11 3R13 41 87 AV3 0
0 10 10 0
0.00
%TW/EFPY 3R11 3R13 41 90 AVI 0.14
.0.15 15
-16 1
0.37
%TW/EFPY 3R11 3R13 41 90
-AV3 0.05 0.05 13 14 1
0.37
%TW/EFPY 3R11 3R13 42 103.
AV2 0
0 16 16 0
0.00
%TW/EFPY 3R11 3R13 43 33 AV3 0.2
'0.12 12
'10
-2
-0.74
%TW/EFPY 3R11 3R13 43 95 AV4 0
0 14 11
-3
-1.10.
%TW/EFPY 3R11 3R13 43 95
-AV5 0.07 0.07 18 15
-3
-1.10
%TW/EFPY 3R11 3R13 43 100 AV4
-0.02
-0.02 22 20
-2
-0.74
%TW/EFPY 3R11 3R13 43 102
- AV5
-0.02 0
13 12
-1
-0.37
%TW/EFPY 3R11 3R13 43
'102 AV6 0.02 0
15
-14
-1
-0.37
%TW/EFPY 3R11 3R13
-44 21 AV1
-0.17 A0.15 12 12 0
0.00
%TW/EFPY 3R11 3R13 45 41 AV3 0.02
'0.02
-17 16
-1
-0.37
%TW/EFPY 3Rl1 3R13 45,
96
.AV2 0.05 D0A1 13 12
-1
-0.37
%TW/EFPY 3Rl1 3R13 45
-96
'AV3 "
0
-0.02 15 12'
-3
-1.10
%TW/EFPY 3R11 3R13 48 25
- AV6 7 0
-0.02 1,8 11
-7
-2.57
%TW/EFPY 3R11 3R13 48 96 eAV5
'0.07
-0.02 19
-18
-1
-0.37
%TW/EFPY 3R11 3R13
.49 62
-AV1 "
0.16
-0.05
'21 22 1
.0.37
%TW/EFPY 3R11 3R13 49 62 AV2
-0.07 0
26 23
-3
-1.10
%TW/EFPY 3R11 3R13 49 62 AV3 0.05 0A 32 32 0
0.00
%TW/EFPY 3R11 3R13 49 62
-AV4
-0.02 0.07 20 23 3
1:10 "
%TW/EFPY 3Rl1 3R13 49 66
-AV1
-0.02 0
15
-17 2
0.74
%TW/EFPY 3R11 3R13 49 66 AV2
-0.05
-0 32 36 4
1.47
%TW/EFPY 3R11 3R13 49 66 AV3
-0.09
-0.15 18 20 2
0.74
%TW/EFPY 3R11 3R13 49 67 AV2 0.07 0.07 25 24
-1
-0.37
%TW/EFPY 3R11 3R13 49 67 AV3
-0.07
-0.07 22 22 0
0.00.
%TW/EFPY 3R11 3R13 49 69 AV2 0.09 0.07 13 13 0
0.00
%TW/EFPY 3R11 3R13 49 70 AV2 0
-0.17 16 12
-4
-1.47
%TW/EFPY 3R11 3R13 49 95 AV2 0
0 18 16
-2
-0.74
%TW/EFPY 3R11 3R13 49 95 AV3 0
0 1,9 18
-1
-0.37
%TW/EFPY 3R11 3R13 49 95 AV4 0
0 15 13
-2
-0.74
%TW/EFPY 3R11 3R13 50 80 AV2 0.16 0.19 12 12 0
0.00
%TW/EFPY 3R11 3R13 50 80 AV3 0.07 0.19 14 14 0
0.00
%TW/EFPY 3R11 3R13 50 83 AV2 0.07 0.07 21 17
-4
-1.47
%TW/EFPY 3R11 3R13 51 89 AV6 0
0 15 13
-2
-0.74
%TW/EFPY 3R11 3R13 52 33 AV5 0.02 0
11 12 1
0.37
%TW/EFPY 3R11 3R13 52 67 AV3 0.12 0.14 16 12
-4
-1.47
%TW/EFPY 3R11 3R13 52,
67 AV4
-0.05
-0.1 20 19
-1
-0.37
%TW/EFPY 3R11 3R13 52 69 AV2 0.09
-0.02 13 14 1
0.37
%TW/EFPY 3R11 3R13 52 87 AV5 0.07 0
16 14
-2
-0.74
%TW/EFPY 3R11 3R13 52 88 AVI
-0.07
-0.07 1,1 11
- 0.
0.00
%TW/EFPY 3R11 3R13 52 88 AV2 0.05
-0.05 15 17 2
0.74
%TW/EFPY 3R11 3R13 52 88 AV4
-0.02
-0.17 17 16
-1
-0.37
-%TW/EFPY 3R11 3R13 53 35 AV4 0.07
-0.02 12 7 12 0
0.00
%TW/EFPY 3R11 3R13 53 35 AV5
- 0.
-0.05 17 19 2
0.74
%TW/EFPY 3R11 3R13 53 35 AV6
-0.15
-0.1 14 16 2
0.74
%TW/EFPY 3R11 3R13 53 70 AV2 0.07
-0.07 15 15 0
0.00
%TW/EFPY 3R11 3R13 54 49 AV2
-0.02
-0.1 15 18 3
1.10
%TW/EFPY 3R11 3R13 54 49 AV3
-0.02 0
23 25 2
0.74
%TW/EFPY 3R11 3R13 54 49 AV4
-0.16 0
11 14 3
1.1029
%TW/EFPY
Serial No.10-632 Docket No. 50-423 Enclosure Page 12 of20 Old New Row Col Elev Old New Old New Change Growth Rate Outage Outage Offset Offset
%TW
%TW I
3R11 3R13 55 40 AV6 0.07 0
19 18
-1
-0.368
%TW/EFPY 3R11 3R13 55 75 AV6
-0.09
-0.09 16 17 1
0.3676
%TW/EFPY 3R1l 3R13 55 84 AV5
-0.07
-0.15 25 25 0
0
%TW/EFPY 3R11 3R13 56 43 AV1
-0.16
-0.24 13 13 0
0
%'IW/EFPY
Serial No.10-632 Docket No. 50-423 Enclosure Page 13 of.20 Table 6 Steam Generator D - Newly Remorted AVB Wear Indications New Outage Row Col Elev New Offset New,%TW 3R13 9
121 AV6
-0.17 11 3R13 25 115 AV2 0.46 10 3R13 30 113 AV2 0
14 3R13 30 114 AVI
-0.1 12 3R13 34 109 AV2 0.02 12 3R13 37 103 AV2 0.02 14 3R13 40 101 AV3 0.17 13 3R13 43 20 AV6 0.05 10 3R13 43 25 AV5 0
11 3R13 43 100 AV5 0.46 11 3R13 43 100 AV6 0.05 12 3R13 47 98 AV5 0.34 13 3R13 52 67 AV5 0.1 15 3R13 58 59 AV1
.*0.36 12
Serial No.10-632 Docket No. 50-423 Enclosure Page 14 of 20 Table 7 Newly Reported TSP Wear Indications SG Row Col Code Location Maximum Circ Axial ETSS Suspect Depth Length Length Cause
(%TW),
(in.)
(in.)
B 30 52 WAR 05H - 0.61 17 0.33 0.30 96910.1 TSP Wear D
35 73 WAR 04H - 0.46 22 0.39 0.27 96910.1 TSP Wear
Serial No.10-632 Docket No. 50-423 Enclosure Page 15 of 20 Table 8 3R13 Results for Newly ReDorted Volumetric Dearadation (non-suDmort related)
Maximum Circ Axial At Least Depth Length Length Suspect One Tube SG Row Col Code Location
(%TW)
(in.)
(in.)
ETSS Cause Bounding?
Comment B
1 119 VOL TSC + 4.11" 23 0.39 0.30 21998.1 FO No longer Yes Clear by FOSAR I
present YesCearbFOSA B
1 120 VOL TSC + 3.72" 19 0.37 0.27 21998.1 FO No longer Yes Clear by FOSAR present B
1 121 VOL TSC + 6.48" 15 0.35 0.60 21998.1 FO No longer Yes Clear by FOSAR presentY B
3 113 WAR 05C - 1.17" 23 0.35 0.24 27901.1 EQ No longer Yes Plugged
____present_
WAR 05C - 0.56" 18 0.31 0.27 96910.1 B
3 114 F FO No longer Yes Plugged present WAR 05C - 0.80" 33 0.39 0.32 27901.1 B
37 68 WAR 03H - 0.54" 31 0.35 0.27 27901.1 FO No longer Yes Plugged present B
44 98 VOL 02H + 15.77" 29 0.29 0.27 21998.1 Fabrication Yes Present in Baseline D
52 42 WAR 01H + 0.51" 26 0.36 0.31 27901.1 FO - Nail Yes Nail Removed Nail Removed and D
52 43 WAR 01H + 0.53" 52 0.47 0.35 27901.1 FO - Nail Yes Tube Plugged D
58 50 WAR 01C + 0.38" 16 0.35 0.27 27901.1 Fe Nol Yes Clear by EQSAR 16present 0.35 Cler
_yFSA D
58 51 WAR 01C + 0.53" 27 0.42 0.29 27901.1 FO No longer present Yes Clear by FOSAR
.1.
.L I
J.
A.
.1
Serial No.10-632 Docket No. 50-423 Enclosure Page 16 of,20 Table 9 Steam Generator B 3R13 Results for Previously Reported Volumetric Degradation (non-support related)
Maximum Circ.
Axial Signal Change Depth Length Length From Previous SG Row Col Code Location
(%TW)
(in.)
(in.)
ETSS Suspect Cause Inspection?
TSP Wear - New B
30 52 WAR 05H - 0.61" 17 0.33 0.3 96910.1 Classification No 3R13
Serial No.10-632 Docket No. 50-423 Enclosure Page 17 of-20 Table 10 Steam Generator D 3R13 Results for Previously Reported Volumetric Degradation (non-AVB related)
Maximum Circ.
Axial Signal Change Depth Length Length From Previous SG Row Col Code Location
(%TW)
(in.)
(in.)
ETSS Suspect Cause Inspection?
D 9
42 WAR 06C - 0.74" 41 0.48 0.29 27901.1 FO. No longer No - Plugged present.
No_-_Pugged D
27 39 VOL 08C - 0.89" 23 0.33 0.32 21998.1 FO. No longer No present.
MBM 04C - 1.49" 16 0.31 0.26 21998.1 Fabrication (1)
No D
38 20 MBM 04C - 2:07 18 0.33 0:55 21998.1 Fabrication (1)
No MBM 04C - 2.81" 15 0.33 0.32 21998.1 Fabrication (1)
No D
52 91 VOL 01H + 2.52 24 0.37 0.30 21998.1 FO. No longer No present.
Note (1): Indication was reclassified as MBM due to a review of history.
Serial No.10-632 Docket No. 50-423 Enclosure Page 18 of 20
- e. Number of tubes plugged during the inspection outage for each active degradation mechanism, Table 11 provides the count of tubes plugged by degradation mechanism.
Tabae 11 Tubes Plugged by Degradation Mechanism DEGRADATION SG B SG D PLUGGED PLUGGED AVB Wear =37%TW (discretionary) 1 0
Non-Support Wear >40% TW 0
2 Non-Support Wear <40% (discretionary) 3 0
IDC (discretionary) 0 1
- f. Total number and percentage of tubes plugged to date, Table 12-provides the total number of tubes plugged and the percentages.
Table 12 Tube Plugging Percentages NUMBER PLUGGED SG A SG B SG C SG D PLUGGED PLUGGED PLUGGED PLUGGED Prior to 3R13 38 16 22 83 During 3R13 0
4 0
3 Total After 3R13 38 20 22 86 Percentage 0.675 0.356 0.391 1.529 Overall Percentage 0.738
- g. The results of condition monitoring, including the results of tube pulls and in-situ testing, No tubes were pulled and no in-situ pressure tests were performed.
The condition monitoring assessment concluded that the structural integrity, operational leakage and accident induced leakage performance criteria were not exceeded during the operating interval preceding 3R13.
Serial No.10-632 Docket No. 50-423 Enclosure Page 19 of 20
- h. The effective plugging percentage for all plugging in each SG, Since no sleeving has been done in tihe' Millstone Unit 3 steam generators, the effective plugging percentage is the' same as the actual plugging percentage.
- i. During Refueling Outage 13 and the subsequent operating cycle, 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, The maximum primary to secondary leakage rate during the cycle prior to the inspection was 0.22 gallons per day (GPD) and was conservatively assumed to be from one SG.
- j.
During Refueling Outage 13 and the subsequent operating cycle, the calculated accident induced leakage rate from the portion of the tubes
-below 13.1 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 Nimiting accident is less than 2.49 times the maximum operational primary to secondary leakage rate, the report should describe how it was determined; and The calculated accident induced leakage rate at the completion of cycle 13 (prior to 3R13) is 2.49 times the maximum value of 0.22 GPD operational leakage rate with all leakage assumed to be from the portion of the tube below 13.1 inches below the top of the tube sheet and all leakage conservatively assumed to be from one SG.
Implementation of the Technical Specification Amendment 249 provides that the administrative limit for operational leakage should be:
Leakage through faulted SG 500 GPD - 2.49* operational leakage of 0.22 GPD
= 499.5 GPD Assumes 9
Leakage remains below 1 GPD All leakage is through cracks in the tube ends.
The administrative limit for operational leakage is:
499.5 GPD / 2.49 = 200.6 GPD
Serial No.10-632 Docket No. 50-423 Enclosure Page 20 of 20 Since the calculated administrative limit 200.6 GPD is > than the 150 GPD operational leakage limit, there is no need to implement an administrative limit below the 150 GPD operational limit.
- k. During Refueling Outage 13 and the subsequent operating cycle, the results of monitoring for tube axial displacement (slippage). If slippage is discovered, the implications of the discovery and corrective action shall be provided.
The tube slippage monitoring was performed on SG B and SG D using the bobbin coil data during 3R13. There was no detection of slippage during the 3R13 examination.
Serial No.10-632 Docket No. 50-423 Page 1 of 2 Attachment I Acronyms ARC Alternate Repair Criteria AVB Anti-Vibration Bar COL Column DNG Ding DNT Dent ECT Eddy -Current Testing EFPY Effective Full Power Years
-ELEV Elevation
.EOC End of Cycle
-EPRI Electric Power Research Institute ETSS Examination Technique Specification Sheet FDB Flow Distribution Baffle F/L Full Length FO Foreign.Object FOSAR
'Foreign Object.Search and Retrieval
- GPD Gallons Per.Day IARC Interim Alternate Repair'Criteria ID Inner Diameter IGA zlntergranular Attack
'MAI Multiple Axial Indication MAS Multiple Axial Signal MBM Manufacturing Burnish Mark
-MCI Multiple Circumferential Indication MCS Multiple Circumferential: Signal MPS3 Millstone Power StationUnit 3 MRPC Motorized Rotating Pancake Coil NQH Non-Quantifiable Historical Indication NQI Non-Quantifiable Indication OD Outer Diameter OVR Over Expansion Above the Tubesheet OXP Over Expansion Within the Tubesheet PDA Percent Degraded Area PLP Possible Loose Part POD Probability of Detection PT Penetrant Testing PWR Pressurized Water Reactor PWSCC Primary Water Stress Corrosion Cracking SAI Single Axial Indication SAS Single Axial Signal SCC Stress Corrosion Cracking SCI Single Circumferential Indication
Serial No.10-632 Docket No. 50-423 Page 1 of 2 Attachment I (continued)
Acronyms SCS Single Circumferential Signal SG Steam Generator SI Special Interest SSI Secondary Side Inspection SVI Single Volumetric Indication TE Tube End TEC TubeEnd Cold-Leg Side TEH Tube End Hot-Leg Side TS Technical Specification TSC Top of Tube.Sheet Cold-Leg Side TSP Tube Support Plate TSH Top of Tube Sheet Hot-Leg Side TTS Top of -Ttbesheet UT Ultrasonic Testing VOL Volumetric Indication WAR
-Wear Indication
%TW Percent Through-Wall
[REDACTED]
Serial No.
10~632 Docket No. 50-423 Page 1 of 1 I
n