ML051460385
| ML051460385 | |
| Person / Time | |
|---|---|
| Site: | Waterford  |
| Issue date: | 05/24/2005 |
| From: | Murillo R Entergy Nuclear South, Entergy Operations |
| To: | Document Control Desk, Office of Nuclear Reactor Regulation |
| References | |
| W3Fl-2005-0037 SR-05-001-00 | |
| Download: ML051460385 (27) | |
Text
Entergy Nuclear South Entergy Operations, Inc.
17265 River Road Killona, LA 70057-3093 Tel 504-739-6715 Entergy Fax 504-739-6698 rmurill@entergy.com Robert J. Murillo Licensing Manager, Acting Waterford 3 W3Fl-2005-0037 May 24, 2005 U.S. Nuclear Regulatory Commission ATTN: Document Control Desk Washington, D.C. 20555
Subject:
Waterford 3 SES Docket No. 50-382 License No. NPF-38 Combined Category C-3 and 15-Day Special Report SR-05-001-00 on the 13th Refueling Outage Steam Generator Tube Inservice Inspection
Dear Sir or Madam:
Pursuant to Technical Specification (TS) 6.9.2, Entergy Operations, Inc. (Entergy) provides the following Combined Category C-3 and 15-Day Special Report SR-05-001-00 on the 13th Refueling Outage Steam Generator Tube Inservice Inspection, for Waterford Steam Electric Station Unit 3. This Special Report provides the results of the Refuel 13 Steam Generator Tube Inservice Inspection in accordance with TS 4.4.4.5.a and 4.4.4.5.c.
The Waterford 3 Steam Generator (SG) tube inspections were performed during the RF13 scheduled refueling outage that began on April 17, 2005. The inspections performed on both SGs involved a 100% full-length bobbin coil examination of all inservice tubes and a 100% rotating pancake coil (RPC) probe inspection of the hot leg (HL) expansion transition (ET) region. The RPC used consists of a plus-point coil, a 0.115 inch pancake coil, and a 0.080 inch pancake coil. The RPC was also utilized for confirmation of bobbin coil calls.
The Plus Point coil was used to test the small radius U-bends, dented eggcrate (EC) intersections and any wear indications that required RPC testing.
In accordance with TS 4.4.4.5.a, the SG tube inspections resulted in plugging 247 tubes in SG 31 and 223 tubes in the SG 32. Sleeves were not utilized to repair these tubes identified during this inspection.
In accordance with TS 4.4.4.5.c, the SG tube inspections resulted in classifying SG 31 Category C-3, due to more than 1% of the inspected tubes being defective. The number of inspected tubes for SG 31 was 8779 of which 247 tubes were plugged during this inspection.
Attachments 1 and 2 summarize the results of these inspections.
i14"
W3Fl-2005-0037 Page 2 This letter contains no commitments.
If you have any questions concerning the above, please contact Greg Scott at (504) 739-6703 or Robert O'Quinn at (504) 739-6387.
Very truly yours, Robert J. Murillo Licensing Manager, Acting RJM/GCS/cbh Attachments:
- 1. RF13 Combined Category C-3 and 15-Day Special Report
- 2. RF13 Steam Generator Plugged Tube Indications
W3F1-2005-0037 Page 3 cc:
Dr. Bruce S. Mallett Regional Administrator U. S. Nuclear Regulatory Commission Region IV 611 Ryan Plaza Drive, Suite 400 Arlington, TX 76011-8064 NRC Senior Resident Inspector Waterford NPS P.O. Box 822 Killona, LA 70066-0751 U. S. Nuclear Regulatory Commission Attn: Mr. N. Kalyanam Mail Stop 0-7 D1 Washington, DC 20555-0001 Wise, Carter, Child & Caraway ATTN: J. Smith P.O. Box 651 Jackson, MS 39205 Winston & Strawn ATTN: N.S. Reynolds 1700 K Street, NW Washington, DC 20006-3817 Platts Energy ATTN: B. Lewis 1200 G. St., N.W. Suite 1000 Washington, DC 20005 Morgan, Lewis & Bockius LLP ATTN: T.C. Poindexter 1111 Pennsylvania Avenue, NW Washington, DC 200042
Attachment I Special Report SR-05-001-00 W3F1I-2005-0037 RF13 Combined Category C-3 and 15-Day Special Report to W3F1 -2005-0037 Page I of 11 RF13 Combined Category C-3 and 15-Day Special Report Waterford 3 began the outage with 8779 tubes in Steam Generator (SG) 31 and 8866 tubes in Steam Generator (SG) 32 in service. This report documents both the 15 day plugged tube report and C3 report as required by Technical Specifications.
There were 247 tubes plugged in SG31 and 223 plugged in SG32. The following is a summary of the historical repairs to date:
Year Outage EFPY SG 31 SG 32 Total Cumulative 1985 PRE-SER 154 169 323 323 1986 RFOI 1.01 0
0 0
323 1987 RF02 2.08 0
1 1
324 1989 RF03 3.31 11 8
19 343 1991 RF04 4.55 161 161 322 665 1992 RF05 5.83 4
5 9
674 1994 RF06 7.15 4
2 6
680 1995 RF07 8.52 15 4
19 699 1997 RF08 9.90 29 26 55 754 1999 RF09 11.02 12 10 22 776 2000 RFHO 12.37 28 38 66 842 2002 RF11 13.60 26 10 36 878 2003 RF12 15.20 127 50 177 1055 2005 RF13 16.68 247 223 470 1525 Total 818 707 1.0 STEAM GENERATOR DESIGN The Waterford 3 Model 70 (3410 MWT) re-circulating steam generators were designed and fabricated by Nuclear Steam System Supplier Combustion Engineering (CE), Inc. in accordance with ASME Code,Section III NB for Class I vessels. The Waterford 3 steam generators each consist of 9,350 high temperature mill annealed inconel 600 U-tubes arranged in a one-inch inner diameter triangular pitch pattern representing 103,574 ft2 of heat transfer area. The U-tubes are 3/4" O.D. by 0.048" nominal wall thickness explosively expanded the full depth of the tube sheet (Westinghouse -
formerly CE's Explansion Process) and welded to the primary cladding. The secondary tube bundle support structure consists of carbon steel eggcrates.
The secondary supports are arranged in the following order:
seven full horizontal eggcrate supports to W3FM -2005-0037 Page 2 of 11
- three horizontal partial eggcrates supports
- two anti-vibration straps (hot and cold batwings)
- seven vertical straps Waterford 3's primary design inlet (hot leg) temperature is 611OF with an outlet temperature (cold leg) of 5530F. As a result of a 1992 T-Hot reduction, Waterford 3 currently operates with an inlet temperature of 6050F and an outlet temperature of 5450F. This was accomplished at the start of cycle six in an effort to reduce the susceptibility to primary and secondary water stress corrosion cracking induced by hot leg temperatures above 6000F.
2.0 INSPECTION RESULTS The initial scope and expansions based on number of examinations are listed in Table 2.1:
Table 2.1 Initial Scope and Expansions Test Tvpe
- Planned
% Scope Expansion SG31 Bobbin 8779 100 %
No RPC ET HL 8779 100 %
No RPC Low Row U-bends 121 100 %
No (rows 1-2)
Dented/Ding 157 20 %
No Wear 67 20%
Yes SG32 Bobbin 8866 100 %
No RPC ET HL 8866 100 %
No RPC Low Row U-bends 122 100 %
No (rows 1-2)
Dented/Ding 185 20 %
No Wear 67 20%
No The bobbin inspections were performed predominantly from the cold leg sides of both steam generators. RPC testing was conducted from both hot and cold legs.
There were 247 tubes plugged in SG31 and 223 tubes plugged in SG32. Table 2.2 lists the number of "indications" identified by generator during RE 3:
to W3F1 -2005-0037 Page 3 of 11 Table 2.2 Indications Identified During RF13 7'
G'312 SG`-32:
Tubes inservice prior to RF 8779 8866 Total Number of tubes previously removed from service 571 484 Repair Candidates from RFO13:
Hot Leg Top of Tubesheet Axial Indications (Above TTS) 2 2
Hot Leg Top of Tubesheet Circ. Indications (Above TTS) 1 0
Hot Leg Tube Sheet Axial Indications (Within Tubesheet) 5 0
Hot Leg Tube Sheet Circ. Indications (Within Tubesheet) 16 1
Tubesheet with Axial and Circumferential Indications 0
0 Support Plate With Axial Indications 101 23 Support Plate With Circumferential Indications 0
0 Batwings With Axial Indication 0
3 Batwings With Volumetric Indication 0
2 Customer Decision Preventative (NSY, PLP, PVN or NTE/PTE) 18 23 Customer Decision Preventative Bobbin Percents <40%o 0
1 Hot Leg Volumetric Indications 0
1 Cold Leg Volumetric Indications 4
0 Row 1 - Row 2 U-Bend Indications 0
0 Bobbin Percents => 40%
2 5
Restricted/Obstructed Tubes or Unable to Com lete Test 0
trite bsrndidate Tu t be R6Unable 7to Complete Test
^
0 Stabilizers Installed During RF13 36 51 Tubes Plugged During RF1 3 - EC Results 123 57 Tubes Plugged During RF13 - Batwing Preventative 124 166 Total Tubes Plugged - Post RF1 3 818 707 to W3Fl-2005-0037 Page 4 of 11 3.0 EVALUATION OF INSPECTION RESULTS The inspections were performed with equipment and techniques qualified in accordance with Appendix H of the Electric Power Research Institute (EPRI)
PWR Steam Generator Examination Guidelines, Rev. 6. Each mechanism will be discussed individually.
3.1 Top of the Tubesheet Circumferential Cracking (Expansion Transition)
This was the eighth 100% inspection of the top of the tube sheet (TTS) region with a rotating probe. The Plus Point coil was used for detection of both axial and circumferential cracking. The extent of testing was + 3 inches to - 11 inches from the secondary face of the tube sheet. Listed in Table 3.1.1 are the outage, sample size, number of indications, and probe used for the indications identified at the top of the tube sheet.
TABLE 3.1.1 TTS CIRCUMFERENTIAL HISTORY Outage Sample SG31 SG32 Probe RF06 (1994) 100 %
0 0
Plus Point RF07 (1995) 100 %
6 1
Plus Point RF08 (1997) 100 %
14 7
Plus Point RF09 (1999) 100 %
2 3
Plus Point RF10 (2000) 100 %
4 8
Plus Point RF11 (2002) 100 %
10 3
Plus Point RF12 (2003) 100 %
11 2
Plus Point RFI3 (2005) 100 %
2 1
Plus Point The number of circumferential indications found per SG in each inspection is shown in Figure 3.1.1.
to -
W3FI-2005-0037 Page 5 of 11 Figure 3.1.1 TTS Circumferential Cracking Waterford 3 Historical TTS Circumferential Cracking History 16 14 12 01 C
m-09 0
8 6-2 RF07 RF08 RF09 RF10 Outage RF1 I RF12 RF13 Screening of the indications was performed for in-situ testing. None of the indications met the minimum criteria for testing.
3.2 Circumferential Cracking within the Tubesheet Circumferential cracking within the tubesheet has been identified as primary water stress corrosion cracking (PWSCC) or originating from the inside diameter of the tube. In an attempt to quantify this, the inspection extent was increased this outage to eleven inches below the secondary face or top of the tubesheet. Table 3.2.1 provides the number of circumferential indications detected within the tubesheet during the RF13 inspection:
Table 3.2.1 Circumferential Indications within the Tubesheet SG31 SG32 Circumferential Indications 16 1
within the Tubesheet During the last inspection (RF12), the depth of the inspection was eight inches into the tubesheet whereas this inspection, the depth was increased
Attachment I to W3FI -2005-0037 Page 6 of 11 to 11 inches to be consistent with C*. A breakdown by location of the cracking within the tubesheet is provided in Figure 3.2.1:
Figure 3.2.1 Circumferential Cracking within the Tubesheet Based on WCAP 16208, stabilization was performed on all circumferential indications above -3 inches. None of the indications exceed the in-situ selection criteria.
3.3 Axial Cracking at the Top of the Tubesheet Historically, axial cracking at the top of the tubesheet has been the predominant damage mechanism at Waterford 3, excluding mechanical wear. The historical summary for this mechanism is listed in Table 3.3.1:
to W3FI -2005-0037 Page 7 of 11 Table 3.3.1 Historical Top of the Tubesheet Inspections Outage Sample SG31 SG32 Probe RF06 (1994) 100 %
0 0
Plus Point RF07 (1995) 100 %
0 0
Plus Point RF08 (1997) 100 %
10 7
Plus Point RF09 (1999) 100 %
3 0
Plus Point RF10 (2000) 100 %
22 22 Plus Point RF11 (2002) 100 %
10 1
Plus Point RF12 (2003) 100 %
10 3
Plus Point RFI3 (2005) 100 %
2 1
Plus Point This is displayed graphically below in Figure 3.3.1:
Figure 3.3.1 TTS Axial Cracking Waterford 3 TTS Historical Axial Cracking 25 20 15 10 5-
- SG3I
- SG32 I
r I
0 4-,
RF07 RF08 RF09 RF10 RF11 RF12 RF13 Outage None of the TTS axial cracks exceeded the in-situ screening criteria for burst or leakage.
to W3FI-2005-0037 Page 8 of 11 3.4 Freespan Indications During the previous inspection (RF12), there were 3 freespan axial cracks identified in a tube adjacent to a stayrod. During the most recent inspection (RF13), no freespan axial cracks were identified.
3.5 Axial Cracking (Eggcrate)
Cracking at eggcrates was first detected at Waterford 3 in 1999 (RF09).
The eggcrate support flaws at Waterford 3 are classified as axially oriented outside diameter stress corrosion cracking. The cracking can be a single crack or multiple cracks interconnected in the tube within the eggcrate support. As noted in Figure 3.5.1, SG31 has the largest number of flaws occurring at the hottest support plate (01 Hot) and generally decreases as the temperature decreases.
SG32 does not have a statistically large enough number to determine the exact distribution. Figure 3.5.2 depicts the number of indications by outage.
Figure 3.5.1 Eggcrate Flaw Distribution Waterford 3 RF13 Eggcrate Axial Cracking Distribution 40
- 35
_ 30
- 25.° 20
_15 10 I
I II I
I O O
O O
O C)
~
c CO p-C CUO (DN COL ho a)amCo D %Ica 00000000000000 o
oo oo Support
Attachment I to W3Fl-2005-0037 Page 9 of 11 Figure 3.5.2 Eggcrate Axial Flaws by Outage Eggcrate Axial Cracking Trend Eggcrate Axial Cracking Trend Waterford 3 120 -
100 en C
80 0
M 5
C
'4-o 40-20 8
2 2
2 0
, I I
I RF09 RF10 RF11 RF12 RF13 Outage None of the eggcrate flaws detected during RF13 inspection met the in-situ pressure test criteria.
3.6 Dent/Ding Inspection The initial inspection program required that in each steam generator 20%
of the dents at intersections identified with the bobbin coil as having voltages 2 2.0 and freespan dings with voltages > 5 were tested with the
+Point coil probe. No degradation was identified.
3.7 Small Radius U-bend Inspection During RF13, 100% of the u-bends in rows 1 & 2 of both generators were tested with the plus point. There were no indications identified.
3.8 Batwing Damage During the RF13 inspection, it was determined that two of the batwing (diagonal strap tube support) in SG32 were not in their normal position. It appears that the batwings had dropped approximately 2 inches down from the normal position. Further evaluations also determined that a number of
Attachment I to W3F1 -2005-0037 Page 10 of 11 new wear was associated with the affected batwings. A large preventative repair campaign was developed to address the condition.
4.0 ROOT CAUSE AND CORRECTIVE ACTIONS Tubing degradation has been previously reported in earlier inspections.
The root cause for the degradation is attributed to age and material of the steam generator tubing and the secondary environment. Copper is believed to be a major contributor. In the RF10 refueling outage (2000), a high temperature chemical cleaning was performed to remove iron, copper and residual amounts of lead from the tube bundle. Problems encountered during the cleaning resulted in the copper being plated out. This not only prompted concerns about crack initiation but also a reduction in probability of detection with eddy current. Therefore, a second chemical cleaning was planned and performed during the RF12 outage. The level of detection was greatly improved from that of the RF11 outage, which resulted in a transient relative to the number of indications identified at the eggcrate supports. The chemical cleaning was expected to be 60-85% effective at removing the copper deposits. Those intersections that contained copper deposits that resulted in significant noise (Bobbin Amplitude >0.53 Vvm &
RPC amp >0.5 V; >0.5" length) on the eddy current tests were preventatively removed from service. This accounted for 11 total tubes.
During the RF13 inspection, it was noted that the amount of copper was even less than what was identified in RF12. This would indicate that the copper was loose after the chemical clean and was dispersed during operation.
The increased number of indications at the eggcrates is consistent with industry experience. The RF12 value was 59 while the RF13 value was 105 in the bounding generator. This was bound by the operational assessment for the previous operating cycle.
Molar ratio control was initiated early in plant life. Since that time, minor adjustments have been made to maintain a neutral to slightly acidic environment.
The more recent hideout return data indicated that near neutral conditions have been maintained.
CONDITION MONITORING Results from the RF13 inspection were compared to the operational assessment results.
The actual number of detected indications was within the frequency of occurrence predicted by the operational assessment model.
Thus, the flaw distribution predicted by the model was reasonable with respect to the actual flaw projections.
to W3Fl-2005-0037 Page 11 of 11 In-situ pressure testing was not required since all flaws identified did not exceed the screening criteria for testing. Therefore, both the structural and leakage integrity requirements were met.
CONCLUSIONS In summary, a comprehensive eddy current examination was performed.
Both steam generators were tested 100% full length with the bobbin coil and 100% at the hot leg ET region with Rotating Pancake Coil (RPC). The areas tested included 100% of the small radius U-bends (rows 1-2), 20% of the wear and 20% of the dented intersections in the eggcrates and freespan.
The indications identified in the tubesheet and at the expansion transition were smaller and lower in numbers than the previous inspection.
Eggcrate axial cracks, which are the dominant degradation mechanism identified during RF13, are calculated to burst at pressures well above that identified for structural adequacy in Regulatory Guide 1.121.
Waterford 3 utilizes N-16 monitors for primary-to-secondary leakage detection. TS 3.4.5.2c states that Reactor Coolant System leakage shall be limited to 75 gallons per day primary-to-secondary leakage per steam generator. Abnormal operating procedures are in place in the event that leakage is detected. Other methods for detecting leakage include a condenser off-gas radiation monitor, steam generator blowdown monitors, main steam line radiation monitors, in addition to the utilization of blowdown grab samples. Entergy Operations is sensitive to the potential rapid progression of tube leakage and will take the necessary measures upon detection, should a primary-to-secondary leak occur. Operators routinely train on primary-to-secondary leaks and tube ruptures utilizing the simulator. The primary-to-secondary leakage during the last operating interval was < 2 gallon per day.
Based upon the comprehensive actions performed during RF13 in conjunction with the ability to rapidly detect and respond to any primary-to-secondary leakage, as described above, Waterford 3 is safe to resume plant operation.
Operational assessments are performed per the guidance of NEI 97-06, Steam Generator Program Guidelines revision 1, January 2001.
Special Report SR-05-001-00 W3FI-2005-0037 RF13 Steam Generator Plugged Tube Indications to W3FI-2005-0037 Page 1 of 11 SG31 Plugged Tube Indications Tube #
ROW 1
9 9
2 14 3
20 4
67 5
4 6
11 11 7
13 8
17 17 8
17 10 2
2 11 112 112 112 112 112 12 8
13 99 14 91 15 8
16 84 84 84 17 113 18 101 19 32 20 53 53 21 30 30 22 48 48 48 48 23 40 24 33 25 107 26 20 27 40 28 11 29 107 30 41 31 20 20 32 88 COL I
1 2
2 11 18 19 19 19 19 19 23 26 26 32 32 32 32 32 36 39 41 44 44 44 44 45 47 50 51 51 52 52 52 52 52 52 54 55 55 56 56 57 57 59 60 60 60 IND SAI SAI SAI SAI PTP SAI SAI SAI SAI SAI SAI SAI SAI SAI SAI SAI SAI SAI SAI SAI SAI SAI SAI SAI SAI SAI MAI SAI SCI SAI SAI SAI SAI SCI SCI SCI SCI SAI SAI SAI SAI MAI SAI SAI SAI SCI MCI SAI PER LOC 01H 01H 01H 03H 03H 02H 02H 03H 03H 04H 03H 07C 07C 01C 01C 01C 01C 01C 01H 02H 03H 07H 01H 01H 01H 01H 05H TSH 05H 05H 07H 07H TSH TSH TSH TSH 06H 01H 02H 05H 07H 01H 02H 04H TSH TSH 01H INCH 0.6
-0.37 0.15
-0.2 0.76 0.54 0.97 0.92 0.46 0.95
-0.15
-0.36
-0.32
-0.79 0.35
-0.52
-0.3 0.54 0.98 0.14 0.87 0.96
-0.12 0.15 0.81 0.93 0.92
-0.16 0.19 0.76
-0.82 0.43
-2.52
-2.49
-2.14
-1.7 0.72
-0.62 0.86 0.83 0.78
-0.59 0.84 0.9
-11.62
-11.48 0.16 to W3FI-2005-0037 Page 2 of 11 SG31 Plugged Tube Indications Tube#
ROW 33 1
34 3
35 7
36 2
37 4
38 6
39 8
40 10 41 12 42 48 48 43 9
44 11 45 13 46 15 47 69 48 14 49 16 50 18 51 20 52 68 53 72 72 72 54 130 55 17 56 21 57 23 58 69 69 69 59 141 60 143 61 20 62 22 63 24 64 26 65 28 66 64 67 29 68 31 69 33 70 35 71 47 72 143 73 45 74 143 75 46 COL 63 63 63 64 64 64 64 64 64 64 64 65 65 65 65 65 66 66 66 66 66 66 66 66 66 67 67 67 67 67 67 67 67 68 68 68 68 68 68 69 69 69 69 69 69 71 71 72 IND PTP PTP PTP PTP PTP PTP PTP PTP PTP SCI SCI PTP PTP PTP PTP SCI PTP PTP PTP PTP SCI SAI SAI SAI SAI PTP PTP PTP SCI SAI SAI SAI PTP PTP PTP PTP PTP PTP SAI PTP PTP PTP SCI PTP PTP PTP PTP PTP PER LOC INCH TSH
-8.75 TSH
-7.33 TSH TSH 04H 05H 05H 02H TSH 02H 04H 02H
-4.19
-6.96 0.96
-0.54 0.87 0.85
-6.38 0.72 0.63 0.8 02H 0.84 TSH
-2.46 to W3Fl-2005-0037 Page 3 of 11 SG31 Plugged Tube Indications Tube #
76 77 78 79 80 81 82 83 84 85 86 87 88 89 90 91 92 93 94 95 96 97 98 99 100 101 102 103 104 105 106 107 108 109 110 111 112 113 114 115 116 117 118 119 120 121 122 123 ROW 47 49 48 49 57 50 100 49 51 50 60 49 53 52 76 53 119 54 56 53 55 57 67 54 56 62 66 70 55 57 59 61 63 65 69 71 73 54 56 58 60 62 64 70 53 55 59 61 COL 73 73 74 75 75 76 76 77 77 78 78 79 79 80 80 81 81 82 82 83 83 83 83 84 84 84 84 84 85 85 85 85 85 85 85 85 85 86 86 86 86 86 86 86 87 87 87 87 IND SAI PVN PTP PTP SAI PTP SAI PTP PTP PTP SAI PTP PTP PTP SAI PTP SAI PTP PTP PCT SAI PTP PTP PTP PTP PTP PTP PTP PTP PTP PTP PTP PTP SAI PTP PTP PTP PTP PTP PTP PTP PTP PTP PTP PCT PTP PTP PTP PER LOC TSH 03H INCH
-0.81 21.47 08H 0.87 04H 01H 0.93 0.9 02H 0.95 01H 0.8 46 BW9 1.69 011H 0.63 07H
-0.27 42 BW9
-2 to W3FI-2005-0037 Page 4 of 1 1 SG31 Plugged Tube Indications Tube #
124 125 126 127 128 129 130 131 132 133 134 135 136 137 138 139 140 141 142 143 144 145 146 147 148 149 150 151 152 153 154 155 156 157 158 159 160 161 162 163 164 165 166 167 168 169 170 171 ROW 63 54 56 58 60 62 64 53 61 97 54 78 55 54 53 54 78 86 102 63 52 49 53 55 50 52 72 49 51 53 50 86 49 103 50 47 46 48 45 47 54 29 31 33 20 22 24 26 COL 87 88 88 88 88 88 88 89 89 89 90 90 91 92 93 94 94 94 94 95 96 97 97 97 98 98 98 99 99 99 100 100 101 101 102 103 104 104 105 105 106 107 107 107 108 108 108 108 IND PTP PTP PTP PTP PTP PTP PTP PTP PTP ScI PTP SAI PTP PTP PTP PTP SAI SAI SAI PTP PTP PTP PTP SAI PTP PTP SCI PTP PTP PTP PTP SAI PTP SAI PTP PTP PTP PTP PTP PTP SAI PTP PTP PTP PTP PTP PTP PTP PER LOC INCH TSH 0.13 03H 03H 07H 02H 0.92
-0.27
-0.14 0.75 04H
-0.36 TSH
-8.39 06H 01H 03H 0.78 0.76 0.99 to W3Fl-2005-0037 Page 5 of 11 SG31 Plugged Tube Indications Tube #
172 173 174 175 176 177 178 179 180 181 182 183 184 185 186 187 188 189 190 191 192 193 194 195 196 197 198 199 200 201.
202 203 204 205 206 207 208 209 210 211 212 213 214 215 216 ROW 28 54 92 17 21 23 115 14 18 138 9
11 13 137 139 2
4 6
8 10 12 136 138 1
3
/5 7
19 19 19 139 6
11 23 69 8
18 37 75 6
86 12 17 17 31 127 126 128 COL 108 108 108 109 109 109 109 110 110 110 111 111 111 111 111 112 112 112 112 112 112 112 112 113 113 113 113 113 113 113 113 114 115 115 115 116 116 117 117 118 118 120 121 121 121 121 122 122 IND PTP SAI SAI PTP PTP PTP SAI PTP PTP PTP PTP PTP PTP PTP PTP PTP PTP PTP PTP PTP PTP PTP PTP PTP PTP PTP PTP SAI SAI SAI PTP SAI SAI SAI SAI MAI SCI SAI SAI SAI SAI MAI MAI SAI SAI PTP PTP PTP PER LOC INCH 02H 1.06 TSH
-0.04 01H 0.79 TSH 0.68 011H 01H 07H 01H 01H 01H 01H 01H TSH 01H 04H 01H 02H 01H 01H 02H 01H
-0.26 0.33 1.03 0.73 0.63 0.47 0.81 1.09
-7.37 0.98 0.77 1.04 0.73 0.85 0.92
-0.9
-0.21 to W3Fl-2005-0037 Page 6 of 11 SG31 Plugged Tube Indications Tube #
ROW COL IND PER LOC INCH 217 21 123 SAI 03H 0.91 218 49 123 SAI 01H 1.06 219 79 127 SAI TSH 0.53 220 89 127 SAI 04H 0.78 221 46 128 SAI TSH
-10.84 222 43 129 SAI 02H 0.87 223 68 130 SAI 05H
-0.28 224 6
132 MAI 02H 0.79 225 98 132 SAI 04H 0.94 226 5
133 SAI 01H 0.75 227 59 133 SAI 01H
-0.65 59 133 SAI 01H
-0.45 59 133 SAI 01H
-0.08 228 16 134 SAI 06H 0.76 16 134 MAI 02H 0.34 229 5
135 SAI 04H*
0.86 230 47 135 SAI 03H
-0.68 231 16 136 SAI 02H 0.85 232 8
140 SAI TSH
-9.48 8
140 SAI TSH
-8.31 233 69 141 SAI 02H 0.26 234 22 142 SAI 02H 0.37 235 45 143 SCI TSH
-5.91 236 42 144 SAI 04H 0.53 237 90 144 NSY 02H 32.97 238 102 144 NSY 08C 14.11 239 81 149 SAI 01H 0.81 240 8
156 SAI 03H 0.88 241 50 158 PTP 242 11 159 SAI 03H 0.84 11 159 SAI 07H 0.82 243 6
162 SAI 03H 0.91 244 1
171 SVI TSC 0.53 245 3
171 SVI TSC 0.1 246 2
172 SVI TSC 0.13 247 4
172 SVI TSC 0.38 Legend:
TSH - Tubesheet Hot SAI - Single Axial Indication MAI - Multiple Axial Indication SCI - Single Circumferential Indication MCI - Multiple Circumferential Indication SVI - Single Volumetric Indication PCT-Percent Through Wall PTP-Preventative Tube Plug NSY - Noisy Tube PVN - Permeability Variation to W3Fl-2005-0037 Page 7 of 11 SG32 Plugged Tube Indications Tube #
ROW COL IND PER LOC INCH 1
11 11 SAI 03H 0.86 2
56 12 PTP 3
36 16 PTP 4
5 19 SAI 02H
-0.81 5
78 28 PTP 6
33 35 PTP 7
24 38 SAI TSH 0.34 8
78 38 PTP 9
119 39 PTP 10 34 44 SAI 07H 0.66 11 75 49 SAI 02H 0.69 12 40 50 SAI 07H 0.6 13 85 53 SAI 04H 0.71 14 85 55 SAI 09C
-0.65 15 95 59 PTP 16 23 61 PTP 17 25 61 PTP 18 106 62 SAI 04H 0.6 19 3
63 PTP 20 5
63 PTP 21 7
63 PTP 22 23 63 PTP 23 2
64 PTP 24 4
64 PTP 25 6
64 PTP 26 8
64 PTP 27 10 64 PTP 28 12 64 PTP 29 9
65 PTP 30 11 65 PTP 31 13 65 PTP 32 15 65 PTP 33 14 66 PTP 34 16 66 PTP 35 18 66 PTP 36 20 66 PTP 37 21 67 PTP 38 22 68 PTP 39 24 68 PTP 40 26 68 PTP 41 28 68 PTP 42 29 69 PTP 43 31 69 PTP 44 33 69 PTP 45 45 71 PTP 46 46 72 PTP 47 48 74 PTP 48 142 74 PTP
01 H
-0.8 to W3Fl-2005-0037 Page 8 of 1 1 SG32 Plugged Tube Indications Tube #
49 50 51 52 53 54 55 56 57 58 59 60 61 62 63 64 65 66 67 68 69 70 71 72 73 74 75 76 77 78 79 80 81 82 83 84 85 86 87 88 89 90 91 92 93 94 95 ROW 49 50 52 52 49 50 54 56 49 51 53 55 57 52 54 56 58 53 55 57 77 95 54 56 58 60 62 64 66 68 70 72 74 76 78 80 82 84 53 55 57 59 61 63 65 67 69 71 COL 75 76 76 76 77 78 78 78 79 79 79 79 79 80 80 80 80 81 81 81 81 81 82 82 82 82 82 82 82 82 82 82 82 82 82 82 82 82 83 83 83 83 83 83 83 83 83 83 IND PTP PTP SAI SAI PTP PTP PTP PTP PTP PTP PTP PTP PTP PTP PTP SAI PTP PTP PTP PTP SAI SAI PTP PTP PTP PTP PTP PTP PTP PTP PTP PTP PTP PTP PTP PTP PTP PTP PTP PTP PTP PTP PTP PTP PTP PTP PTP PTP PER LOC INCH 01H 01H 05H
-0.8 0.73
-0.33 02H
-0.13 01H
-0.22 to W3Fl-2005-0037 Page 9 of 11 SG32 Plugged Tube Indications Tube #
96 97 98 99 100 101 102 103 104 105 106 107 108 109 110 111 112 113 114 115 116 117 118 119 120 121 122 123 124 125 126 127 128 129 130 131 132 133 134 135 136 137 138 139 140 141 142 143 ROW 73 75 77 79 81 83 85 91 54 56 58 60 62 64 66 68 70 72 74 76 78 80 82 84 55 57 65 67 69 145 147 58 64 53 55 57 59 63 65 58 60 64 53 55 57 59 61 54 COL 83 83 83 83 83 83 83 83 84 84 84 84 84 84 84 84 84 84 84 84 84 84 84 84 85 85 85 85 85 85 85 86 86 87 87 87 87 87 87 88 88 88 89 89 89 89 89 90 IND PTP PTP PTP PTP PTP PTP PTP SAI PTP PTP PTP PTP PTP PTP PTP PTP PTP PTP PTP PTP PTP PTP PTP PTP PcT PTP PTP PTP PTP SVI SvI PTP PTP PTP PTP PTP PTP PTP PTP PTP PTP PTP PTP PTP PTP PTP PTP PTP PER LOC INCH BW3
-0.97 41 BW9 1.57 BWI 4.79 BWI 3.25 to W3FI-2005-0037 Page 10 of 11 SG32 Plugged Tube Indications Tube #
144 145 146 147 148 149 150 151 152 153 154 155 156 157 158 159 160 161 162 163 164 165 166 167 168 169 170 171 172 173 174 175 176 177 178 179 180 181 182 183 184 185 186 187 188 189 190 191 ROW 56 58 60 62 55 57 59 61 123 54 56 58 53 55 54 56 53 83 52 49 51 50 74 49 51 50 49 71 48 88 47 57 46 45 29 31 33 20 22 24 26 28 17 21 23 143 14 18 COL 90 90 90 90 91 91 91 91 91 92 92 92 93 93 94 94 95 95 96 97 97 98 98 99 99 100 101 101 102 102 103 103 104 105 107 107 107 108 108 108 108 108 109 109 109 109 110 110 IND PTP PTP PTP PTP PTP PTP PTP PTP SAI PTP PTP PTP PTP PTP PCT PTP PTP SAI PTP PTP PTP PTP SA1 PTP PTP PTP PTP SCI PTP PTP PTP SAI PTP PTP PTP PTP PTP PTP PTP PTP PTP PTP PTP PTP PTP PTP PTP PTP PER LOC INCH BW2 0.72 04H 0.71 TSH 1.03 TSH 07H
-0.08 0.5 to W3FI-2005-0037 Page 11 of 11 SG32 Plugged Tube Indications Tube #
192 193 194 195 196 197 198 199 200 201 202 203 204 205 206 207 208 209 210 211 212 213 214 215 216 217 218 219 220 221 222 223 ROW 20 96 9
11 13 15 2
4 6
8 12 1
3 5
7 9
5 22 54 138 48 128 127 46 84 18 31 47 49 6
2 2
2 2
COL 110 110 111 111 111 111 112 112 112 112 112 113 113 113 113 113 115 118 118 118 128 130 131 134 136 140 141 143 143 146 148 148 150 150 IND PTP PTP PTP PTP PTP PTP PTP PTP PTP PTP PTP PTP PTP SAI PTP PTP SAI SAI PTP PTP PCT SVI PTP PTP SAI PTP SAI PCT PTP NSY SAI SAI SAI SAI PER LOC INCH 01H 01H 06H 48 BW5 TSH 0.04
-0.16 0.35 0.8 10.94 BW5
-0.86 04H 0.93 44 BW5 1.08 04H 07C 07C 07C 07C 30.72
-0.47
-0.5 0.35 0.21 Legend:
TSH - Tubesheet Hot BW - Bat Wing SAI - Single Axial Indication MAI - Multiple Axial Indication SCI - Single Circumferential Indication MCI - Multiple Circumferential Indication SVI - Single Volumetric Indication MVI - Multiple Volumetric Indication PCT - Percent Through Wall PTP - Preventative Tube Plug NSY - Noisy Tube