W3F1-2003-0089, Combined Category C-3 and 15-Day Special Report SR-03-002-00 on the 12th Refueling Outage Steam Generator Tube Inservice Inspection

Combined Category C-3 and 15-Day Special Report SR-03-002-00 on the 12th Refueling Outage Steam Generator Tube Inservice Inspection

ML033290432
Person / Time
Site:	Waterford
Issue date:	11/18/2003
From:	Sen G Entergy Operations
To:	Document Control Desk, Office of Nuclear Reactor Regulation
References
W3F1-2003-0089
Download: ML033290432 (23)

Text

Entergy Entergy Operations, Inc.

17265 River Road Killona, LA 70066 Tel 504 739 6650 W3Fl-2003-0089 November 18, 2003 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-03-002-00 on the 12th Refueling Outage Steam Generator Tube Inservice Inspection

Dear Sir or Madam:

Pursuant to Technical Specifications (TS) 6.9.2, Entergy Operations, Inc. (Entergy) provides the following Special Report (SR) Number SR-03-002-00, Combined Category C-3 and 15-Day Special Report SR-03-002-00 on the 12th Refueling Outage Steam Generator Tube Inservice Inspection, for Waterford Steam Electric Station Unit 3. This Special Report provides the results of the Refuel 12 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 RF12 scheduled refueling outage that began on October 20, 2003. 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 127 tubes in SG 31 and 50 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 require repair. The number of inspected tubes for SG 31 is 8906 and 127 tubes were plugged during this inspection.

Attachments 1 and 2 summarize the results of these inspections.

,gk(17

W3F1 -2003-0089 Page 2 This letter contains no commitments. If you have any questions concerning the above, please contact R.L. Williams at (504) 739-6255 or Robert O'Quinn at (504) 739-6387.

Very truly yours, Gautam Sen Manager, Licensing Waterford Steam Electric Station, Unit 3 GSIRLW/cbh Attachments:

1. RF12 Combined Category C-3 and 15-Day Special Report

2. RF12 Steam Generator Plugged Tube Indications

W3Fl-2003-0089 Page 3 cc: Mr. Thomas P. Gwynn Acting 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 1400 L Street, NW Washington, DC 20005-3502 Platts Energy ATTN: B. Lewis 1200 G. St., N.W. Suite 1000 Washington, DC 20005

Attachment I Special Report SR-03-002-00 W3FI-2003-0089 RF12 Combined Category C-3 and 15-Day Special Report to W3FI-2003-0089 Page I of 11 RF12 Combined Category C-3 and 15-Day Special Report This is the first steam generator inspection that resulted in the steam generators being classified as C-3 (>10% of the tubes inspected are degraded or >1% are defective).

Waterford 3 began the outage with 8906 in (SG 31) and 8916 (SG 32) tubes in service. This report documents both the 15 day plugged tube report and C3 report as required by Technical Specifications 4.4.4.5.a and 4.4.4.5.c. There were 127 tubes plugged in SG 31 and 50 plugged in SG 32. Since >1% of the inspected tubes require repair in Steam Generator 31, an eight hour notification was made to the NRC Operations Center at 1152 EST on November 4, 2003. The following is a summary of the historical repairs to date:

Year Outage EFPY SG 31 SG 32 1985 PRE-SER 155 169 1986 RF01 1.01 0 1 1987 RF02 2.08 3 0 1989 RF03 3.31 10 9 1991 RF04 4.55 160 161 1992 RF05 5.83 4 5 1994 RF06 7.15 3 2 1995 RF07 8.52 14 4 1997 RF08 9.90 29 25 1999 RF09 11.02 12 10 2000 REI0 12.37 28 38 2002 RF1I 13.70 26 10 2003 RF12 15.00 127 50 Total 571 484 There were two issues that added to the increased number of defective tubes. The first was an increased extent of the tubesheet inspection. In the previous RF1 1 outage, the extent into the tubesheet was limited to -5 inches from the top of the tubesheet. During RF12, the extent was increased to -8 inches. To ensure an adequate extent was acquired, the extent was somewhat lower than -8 inches. This resulted in 38 additional indications being identified. This will be discussed in detail later.

The second issue was chemical cleaning on the secondary side of the generator. Due to noise on the eddy current tests, which resulted from the previous chemical cleaning, a second cleaning was performed to remove the copper interference in the support plates.

The post cleaning eddy current testing indicated that the support signals were much cleaner and resulted in a better probability of detection (POD). An increase in the total population of eggcrate cracking can be attributed to this issue. In SG 31, 59 total indications were identified as compared to 2 in the previous outage.

Also there were 11 tubes that had copper deposits sufficient enough to degrade the POD.

These tubes were removed from service.

to W3Fl -2003-0089 Page 2 of 11 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 (CE's Expansion 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

• six 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 553 0F. As'a result of a 1992 T-Hot reduction, Waterford 3 currently operates with an inlet temperature of 6050 F and an outlet temperature of 545 0F. 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 6000 F..

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 8906 100 % N/A RPC ET HL 8906 100 % N/A RPC Low Row U-bends 120 100 % N/A (rows 1-2)

RPC Row 3 -10 U-bends 102 20 % N/A Dented/Ding 71 20 % Yes*

to W3Fl-2003-0089 Page 3 of 11 SG32 Bobbin 8916 100 % N/A RPC ET HL 8916 100 % N/A RPC Low Row U-bends 123 100 % N/A (rows 1-2)

RPC Row 3 -10 U-bends 102 20 % No Dented/Ding 75 20 % No

• The denUding program in SG31 was expanded due to finding axial cracks in dents at the 01 Hot supports. All dented eggcrates on the hot leg side were tested with the plus point probe.

The bobbin inspections were performed from the cold leg sides of both steam generators. RPC testing was conducted from both hot and cold legs. There were 127 tubes plugged in SG31 and 50 tubes plugged in SG32. Table 2.2 lists the number of "indications" identified by generator during RF12:

Table 2.2 Indications Identified During RF12 Type of Indication at Location SG31 SG32 Hot Leg Top of Tubesheet Axial Indication (Above TTS) 10 3 Hot Leg Top of Tubesheet Circumferential Indication (Above TS) 11 2 Hot Leg Tubesheet Axial Indication (Within Tubesheet) 29 7 Hot Leg Tubesheet Circumferential Indication (Within Tubesheet) 39 0 Dent at Support Plate with Axial Indication 2 0 Support Plate (eggcrate) with Axial Indications 59 33 Support Plate (eggcrate) with Circumferential Indications 0 0 Freespan Axial Indications 0 3 Hot Leg Volumetric Indications 1 3 Cold Leg Volumetric Indications 0 0 Low Row U-Bend Indications 0 0 Wear > 39% 0 2 Copper Residual 11 0 Permeability Variation (PVN) or noisy (NSY) 0 6 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 This was the seventh 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 - 8 inches from the secondary face of the tube sheet. Listed in Table 3.1.1 are the outage, to W3Fl-2003-0089 Page 4 of I1 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 l 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 Pius Point RF10 (2000) - l 100 % 4 8 Plus Point RF11 (2002) 100 % 10 3 Plus Point RF12 (2003) 100 % l 11 2 Plus Point The,number of circumferential indications found per SG in each inspection is shown in Figure 3.1.1.

Figure 3.1.A TTS Circum%.,eential-Craidking Waterford 3 Histori:al TTS Circumferential Cracking History 16 -

14-12-

=010

.S6 a, 8- 11

< = 1 a=

SG32 4

2 0

RF07 RF08 RF09 RF10 RF11 RF12 Outage Screening of the indications was performed for in-situ testing. One indication in SG32 exceeded the criteria for leakage at main steam line break (MSLB) pressure. It did not exceed the criteria for proof testing. The' tube was 75-91.

Details of the indication is listed in Table 3.1.2:

Table 3.1.2 In-situ Test Candidate

- ~~~~~~~~~~~~~~~~~~~~~~~~

Gen l Row l Line l Location l Circ. Ext. l Max. Depth l PDA l 32 75 91 TSH-0.12 1 1400 99% 38.5 to W3FI-2003-0089 Page 6 of 11 Based on CEOG Task 1154, stabilization was performed on all circumferential indications above -3 inches. Several tubes had multiple indications. 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:

Table 3.3.1 Historical Top of the Tubesheet Inspections Outage Sample SG31 SG32 Probe RF06 (1994) 100 % 0 0 Plus Pointl 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 t.

RF12 (2003) 100 % 10 3 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 0

RF07 RF08 RF09 RF10 RF1 I RF12 Outage

- I. :.. . t". ! - to W3Fl-2003-0089 Page 5 of 11 f.te d The tube was tested up to normal operating delta pressure (NODP) and MSLB.

The actual pressures achieved were 1650 and 2850 psia. No leakage was detected. This was the first circumferential crack in-situ tested at Waterford 3.

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 eight inches below the secondary face or top of the tubesheet. The following results were obtained in table 3.2.1:

Table 3.2.1 Circumferential Indications within the Tubesheet SG31 SG32 Circumferential Indications 39 0 within the Tubesheet 20 of the 39 total circumferential indications were previously identified within the inspected level. Below -5 inches, 19 additional indications were found. There were no circumferential indications identified within the SG32 tubesheet. A breakdown by location of the cracking within the tubesheet is listed in Figure 3.2.2:

Figure 3.2.2 Circumferential Cracking within the Tubesheet SG31 Circumferential Cracking within the Tubesheet 30 0725 0~~~~~2 S-20 20 19 51 0

.10 ITS 0.00 to -5.00 TTS -5.01 to -10.00 Extent

. -" I ' , -

I r" - II to I W3FI -2003-0089 Page 7 of 11 None of the TTS axial cracks exceeded the in-situ screening criteria for burst or leakage.

There were a total of 29 axial indications in SG31 and 7 indications in SG32 within the tubesheet. As discussed before, the added extent of testing resulted in additional indications being found. 17 of the 36 indications were located in the previously tested extent while the remaining 19 indications were identified below

- 5 inches. This data is graphically displayed in Figure 3.3.2:

Figure 3.3.2 Axial Cracking within the Tubesheet Axial Cracking within the Tubesheet 18 -16 16 -16~~1 _ ll l t g1

, 14 - 13-C 120

.2 1 -_ _ _

,I...

M 10 0 6 __ __ [-3

'0 8 -i 2 -1I TTS 0.00 to -5.00 TTS -5.01 to -10.00 Extent 3.4 Freespan Indications This was the first inspection where freespan indications were identified. One tube was identified with bobbin as having a distorted freespan indication. This tube was adjacent to a stay rod. Plus point identified lines" of sludge between the tube and the stay rod. The plus point confirmed the presence of three axial cracks. The bobbin data for the tubes around all of the stay rods were re-analyzed for similar indications. No additional indications were identified. The indications were small relative to axial extent and depth. The data associated with the flaws is as follows:

SG Row Col Location Axial Lenath 31 42 140 01H + 3.26 0.24 31 42 140 01H + 3.45 0.18 31 42 140 01H + 3.87 0.29 None of the indications met the screening criteria for in-situ testing.

to W3Fl-2003-0089 Page 8 of 11 3.5 Axial Cracking (Eggcrate)

Cracking at eggcrates was first detected at Waterford 3 in 1999 (RF09). Based on the examination results of tubes removed during the ANO-2 outages in 1992 and 1996, 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, the largest number of flaws occurs at the hottest support plate (01 Hot) and generally decreases as the temperature decreases. Figure 3.5.2 depicts the number of indications by outage.

Figure 3.5.1 Eggcrate Flaw Distribution Waterford 3 Historical Eqncrate Indications 40 -

35 30

°25 X 20 o15-5l - -

0 av, u a CDoa aCD a C Nsoa v Support to W3Fl-2003-0089 -' t Page 9 of 11

. Figure 3.5.2 Eggcrate Axial Flaws by Outage Waterford 3 Eqqcrate Indications by Outage 60 50 I

.~40 Xo 2° , , , , I D_ 1SG31 30 E a*SG32 20 z0 o

RFO9 RF10 RF11 RF12 Outage None of the eggcrate flaws detected during RF12 inspection met the in-situ pressure test criteria. As mentioned previously in this report, the detection capability of the eddy current inspection was enhanced during RF12 due to the chemical cleaning; therefore, an increase in eggcrate indications was not only predicted in the degradation assessment but was also found during the subject outage.

3.6 Dented Eggcrate Axial Indications The initial inspection program required that in each steam generator 20% of the dented intersections identified with the bobbin coil as having voltages 2 2.0 be tested with the +Point coil probe. Included in this sample were all new dented intersections and dented intersections > 2 volts from the previous outage (RF1 1) results that showed an increase in voltage of 20% in RF12. Of the total population of 403 dents = 2 volts, 248 of these were tested with +Pt RPC with 2 flaw like indications identified in SG 31. The indications identified in SG 31 were both at the 01H eggcrate support and resulted in an expansion of the dent inspection program to all dented intersections on the hot leg side of SG 31.

Neither of the indications exceeded the screening criteria for in-situ testing.

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. Based on the examination results of the tubes pulled in the ANO2 Fall 1996 outage (2F96), the damage at the eggcrate support is outside diameter stress corrosion cracking (ODSCC). Copper is believed to be a major contributor. In the RF10 refueling outage (2000), a high temperature chemical cleaning was performed to remove copper and residual amounts of lead from the tube bundle. Problems encountered during the cleaning to W3Fl -2003-0089 Page 10 of 11 resulted in thW'copper being plated out. This inot;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 RF1 I 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.

The increased number of indications identified within the tubesheet is due to primary water stress corrosion (PWSCC). This is a common mechanism seen in steam generators of this design. The indications identified in the previously tested zone were consistent with what was expected.

The finding of cracking on the cold leg and in the freespan is also attributed to the better probability of detection following the chemical cleaning. Combustion Engineering steam generators have experienced this mechanism previously.

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 RF12 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.

In-situ pressure testing was performed on the flaw that exceeded the screening criteria. This flaw (a TTS circumferential) was taken to MSLB pressure with zero leakage.

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 RPC, 100% of the small radius U-bends (rows 1-2), 20% of the small radius U-bends (rows 3-10), and 20% of the dented intersections in the eggcrates and freespan.

The top of tubesheet circumferential cracks detected in RF12 exhibited sizes that were bound by previous inspections.

The eggcrate axial cracks identified during RF12 were calculated to burst at pressures well above that identified for structural adequacy in Regulatory Guide 1.121.

to W3Fl-2003-0089 Page 11 of 11 Waterford 3 utilizes N-16 monitors for primary-to-secondary leakage detection. TS 3.4.5.2 Reactor Coolant System leakage limits the total primary-to-secondary leakage through all steam generators to 1 gpm and 720 gallons per day through any one 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 < 1 gallon per day.

Based upon the comprehensive actions performed during RF12 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.

An operational assessment will be completed within 90 days following startup.

Attachment 2 Special Report SR-03-002-00 W3FI-2003-0089 RF12 Steam Generator Plugged Tube Indications to W3Fl-2003-0089 Page 1 of 7 SG31 Plugged Tube Indications TUBE# ROW COL VOLTS IND LOCN INCHI 1 -3 1 0.22 SAi TSH -0.16 2 5 1 0.16 SAI TSH -0.18 3 5 63 0.14 SCI TSH -0.02 4 6 22 0.35 SVI TSH 0.17 5 7 39 0.26 SAI 01H 0.74 6 9 135 0.55 SCI TSH -2.05 7 11 15 0.18 SAI 03H -0.37 8 12 138 0.37 SAI 02H 0.41 9 15 111 0.19 SAI TSH 0.16 10 15 127 0.5 SAI 01H 0.1 11 16 2 0.11 SAI TSH -0.11 12 16 16 0.32 SAI 03H 0.72 13 16 160 0.25 SAI 03H -0.67 16 .60 0.31 SAI 03H -0.45 14 17 113 0.47 SAI 01H 0.04 15 17 145 1.4 SAI TSH -8.1 17 145 0.64 SAI TSH -7.34 16 18 6 0.14 SCI TSH -0.07 17 18 22 0.2 SAI 04H 0.76 18 18 136 0.27 SCI TSH -7.69 19 20 14 0.26 SAI 03H 0.76 20 20 126 0.35 MAI 01H 0.03 21 20 146 0.24 SAI 04H 0.58 22 21 15 0.12 SAI 03H 0.66 23 22 42 0.96 SCI TSH -6.38 24 22 130 0.11 SAI 01H 0.69 25 26 122 0.2 SAI 01H 0.75 26 27 3 0.43 CUD 0IC 0 27 29 59 0.37 SAI 06H -0.47 28 30 38 0.22 SCI TSH -0.11 29 30 62 0.24 SAI 011H 0.81 30 30 122 0.23 SAI 01H 0.67 30 122 0.47 SCI TSH -0.06 31 32 46 0.3 SAI 03H 0.74 32 35 117 0.63 SAI TSH -8.58 33 35 119 0.79 SAI TSH -2.89 34 36 50 0.51 SCI TSH -2.93 36 50 0.22 SCI TSH -2.28 35 37 47 0.56 SCI TSH -5.63 to W3Fl-2003-0089 Page 2 of 7 SG31 Plugged Tube Indications TUBE # ROW COL VOLTS IND LOCN INCHI 36 37 109 0.31 SAI TSH -1.17 37 109 0.33 SAI TSH -0.55 37 37 121 0.38 SAI 01H 0.65 38 37 141 1.75 SAI TSH -10.08 39 38 56 0.46 SCI TSH -4.51 40 38 64 0.42 SAI TSH -0.4 38 64 0.23 SCI TSH -8.86 38 64 0.27 SCI TSH -3.31 41 38 108 0.14 SAI TSH 0.28 42 38 118 0.42 SCI TSH -4.5 38 118 0.56 SCI TSH -4.09 43 38 120 0.54 SCI TSH -1.92 44 38 130 0.28 SAI 01H -0.88 38 130 0.17 SAI 01H -0.48 38 130 . 0.39 SCI TSH -7.33 44 38 130 0.34 SCI TSH -2.93 45 39 55 0.3 SCI TSH -3.33 46 41 49 1.26 SCI TSH -10.17 47 42 48 2.29 SCI TSH -8.83 48 42 136 0.48 SAI 02H 0.34 42 136 0.49 SAI 02H 0.67 49 43 61 0.28 SCI TSH -2.44 43 61 0.36 SCI TSH -1.98 50 43 125 0.21 SAI 01H -0.84 43 125 0.52 SAI 03H 0.24 43 125 0.17 SAI 04H 0.63 51 44 18 0.3 SAI 02H -0.83 52 44 46 0.74 SAI TSH -6.3 53 44 120 0.47 SCI TSH -8.95 44 120 0.65 SCI TSH -7.25 44 120 1.24 SCI TSH -6.77 54 45 129 0.14 SAI 01H 0.58 55 46 56 0.34 SCI TSH -6.98 56 46 116 0.52 SAI TSH -6.91 46 116 0.56 SAI TSH -2.53 46 116 0.66 SCI TSH -1.54 57 47 29 0.18 SAI 05H 0.68 to W3Fl-2003-0089 Page3of7 SG31 Plugged Tube Indications TUBE# ROW COL VOLTS IND LOCN INCH1 58 47 57 0.19 SAI 01H -0.41 47 57 0.35 SAI 05H 0.69 47 57 0.84 SAI 06H 0.03 47 57 0.52 SCI TSH -3.42 59 47 109 0.32 SAI TSH -1.2 60 48 54 0.16 SAI 05H 0.92 61 48 56 0.39 SCI TSH -2.32 48 56 0.64 SCI TSH -0.81 62 49 55 0.1 SAI 01H -0.93 63 49 121 0.27 SAI 03H 0.56 64 50 68 0.27 SAI 05H 0.56 65 51 127 0.17 SAI 01H -0.74 66 53 105 0.51 SAI TSH -2.03 53 105 0.12 SAI TSH -1.32 53 105 0.32 SAI TSH -0.94 67 55 115 0.19 SAI 01H 0.77 68 57 87 0.6 SAI TSH -3.18 69 57 89 0.46 SAI TSH -1.53 70 58 50 0.34 SAI 02H -0.96 71 58 82 0.38 SAI 03H -1.03 72 58 106 0.28 SCI TSH 0.08 73 58 108 0.63 SCI TSH -8.7 74 59 89 0.48 SAI TSH -1.05 75 60 40 0.06 SCI TSH -0.11 76 61 81 0.34 SAI TSH -2.01 77 63 89 0.24 SAI 03H 0.6 78 63 97 0.4 SAI 01H -0.63 79 66 76 0.4 SAI 05H 0.68 80 66 92 0.47 SAI 01H 0.19 81 67 119 0.2 SAI TSH -0.13 82 68 90 0.6 SAI TSH -1.13 83 68 96 0.73 SAI TSH -1.47 68 96 0.49 SCI TSH -2.39 84 68 118 0.45 SCI TSH -7.65 68 118 0.23 SCI TSH -6.83 85 68 132 0.53 SCI TSH -3.78 86 69 69 0.22 SAI TSH 0.22 87 70 142 0.37 SAI 03H 0.84 88 72 74 0.41 SAI 03H 0.66 72 74 0.18 SAI 04H 0.69 to W3Fl-2003-0089  : !ij Page 4 of77A SG31 Plugged Tube Indications TUBE# ROW COL VOLTS IND LOCN INCHI 89 88 0.73 SAi TSH -1.06 72 88 0.36 SCI TSH -7.89 90 72 118 0.12 SAI TSH -0.12 91 72 120 0.43 SCI TSH -8.92 92 73 97 0.37 SAI 03H -0.15 93 74 70 0.29 SCI TSH -7.96 94 74 118 0.46 SAI TSH -6.51 95 75 55 0.44 SAI TSH -7.75 96 76 30 0.45 SAI 02H 0.71 97 76 160 0.21 SAI 02H 0.79 98 78 50 0.24 SAI 01H 0.6 99 79 15 0.53 CUD 02H 0.03 100 82 26 0.23 SCI TSH 0.17 101 82 106 0.17 SAI TSH -0.18 102 84 106 1.06 SCI TSH -9.1 84 106 1.2 SCI TSH -8.6 84 106 0.43 SCI TSH -7.94 103 86 96 0.48 SCI TSH -3.78 104 87 105 0.48 SAI TSH -12.68 87 105 4.02 SAI TSH -11.04 87 105 3.44 SAI TSH -9.86 105 88 122 0.21 SAI 02H 0.72 106 89 105 0.15 SAI TSH -0.22 107 90 78 0.7 MAI 03H -0.45 90 78 0.33 SAI 03H 0.66 108 90 90 0.15 SCI TSH -0.02 109 98 24 0.48 CUD 01H 0 98 24 0.47 CUD 01C 0 110 99 79 1.97 SAI TSH -8.41 111 99 103 0.47 SAI TSH -8.9 112 100 124 0.14 SAI 01H 0.78 113 101 151 1.13 CUD 01H 0 114 111 83 0.18 SAI 03H 0.5 115 125 133 0.64 CUD 01H 0.62 116 127 113 0.29 SCI TSH -0.05 117 128 92 0.15 SCI TSH -0.01 118 128 114 0.2 SCI TSH -0.06 119 129 129 0.87 CUD 02H 0 120 132 112 15.16 PVN 03H 1.19 121 133 123 0.4 CUD 01C 0

-? f

'I : 4 - to W3Fl-2003-0089 Page 5 of 7 SG31 Plugged Tube Indications TUBE # ROW COL VOLTS IND LOCN INCHI 122 138 58 0.98 CUD 01H 0 123 139 61 0.6 CUD 01C 0 124 140 62 0.73 CUD 01H 0 125 141 63 0.66 CUD 01H 0 126 142 94 0.21 SAI 01H 0.87 127 142 106 0.31 SAI 01H 0.4 Legend:

TSH - Tubesheet Hot SAI - Single Axial Indication MAI - Multiple Axial Indication SCI - Single Circumferential Indication MCI - Multiple Circumferential Indication SVI - Single Volumetric Indication MVI - Multiple Volumetric Indication CUD - Copper Deposit PVN - Permeability Variation

v P-1 I

I to

. If.-, .-t ir; 141.

W3Fl-2003-0089 Page 6 of 7 SG32 Plugged Tube Indications

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TUBE # ROW COL VOLTS IND LOCN INCHI 1 155 0.12 SvI TSH 0.47 2 4 126 0.24 SAI 01H -0.25 3 6 162 0.2 SAI TSH -23.46 4 9 51 0.19 SAI 05C 0.69 5 10 20 0.16 SAI 01H -0.88 6 10 24 0.15 SAI 02H -0.79 10 24 0.09 SAI 02H -0.68 10 24 0.5 SAI 05H 0.78 7 10 160 0.31 SAI 03H -0.37 10 160 0.23 SAI 03H -0.16 8 11 29 0.14 SAI 05H 0.76 9 12 14 0.29 SAI 03H 0.82 10 12 156 0.3 .SAI 03H -0.99 11 15 113 0.33 SAI 07H 0.58 12 16 18 0.17 SAI 03C -0.87 13 16 160 0.11 SAI 02H 0.66 14 16 166 0.56 SAI 03H -0.88 15 19 27 8.14 NSY 02H 16.74 16 19 33 4.88 NSY 07H 7.41 17 19 35 10.59 NSY 05C 19.46 18 19 37 0.35 SAI TSH -12.9 19 37 0.33 SAI TSH -10.59 19 37 0.29 SAI TSH -14.13 19 21 123 0.76 SAI TSH -4.84 20 21 129 0.25 SAI 02H 0.65 21 25 117 0.2 SVI TSH 3.38 22 27 33 0.59 SAI 03H 0.8 23 27 39 0.3 SAI 01H 0.4 24 29 35 3.88 NSY 04H 27.23 29 35 0.26 SAI 03H 0.53 25 29 51 0.49 SCI TSH -0.26 26 34 130 0.19 SAI 01H 0.5 27 37 51 0.13 SAI TSH 0.65 28 42 140 0.24 SAI 01H 3.13 42 140 0.22 SAI 01H 3.45 42 140 0.43 SAI 01H 3.66 29 45 35 3.87 NSY BWI 23.76 30 48 6 0.15 SAI TSH 0.02 31 53 101 0.37 SAI 01H 0.3 32 54 88 1.86 PCT BW9 1.97

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I.., 5.1 W3Fl-2003-0089 Page 7 of 7 SG32 Plugged Tube Indications TUBE # ROW; COL VOLTS IND LOCN INCH1 33 56 88 1.7 PCT BW9 1.7 34 58 50 0.35 SAI 03H -0.4 35 65 111 0.5 SAI 02H 0 65 111 0.21 SAI 03H 0.9 36 73 67 0.12 SAI TSH -0.01 37 75 91 1.81 SCI TSH -0.12 38 75 113 0.22 SAI 04H 0.68 39 78 120 0.27 SAI 04H 0.65 40 83 119 0.32 SAI 03H -0.36 41 89 39 0.26 SAI 03H 0.85 42 90 52 PTP 43 91 53 0.27 SAI 04H 0.54 44 93 23 0.23 SAI 01H 0.2 45 107 65 0.8 SAI TSH -6.82 46 107 93 1.08 SAI TSH -7.61 47 108 92 0.21 SAI 01H 0.6 48 117 109 0.3 SAI 011H 0.54 49 122 110 0.12 SAI 01H 0.55 50 135 57 0.55 SVI BW9 -4.65 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 PTP - Preventative Tube Plug PCT - Percent Through Wall NSY - Noisy Tube