ML083460010

Response to Request for Additional Information - 180 Day Report on the Spring 2008 Steam Generator Tube Inspection

ML083460010
Person / Time
Site:	Calvert Cliffs
Issue date:	12/03/2008
From:	Flaherty M Constellation Energy Group, Nuclear Generation Group
To:	Document Control Desk, Office of Nuclear Reactor Regulation
References
TAC MD9446
Download: ML083460010 (32)

Text

Calvert Cliffs Nuclear Power Plant Constellation Energy-Nuclear Generation Group 1650 Calvert Cliffs Parkway Lusby, Maryland 20657 December 3, 2008 U. S. Nuclear Regulatory Commission Washington, DC 20555 ATTENTION:

SUBJECT:

Document Control Desk Calvert Cliffs Nuclear Power Plant Unit No. 1; Docket No. 50-318 Response to Request for Additional Information - 180 Day Report on the Spring 2008 Steam Generator Tube Inspection (a)

Letter from Mr. M. D. Flaherty (CCNPP), to Document Control Desk (NRC), dated July 31, 2008, Spring 2008 - 180 Day Steam Generator Report

REFERENCES:

(b)

Letter from Mr. D. V. Pickett (NRC) to Mr. J. A. Spina (CCNPP), dated October 15, 2008, Request for Additional Information Re: 180-Day Report on the Spring 2008 Steam Generator Tube Inspection-Calvert Cliffs Nuclear Power Plant, Unit No. I (TAC No. MD9446)

In Reference (a), Calvert Cliffs Nuclear Power Plant submitted the 180 Day Report on the Spring 2008 Unit I Steam Generator Tube Inspection.

In Reference (b), the Nuclear Regulatory Commission requested additional information to be submitted to support their review of the report. Our response to this request is attached.

Should you have questions regarding this matter, please contact Mr. Jay S. Gaines at (410),495-5219.

Very truly yours, Mark D. Flaherty Manager - Engineering Services MDF/KLG/bjd

Attachment:

(1)

Response to Request for Additional Information -- Unit 1 180 Day Steam Generator Report cc:

D. V. Pickett, NRC S. J. Collins, NRC Resident Inspector, NRC S. Gray, DNR X047

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ATTACHMENT (1)

RESPONSE TO REQUEST FOR ADDITIONAL INFORMATION -- UNIT 1 180 DAY STEAM GENERATOR REPORT Calvert Cliffs Nuclear Power Plant, Inc.

December 3, 2008

ATTACHMENT (1)

RESPONSE TO REQUEST FOR ADDITIONAL INFORMATION -- UNIT 1180 DAY STEAM GENERATOR REPORT

RAI 1

For each refueling outage since installation of the steam generators (SGs), please provide the cumulative effective full power months that the SGs have operated.

CCNPP Response:

As of the Calvert Cliffs Nuclear Power Plant (Calvert Cliffs) Unit 1 2004 refueling outage, both SGs 11 and 12 had operated for 21.13 effective full power months (EFPM). As of the 2006 refueling outage, they had operated for 42.38 EFPM. As of the 2008 refueling outage, they have operated for 64.34 EFPM.

RAI 2

In the report, it is stated that "324fan bar wear (FBW) indications in 272 tubes were identified in the Calvert Cliffs Nuclear Power Plant Unit 1 SGs during the spring 2008 inspection; an increase of approximately 2/3fioom the 189 indications in 166 tubes identified during the 2004 inspection." Please describe any insights on the cause of the increase of FBW indications. Please also describe the size distribution of the new FBW indications found in the spring 2008 inspection in comparison to the size distribution of the FBW indications found in the 2004 inspection. If the size distribution of the new indications is comparable or more severe than the size distribution of the old indications, please discuss whether the conditions are becoming worse with time. Please also discuss what tubes are considered to be in the "'pre-definedfan bar wear susceptible region" and why it appears to differ between the two SGs.

CCNPP Response:

Based on the known degradation mechanism of FBW in Babcock and Wilcox (B&W) replacement SGs, it was expected that there would be new indications of FBW during the 2008 inspection. Fan bar wear is caused by locally increased tube support clearances. These increased clearances may be the result of a different method of bundle support used during manufacturing, or the result of grid adjustments that were made to improve manufacturability. These causes do not change with time, so the condition of the SGs is not becoming worse with time. Indications of wear in new tube locations during the 2008 inspection were seen because wear occurs over a spectrum of wear rates. Those locations with higher wear rates were evident as wear indications during the first inspection in 2004. Areas with lower wear rates likely had wear below the detectability threshold in 2004, and only after an additional two cycles of operation did they show up as "new" wear in 2008. In all cases, the FBW rate is expected to slow dramatically after wear is initiated. This was supported by the 2008 inspection results which revealed only a small growth rate of existing indications.

In addition the FBW indications, first reported in 2008, were generally shallower than those reported in 2004, despite having been in service three times longer. This can be seen by the results presented in Figures 1 and 2 below. Figure 1 shows the FBW indications that were reported in 2004. Figure 2 shows the indications that were first reported in 2008, which are, on average, shallower.

I

ATTACHMENT (1)

RESPONSE TO REQUEST FOR ADDITIONAL INFORMATION -- UNIT 1180 DAY STEAM GENERATOR REPORT 2004 Fan Bar Wear Indications 35-30-

• SG 11 ESG 12 o 25 0 20 Lo 15-E 10 -

z

L..

lih,.

.U 0

0 2

4 6

8 10 12 14 16 18 20 22 24 Wear Depth (% Through-Wall)

Figure 1: 2004 Fan Bar Wear Indications 35 30 o 25 20 Sb.

o 15 1..

E 10 z

5 0

2008 New Fan Bar Wear Indications

• SG 11 ISG 12 I..

I All.lh1111 *l' 1

a,.I-,E 0

2 4

6 8

10 12 14 16 18 20 22 24 Wear Depth (%Through-Wall)

Figure 2: Fan Bar Wear Indications First Reported in 2008 To show the growth rate of wear from 2004 to 2008, Figure 3 shows the depth in 2008 of FBW indications that were first reported in 2004 (those values are shown in Figure 1). In comparing Figures 1 and 3, one can see that little overall growth occurred between 2004 and 2008, which supports the analysis that FBW growth slows over time. Based on the smaller size of new indications, and the very small growth rate of existing indications, it is concluded that conditions are not becoming worse with time.

2

ATTACHMENT (1)

RESPONSE TO REQUEST FOR ADDITIONAL INFORMATION -- UNIT 1180 DAY STEAM GENERATOR REPORT 2008 Pre-Existing Fan Bar Wear 35 3SG 11 uSG 12 30 o 25 "am Z*

0 20 C

o 15 E 10 f Z

5 -l a

0 2

4 6

8 10 12 14 16 18 20 22 24 Wear Depth (%Through-Wall)

Figure 3: 2008 Distribution of Fan Bar Wear Indications First Reported in 2004 Regarding the "Pre-Defined Fan Bar Wear Susceptible Region," it is known from industry experience that FBW occurs at tubes with intermediate radii. This is confirmed by the following explanation provided by a B&W representative in an email response to Calvert Cliffs:

"It is recognized that achieving small clearances between tubes and supports is essential for mitigation of wear. Within the susceptible region the tube to support clearances are somewhat variable since the layers of tubes are capable of laterally shifting within their available clearances. If a few layers within the susceptible region bunch up then larger clearances may open in other positions within the susceptible region thereby initiating tube wear. The smaller radius tubes are stiffer in their out-of-plane direction and have less cross flow therefore have better clearance control and are less susceptible to wear and consequently are not within the susceptible region. Also the tubes closest to the external U-bend support structure are stiffer in their out-of-plane direction since the support structure maintains a regular pitch pattern. This enhanced pitch control in the region closest to the support structure helps to control the clearances and therefore is less susceptible to wear."

The "fan bar wear susceptible region" was not defined to encompass every region that could possibly experience fan bar wear; rather it was defined to bound the location of the 2004 FBW indications, and therefore the region where higher growth rate wear is more likely.

The possibility exists for less significant FBW to occur outside the defined susceptible region, and a sample of tubes was inspected throughout the rest of the SG to find any such wear. Between the two SGs, only 1 FBW indication was seen outside the "fan bar wear susceptible region."

In SG 12, the susceptible region was slightly larger because a single indication was identified in 2004 that was located away from the location of the other indications. Because this was a single indication, the main FBW susceptible region was left unchanged, but a conservative buffer of 60 tubes around this one tube was included in the buffer zone. The shaded regions of Figures 4 and 5 show the FBW susceptible region for SGs 11 and 12, respectively. Also shown are the FBW indications identified in 2004, which 3

ATTACHMENT (1)

RESPONSE TO REQUEST FOR ADDITIONAL INFORMATION -- UNIT 1180 DAY STEAM GENERATOR REPORT were used to determine the "fan bar wear susceptible region." Figures 6 and 7 show the entire inspection maps for SGs 11 and 12 respectively, which include the bundle peripheries and a sample of the rest of the tube bundles. They also show all of the FBW indications detected in 2008.

Calvert Cliffs Unit 1 Fan Bar Wear - Critical Area and Buffer Zone GROUP TUBES 9 S 12,1104 Wwu N

LI -31r JarWE Vlc-

'~e _'c, C re C -. r Be, 'Oeo CA 1 504 SUALE 60 (1534t X Tue Jan 29 12:20 N 2M8LI SIG I I HOT PRI41ARY FACE TOTAL IUBES, 3411 SELETE.D TUBES 19M OUT OF SERVICE t#) NA NOI/i F

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-7:-

737 t:-7 t:-: -:t t-

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tT-:T -T--.

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77

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I...I MANWAY Figure 4: Fan Bar Wear Susceptible Region for Steam Generator 11 4

ATTACHMENT (1)

RESPONSE TO REQUEST FOR ADDITIONAL INFORMATION -- UNIT 1180 DAY STEAM GENERATOR REPORT Calvert Cliffs Unit 1 Fan Bar Wear - Critical Area and Buffer Zone GROUP TUBES SG 12 2004 Wear 87 B Fan Ear Wear BJfw Zone 389 C Fan Bar Wear CA 1605 S.G 12 HOT PRIMARY FACE TOTAL TUBES: 8471 SELECTED TUBES: 1994 OUT OF SERVICE (#):

NA SCALE: 0.067388 X Tue Jan 29 12:09.19 2008 NOZZLE

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.r tIte--,ýý;-ýý,ýt'-ý.+.tlt.+ý,ýýt.tI ----------

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MANWAY Figure 5: Fan Bar Wear Susceptible Region for Steam Generator 12 5

ATTACHMENT (1)

RESPONSE TO REQUEST FOR ADDITIONAL INFORMATION -- UNIT 1180 DAY STEAM GENERATOR REPORT GROUP TUBES-HIDDEN Calvert Cliffs Unit 1 C

16M -125 1R18 Fan Bar Wear TestC,...

CA.BZ 238.-0 SO I I TOTAL TUBES.

8471 HOT SELECTED TUBES. 4261 PRIMARY FACE OUT OF SERVICE (t)

I SCALE 0,087388 X Tue Mai 04 12 1 06 2008 NOZZLE 4-I*

- - = * : :' :

I i.,

I

1.

-As MANWVAY Figure 6: 2008 Inspection Map and Fan Bar Wear Indications for Steam Generator 11 6

ATTACHMENT (1)

RESPONSE TO REQUEST FOR ADDITIONAL INFORMATION -- UNIT 1180 DAY STEAM GENERATOR REPORT GROUP IUBES-HI-L)- N 0 Fo~Br BtWcon 144-0 Calvert Cliffs Unit 1 C Ciuc.IArwou6

,-.142 1 R1 8 Fan Bar Wear Tested*OutsideCA8Z 2242:*

S.G 12 TOTAL TUBES. 8471 HOT SELECTED TUBES. 423ti PRIMARY FACE OUT OF SERVICE (3) 0 SCALE O W1388 X 1u. J M., U4 12 010 _1J 0M NOZZLE S,4 4..

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MAN WAY Figure 7: 2008 Inspection Map and Fan Bar Wear Indications for Steam Generator 12

RAI 3

Please describe the scope and results of any secondary side inspections.

CCNPP Response:

No secondary side inspections were performed during the 2008 SG inspection. This was based upon the following: bobbin-probe eddy current was performed on 100% of the periphery and the no tube lane border to look for loose parts (see inspection map in Figures 6 and 7) and none were detected. One tube (SG1 1 R8C130) contained a small indication of wear [7% through-wall (TW)] at the 5th lattice support on the hot side along with an indication that was most likely caused by a lattice bar burr. The surrounding tubes were examined with rotating probes and no foreign object or wear indications were identified.

Because the wear conditions in SG1 1 R8C 130 could not be visually investigated on the secondary side due to difficulty in reaching the location, the decision was made to conservatively treat the indication as a foreign object and to preventively stabilize and plug the tube.

A secondary side visual inspection was a planned contingency with equipment and personnel available.

An inspection would have been performed if conditions required it. However, as stated above, the wear on tube SG 11 R8C 130 could not be investigated because of the difficulty in reaching that location, so a secondary side inspection was not conducted for that indication.

It should also be noted that the 2004 Unit 1 SG inspection consisted of a 100% bobbin inspection and an extensive secondary side visual inspection. During this 2004 inspection no foreign objects were detected 7

ATTACHMENT (1)

RESPONSE TO REQUEST FOR ADDITIONAL INFORMATION -- UNIT 1180 DAY STEAM GENERATOR REPORT in the Unit I SGs. Therefore it is believed that foreign material intrusion is not a significant problem for Calvert Cliffs Unit I SGs.

RAT 4:

Please discuss the nature of the "ambiguous bobbin indications."

CCNPP Response:

The term "ambiguous bobbin indication" was used to refer to any indication that was not caused by FBW and required follow-up testing. There were six "ambiguous bobbin indications" on SG 11 and three on SG 12, as shown in Table I below. After inspection with a rotating probe coil, all of these indications were confidently classified as described below.

SGlI R8C130 showed an indication of a lattice grid burr and was conservatively plugged as described above.

The indications in tubes SGII R17C55, SG11 R115C125, and SGI 1 R137C83 were determined not to represent tube damage or degradation after inspection with a rotating probe coil.

The indications in tubes SG1 1 R78C94, SG12 R122C86, and SG12 R134C88 were determined to be wear caused by lattice support wear. Based on the low observed growth rate from the initial operation of the SGs to the 2008 inspection, it was concluded that these indications will not threaten tube integrity before the next scheduled inspection.

The indications in tubes SGI 1 R126C 114 and SG12 R106C134 were determined to be caused by foreign objects. In both cases, no foreign objects remained adjacent to the tube. More information about the evaluation of these indications is provided in the response to RAI 8.

Table 1: Description of"Ambiguous" Bobbin Indications Foreign Steam Offset Maximum Cause o F Object Plugged Generator Row Column Elevation (in)

Depth Damae POtent and (in)

(%TW)

Damage Potentially Stabilized Present 11 8

130 05H

-1.51 7

Foreign Object Yes*

Yes Wear 11 17 55 TSC

-0.13 N/A No Damage No No 11 78 94 04H 0.51 11 Lattice Support No No Wear 11 115 125 F07 12.11 N/A No Damage No No 11 126 114 TSH 0.95 26 Foreign Object No No Wear 11 137 83 F06 12.09 N/A No Damage No No 12 106 134 TSH 7.12 30 Foreign Object No No Wear 12 122 86 07C 1.07 9

Lattice Support No No Wear 12 134 88 02H

-1.53 14 Lattice Support No No I

I_

Wear Lattice support burr or small foreign object. Conservatively treated as foreign object.

8

ATTACHMENT (1)

RESPONSE TO REQUEST FOR ADDITIONAL INFORMATION -- UNIT 1180 DAY STEAM GENERATOR REPORT

RAI 5

Presumably, a number of new bobbin indications were identified near the fan bars. Of tlwse new bobbin indications, it does not appear that all were inspected with rotating probes and that only those indications greater than 15% through-wall were inspected with a rotating probe. If the Nuclear Regulatory Commission staff's understanding is correct, discuss how the causal mechanisms for these new bobbin indications were determined. Please discuss how wear attributed to tube-to-tube contact and loose parts was ruled out as the causal mechanism.

CCNPP Response:

A cutoff of 15% TW for inspecting with rotating probes was chosen to provide a reasonably large inspection population of large wear in order to confirm that the length of the new and pre-existing wear did not exceed the bounding value of length used in the Condition Monitoring / Operational Assessment report. During the 2004 inspection, all indications of FBW were inspected with a rotating probe coil.

Because there was very little growth of existing indications, it was determined that only the tubes with the largest wear needed to be inspected in 2008 in order to confirm that the wear had the same characteristics.

The plants that operate B&W replacement SGs share their experiences at an annual meeting and through interim phone calls. None of these plants have experienced foreign object wear in the fan bar region, and it is unlikely that a part small enough to work its way that high in the SG could cause significant damage.

Additionally, the fan bar supports have only two offset contact points with the tube, whereas the lattice supports have four contact points, which further decreases the likelihood of a loose part causing damage at a fan bar support rather than becoming stuck at a lattice support. Based on this information, the absence of loose part indications in the eddy current data was taken as reasonable assurance that the wear identified was not caused by loose parts. In addition, tube-to-tube contact was ruled out because FBW occurs only at the fan bar supports, while tube-to-tube contact occurs between supports. The fan bars are identifiable with eddy current by their unique signal, and no wear indications were identified away from the fan bar supports.

RAI 6

Please discuss whether any tubes were identified that were in close proximity.

CCNPP Response:

There were no tubes identified via eddy current inspection that were in close proximity to one another.

RAI 7

Please provide a list of all service induced indications including their location, orientation (if linear) and measured sizes.

CCNPP Response:

There have been no linear indications detected at Calvert Cliffs. All of the indications of degradation identified during the 2008 SG inspection were volumetric in nature. The details of the length and size of the indications are provided in Enclosure (1) (SG 11) and Enclosure (2) (SG 12).

RAI 8

Please discuss whether a secondary side visual inspection was performed near the tubes attributed to foreign object wear (SG11 R126C1J4 and SG12 R106C134) to confirm the absence of a loose part. In 9

ATTACHMENT (1)

RESPONSE TO REQUEST FOR ADDITIONAL INFORMATION -- UNIT 1180 DAY STEAM GENERATOR REPORT addition, please discuss whether potential loose part indications (from the eddy current data) were visually inspected to identify and remove any loose parts. If any possible loose part indications were left in service without visual inspection, please discuss how it was confirmed that tube integrity would be maintained CCNPP Response:

No secondary side inspection was performed near the two tubes with indications attributed for foreign object wear (SG1 I R126C1 14 and SG12 R106C134). These indications were dispositioned based on eddy current results. For SGI I R126C 114 and SGI2 R106C134, 3-coil rotating probes were used in these tubes and in the bounding surrounding tubes (at least 1 tube deep) and no foreign object was found.

Both of these indications were sized using the most conservative eddy current sizing technique for the condition involved (rotating probe technique 27903.1).

No indications of potential loose parts were identified during this inspection other than the tube (SGl 1 R8C130) that was plugged and removed from service as discussed earlier. Since no objects remain adjacent to any of the remaining in service tubes (see Table I above) that have experienced foreign object wear there is no potential for continued, ongoing damage from this cause.

The inspection also demonstrated that the wear caused to date is not a threat to the structural integrity of the tubes going forward. However, the potential for undetected foreign object wear and the development of new foreign object wear in each SG during ensuing operating intervals must be considered. It is difficult to predict if and when foreign object wear - a random and inherently unpredictable phenomenon - will occur.

However, by examining the aggregate operating history of Calvert Cliffs Unit 1 SGs with respect to foreign object wear, a judgment of the risk was developed. During the 2004 Unit I inspection, extensive secondary side examinations were performed along with an eddy current examination of all tubes in both SGs. These inspections revealed no foreign objects which could damage SG tubes and revealed no foreign object related tube damage. After two additional cycles of operation, the 2008 Unit 1 inspections, which included the entire bundle periphery two-to-four tubes deep, revealed no foreign object wear which challenged integrity performance criteria, and identified only one tube with an adjacent potential foreign object indication (the tube which was plugged during the 2008 inspection).

The two wear indications attributed to foreign objects which remain in service were caused by migratory foreign objects no longer present adjacent to the affected tubes. These objects were not located during this examination and have either moved out of the SGs through the blowdown system and are no longer capable of causing tube damage, or have moved to a new location within the tube bundle. Migratory objects are known to move in the direction of the flow, toward the interior of the tube bundle and toward areas of lower flow.

Both affected tubes are located on the bundle periphery which is the area of maximum cross flow and therefore the area which poses the highest potential for developing deep foreign object wear. Yet in this location the objects did not cause structurally significant tube damage. If the objects remain in the bundle they have likely moved inboard to a region of the bundle with lower cross flow and lower potential to cause significant tube damage. Therefore, if they remain within the tube bundle, the objects are judged to be unlikely to pose a threat to tube integrity.

Based on these observations, there is reasonable assurance that foreign object wear will not result in damage that exceeds the structural performance criteria prior to the next SG inspection. Because no wear exceeding the structural criteria is expected, it is concluded that the operational leakage and accident leakage performance criteria will not be exceeded by foreign object wear.

10

ENCLOSURE (1)

Steam Generator 11 Indication Report Calvert Cliffs Nuclear Power Plant, Inc.

December 3, 2008

ARVA NP Inc CUtoeer Nam e; Calvert C1cfa3 Unit I 03/07/08 14:28:27 Co*ponent:

$1G 11 Paqe 2 of 4 FE Near Indicatiors (Sort by Row/Cal)

QCUE3Y:

FB Near Indications by rev R.OW COL VOLTS DEC CHI IND %TW LOCATION 57 s8 60 68 68 69 72 73 76 77 78 80 83 83 83 84 85 86 87 87 88 88 89 89 89 90 91 92 92 92 89 82 68 54 84 79 86 107 86 69 84 86 69 79 87 86 81 80 75 79 84 86 69 81 83 84 81 74 76 78 92 88 93 69 93 93 94 74 94 76 94 82 94 84 95

• 75 95 83 95 85 96 74 96 80 96 82 97 65 97 75 97 79 98 74 98 80 98 82 98 90 99 65 99 79 99 83 99 89 100 78 100 82 100 84 100 90 101 75 101 79 101 83 101 87 102 78 102 80 102 86 103 79 103 81 103 83 104 80 104 82 0.25 0.13 0.14 0.17 0.16 0.13 0.16 0.09 0.21 0.10 0.12 0.16 0.11 0.10 0.11 0.13 0.14 0.11 0.12 0.11 0.18 0.22 0.12 0.10 0.11 0.20 0.13 0.12 0.13 0.16 0.13 0.14 0.10 0.13 0.14 0.08 0.08 0.12 0.12 0.13 0.11 0.12 0.11 0.22 0.19 0.09 0.14 0.09 0.12 0.14 0.10 0.12 0.22 0.13 0.15 0.13 0.13 0.12 0.18 0.12 0.19 0.20 0.15 0.10 0.16 0.16 0.16 0.18 0.26 0.11 0.11 0.09 0.11 0.24 0.28 0.16 0.06 0.16 0.18 0.29 110 P3 TWD 14 132 P3 TWO 6 142 P3 TWO 7 131 P3 TWO 9 133 P3 TWO 8 133 P3 TTD 7 141 P3 TWO 8 74 P3 TWO 6 108 P3 TWO 11 98 P3 Two 5 11 P3 TWD 7 13C P3 TWO 8 108 P3 TWO 5 129 P3 TWO 5 134 P3 TWD 5 133 P3 TWO 6 128 P3 TWD 7 59 P3 TO'D 5 140 P3 TWO 5 136 P3 TWO 6 120 P3 TWO 8 118 P3 TWD 12 136 P3 TWD 5 85 P3 TWOD 6 72 P3 TWD 6 130 P3 TWO 10 119 P3 TWD 7 131 P3 TOD 5 75 P3 TWO 7 117 P3 TWO 9 146 P3 TWO 6 14! P3 TWO 7 11 P3 TWD 5 14C P3 TWD 6 143 P3 TWO 7 138 P3 TWO 2 76 P3 TWO 4 13C P3 TWO 6 88 P3 TWO 6 103 P3 TWO 6 12f P3 TWO 5 90 P3 TWO 6 132 P3 TWO 6 124 P3 TWD 10 94 P3 TWO 10 99 P3 TWO 5 121 P3 TWO 7 156 P3 TWO 4 138 P3 TWO 5 60 P3 TWO 7 123 P3 TWO 5 106 P3 TWO 6 112 P3 TWO 10 i18 P3 Two 7 121 P3 TWO 8 103 P3 TWD 7 112 P3 TWO 7 125 P3 TWO 6 114 P3 TWO 9 80 P3 TWD 6 120 P3 TWD 10 115 P3 TWO 10 125 P3 TWD 129 P3 TWD 6 130 P3 TWO 8 134 P3 TWO 8 129 P3 TWO 8 102 P3 TWO 9 111 23 TWO 13 135 P3 TWO S 140 P3 TWD 5 126 P3 TWO 5 137 23 TWO 6 121 t3 TWO 12 133 P3 TWO 14 01 ?3 TwO 6 137 P3 TWO 1 117 P3 TWO 8 113 P3 TWO 9 135 P3 TWO 15 FOB P07 r07 F07 T06 T07 T07 707 F07 roe F08 r07 P08 roe Fos r07 Fos F07 r07 F06 F09 r07 r07 roe FOB F07 F07 P07 P07 F06 PlO F07 F07 F07 P08 r07 P06 F08 F08 ro8 r07 F07 o07 F08 r07 F07 r07 F07 P06 r07 F07 P07 F07 F07 F07 r07 F07 F07 F07 F07 F07 P06 P06 F07 P07 F07 r07 r0 6 F07 P07 F06 F08 rO0 r07 r07 o07 r07 r07 F07 41.48

+1.71

+0.90

-1.14

-0.80

-0.90

+1.47

-1.29

+1.53

+0.72

+0.83

+1.78

+0.70

+0.65

+1.69

+0.75

+1.46

+1.72

-0.74

+0.76

+1.82

+1.81

+0.63

+0.76

+1.79

+1.75

+1.69

+1.68

+0.50

-0.90

-1.92

+0.77

+0.76

+1.71

+0.77

-1.87

-1.92

+0.75

-0.54

+0.77

+0.65

+0.70

+0.82

+1.04

-0.55

+0.78

+0.77

-0.92

+0.85

+0.74

+1.77

+1.83

+0.79

+0.76

+1.68

+0.83

+1.76

+1.14

+1.76

+0.55

+0.71

-1.86

+0.66

+1.72

+1.73

+1.79

+1.77

-0.74

-0.59

+0.68

-1.83

-1.80

+0.76

+1.70

+1.72

-0.75

-1.87

-0.57

+0.83

+0.90 EXT EXT TEC TEE TEC TEE TEC TER TEC TEE TIC TER TEC TER TEC TEE TEC T*E TEC TEE TEC TER TEC TEE TIC TER TIC TEE TEC TER T3C TER TEC TER TEC TER TEC TEE TEC TER TEC TEE TEC TER TEC TEE TEC TER TIC TER TIC TEE TEC TER TEC TER TEC TER TEC TER TEC TER TEC TEE TEC TEE TEC TEE TEC TEE TEC TER TEC TES TEC TEE TEC TEE TIC TEE TEC TEE TIC TEE TIC TER TEC TER TEC TEE TEC TER TEC TEE TEC TER TEC TEE TEC TEE TIC TEE TEC TEE TEC TEE TEC TER TEC TER TEC TER TEC TEA TIC TEE TEC TEE TEC TEE TEC TER TEC TEE TEC TER TEC TEE TEC TEE TEC TEE TIC TEI TEC TER TEC TER TEC TEE TEC TER TEC TIE TEC TEE TEC TER TIC TEE TEC TER TEC TER TIC TEE TEC TEE TEC TER TEC TER OTIL I

OTIL 2

CAL I 42 LAR 11 16 LAR 11 5

12 LA.

11 17 11 15 6

LAR 11 16 LA.

1II LAR 11 12 LAR 11 11 12 14 11 LAP.

11 LAR 6

LAR 6

LA.R 11 15

LAP, 11 LAP 6S 11 13 13 11 11 11 43 15 LAR 6

14 14 12 LAP.

5 14 5

12 13 11 11 15 13 12 LAP.

14 12 12 12 42 16 11 5

43 L.AE.

11 LAP.

11 6

43 13 12 12 6

11 11 12 12 12 11 LAP 11 11 LAP.

5 11 12 LEG HOT HOT HOT HOT SOT SOT DOT SOT ROT HOT SOT HOT HOT HOT HOT HOT HOT NOT NOT HOT HOT HOT ROT ROT HOT HOT HOT POT HOT ROT POT EOT HOT HOT HOT HOT HOT HOT HOT HOT SOT HOT SOT SOT HOT HOT HOT POT POT HOT HOT HOT HOT HOT HOT ROT HOT SOT HOT HOT SOT HOT HOT SOT POT HOT ROT HOT HOT HOT HOT HOT ROT HOT HOT ROT ROT SOT HOT HOT PROBE 6200!

6200!

62001 62001.

6200L 6200!

6200L 6200!

620UL 6200L 620UL 62010L 62005 62001 6200!

620!L 6200!

62001 6200!

6200L 62001 6200L 62001.

6201L 6200L 6200!

6200L 6200L

6200U, 62001.

6200!

62001 620CL 62001 62001 6200L 6200!

62001 6200L 620UL 620C7L 6200!

62005 62CUL 6200!

620!L 6200!

6200C 620UL 6200C 62C0UL 62 CL 62CU!

62CU!

620U!

6200!

6200!

62001 6200!.

62C!.

62CCL 62 CL 6200L 6200!

6200!

6200!

6200!.

6200U 6200L 62001 6200L 6200L 62001 620'L 6200!

62001.

62CUL 62CCL 62CU!

62CUL

AREVA NP Inc Customer Name: Calvert Cliffs Unit 1 03/07/08 14:28:27 Component: S/G 11 Page 3 of 4 FB Wear Indications (Sort by Row/Col)

QUERY: FB Wear Indications by rov.qry ROW COL VOLTS DEG CH rND %TW LOCATION EXT EXT UTIL I

OUTL 2

CAL # LEG PROBE 104 88 105 75 105 79 105 85 105 89 106 78 106 80 106 82 106 86 106 88 107 79 107 83 107 85 107 87 107 89 108 78 108 84 108 88 109 79 109 83 109 87 110 76 110 78 111 79 111 87 111 89 112 76 112 78 112 80 113 79 113 83 113 85 113 89 114 74 114 76 114 78 114 80 114 82 115 75 115 79 115 85 115 87 115 91 116 72 116 78 116 86 117 79 117 83 117 87 117 99 118 78 120 82 120 88 121 79 123 81 125 81 127 81 127 91 0.12 0.11 0.15 0.33 0.12 0.12 0.28 0.17 0.15 0.11 0.16 0.23 0.17 0.11 0.34 0.14 0.17 0.14 0.16 0.13 0.14 0.12 0.14 0.13 0.17 0.12 0.16 0.14 0.15 0.22 0.23 0.12 0.10 0.13 0.17 0.18 0.27 0.14 0.08 0.12 0.12 0.13 0.22 0.18 0.19 0.12 0.15 0.11 0.17 0.12 0.11 0.18 0.10 0.23 0.15 0.25 0.57 0.12 0.11 0.12 0.11 0.14 0.43 0.20 0.11 0.12 0.10 0.14 0.10 0.19 0.12 0.15 139 P3 135 P3 127 P3 131 P3 142 P3 102 P3 124 P3 127 P3 130 P3 114 P3 135 P3 127 P3 129 P3 123 13 120 P3 108 P3 118 P3 147 P3 131 P3 131 P3 114 P3 108 P3 121 P3 129 P3 119 P3 108 P3 105 P3 125 P3 116 P3 129 P3 103 P5 133 P3 117 P3 136 P3 98 P3 128 P3 131 P3 131 P3 122 P3 141 P3 85 P3 117 P3 141 P3 134 P3 118 P3 134 P3 123 P3 137 P3 131 P3 138 P3 135 P3 127 P3 134 P3 134 P3 125 P3 124 P3 125 P3 117 P3 141 P3 99 P3 128 P3 100 P3 123 P3 137 P3 III P3 92 P3 130 P3 145 P3 130 P3 129 P3 132 P3 136 P3 TWO 5 TwO 5 TWO 7 TwO 16 TWO 6 TOD 5 TWO 15 TWO 9 TWO 8 TWo 6 TWD 8 TWO 12 TWD 10 TWO 5 TWO 16 TWO 7 TWO 9 TWO, 7 TWO 8 Two 7 TWO 8 TWO 6 TWD 7 TWD 7 TWD 9 TWD 6 TWO 8 TWO 6 TWO 8 TWO 11 TWO 9 TWO 6 TWO 5 TWo 7 TWO 8 TWO 9 TWo 13 TWO 7 TWO 2 TWO 7 TWO 5 TWD 6 TWo 11 TWO 9 TWO 10 TWO 5 TWO 8 TWO 6 TWO 9 TWO 6 TWD 6 TWD 8 TWO 4 TWO 12 TWO 8 TWO 12 TWO 23 TWO 6 TWO 5 TWO 6 TWO 6 TWo 7 TWO 20 TWO 10 TWO 6 TWO 6 TWO 5 TWD 7 TWO 5 TWoD 10 TWO 7 TWO 9 P06 F06 F07 F07 F06 F07 P07 F07 F06 F07 F07 107 P08 r07 r07 P07 E06 T07 708 707 1706 P06 F06 r08 P07 F06 706 P07 F07 F06 F09 F07 F07 F07 707 106 F06 F07 10?

r07 r70 F06 707 707 r07 F07 r06 707 707 TO?

r07 F06 r07 F07 F06 r07 7o06

'07 r07 r0E F07 F06 7'06 704 7"06 r07 F07 FOB F06 F09 F06

-1.69

-0.74

+1.74

+1.76

-0.76

+0.75

+0.83

+0.78

-1.74

+0.74

+0.84

+1.67

-0.78

-1.89

-0.55

+0.72

-1.88

+0.78

-1.23

+1.75

-0.85

-0.78

-0.80

-0.55

+0.46

+0.48

+1.61

+0.78

+0.80

-1.73

+1.16

+0.61

+0.74

+0.77

+0.73

+1.67

-0.76

-0.55

+0.82

+0.70

-1.90

+0.81

+0.82

+0.76

+0.76

+1.72

-0.77

+0.72

+0.72

-1.90 40.85

+1.69

+0.75

+1.69

-0.79

+1.69

-0.80

-0.55

+0.75

+0.76

+0.80

-1.79

+1.48

+0.84

+1.80

-0.80

+1.60

+1.69

+0.65

-1.47

+1.72 40.89 TEC TEN TEC TEE TEC TER TEC TER TEC TER TEC TER TEC TEE TEC TER TEC TER TEC TER TEC TEN TEC TER TEC TER TEC TER TEC TEE TEd TEE TEC TER TEC TER TEC TEE TEC TEE TEC TEE TEC TER TEC TEN TEC TER TEC TEE TLC TEE TEC TEE TEC TEN TEC TEE TEC TEN TEC TEN TEC TER TEC TEN TEC TEN TEC TEN TEC TEN TEC TER TEC TEN TEC TEN TEC TER TEC TER TEC TEN TEC TEN TEC TER TEC TEN TEC TER TEC TEN TEC TEN TEC TEE TEC TEE TEd TEN TEC TEE TEC TEN TEC TEN TEC TEN TEC TER TEC TEN TEC TEN TEC TEN TEC TEN TEC TEN TEC TER TEC TER TEC TEN TEC TER TEC TEN TEC TER TLC TEE TEC TEN TEC TEN TEC TEN TEC TER 11 43 13 12 12 11 42 12 12 12 12 12 42 11 5

12 12 43 11 6

6 43 12 6

LAR 6

LAR 6

11 14 12 12 LAR 11 12 43 1311 11 12 LAR 5

11 42 14 14 12 12 12 14 LAR 11 12 12 12 42 14 11 11 LAR 11 12 LAR 12 LAR 6

11 18 12 12 LAR 11 LANR 11 43 43 12 11 12 LAR 11 42 42 HOT POT HOT HOT NOT NOT NOT HOT NOT NOT NOT HOT HOT SOT SOT HOT ROT ROT HOT NOT HOT HOT HOT HOT HOT HOT HOT HOT HOT HOT HOT HOT HOT HOT ROT NOT HOT POT HOT HOT HOT HOT HOT NOT ROT HOT HOT HOT NOT SOT HOT NOT HOT HOT HOT HOT SOT HOT HOT SOT SOT ROT HOT HOT NOT NOT HOT HOT NOT NOT HOT ROT 62CUL 62C0L 62CDL 62CUL 620CL 6200L 6200L 620UL 620UL 6200L 620UL 62001 6200L 6200L 620UL 6209L 620UL 620UL 620UL 620UL 620UL 620UL 6200L 620UL 620UL 6200L 6200L 620DL 620UL 6200L 6207L 6200L 62001 62001 620UL 620CL 6200L 6207L 6203L 6203L 620UL 6200L 6200L 6209L 6207L 6200L 6203L 6203L 6203L 6207L 62071L 6207L 620JL 6203L 6203L 620n1 6207L 620DL 6203L 6203L 6207L 6207L 6201L 6207L 6207L 6207L 620"CL 62073L 6207L 620rL 620UL 620UL Total Tubes

128 Total Records: 152

AREVA NP Inc Customer Name: Calvert Cliffs Unit I 03/07/08 14:28:27 Component; S/C 11 Page 2 of 4 PH Wear Indications (SoXt by RowICol)

QOUERY: 7B Wear Indications by row ROW COL VOLTS DEG CHN INO %TW LOCATION 57 58 60 68 68 69 72 73 76 77 78 80 83 83 83 84 85 86 87 87 88 88 89 89 89 90 91 92 92 92 92 93 93 94 94 94 94 95 95 95 96 96 96 97 97 97 98 98 98 98 99 99 99 99 100 100 100 100 101 101 101 101 102 102 102 103 103 103 104 104 89 0.25 82 0.13 68 0.14 54 0.17 84 0.16 79 0.13 86 0.16 107 0.09 86 0.21 69 0.10 84 0.12 86 0.16 0.11 69 0.10 79 0.11 0.13 87 0.14 86 0.11 81 0.12 80 0.11 75 0.18 79 0.22 0.12 84 0.10 0.11 86 0.20 69 0.13 81 0.12 83 0.13 84 0.18 81 0.13 74 0.14 76 0.10 78 0.13 0.14 0.08 88 0.08 69 0.12 83 0.12 74 0.13 76 0.11 82 0.12 84 0.11 75 0.22 83 0.19 85 0.09 74 0.14 8o 0.09 82 0.12 65 0.14 75 0.10 79 0.12 74 0.22 80 0.13 82 0.15 0.13 90 0.13 65 0.12 79 0.18 83 0.12 89 0.19 78 0.20 82 0.15 84 0.10 90 0.16 75 0.16 79 0.16 0.18 83 0.26 87 0.11 0.11 78 0.09 80 0.11 86 0.24 79 0.28 0.16 81 0.06 83 0.16 80 0.10 82 0.29 110 P3 132 P3 142 P3 131 P3 133 P3 133 P3 141 P3 74 P3 108 23 98 P3 117 P3 130 P3 108 P3 129 P3 134 P3 133 P3 128 P3 59 P3 14C P3 13( P3 12C P3 1le P3 13(

P3 85 23 72 P3 13C P3 11S P3 131 P3 75 P3 117 P3 146 P3 145 P3 117 P3 140 P3 143 P3 13f: P3 76 P3 130 P3 88 P3 103 P3 126 P3 90 P3 132 P3 124 P3 94 P3 99 P3 121 P3 156 P3 138 P3 60 P3 123 P3 106 P3 112 P3 I18 P3 121 P3 103 P3 112 P3 125 P3 114 P3 88 P3 120 P3 115 P3 125 P3 129 P3 130 P3 134 P3 129 P3 102 P3 lI1 I 3

135 P3 140 P3 124 P3 137 P3 121 P3 133 P3 81 P3 137 13 117 P3 113 P3 135 P3 TWO 14 Two 6 TWD 7 TWO 9 TWO 8 TWO 7 TWO 8 TWO 6 TWO 11 TWD 5 TWO 7 TWO 8 TWO 5 TWO 5 TWO 5 TWD 6 TWO 7 TWD 5 Two 5 TWO 6 TWO 8 TWO 12 TWO 5 Two 6 TWO 6 TWO 10 TWD 7 TWO 5 TWO 7 TWO 9 TWO 6 TWO 7 TWO 5 Two 6 TWO 7 TOD 2 TWO 4 TWD 6 TWO 6 TWO 6 TWO 5 TWO 6 Two 6 TWO 10 Two 10 TWD 5 TWO 7 TWD 4 TWO 5 Two 7 TWO 5 TWO 6 TWO 10 TWO 7 TWO 0 TWD 7 TWO 7 TWO 6 TWO 9 TWO 6 TWO 10 Two 10 TWO 8 TWO 6 TWD 8 Two 8 TWO 8 TWO 9 TWO 13 TWO 5 TWO 5 TWO 5 TWO 6 TWD 12 TWO 14 TWO 8 TWO 1 TWO 8 TWO 9 TOD 15 T08 P07 70?

F07 F06 707 707 707 707 r08 F08 707 r08 r08 07 F08 F07 F07 F06 F09 F07 707 r08 F08 F07 r07 F07 707 706 F10 707 707 r07 r08 707 F06 r08 r08 r08 V07 F07 707 r08 F07 707 707 707 706 r07 F07 r07 707 r07 707 F08 707 F07 F07 F07 706 F07 F06 F06 F07 707 707 707 r06 707 707 P06 F06 708 F07 r07 706 T0?

F07 F07 707

+1.48

+1.71

+0.90

-1.14

-0.80

-0.90

+1.47

-1.29

+1.53

+0.72

+0.83

+1.78

+0.70

+0.65

+1.69

+0.75

+1.46

+1,72

-0.74

+0.76

+1.82

+1.81

+0.63

+0.76

+1.79

+1.75

+1.69

+1.68

+0.50

-0.90

-1.92

+0.77

+0.76

+1.71

+0.77

-1.87

-1.92

+0.75

-0.54

+0.77

+0.85

+0.70

+0.82

+1.84

-0.55

+0.78

+0.77

-0.92

+0.85

+0.74

+1.77

+1.83

+0.79

+0.76

+1.88

+0.83

+1.76

+1.14

+1.76

+0.55

+0.71

-1.86

+0.66

+1.72

+1.73

+1.79

+1.77

-0.74

-0.59

+0.68

-1.83

-1.80

+0.76

+1.70

+1.72

-0.75

-1.87

-0.57

+0.83

+0.90 EXT EXT TEC TER TEC TEE TEC TER TEC TER TEC TER TEC TER TEC TER TEC TEE TEC TER TEEC TER TEC TEN TEC TER TEC TER TEC TEN TEC TEN TEC TEE TEC TER TEC TER TEC TEN TEC TEE TEC TEE TEC TEE TEC TEE TEC TEN TEC TEE TEC TEN TEC TER TEC TER TEC TER TEC TEN TEC TEN TEC TER TEC TEH TEC TEN TEC TER TEC TEN TEC TEN TEC TEN TEC TER TEC TEE TEC TEN TEC TEN TEC TEN TEC TEE TEC TEN TEC TER TEC TER TEC TER TEC TEN TEC TEE TEC TEN TEC TEE TEC TER TEC TER TEC TER TEC TEN TEC TER TEC TER TEC TEH TEC TEE TEC TEE TEC TEN TEC TEN TEC TEN TEC.TEH TEC TER TEC TEN TEC TER TEC TEN TEC TEN TEC TEN TEC TEE TEC TEN TEC TER TEC TER TEC TER TEC TEN TEC TER TEC TEN TEC TER UTIL 1

UTIL 2

CAL # LEG PROBE 42 LAR 11 16 LAR 11 5

12 LAR 11 17 11 15 6

LAR 11 LAR 11 16 LAR 11 LAN 11 12 LAR 11 11 12 14 11 LAR 11 LAN 6

LAN 6

LMN 11 15 LANR 11 LAR 6

5 11 33 13 11 11 11 43 15 LAR 6

14 14 12 LAR 5

14 5

12 13 11 11 15 13 12 LAN 14 12 12 12 42 16 11 5

43 LAR 11 LAR 11 6

43 13 12 12 611 11 12 12 12 11 LAN 1

11 11 11 HOT HOT NOT HOT SOT NOT SOT HOT HOT SOT HOT HOT HOT HOT HOT HOT NOT NOT HOT ROT ROT HOT NOT HOT NOT HOT HOT HOT ROT POT ROT POT NOT HOT ROT NOT HOT HOT HOT HOT HOT HOT ROT HOT HOT LOT ROT HOT HOT HOT NOT NOT HOT HOT HOT ROT HOT ROT NOT NOT HOT HOT HOT ROE HOT HOT HOT HOT HOT HOT HOT HOT HOT HOT NOT EDT HOT HOT HOT HOT 6200L 6203L 6207L 6200L 6200L 620UL 6200L 6200L 6200L 6200L 62001 6200L 6200L 620UL 6200L 620CL 6200L 6200L 6200L 6200C 6200C 6200L 6200L 62C0L 62COL

62C0T, 62COL 62(0U 62CU0 62C01 62C0L 62CCL 62C0 62CuL 62CM0 62M01 62C0L 6201L 6200L 62C0L 6200L 62COL 6200U 62001 6200L 620U0L 620UL 6200L 6200L 6200L 6200L 6200L 62005 6200L 6200L 6200L 6200L 6200L 6200L 62001 6200L 6200L 6200L 620UL 6200L 620M 6200=1 6200L 62001 62001 62001 6200n 62001 6200L 6200L 6200L 62001 6200L 62001 6200L

AREVA VP Inc 03/07/08 14:27:48 Customer Name: Calvert Cliffs Unit 1 Cozponent: S/G 11 Page 2 of 2 Lattice Support Wear indications CUERY: TSP Wear Indications ROW COL VOLTS DE. CHN IND %TW LOCATION EXT EXT UTIL 1

UTIL 2

CAL # LEG PROSE 78 94 0.19 126 P3 TWD 11 04H

+0.51 TIC TER LAR 42 HOT 6203L Total Tubes

1 Total Records: I

PZVA NP Inc 03/07/08 14:30:31 Customer Fame: Calvert Cliffs Onit 1 Component: S/G 11 Page : of 2 DSX Indications QUERY: DSI Indications ROW COL VOLTS DEG CHN M*D %TW LOCATION EXT EXT (TIL 1 OTIL 2

CAL # LEG PPRO13 8

130 0.13 68 PI OSI 05H

-1.51 TEC TER LAP.

31 ROT IOUL Total Tubes 1

Total Records: 1

AREVA NP Inc 03/07108 14:30:50 Customer Nlame: Calvert Cliffs Unit 1 Component: SIG 11 Page 2 of 2 DTI IndLcations QUERY: DTI Indications ROW COL VOLTS DEG CNN IND %TW LOCATION EXT LXT UTIL 1

UTIL 2

CAL # LEG PROBZ 17 55 3.84 110 P4 DTI TSC

-0.13 TEC TEH LAR 50 NOT 620DL Total Tubes

1 Total Records: I

AREVA NP Inc 03/07/08 14:30:15 Customer Na1se: Calve:t Cliffs Unit 1 Component: S/C 11 Page 2 of 2 NQI Indications OUERY: NQ! Indications ROw COL VOLTS DEG CIN ISO MTW LOCATION EXT EXT OTIL 1

UTIL 2

CAL # LE5 PRO3E w........

~

n

.-.l m

115 125 5.75 141 5 NQ1 r07

+212.11 TEC TEH DBP LAR 5

HOT 620UL 126 114 0.12 127 P1 NQ0 TSH 40.95 TFC TEH LAR 2

HOT 6200L Total Tubes

2 Total Records: 2

ARZVA NP Inc 03/07/08 14:29:56 Customer Name: Calvert Cliffs Unit I Component: S/C 11 Page 2 of 2 PLP Indications OUERY: PLP rndica=ion$

ROW COL VOLTS DEG C014 Z4D ITW LOCATION EXT EXT UTIL 1

OTIL 2

CAL # L!G PROBE 8

130 0.73 265 10 PLP 05H

-1.54 05H 05H LA, 41 HOT 610FP Total Tubes

1 Total Records: 1

AAREVA NP Inc Customer Name; Calvert Cliffs Unit I 03/07/08 14:28:07 Coaponent: Sf0 11 Page 2 of 2 wAR indications QUERY: WAR Indications ROW COL VOLTS DEG CHN X8D %TN LOCATION EXT EXT OTIL 1

UTIL 2

8 130 0.16 111 P4 WAR 05H

-1.50 05H 05H 7

78 94 0.15 78 P4 WAR 04H

+0.61 04H 04H 8

105 79 0.29 105 PS WAR F07

+1.84 r07 F07 22 107 83 0.26 107 PS WAR F07

-0.50 F07 F07 20 117 79 0.36 102 PS WAR r06

-0.83 F06 F06 25 120 82 0.23 88 P5 WAR F06

+1.55 F06 F06 18 126 114 0.07 72 P4 WAR TSH

+0.85 TSH 018 3

CAL 4 LEG 41 HOT 54 HOT 40 HOT 40 HOT 40 HOT 40 HOT 41 HOT PEZBE 6101?

5(0PP 50OPP 5(0PP 610PP Total Tubes

7 Total Records: 7

AREVA NP Inc 03/07/08 14:31:04 Cust*mer Name: Calvert Cliffs Unit I Component: S/G 11 Page 2 of 2 DNG Indications Q7ERY: DNG Indications ROW COL VOLTS DEG CNN IND %TW LOCATION EXT EXT UTIL 1

UTIL 2

CAL f LEG PIROBE 48 160 23.40 180 PI DUG F04

+1.17 TEC TER 4

ROT 6200L 114 38 2.32 191 P1 DNG F06

+4.42 TEC TER 8

HOT 620UL 114 68 14.41 181 P1 DNG 02C

-2.62 TEC TER 15 ROT 620UL Total Tubes

3 Total Records: 3

ENCLOSURE (2)

Steam Generator 12 Indication Report Calvert Cliffs Nuclear Power Plant, Inc.

December 3, 2008

AREVA HP Inc Customer Name: Calvert Cliffs Unit I 3/7/2008 2:18:33 Fm Component: S/G 12 Page 2 of 4 FB Wear Indications (Sort by Row/Col)

QUERY: FB Wear ROW COL VOLTS 40 16 0.16 41 45 0.26 61 85 0.16 63 59 0.14 66 94 0.11 0.10 67 89 0.16 68 92 0.10 76 90 0.12 76 92 0.12 83 87 0.18 83 91 0.10 84 88 0.12 84 92 0.20 85 59 0.25 85 75 0.13 85 89 0.12 85 91 0.16 86 90 0.13 87 75 0.19 87 77 0.14 87 83 0.12 88 92 0.16 0.14 89 79 0.15 89 83 0.14 89 91 0.14 0.16 0.19 90 92 0.12 91 75 0.11 92 78 0.19 92 90 0.12 0.32 92 92 0.12 92 94 0.11 93 71 0.17 93 83 0.18 93 91 0.12 93 95 0.14 93 107 0.16 94 76 0.13 0.13 94 82 0.12 94 90 0.13 94 92 0.12 0.15 95 79 0.14 95 81 0.18 95 83 0.17 96 88 0.12 96 90 0.13 97 81 0.14 97 63 0.19 0.12 97 91 0.16 98 72 0.15 98 76 0.14 98 82 0.14 98 84 0.10 98 90 0.13 99 75 0.12 99 79 0.15 99 83 0.09 0.12 0.12 99 87 0.12 99 89 0.17 0.12 99 93 0.12 99 95 0.15 100 78 0.16 100 90 0.18 101 75 0.14 101 83 0.18 101 91 0.13 0.13 10o 93 0.17 102 76 0.17 102 78 0.12 Indications by row DEG CHN 99 P3 116 P3 98 P3 0

P3 132 P3 109 P3 92 P3 87 P3 137 P3 73 P3 129 P3 129 P3 85 P3 16 P3 102 P3 60 P3 110 P3 58 P3 113 P3 131 P3 137 P3 0

P3 44 P3 49 P3 118 P3 0

P3 94 P3 54 P3 95 P3 104 P3 127 P3 123 P3 142 P3 121 P5 33 P3 53 P3 125 P3 0

P3 107 P3 90 P3 158 P3 103 P3 128 P3 128 P3 95 P3 108 P3 107 P3 129 P3 131 P3 0

P3 111 P3 85 P3 141 P3 0

P3 0

P3 96 P3 131 P3 84 P3 100 P3 0

P3 120 P3 118 P3 120 P3 0

P3 0

P3 0

P3 141 P3 122 P3 80 P3 117 P3 127 P3 111 P3 122 P3 121 83 0

P3 49 P3 49 P3 122 F3 99 P3 113 P3 IND %TW TWO 15 TWO 12 TWD 8 TWO 6 TWD 11 TWO 10 TWO 7 TWO 6 TWO 6 TWO 7 TWo 8 TWO 10 TWO 6 TWO 11 T*oD 19 TWO 6 TWD 6 TWO 9 TWO 6 TWD 16 TWO 13 TWO, 12 TWO 9 TWo 8 TWO 6 TWO 7 TWO 8 TWO 9 TWD 11 TWO 11 TWO 10 TWO 8 TWD 6 TWO 10 TWO 7 TWO 6 TWO 14 Two 9 TWo 7 TWO 8 TWO 13 TWo 6 TWD 6 TWO 5 TWO 6 TWD 6 TWO 8 TWD 13 TWO 15 TWO 15 TWD 6 TWD 6 TweD 6 TWO 9 TWD 6 TrD 9 TWO 13 TWO 6 TWO 6 TWO 10 TWO 6 TWO 11 TWO 14 TWO 10 TWO 12 TWD 12 TWO 6 TWO 8 TWO 6 TWO 12 TWO 13 TWO 7 TWO 8 TWO 6 TWV 9 TWO 8 TWO 8 TWO 10 TWO 7 TWO 11 LOCATION EXT EXT 0TIL 1

m P06 r07 F09 Flo r07 F`07 F07 r08 F07 P08 r07 Fro F07 FOB F11 F05 F07 F07 r07 Fo6 F08 r07 F08 P05 P08 P07 F06 P08 F07 F0.7 P0.7 70.7 roe P0?

F07 F06 r08 707 F07 r07 F06 r06 F0?

708 F07 P07 107 F06 F07 F07 F07 To?

F07 F06 F07 F07 r06 r07 Fos T07 F06 707 708 F07 F07 r06 r06 F07 r07 F06 Fos 107 r07 F07 106 F07 F06 F06

+0.71

-1.22

-1.03

+2.65

+1.94

+0.88

+1.30

+0.74

-1.95

+0.78

+1.77

-0.91

-1.93

+0.78

+1.36

+0.78

+2.22

-0.76

-1.95

+1.74

+1.71

+0.48

+0.76

+1.88

+0.74

+0.44

+1.84

+0.73

-1.82

-1.91

+1.76

-1.82

-1.88

+1.25

+0.78

+1.84

-1.79

+0.46

+1.77

+0.82

+0.11

+0.72

-1.76

-1.87

-1.94

+0.80

+1.94

+1.78 41.78

+0.44

+1.79

-1.92

+1.75 40.48 40.39

+0.76

-1.94

-1.80 40.70

-1.93

-1.95

,1.76

+1.76

+0.51

-0.60

-0.66

+0.71

-1.39

+0.78

+0.87

-1.89

-1.84

-1.90

+1.80

+0.44

+0.69

-1.84

+0.82

-1.89

-1.82 TEC TER TEC TER TEC TEE TEC TER TEC TEE TEC TER TEC TER TEC TEE TEC TER TEC TEI TEC TEE TEC TEH TEC TER TEC TEI TEC TEE TEC TEE TIC TEH TIC TER TEC TER TEC TER TIC TER TEC TER TEC TEI TEC TER TEC TEI TEC TER TEC TER TEC TEN TIC TER TEC TER TEC TEI TEC TEI TEC TEI TEC TEE TEC TEI TSC TEI TEC TEI TEC TEN TEC TER TEC TEN TEC TER TEC TER TIC TEI TEC TEI TEC TER TEC TEH TEC TEI TEC TER TEC TIN TEC TEN TEC TEI TEC TEE TEC TER TEC TER TIC TEN TEC TEI TEC TER TEC TEI TEC TER TEC TEI TEC TER TEC TEI TEC TEI TEC TER TEC TEH TEC TER TEC TEI TEC TER TEC TEI TEC TER TEC TEN TEC TEI TEC TEI TEC TER TEC TEI TEC TEI TEC TEI TEC TER TEC TER TEC TER CTEL 2 CAL # LEG 9

HOT 46 HOT 16 HOT 10 NOT LAR 17 NOT LAR 17 HOT 19 HOT 18 HOT 19 ROT 18 ROT 19 NOT LAR 17 HOT 19 NOT 18 ROT 9

HOT 14 NOT 19 NOT 18 NOT 19 NOT 13 NOT 13 NOT LAR 5

NOT 18 HOT 18 ROT 14 HOT 6

NOT 18 NOT 18 NOT 18 H0o" LAR 17 nOT 13 ROT 14 NOT 19 sOT 19 HOT 18 HOT 18 BOT LAR 11 nOT 6

NOT 18 NOT 18 ROT LAR 15 NOT 14 NOT 14 NOT 14 NOT 19 HOT 39 NOT 39 HOT 13 HOT 13 NOT 5

ROT 19 HOT 19 ROT 14 HOT 6

NOT 6

HOT 18 ROT LAR 11 NOT 14 HOT 14 NOT LAR 5

HOT 19 NOT LAR 13 HOT LAR 13 NOT LAR 5

HOT LAR 5

HOT LAR 5

HOT 19 HOT 19 NOT 19 NOT LAR 17 HOT LAR 17 HOT 14 NOT 19 NOT 14 HOT 6

HOT 18 HOT 18 NOT LA 18 NOT 14 HOT LA.

13 HOT PROBE 6200U 6200L 62001 620UL 62001 620UL 62001 62001 62001 6200L 6200L 620UL 620CL 620CL 6200L 620CL 620CL 620CL 6200L 620CL 620C1 620CL 620CL 620CL 620CL 620CL 620CL 620Th 620t'L 620VL 620CL 620VL 620VL 620EtL 620VL 620UL 620UL 620VL 620CL 620UL 6201CL 62CUL 620CL 620UL 620UL 620UL 620UL 620UL 620UL 620UL 620UL 620UL 620UL 620UL 620UL 6201L 620UL 6201CL 62001L 620UL 62031

62OUL, 6201L 62031 6207L 6201L 62031 620:1 62031 62031 62031 6203L 62001 620T1 6203L 6201L 6201L 6201L 62071

A w Inc 3/7/2008 2:18:33 PH Customer Name: Calvert Cliffs Unit 1 Component: S/G 12 Page 3 of 4 FB Wear Indications (Sort by Row/Col)

OCERY: F3 Wear Indications by rov.qry ROW COL VOLTS DEG CHN IND %TW LOCATION EXT EXT UTIL 1

UTIL 2

CAL 4 LEG FROSE 102 82 0.24 139 P3 TWO 10 P06

-1.79 TEC TEE 14 SOT 620UL 102 86 0.12 125 P3 TWO 6 r06

-0.76 TEC TER 19 HOT 620tL 102 88 0.15 108 P3 TWD 14 F06

+0.72 TEC TER 39 HOT 620UL 103 73 0.11 141 P3 TWO 10 r07

+1.61 TEC TEN 11 HOT 62001L 103 75 0.17 129 P3 TWO 15 r07

+1.72 TEC TEE LAP 13 ROT 620VL 103 '9 0.22 141 P3 TWO 18 F07 41.69 TEC TER 13 HOT 620V5 0.23 133 P3 TWo 18 P06

-0.89 TEC TEE 13 HOT 620VL 103 81 0.35 128 P3 TWD 23 F07

+1.87 TEC TER LAR 13 HOT 620CL 0.11 127 P3 TWD 10 F06

-0.80 TEC TER LAP 13 SOT 6200'7 103 83 0.24 0

P3 TWD 19 P06

+0.42 TEC TER 5

HOT 62007.

103 85 0.16 145 P3 TWD 13 r07

-0.87 TEC TEE LAR 15 NOT 620v1.

103 89 0.16 108 P3 TWD 7 P07

+0.76 TEC TEN 19 ROT 620UL 103 91 0.15 134 P3 TWD 13 P07

+0.74 TEC TEN LAIR 17 HOT 620UL 0.19 102 P3 TWD 16 F06

-1.95 TEC TER LAR 17 ROT 620VL 104 72 0.13 116 P3 TWO 6 P06

-1.65 TEC TEN 12 HOT 620UL 104 76 0.14 141 P3 TD 13 P06

-1.85 TEC TEE 13 ROT 620VL 104 78 0.20 134 P3 TWO 9 F07

+0.71 TEC TEE 14 HOT 6200L 104 80 0.14 141 P3 TWO 13 P06

-1.78 TEC TEE 13 HOT 620UL 104 82 0.12 118 P3 TWO 11 r06

-1.91 TEC TER LAR 13 HOT 620U0 104 84 0.26 0

P3 TWO 12 P06

+1.23 TEC TER LAR 6

HOT 620UL 104 88 0.19 127 P3 TWO 8 F07

-1.95 TEC TEE 19 HOT 620UL 104 90 0.19 135 P3 TWO 9 F07

-1.86 TEC TER 19 HOT 620UL 104 94 0.16 105 P3 TWO 9 F07

+1.99 TEC TEE 18 HOT 620UL 105 83 0.27 0

P3 TWO 13 F07

-0.57 TEC TEE 6

HOT 620UL 0.27 0

P3 TWD 13 F06

-0.59 TEC TEE 6

ROT 6200UL 105 85 0.19 111 P3 TWO 9 P07

+0.69 TEC TEE 16 NOT 620UL 0.09 60 P3 TWO 5 F06

-1.82 TEC TEE 16 ROT 620UL 105 87 0.19 114 P3 TWD 9 r07

+0.67 TEC TER 19 HOT 62007 105 89 0.57 136 P3 TWO 21 F07

+1.30 TEC TER LAR 19 ROT 62001L 105 91 0.14 83 P3 TWO 8 P07

+0.73 TEC TEN 18 HOT 6201.L 0.16 68 P3 TWO 9 F06

-1.92 TEC TEH 18 HOT 620UL 105 93 0.13 53 P3 TWO 8 F07

+0.82 TEC TEN 18 ROT 620UL 106 76 0.22 128 P3 TWO 9 r07

+0.69 TEC TER 14 HOT 620U0 106 78 0.13 138 P3 TWO 12 F07

+0.74 TEC TER 13 NOT 620UL 106 82 0.19 114 P3 TWo 8 F07

+0.63 TEC TEE 14 HOT 620UL 0.14 117 P3 TWD 6 P06

-1.93 TEC TEB 14 HOT 620u0 106 84 0.09 0

P3 TWD 10 F06

-0.80 TEC TEE LAR 5

HOT 620UL 106 88 0.12 132 P3 TWO 6 P07

-1.86 TEC TEE 19 HOT 620UL 106 90 0.12 121 P3 TWO 6 P07

-1.86 TEC TEE 19 ROT 620UL 106 94 0.08 106 P3 TWO 9 P07

+1.86 TEC TEN 38 HOT 620UL 107 77 0.21 127 P3 TWO 17 F06

-0.74 TEC TER 13 HOT 620UL 107 83 0.19 0

P3 TWO 16 F07

-0.59 TEC TEE 5

ROT 620UL 0.31 0

P3 Two 22 706

+0.46 TEC TER LAR 5

NOT 6201.L 107 85 0.29 146 P5 TWO 11 F07

-1.50 TEC TEN LA.R 15 HOT 620U1 107 89 0.16 120 P3 TWO 7 F07

+0.76 TEC TER 19 HOT 620UL 108 82 0.17 140 P3 TWO 15 r07

+0.72 TEC TEE 13 HOT 620UL 0.20 144 P3 T7" 16 P06

-1.93 TEC TEE 13 ROT 620U0 108 84 0.13 0

P3 TWO 6 P06

-0.75 TEC TEN 6

SOT 620UL 0.21 0

P3 TWO 10 r07

+1.59 TEC TEE LAR 6

NOT 620UL 0.20 0

P3 TWo 10 706

+1.21 TEC TER LAR 6

HOT 620UL 108 86 0.31 117 P5 TWD 10 F05

-1.32 TEC TER 19 HOT 620UL 108 88 0.15 121 P3 TWo 7 r07

-1.82 TEC TER 19 NOT 62001 0.18 120 P3 TWO 8 F06

-0.82 TEC TEN 19 HOT 620WL 109 79 0.18 130 P3 TWO 0 F06

-0.80 TEC TEN 14 HOT 6200L 109 83 0.13 0

P3 TWO 7 P06

+0.45 TEC TEE 6

HOT 62071 109 89 0.18 133 P3 TWD 8 F0?

+0.76 TEC TEE 19 SOT 6203L 110 78 0.13 59 P3 TWO 12 F07

+0.74 TEC TEN 13 HOT 6201L 110 86 0.19 121 P3 TWO 9 F0?

+1.77 FEC TER 19 HOT 6207L 0.40 118 P3 TWO 16 F06

-0.76 TEC TEN 19 HOT 6207L 110 88 0.17 102 P3 TWO 8 F07

+1.86 TEC TER 19 HOT 6207L 110 90 0.16 140 P3 TWO 7 P07

-1.43 TEC TEN 19 HOT 62071L 110 92 0.16 128 P3 TWD 8 F06

-0.87 TEC TEE 39 ROT 6207L 111 79 0.14 127 ?3 TWD 13 F07

+1.78 TEC TEE LAR 13 ROT 62077.

0.16 140 P3 TWO 14 F06

-0.87 TEC TEE LAP 13 HOT 62037 111 85 0.17 122 P3 TWO 14 F07

+0.72 TEC TEN LAP 15 SOT 6203L I11 87 0.22 110 P3 TWO 10 F07

+0.69 TEC TER 19 HOT 6203L 111 89 0.64 129 P3 TWO 23 F07

+1.23 TEC TER LAR 19 HOT 62077L 112 78 0.12 123 P3 TWO 5 207

+0.74 TEC TEE 14 ROT 62077.

112 90 0.19 151 P5 TWO 6 F05

+1.17 TEC TER 19 HOT 62071L 113 83 0.17 0

P3 TWO 15 F06 40.42 TEC TEH 5

ROT 6203L 113 67 0.13 90 P3 TWO 6 P07

+0.76 TEC TEN 19 HOT 6203L 114 76 0.10 99 P3 TWO 4 706

-1.75 TEC TER 14 ROT 62071 114 80 0.15 100 P3 TwO 7 706

-1.89 TEC TER 14 NOT 62071L 114 92 0.08 90 P3 TWO 8 PO6

+1.71 TEC TEE 38 HOT 62071.

115 83 0.13 0

P3 TWD 12 P06

+0.48 TEC TEE 5

HOT 6200L 115 85 0.16 105 P3 TWO 13 Po7

+0.69 TEC TER LAR 15 HOT 620UL 115 87 0.18 98 P3 TWO 8 P07

+0.71 TEC TEE 19 ROT 620UL 116 84 0.12 0

P3 TWD 12 F07

+1.61 TEC TEE LAR 5

HOT 620UL 0.14 0

P3 TWO 13 F06

-0.78 TEC TFE LAR 5

HOT 620UL 116 86 0.17 113 P3 TWO 8 F07

+1.73 TEC TER 19 HOT 620UL

AREVX NP Inc 3/7/2008 2:18:

CuStomer NaMe: Calvert Cliffs Unit 1 Component: S/G FB Wear Indications (Sort by Row/Col)

QUERY:

FB Wear Indications by row.qry ROW COL VOLTS DEG CdN IWNO %TW LOCATION EXT EXT UTIL I

0.19 98 23 TWO 9 F06

-0.76 TEC TER 116 88 0.16 112 23 TWO 7 F06

-0.82 TEC TER 116 92 0.17 92 P3 TWO 10 F06

+1.77 TEC TEE 117 79 0.11 136 P3 TWO 5 F07

+1.78 TEC TEE 117 89 0.17 135 73 TWO 8 F07

+0.67 TLC TER 118 76 0.13 117 P3 TWD 6 F06

-1.84 TEC TER 120 80 0.19 138 P3 TWo 16 r07

-1.80 TEC TEE 120 84 0.15 0

P3 TWO 14 F06

-0.86 TEC TEE 121 85 0.26 114 P3 TWO 12 E06

-1.93 TEC TEE 121 87 0.12 121 P3 TWO 6 F07

+0.72 TEC TEE 123 87 0.10 153 P3 TWD 5 F07

+0.72 TEC TEE 128 80 0.20 137 P5 TWO 7 F06

-1.39 TEC TER

34 P4

12 Paqe 4 of 4 UTIL 2

CAL 0 LEG 19 HOT 19 HOT LAP.

18 HOT 14 NOT 19 HOT 14 HOT LAR 13 HOT 5

ROT 26 HOT 19 HOT 19 ROT 13 HOT 620U-,

620m 620OZ 620U1 6200L 620M.

62001 620V.

6200*

6200L 620U'.

620CU Total Tubes

144 Total Records: 172

9 AREV1 NP Inc Customer N~ame: Cal7ert Cliffs Unit I 3/712008 2:19:04 PM Component: S/G 12 Paqe 2 of 2 Lattice Support Wear Indications QUERY: TSP Wear Indications ROW COL VOLTS DEC CIO INO %TW 122 86 0.20 129 P3 Two 9 134 68 0.15 118 P3 TWO 14 LOCATION 07C

+1.07 02H

-1.53 EXT EXT UTIL 1

UTIL 2

CAL I LEG TEC TER LAR 19 ROT TEC TER LAR 1

ROT PROBEK 62OUL 62011L Total Tubes

2 Total Records: 2

hREvA tP Inc 3/7/2008 2:17:15 PM Customer Name: Calvert Cliffs Unit 1 Component: S/c 12 Page 2 of 2 NOI Indications QUERY: NQI Indications ROW COL VOLTS DEG C824 IND ITW LOCATION EXT EXT UTIL I

UTIL 2

CAL # LEG PROB-E 106 134 0.64 68 5 NQO:

TSH

+7.12 TEC TER LAP 2

HOT 620CIL Total Tubes

1 Total Records: 1

ARMV nP Inc 3/7/2008 2:19:55 PM Customer Name: Calvert Cliffs Unit 1 Component: S/G 12 Page 2 of 2 DFS/DFH indications QUERY: DFrHDYS Indications ROW COL VOLTS DFO C.HN flD %TW LOCATION EXT EXT UTIL 1

UTIL 2

CAL I LEG KOBE 22 46 0.34 99 5

DFS 03C

+14.47 TEC TEE LAR 45 HOT 620UL 60 74 0.26 152 5 DFS 05

+32.78 TEC TER LAR 13 HOT 620UL 79 139 0.30 153 5 DFH 0lC

+9.55 TEC TE.

LAR 41 HOT 620UL Total Tubes

3 Total Records: 3

AREVA NP Inc Customer Name: Calvert Cliffs Unit I 3/7/2008 2:19:33 PH Component: S/G 12 Page 2 of 2 WAR Indications QUERY: WAR Zndication3 ROW COL VOLTS DEG CHN IND 85 59 0.25 77 P5 WAR 87 75 0.18 111 P5 WAR 103 79 0.21 108 P5 WAR 0.21 108 P5 WAR 103 81 0.29 100 PS WAR 103 83 0.20 107 P5 WAR 103 91 0.21 100 P5 WAR 105 89 0.31 106 P5 WAR 106 134 0.14 71 P4 WAR 107 77 0.22 103 P5 WAR 107 83 0.19 103 P5 WAR 0.23 106 P5 WAR 108 82 0.19 119 P5 WAR 110 86 0.28 107 P5 WAR 111 89 0.39 102 P5 WAR 120 80 0.19 83 P5 WAR 122 86 0.14 85 PS WAR 134 88 0.18 82 P4 WAR 0.18 86 P4 WAR

%TW LOCATION EXT EXT UTIL 1

UTIL 2

F07

+1.46 F07 to7 22 r07

+1.83 r07 F07 17 F06

-0.79 F07 F06 19 r07

+1.80 P07 F06 19 r07

+1.87 F07 F07 24 FOG 40.49 F06 F06 18 F06

-1.75 r07 F03 19 F07

+0.98 r07 F07 25 TSH

+7.18 TSH 01R 10 F06

-0.71 T06 F06 20 F06

+0.21 r0o F06 18 F07

-0.50 r08 F06 20 F06

-1.80 F06 F06 18 F06

-0.87 F06 P06 24 F07

+1.01 r07 r07 29 F07

-1.83 P07 V07 18 07C

+1.08 07C 07C 14 02H

-1.54 01H 02H 13 02B

-1.55 01R 03H 12 CAL I LEG 34 HOT 34 HOT 34 HOT 34 HOT 34 HOT 34 HOT 34 HOT 34 HOT 37 HOT 34 BOT 34 HOT 34 HOT 34 HOT 34 HOT 34 HOT 34 HOT.

34 HOT 37 HOT 36 HOT PRO13E 56072 560??

560?P 5602P 560??

5602?

5607P 5602P 610?P 560?P 560?P 560?P 560?P 560?P 5607?

560?P 560?P 6107P 610?P Total Taube

16 Total Records: 19

AREVA NP Znc Customer Name: CalveOt Cliffs Unit 1 DNG Indications QUERY:

DNG IndLcations ROW COL VOLTS DEG CHN IND %TW LOCAT 18 164 5.48 186 P1 DNG t0.

38 86 1.00 185 PI ONG 05H 102 28 5.22 181 P1 DNG rlo 117 41 3.72 183 P1 DNG F09 2.16 183 P1 DNG F07 120 44 2.92 181 PI DXG F07 3/7/2008 2:16:27 PM Corponent: S/G 12 Page 2 of 2 ION EXT EXT UTIL 1

UTIL 2

CAL#

LEC 40.46 TEC TEE HR 4

ROT

+22.77 TEC TEE 47 HOT

-0.90 TEC TER 8

HOT

-1.18 TEC TEE 6

HOT

-1.29 TEC TER 6

HOT

-0.83 TEC TEE 8

HOT PR03E 620"L 62037 620UL 620UL 6201!L 6200L Total Tubes

5 Total Records: 6