ML092360407

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Spring 2009 - 180 Day Steam Generator Report - Engineering Information Record
ML092360407
Person / Time
Site: Calvert Cliffs Constellation icon.png
Issue date: 06/24/2009
From: Adrienne Brown, Fleck J, Waskey C
AREVA NP
To:
Office of Nuclear Reactor Regulation
References
20004-015, 51-9111710-000
Download: ML092360407 (26)
v • d • e


Text

20004-015 (09/30/2008)

AREVA AREVA NP Inc.,

an AREVA and Siemens company Engineering Information Record Document No: 51 - 9111710 - 000 Calvert Cliffs Unit 2, Spring 2009 - 180 Day Steam Generator Report Page 1 of 26

A 20004-0*15 (09/3012008)

AR.EVA Document No.: 51-9111710-000.

AREVA NP Inc.,

an AREVA and siemens company Calver Cliffs Unit 2, Spring 2009- 180 Day Steam Generator Report Safety Related? M YES F*]NO..

Does this document contain assumptio'ns reqquiring verifiictio?. EYES . NO Signature Block PageslSectlons Name and P..... RILRi PreparedlRekiewedl.

TitlelDiscipli"e signature AACRF Date Approved or Comments Chris DWaskey I7// / P All E n in,

.:.eer ....

Alan M-Brown' R ,.,/ l Principal En-gineer _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _

Jeff M Fleck -y Av All Manager ~ < c7iFld _ _ _ _ __ _ __ _

Tom Baummer Cutomerm All; Customer Concurrence Customer Review 61P/vcw" Rep.resentative. _.._*__

r..(....... u. ......r . * ;ri , .... * .... ..

Note: P/L designates Preparer (P), Lead Prepare r(LP)

RI LR d gnates

  • ,si Review.e.(R), L Reviewer,

,ead. LR)

A/A-CF designates Approver AApoe of~Customer Requested ForaACR Page. 2

A 20004-015 (09/30/2008)

AR EVA Document No.: 51-9111710-000 AREVA NP Inc.,

an AREVA and Siemens company Calvert Cliffs Unit 2, Spring 2009 - 180 Day Steam, Generator Report Record of Revision Revision Pages/Sections/

No. Date Paragraphs Changed Brief Description / Change Authorization 000 June 2009 All Original release

____ .1._____ 1 __________ .1.____________________

+ +/-

+ 4 +

4- I +

.4- 4 +

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Page 3

A

,AREVA Document No.: 51-9111710-000 AREVA NP Inc.,

an AREVA and Siemens company Calvert Cliffs Unit 2, Spring 2009 - 180 Day Steam Generator Report Table of Contents Page SIG NATURE BLOCK................................................................................................................... 2 RECO RD O F REVISIO N .......................................................................................................................... 3 LIST O F TABLES ..................................................................................................................................... 5 LIST O F FIGURES ................................................................................................................................... 6 CALVERT CLIFFS NUCLEAR POWER PLANT UNIT 2 - SPRING 2009 ......................................... 8 Page 4

A AREVA Document No.: 51-9111710-000 AREVA NP Inc.,

an AREVA and Siemens company Calvert Cliffs Unit 2, Spring 2009 - 180 Day Steam Generator Report List of Tables Page TABLE 1 NDE TECHNIQUES UTILIZED FOR IDENTIFIED DEGRADATION ................................. 14 TABLE 2 FO REIG N O BJECT WEAR ................... 7............................................................................. 18 TABLE 3 LIST O F TUBES PLUG G ED .............................................................................................. 19 TABLE 4 TUBE PLUGG ING SUM MARY ........................................................................................... 21 Page 5

AR EVA Document No.: 51-9111710-000 AREVA NP Inc.,

an AREVA and Siemens company Calvert Cliffs Unit 2, Spring 2009 - 180 Day Steam Generator Report List of Figures Page FIGURE 1 SG 21 SUSCEPTIBLE FAN BAR WEAR ZONE AND BOBBIN INSPECTION SCOPE ....... 10 FIGURE 2 SG 22 SUSCEPTIBLE FAN BAR WEAR ZONE AND BOBBIN INSPECTION SCOPE ....... 11 FIGURE 3 SG 21 ROTATING PROBE INSPECTION SCOPE ........................................................ 12 FIGURE 4 SG 22 ROTATING PROBE INSPECTION SCOPE .............................. 13 FIGURE 5 FAN BAR THROUGHWALL DEPTH DISTRIBUTION ...................................................... 16 FIGURE 6 SG21 FAN BAR WEAR CONDITION MONITORING ..................................................... 22 FIGURE 7 SG 22 FAN BAR WEAR CONDITION MONITORING ...................................................... 23 FIGURE 8 SG 21 FOREIGN OBJECT CONDITION MONITORING WITH PART NOT PRESENT ....... 24 FIGURE 9 SG 21 FOREIGN OBJECT CONDITION MONITORING WITH PART PRESENT ........... 25 FIGURE 10 SG 22 FOREIGN OBJECT CONDITION MONITORING WITH PART NOT PRESENT ..... 26 Page 6

A AREVA Document No.: 51-9111710-000 AREVA NP Inc.,

an AREVA and Siemens company Calvert Cliffs Unit 2, Spring 2009 - 180 Day Steam Generator Report CALVERT CLIFFS NUCLEAR POWER PLANT UNIT 2 180-DAY REPORT ON THE SPRING 2009 STEAM GENERATOR TUBE INSPECTION Page 7

A AREVA Document No.: 51-9111710-000 AREVA NP Inc.,

an AREVA and Siemens company Calvert Cliffs Unit 2, Spring 2009 - 180 Day Steam Generator Report CALVERT CLIFFS NUCLEAR POWER PLANT UNIT 2 - SPRING 2009 During the Calvert Cliffs Nuclear Power Plant (CCNPP) Unit 2, Spring 2009 refueling outage, both of the steam generators (i.e., SG21 and SG22) were inspected in accordance with CCNPP Technical Specification (TS) 5.5.9. The Spring 2009 outage (designated as 2R18) was the second in-service inspection of the steam generators and occurred after 5.67 effective full power years (EFPY). The first in-service inspection was performed during the Spring of 2005 after the first cycle of operation at 1.82 EFPY.

The discussion below summarizes the results of the inspection consistent with the 180-day reporting requirements of Technical Specification (TS) 5.6.9. Bold wording restates the TS requirement, followed immediately by the required CCNPP information.

A report shall be submitted within 180 days after the initial entry into Mode 4 following completion of an inspection performed in accordance with the Specification 5.5.9, Steam Generator (SG) Program.

Initial entry into Mode 4 occurred on March 13, 2009; therefore, this report is required to be submitted by September 9, 2009.

The report shall include:

a. The scope of inspections performed on each SG The following primary side inspections were performed in SG21 during the Spring 2009 refueling outage:

- Full length eddy current bobbin probe examination of 5262 tubes (-62%) including:

o All tubes within the pre-defined fan bar wear susceptible region (1948 tubes; see Figure 1) o All bundle periphery and no-tube lane locations approximately 5 to 10 tubes deep including:

0 Initial scope of 1138 tubes, and 0 Expanded scope of an additional 1026 tubes o Bounding of previously plugged tubes (5 tubes) o Random sample of 1145 tubes.(-21.3%) of the remaining uninspected population

- Rotating eddy current probe examinations of 1825 locations including (see Figure 3):

o All fan bar wear indications sized 15%TW or greater (19 locations in 18 tubes) o All bobbin I-Codes (22 locations in 22 tubes) n Bobbin I-Codes reported included NQI's (Non-Quantifiable Indications) and DTI's (Distorted Tubesheet Indications). These are bobbin signals indicative of possible degradation that are not attributable to fan bar wear.

o One bobbin PLP (Potential Loose Part) location o 288 locations to bound locations of foreign objects and/or foreign object wear, including foreign objects discovered during the visual secondary side exam o 732 peripheral tubes at the top of the hot leg tubesheet o 763 peripheral tubes at the top of the cold leg tubesheet.

- Visual inspection of all previously installed plugs Page 8

A AREVA Document No.: 51-9111710-000 AREVA NP Inc.,

an AREVA and Siemens company Calvert Cliffs Unit 2, Spring 2009 - 180 Day Steam Generator Report The following primary side inspections were performed in SG22 during the Spring 2009 refueling outage:

Full length eddy current bobbin probe examination of 4236 tubes (50%) including:

o All tubes within the pre-defined fan bar wear susceptible region (1987 tubes; see Figure 2) o All bundle periphery and no-tube lane locations 2 to 4 tubes deep (1115 tubes) o Bounding of previously plugged tubes (12 tubes) o Random sample of 1122 tubes (20.9%) of the remaining uninspected population Rotating eddy current probe examinations of 385 locations including (see Figure 4):

o All fan bar wear indications sized 15%TW or greater (36 locations in 33 tubes) o All bobbin I-Codes (3 locations in 3 tubes)

Bobbin I-Codes reported included NQI's (Non-Quantifiable Indications) and DTI's (Distorted Tubesheet Indications). These are bobbin signals indicative of possible degradation that are not attributable to fan bar wear.

o One bobbin PLP (Potential Loose Part) location o 37 tubes at the top of the cold leg tubesheet to bound tubes that were previously plugged due to a foreign object o 308 locations to bound locations of foreign objects and/or foreign object wear, including foreign objects discovered during the visual secondary side exam

- Visual inspection of all previously installed plugs The following secondary side inspections were performed in SG21:

- Secondary side visual inspection of the tubesheet regions including:

o Annulus and no-tube lane regions o Multiple inner bundle passes o Significant search and retrieval efforts for foreign objects o All objects that could be reasonably inspected visually

- Secondary side visual inspection of the I" (lowermost) lattice support The following secondary side inspections were performed in SG22

- Secondary side visual inspection of the tubesheet regions including:

o Annulus and no-tube lane regions (

o Multiple inner bundle passes o Significant search and retrieval efforts for foreign objects o All objects that could be reasonably inspected visually

- Secondary side visual inspection of the It (lowermost) lattice support

- Visual inspection of steam drum internal components

- Visual inspection of the u-bend region of the tube bundle Page 9

A Document No.: 51-9111710-000 AR EVA AREVA NP Inc.,

an AREVA and Siemens company Calvert Cliffs Unit 2, Spring 2009 - 180 Day Steam Generator Report 1" GROUP TUBES-HIDDEN Calvert Cliffs Unit 2 w 85.0 2R1 8 Fan Bar Wear oTouoo,.eZoto 1948 S/G.21 TOTAL TUBES: 8471 SCALE: 0.067388 X STue Ap21 19:52:15 2009 HOT SELECTED TUBES: 5262 ., -

PRIMARY FACE OUT OF SERVICE (#)" 37  : -= 4-,,.

NOZZLE 20~ go 00 4 2o 40 200 9 100 - ---

140 100 I4m 130 120 Ila- go1 10 0 30 20 10 MANWAY Figure 1 SG 21 Susceptible Fan Bar Wear Zone and Bobbin Inspection Scope Page 10

A Document No.: 51-9111710-000 AREVA AREVA NP Inc.,

an AREVA and Siemens company Calvert Cliffs Unit 2, Spring 2009 - 180 Day Steam Generator Report GROUP TUBES-HIDDEN Calvert Cliffs Unit 2 ,

2R18 Fan Bar Wear oThsledOotsieZcne 4236-,8 S" SCALE: 0.067"8 X.....

S/G 22 TOTAL TUBES: 8471 SCALE:1 0;7388X TugNr2129:27:462009 HOT SELECTED TUBES: 4236 PRIMARY FACE OUT OF SERVICE(#): 29 -

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"'MANWAY Figure 2 SG 22 Susceptible Fan Bar Wear Zone and Bobbin Inspection Scope Page 11

A AREVA Document No.: 51-9111710-000 AREVA NP Inc.,

an AREVA and Siemens company Calvert Cliffs Unit 2, Spring 2009 -180 Day Steam Generator Report GROUP TUBES Calvert Cliffs Unit 2 Outage SIG21 TOTAL TUBES: 8471 .SCALEý QOf64973X: .

HOT SELECTED TUBES: 1072 . ... T*e J*tn.23 6:86 321209*

PRIMARY FACE OUT OF SERVICE (#): NA NOZZLE-AID.-*-.---- . -

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MANAY Figure 3 SG 21 Rotating Probe Inspection Scope Page 12

A AR EVA Document No.: 51-9111710-000 AREVA NP Inc.,

an AREVA and Siemens company Calvert Cliffs Unit 2, Spring 2009 - 180 Day Steam Generator Report ROUP TUBE-S7 Calvert Cliffs, Unit.2 Outage.

S/G 22 TOTALTUBES: 8471 SCALE: 0.064973 X.

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Figure 4 SG 22 Rotating Probe Inspection Scope Page 13

A AR EVA Document No.: 51-9111710-000 AREVA NP Inc.,

an AREVA and Siemens company Calvert Cliffs Unit 2, Spring 2009 - 180 Day Steam Generator Report

b. Active degradation mechanisms found Two degradation mechanisms were identified during this examination and are evaluated herein: 1) fan bar wear, and 2) foreign object wear.

No evidence of corrosion degradation processes or lattice support wear was identified. There were also no tubes identified that were in close proximity to one another.

c. Nondestructive examination techniques utilized for each degradation mechanism The following table identifies NDE examination techniques utilized for each identified degradation mechanism.

For foreign object wear indications, ETSS 27901.1 was used for depth sizing if the object was not present. This technique is qualified for leaving indications in service. If the part was still present, ETSS 96910.1 was used for depth sizing. Since this is an extended technique for foreign object wear, this information was used for condition monitoring purposes only (i.e., all tubes with foreign object wear with the part still present were removed from service).

Table I NDE Techniques Utilized for Identified Degradation Degradation Mechanism Inspection Type EPRI ETSS Fan bar wear T Bobbin 96004.1 (Rev. 11)

+PointTM 96910.1 (Rev. 10)

Bobbin 27091.2 (Rev. 0)*

Foreign Object Wear +27901.1 (Rev. 0) **

Foreign__ObjectWear_+PointTM_ (circ groove)

+PointTM 96910.1 (Rev. 10)

  • The bobbin probe was the primary means of detecting foreign objects and foreign object wear during the inspection. This ETSS is qualified to detect foreign object wear (i.e. volumetric degradation) in the freespan in general; however detection of wear and foreign objects confined to a region very close to the top of the tubesheet is difficult. Bobbin detectability in this region was enhanced through the use of a three frequency "turbo mix" which has been shown in the field to provide improved detection in this region.
    • There are other EPRI techniques qualified for sizing of foreign object wear depending on the shape of the flaw.

ETSS 27901 was selected based on the circumferential groove appearance of the foreign object wear indications detected during the 2R1 8 inspection.

Page 14

A AREVA Document No.: 51-9111710-000 AREVA NP Inc.,

an AREVA and Siemens company Calvert Cliffs Unit 2, Spring 2009 - 180 Day Steam Generator Report

d. Location, orientation (if linear), and measured sizes (if available) of service induced indications Fan bar wear (FBW) is a mechanical degradation process which produces volumetric tube wear at the interface between the ubend anti-vibration supports (fan bars) and the tubes. In total, 330 fan bar wear (FBW) indications in 258 tubes were identified in the CCNPP Unit 2 steam generators during the 2R18 inspection. 131 of the indications were newly reported during 2RI 8. This represents an increase of about 66% since the first inservice inspection in 2005 (2R16). None of the reported indications exceeded the Technical Specification plugging limit of 40%TW, and none were plugged. The maximum depth reported was a 28%TW indication in SG22. The largest newly-reported indication was a 19%TW indication in SG21. Figure 5 shows the distribution of the fan bar wear depths for both steam generators as reported with the bobbin coil. As shown in the figure, SG22 contained more indications and also contained the majority of the indications greater than 20%TW.

As expected, the growth rates for the fan bar wear indications decreased, significantly from the growth rates observed during the first cycle of operation. The median growth rate of FBW reported during both the 2009 and 2005 inspections was 0.31 %TW/EFPY in both SGs compared to median growth rates during the first cycle of 7.48 %TW/EFPY in SG21 and 6.71 %TW/EFPY in SG22. The upper 95t' percentile growth rates were also determined using Benard's equation as discussed in the EPRI SG Integrity Guidelines. The upper 95w' percentile growth rate for indications reported during both the 2009 and 2005 inspections was 2.34 %TW/EFPY in SG21 and 2.08 %TW/EFPY in SG22. The upper 95th percentile growth rates during the first cycle of operiation were 12.39 %TW/EFPY in SG21 and 13.42 %TW/EFPY in SG22.

Based on the Unit 1, 2008 inspection results, an increased number of fan bar wear indications was expected. The decrease in the number of new indications and the slower growth rate compared with the Unit 2, 2005 results show that the degradation mechanism is not becoming more severe with time.

Fan bar wear is caused by the relative motion between the tubes and adjacent fan bars due to flow related forces.

As wear depths increase, the contact area between the tubes and fan bars increases, which slows the rate of throughwall growth. As a result, the growth rate of previously detected indications is expected to decrease with more time in service. The Unit 2, 2R18 inspection found fewer new indications and a lower growth rate than what was found after the first in-service inspection. This is consistent with the current understanding of fan bar wear.

Page 15

A AREVA Document No.: 51-9111710-000 AREVA NP Inc.,

an AREVA and Siemens company Calvert Cliffs Unit 2, Spring 2009 - 180 Day Steam Generator Report 80 70 60

  • 50

.2_

40 0

- 30 z

20 10 0

<2 4 6 8 10 12 14 16 18 20 22 24 26 28 30 >30 Measured Wear Depth (%TW)

Figure 5 Fan Bar Throughwall Depth Distribution Page 16

A&

AREVA Document No.: 51-9111710-000 AREVA NP Inc.,

an AREVA and Siemens company Calvert Cliffs Unit 2, Spring 2009 - 180 Day Steam Generator Report During the 2R18 inspection, 32 indications of foreign object wear were detected in 28 tubes with the +PointTM coil. These indications were reported as LPW (Loose Part Wear) indications in the eddy current database. Most of these indications were located within the first three inches above the top of the tubesheet. However, six indications were reported to be clearly in the freespan region between the tubesheet and the first lattice grid support. In addition, one indication was reported at about four inches below the fifth lattice grid support.

Table 2 is a summary of all of the foreign object wear identified during the 2009 inspection. As shown in the table, some locations had foreign objects detected by eddy current while other locations had no signs of foreign objects. In some cases where foreign objects were detected, the objects were successfully removed from the steam generator. In these cases, the lengths and depths shown are those reported after removal of the part using ETSS 27901.1.

Six of the 32 LPW indications were related to locations of previously known wear. All six of these locations were in SG22. The remaining 26 LPW indications were newly identified during the 2009 inspection.

In SG22, there were seven indications of loose part wear detected. Six of these seven indications were related to previously detected loose part wear. The one exception was an indication in SG22 RI 12 C82 located at an elevation of 05H -4.02". This indication had a measured depth of 23%TW. In all seven cases, the foreign object was not detected by eddy current. This is consistent with the results from the 2005 inspection in SG22.

In addition to loose part wear indications, there were a large number of Possible Loose Part (PLP) indications, which were inspected with the rotating probe coil. Secondary side visual inspections were also performed of all reasonably accessible PLP locations. In total, 75 foreign objects were detected by the eddy current and visual inspections: 47 in SG 21 and 28 in SG 22. All loose parts that were left in service, whether or not they had caused wear, were addressed in an engineering evaluation to ensure that tube integrity will be maintained until the next inspection.

Page 17

A AREVA Document No.: 51-9111710-000 AREVA NP Inc.,

an AREVA and Siemens company Calvert Cliffs Unit 2, Spring 2009 - 180 Day Steam Generator Report Table 2 Foreign Object Wear Measured or Eddy Current Bounding Loose Part SG Row Col Ind %TW S Elevation Technitue Length Detected SG21 10 2 LPW 45 TSC 0.06 27901.1 0.23 No SG21 11 1 LPW 34 TSC 1.35 27901.1 0.46 Yes (Removed)

SG21 11 161 LPW 54 TSH 0.16 27901.1 0.39 Yes (Removed)

SG21 12 2 LPW 48 TSC 0.31 27901.1 0.46 Yes (Removed)

SG21 12 2 LPW 37 TSC 1.27 27901.1 0.23 Yes (Removed)

SG21 12 2 LPW 21 TSC 1.77 27901.1 0.32 Yes (Removed)

SG21 12 162 LPW 24 TSH 0.13 27901.1 0.21 Yes (Removed)

SG21 13 161 LPW 47 TSH 0.16 27901.1 0.47 Yes (Removed)

SG21 18 4 LPW 5 TSC 0.12 96910.1 1.5 Yes (Removed)

SG21 37 5 LPW 21 TSH 0.47 27901.1 0.23 No SG21 38 6 LPW 30 TSH 0.54 96910.1 0.31 Yes SG21 39 5 LPW 6 TSH 0.36 96910.1 0.18 Yes SG21 72 146 LPW 32 TSH 0.24 ,27901.1 0.22 Yes (Removed)

SG21 75 147 LPW 19 TSH 18.07 27901.1 1.5 No SG21 77 147 LPW 21 TSH 18.01 27901.1 1.5 No SG21 77 149 LPW 21 TSH 21.44 27901.1 0.21 No SG21 90 26 LPW 11 TSH 0.25 96910.1 1.5 Yes SG21 91 27 LPW 16 TSH 0.45 96910.1 1.5 Yes SG21 93 27 LPW 13 TSH 0.14 96910.1 1.5 Yes SG21 131 95 LPW 5 TSC 0.13 96910.1 0.19 Yes SG21 131 97 LPW 5 TSC 0.18 96910.1 0.21 Yes SG21 134 74 LPW 5 TSH 0.38 96910.1 0.16 Yes SG21 135 75 LPW 4 TSH 0.12 96910.1 0.11 Yes SG21 135 75 LPW 2 TSH 0.44 96910.1 0.13 Yes SG21 136 74 LPW 4 TSH 0.9 96910.1 0.22 Yes SG22 14 4 LPW 24 TSC 0.49 27901.1 0.18 No SG22 17 1 LPW 25 TSC 0 27901.1 0.15 No SG22 18 2 LPW 24 TSC -0.13 27901.1 0.21 No SG22 112 82 LPW 23 05H -4.02 27901.1 0.41 No SG22 124 116 LPW 17 01C -11.55 27901.1 0.24 No SG22 126 116 LPW 37 TSC 13.02 27901.1 0.36 No SG22 126 116 LPW 23 TSC 12.73 27901.1 0.24 No Page 18

A AREVA Document No.: 51-9111710-000 AREVA NP Inc.,

an AREVA and Siemens company, Calvert Cliffs Unit 2, Spring 2009 - 180 Day Steam Generator Report

e. Number of tubes plugged during the inspection outage for each active degradation mechanism Thirty-four tubes in SG21 were plugged during 2R1 8 (see Table 3). All of the tubes were plugged due to foreign objects or foreign object wear. All tubes that had wear and a foreign object present were plugged. Several tubes with a part present but no wear were also conservatively plugged. The tubes labeled as PTP (Preventative Tube Plug) were plugged to bound locations of foreign objects remaining in the steam generator. There were no tubes in SG22 that were plugged during the 2009 refueling outage.

Table 3 List of Tubes Plugged SG Row Col Hot Leg Cold Leg Reason for Tube Repair Tube Stab Qty.

SG21 11 1 ROLLED ROLLED LPW @ TSC+1.35 1 NO SG21 10 2 ROLLED ROLLED LPW @ TSC+0.06 2 NO SG21 12 2 ROLLED ROLLED LPW @ TSC+0.31 3 NO SG21 15 3 ROLLED ROLLSTAB PTP 4 YES SG21 17 3 ROLLED ROLLSTAB PLP @ TSC+0.47 5 YES SG21 19 3 ROLLED ROLLSTAB PLP @ TSC+0.38 6 YES PLP @ TSC+0.47 SG21 14 4 ROLLED ROLLSTAB 7 YES PLP @ TSC+0.46 SG21 16 4 ROLLED ROLLSTAB PLP @ TSC+0.53 8 YES SG21 18 4 ROLLED ROLLSTAB LPW @ TSC+0.12 9 YES SG21 20 4 ROLLED ROLLSTAB PLP @ TSC+0.47 10 YES SG21 15 5 ROLLED ROLLSTAB PTP 11 YES SG21 19 5 ROLLED ROLLSTAB PLP @ TSC+0.65 12 YES SG21 37 5 ROLLSTAB ROLLED LPW @ TSH+0.47 13 YES SG21 39 5 ROLLSTAB ROLLED LPW @ TSH+0.36 14 YES SG21 38 6 ROLLSTAB ROLLED LPW @ TSH+0.54 15 YES SG21 40 6 ROLLSTAB ROLLED PLP @ TSH+0.72 16 YES SG21 90 26 ROLLSTAB ROLLED LPW @ TSH+0.25 17 YES SG21 92 26 ROLLSTAB ROLLED PLP @ TSH+0.53 18 YES Page 19

A AREVA Document No.: 51-9111710-000 AREVA NP Inc.,

an AREVA and Siemens company Calvert Cliffs Unit 2, Spring 2009 - 180 Day Steam Generator Report Table 3 List of Tubes Plugged SG Row Col Hot Leg Cold Leg Reason for Tube Repair Tube Stab Qty.

SG21 91 27 ROLLSTAB ROLLED LPW @ TSH+0.45 19 YES SG21 93 .27 ROLLSTAB ROLLED LPW @ TSH+0.14 20 YES SG21 134 74 ROLLSTAB ROLLED LPW @ TSH+0.38 21 YES SG21 136 74 ROLLSTAB ROLLED LPW @ TSH+0.90 22 YES SG21 131 75 ROLLSTAB ROLLED PLP @ TSH+0.57 23 YES SG21 133 75 ROLLSTAB ROLLED PLP @ TSH+0.42 24 YES LPW @ TSH+0.12 SG21 135 75 ROLLSTAB ROLLED 25 YES LPW @ TSH+0.44 SG21 132 76 ROLLSTAB ROLLED PLP @ TSH+0.64 26 YES SG21 135 89 ROLLED ROLLSTAB PLP @ TSC+0.15 27 YES SG21 134 90 ROLLED ROLLSTAB PLP @ TSC+0.11 28 YES SG21 131 95 ROLLED ROLLSTAB LPW @ TSC+0.13 29 YES SG21 133 95 ROLLED ROLLSTAB PLP @ TSC+0.54 30 YES SG21 132 96 ROLLED ROLLSTAB PLP @ TSC+0.44 31 YES SG21 131 97 ROLLED ROLLSTAB LPW @ TSC+0.18 32 YES SG21 11 161 ROLLED ROLLED LPW @ TSH+0.16 33 NO SG21 13 161 ROLLED ROLLED LPW @ TSH+0.16 34 NO Totals: 34 29 LPW = Loose Part Wear; PLP = Potential Loose Part; PTP = Preventative Tube Plug Page 20

A ARIEVA Document No.: 51-9111710-000 AREVA NP Inc.,

an AREVA and Siemens company Calvert Cliffs Unit 2, Spring 2009 - 180 Day Steam Generator Report

f. Total number and percentage of tubes plugged to date There are 37 tubes plugged in SG21, 34 of which were plugged during the Spring 2009 outage. There are 29 tubes plugged to date in SG22, none of which were plugged during the Spring 2009 outage.

Table 4 Tube Plugging Summary Tubes Installed Tubes Plugged To-Date SG21 . 8,471 37 (0.437%)

SG22 8,471 29 (0.342%)

Total 16,942 66 (0.390%)

g. The results of condition monitoring, including the results of tube pulls and in-situ testing The condition monitoring assessment is summarized in Figures 4 through 8. The figures provide the condition monitoring limit curves corresponding to the NDE technique employed for each degradation type. All reported degradation falls below the applicable condition monitoring curve and therefore satisfies the Technical Specification structural performance criteria. For volumetric indications, meeting the structural performance criteria also provides reasonable assurance that the accident leakage performance criteria would be satisfied at the lower steam line break pressure differential. Since this conclusion could be reached analytically using NDE inspection results with a full accounting of significant uncertainties, no in-situ pressure testing was required to demonstrate structural and leakage integrity. During the past operating cycle, no measurable primary-to-secondary leakage was observed, thereby satisfying the operational leakage performance criteria.

The results of the 2009 inspection and the condition monitoring conclusions confirm that the 2005 operational assessment was appropriately bounding. No tubes were removed from the SG for destructive examination.

h. The effective plugging percentage for all plugging in each SG There are no sleeves installed in the CCNPP Unit 2 steam generators, therefore the effective plugging percentage is the same as stated in (f) above.

Page 21

A AREVA Document No.: 51-9111710-000 AREVA NP Inc.,

an AREVA and Siemens company Calvert Cliffs Unit 2, Spring 2009 - 180 Day Steam Generator Report 100

. ...... CMM.LLimit mi.-.T - ETSS S S 96004.1 96 04.

90

- -- 95/50 Repair Limit (2 Cycle Operation) 80 ................. .Wear

..... ......... Depth - Assumed Bounding Length

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Figure 6 SG21 Fan Bar Wear Condition Monitoring Page 22

A AREVA Document No.: 51-9111710-000 AREVA NP Inc.,

an AREVA and Siemens company Calvert Cliffs Unit 2, Spring 2009 - 180 Day Steam Generator Report 100

- - - CM Limit - ETSS 96004.1 90

-95/50 Repair Limit (2 Cycle Operation)

Wear Depth - Assumed Bounding Length 80

£ Wear Depth - Measured Length 70 60

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Figure 7 SG 22 Fan Bar Wear Condition Monitoring Page 23

A Document No.: 51-9111710-000 AREVA AREVA NP Inc.,

an AREVA and Siemens company Calvert Cliffs Unit 2, Spring 2009 - 180 Day Steam Generator Report 100

- - - CM Limit - ETSS 27901.1 90

  • Wear Depth - Assumed Bounding Length 80
  • Wear Depth - Measured Length 70 - E ,,i 60 0) 0 50 A

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0) A 30 -

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  • AA A 20 10 0 4-i-r-i 0.0 0.1 0.2 0.3 0.4 0.5 0.6 0.7 0.8 0.9 1.0 1.1 1.2 1.3 1.4 1.5 1.6 1.7 1.8 1.9 2.0 Axial Length (in)

Figure 8 SG 21 Foreign Object Condition Monitoring with Part not Present Page 24

A AR EVA Document No.: 51-9111710-000 AREVA NP Inc.,

an AREVA and Siemens company Calvert Cliffs Unit 2, Spring 2009 - 180 Day Steam Generator Report 100

- - - CM Limit - ETSS 96910.1 90

  • Wear Depth - Assumed Bounding Length 80 A Wear Depth - Measured Length 70 60 0

50 ..

V 40 U) a)

30 20 10 iA A a

0 .

0.C0 0.1 0.2 0.3 0.4 0.5 0.6 0.7 0.8 0.9 1.0 1.1 1.2 1.3 1.4 1.5 1.6 1.7 1.8 1.9 2.0 Axial Length (in)

Figure 9 SG 21 Foreign Object Condition Monitoring with Part Present Page 25

4 A

AREVA Document No.: 51-9111710-000 AREVA NP Inc.,

an AREVA and Siemens company Calvert Cliffs Unit 2, Spring 2009 - 180 Day Steam Generator Report 100

- - - CM Limit- ETSS 27901.1 90

< Wear Depth - Assumed Bounding Length 80

, Wear Depth - Measured Length 70

-c 60 ....................

~1) 0 50 V

a) 40 A

U, a) 30 A

20

,10 0

0.0 0.1 0.2 0.3 0.4 0.5 0.6 0.7 0.8 0.9 1.0 1.1 1.2 1.3 1.4 1.5 1.6 1.7 1.8 1.9 2.0 Axial Length (in)

Figure 10 SG 22 Foreign Object Condition Monitoring with Part not Present Page 26

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