Text

Proposed Emergency License Amendment Request, Modified Interim Alternate Repair Criteria for Unit 1 B Steam Generator Tube Repair
	ML091270444
Person / Time
Site:	Surry
Issue date:	05/05/2009
From:	Price J; Virginia Electric & Power Co (VEPCO)
To:	; Document Control Desk, Office of Nuclear Reactor Regulation
References
	09-295
	Download: ML091270444 (109)
	v • d • e

VIRGINIA ELECTRIC AND POWER COMPANY RICHMOND, VIRGINIA 23261 10 CFR 50.90 May 5, 2009 U.S. Nuclear Regulatory Commission Serial No.09-295 Attention: Document Control Desk SPS LIC/CGL RD Washington, D.C. 20555 Docket No.

50-280 License No.

DPR-32 VIRGINIA ELECTRIC AND POWER COMPANY (DOMINION)

SURRY POWER STATION UNIT I PROPOSED EMERGENCY LICENSE AMENDMENT REQUEST MODIFIED INTERIM ALTERNATE REPAIR CRITERIA FOR UNIT I B STEAM GENERATOR TUBE REPAIR Pursuant to 10 CFR 50.90 and 10 CFR 50.91(a)(5), Dominion requests an emergency amendment of the Facility Operating License, in the form of a change to the Technical Specifications (TS) to Facility Operating License Number DPR-32 for Surry Power Station Unit 1. This proposed License Amendment Request (LAR) modifies the Unit 1 interim alternate repair criteria (IARC) in TS 6.4.Q, "Steam Generator (SG) Program," and TS 6.6.3, "Steam Generator Tube Inspection Report." The proposed emergency LAR incorporates a modified IARC for the Unit I B SG tube repair criteria during the Unit 1 Refueling Outage 22 and the subsequent operating cycle and revises the reporting requirements for the Unit 1 B SG. Specifically, this change requests approval of a modified IARC that does not require plugging of Unit 1 B SG tubes with permeability variation indications that may mask flaws in the bottom one inch of the tubesheet. As a conservatism, the proposed change includes a commitment to use a 4.7 leakage factor (accident induced leak rate to operational leak rate) throughout the period of application of the change. In addition, the primary to secondary leakage in TS 3.1.C. 1.d and TS 4.13.B is limited to 20 gallons per day (gpd) for the Unit 1 B SG for the Unit 1 Operating Cycle 23. Associated revisions to the Bases for TS 3.1.C and TS 4.13 are included for the NRC's information.

A discussion of the proposed LAR and the basis for the emergency submittal are provided in Attachment 1. The marked-up and proposed TS pages are provided in Attachments 2 and 3, respectively.

We have evaluated the proposed LAR and have determined that it does not involve a significant hazards consideration as defined in 10 CFR 50.92. The basis for that determination is provided in Attachment 1. We have also determined that operation with the proposed change will not result in any significant increase in the amount of effluents that may be released offsite and no significant increase in individual or cumulative occupational radiation exposure.

Therefore, the proposed amendment is eligible for categorical exclusion as set forth in 10 CFR 51.22(c)(9).

Pursuant to 10 CFR 51.22(b), no environmental impact'statement or environmental assessment is needed in connection with the approval of the proposed change. The basis for that determination is also provided in.

To avoid an unnecessary delay in plant restart following the ongoing Surry Unit I refueling outage, Dominion requests that the proposed emergency LAR be reviewed and approved

Serial No.09-295 Docket No. 50-280 Page 2 of 3 by 1730 hours0.02 days 0.481 hours 0.00286 weeks 6.58265e-4 months on May 7, 2009.

As requested by the NRC during a conference call on May 4, 2009, supplemental information regarding tube slippage/pullout and estimated H* values for the Model 51 F steam generator will be transmitted by separate correspondence.

If you have any further questions or require additional information, please contact Mr. Gary D. Miller at (804) 273-2771.

Sincerely, J.

Price V QPresident - Nuclear Engineering Attachments:

1. Discussion of Change

2. Marked-up Technical Specifications Pages'

3. Proposed Technical Specifications Pages

4. Westinghouse Letter LTR-SGMP-09-63 dated May 4, 2009

5. Summary of Unit 1 SG Linear Indications, Tube Maps of Permeability Variation Indications, and Summary of Permeability Variation Indications Commitments made in this letter:

1. As a conservatism, the proposed change includes a commitment to use a 4.7 leakage factor throughout the period of application of the proposed change.

COMMONWEALTH OF VIRGINIA

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COUNTY OF HENRICO

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The foregoing document was acknowledged before me, in and for the County and Commonwealth aforesaid, today by J. Alan Price, who is Vice President - Nuclear Engineering, of Virginia Electric and Power Company. He has affirmed before me that he is duly authorized to execute and file the foregoing document In behalf of that Company, and that the statements in the document are true to the best of his knowledge and belief.

Acknowledged before me this _

day of (

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2009.

My Commission Expires:

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Notary Public VIC101 L. MULL I

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Commonwealth oW vi*ginia I

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My Commislmon Expires May 31. 2010

Serial No.09-295 Docket No. 50-280 Page 3 of 3 cc:

U.S. Nuclear Regulatory Commission Region II Sam Nunn Atlanta Federal Center 61 Forsyth Street, SW Suite 23T85 Atlanta, Georgia 30303 NRC Senior Resident Inspector, Surry Power Station State Health Commissioner Virginia Department of Health James Madison Building - 7th Floor 109 Governor Street Room 730 Richmond, Virginia 23219 Mr. J. F. Stang, Jr.

NRC Project Manager U. S. Nuclear Regulatory Commission One White Flint North Mail Stop 8G9A 11555 Rockville Pike Rockville, Maryland 20852 Ms. D. N. Wright NRC Project Manager U. S. Nuclear Regulatory Commission One White Flint North Mail Stop 8H4A 11555 Rockville Pike Rockville, Maryland 20852 Ms. K. R. Cotton NRC Project Manager U. S. Nuclear Regulatory Commission One White Flint North Mail Stop 16E15 11555 Rockville Pike Rockville, Maryland 20852

Serial No.09-295 Docket No. 50-280 ATTACHMENT 1 Discussion of Change Virginia Electric and Power Company (Dominion)

Surry Power Station Unit I

Serial No.09-295 Docket No. 50-280 DISCUSSION OF CHANGE 1.0

SUMMARY

DESCRIPTION Pursuant to 10CFR50.90 and 10CFR50.91(a)(5), Virginia Electric and Power Company (Dominion) hereby requests an emergency amendment in the form of changes to the Technical Specifications (TS) to Facility Operating License Number DPR-32 for Surry Power Station Unit 1. This proposed License Amendment Request (LAR) modifies the Unit 1 interim alternate repair criteria (IARC) in TS 6.4.Q, "Steam Generator (SG)

Program," and TS 6.6.3, "Steam Generator Tube. Inspection Report." The proposed emergency LAR incorporates a modified iARC for the Unit I B SG tube repair criteria during the Unit 1 Refueling Outage 22 and the subsequent operating cycle and revises the reporting requirements for the Unit 1 B SG.

Specifically, this change requests approval of a modified IARC that does not require plugging of Unit 1 B SG tubes with permeability variation indications that may mask flaws in the bottom one inch of the tubesheet. As a conservatism, the proposed change includes a commitment to use a 4.7 leakage factor (accident induced leak rate to operational leak rate) throughout the period of application of the change. In addition, the primary to secondary leakage in TS 3.1.C.l.d and TS 4.13.B is limited to 20 gallons per day (gpd) for the Unit I B SG for the Unit 1 Operating Cycle 23. Associated revisions to the Bases for TS 3.1.C and TS 4.13 are included for the NRC's information.

Dominion requests that the proposed change be processed as an emergency LAR to prevent delay in either resumption of operation or of increase in power output up to the plant's licensed power level of Surry Unit 1. A discussion of the proposed TS change and the basis for the emergency LAR are provided in Attachment 1. The marked-up and proposed TS pages are provided in Attachments 2 and 3, respectively.

2.0 DETAILED DESCRIPTION OF CHANGE The following specific changes to the Surry TS are proposed:

TS 3.1.C.- RCS Operational Leakage TS 3.1.C.1.d is being revised to limit the RCS primary to secondary leakage for the Unit 1 B steam generator to 20 gallons per day during the Operating Cycle 23:

d. 150 gallons per day primary to secondary LEAKAGE through any one steam generator (SG), with the following exception.

The primary to secondary LEAKAGE for the Unit 1 B steam generator will be limited to 20 gallons per day during Operating Cycle 23 TS Bases 3.1 - RCS Operational Leakage TS Bases 3.1, Applicable Safety Analysis and Limiting Condition for Operation, section d, Primary to Secondary LEAKAGE through Any One SG, is being revised to add a Page 1 of 16

Serial No.09-295 Docket No. 50-280 discussion on the basis for limiting the primary to secondary leak rate to 20 gallons per day for Operating Cycle 23 on Unit I B steam generator. The following sentence will be added:

Due to the permeability variation indications in the Unit 1 B steam generator found during Refueling Outage 22, the primary to secondary leak rate for that steam generator is limited to 20 gallons per day for Operating Cycle 23.

TS 4.13 - RCS Operational Leakage TS 4.13.B is being revised to limit the RCS primary to secondary leakage for the Unit 1 B steam generator to 20 gallons per day during the Operating Cycle 23:

B. Verify primary to secondary LEAKAGE is < 150 gallons per day through any one SG once every 72 hour8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months s1, with the following exception.

The primary to secondary LEAKAGE for the Unit 1 B steam generator will be verified to be < 20 gallons per day during Operating Cycle 23.

TS Bases Surveillance Requirements 4.13.B TS Bases 4.13.B is being revised to discuss the 20 gallons per day primary to secondary leak rate limit on Unit 1 B steam generator for Operating Cycle 23. The first sentence of the paragraph will be revised as follows:

This SR verifies that the primary to secondary LEAKAGE is less that or equal to 150 gallons per day through any one SG, with the following exception. The primary to secondary LEAKAGE for the Unit 1 B steam generator will be limited to 20 gallons per day during Operating Cycle 23.

TS Bases 4.13.B is also being revised to indicate that if the leakage rate cannot be assigned to an individual generator, then all the leakage should be conservatively assigned to one SG:

If it is not practical to assign the LEAKAGE to an individual SG, all the primary to secondary LEAKAGE should be conservatively assumed to be from one SG; for Unit 1 that leakage should be assumed to be through the B steam generator for Operating Cycle 23.

Associated revisions to the Bases for TS 3.1.C and TS 4.13 are included for the NRC's information.

TS 6.4.Q - Steam Generator (SG) Proaram TS 6.4.Q.3 is being revised to add TS 6.4.Q.3.c:

Page 2 of 16

II Serial No.09-295 Docket No. 50-280

c. For Unit 1 Refueling Outage 22 and the subsequent operating cycle, tubes in the B steam generator with permeability variation indications that may mask flaws in the bottom one inch of the tubesheet do not require plugging.

TS 6.6.A.3-Steam Generator Tube Inspection Report TS 6.6.A.3 is being revised to add TS 6.6.A.3.o:

o. Following completion of a Unit 1 inspection performed in Refueling Outage 22 (and any other inspections performed in the subsequent operating cycle), for the B steam generator, the number of permeability variation indications including location and total circumferential extent.

Consistent with the addition of TS 6.6.A:3.o, the word "and" is being deleted from the end of TS 6.6.A.3.m and being added to the end of TS 6.6.A.3.n.

3.0 MODIFIED INTERIM ALTERNATE REPAIR CRITERIA BACKGROUND AND INSPECTION RESULTS

3.1 Background

In a letter dated October 14, 2008 (Serial No. 08-0521) [Reference 1], Dominion requested a license amendment for Surry Unit 1 to incorporate an IARC into the provisions for SG tube repair for use during the Surry Unit I Refueling Outage 22 and the subsequent operating cycle.

A February 20, 2009 letter (Serial No.09-071) provided the response to an NRC request for additional information, including a commitment to use the 2.5 leakage factor [Reference 2].

The Unit 1 IARC was approved by the NRC on April 8, 2009 by TS Amendment 263/-- [Reference 3].

This proposed LAR modifies the Unit 1 IARC incorporated into TS 6.4.Q, "Steam Generator (SG) Program," and TS 6.6.3, "Steam Generator Tube Inspection Report," by TS Amendment 263/-. The proposed LAR incorporates a modified IARC for the Unit 1 B SG tube repair criteria during the Unit 1 Refueling Outage 22 and the subsequent operating cycle and revises the reporting requirements for the Unit 1 B SG.

The proposed change requests approval of a modified IARC that does not require plugging of Unit I B SG tubes with permeability variation indications that may mask flaws in the bottom one inch of the tubesheet. Tubes with flaws detected in the bottom one inch that exceed 94 degrees in circumferential extent will be plugged in accordance with current TS. The proposed LAR is required to preclude unnecessary SG tube plugging due to the permeability variation indications that potentially mask flaws while still maintaining tube structural and leakage, integrity. As a conservatism, a commitment is being made to use a 4.7 leakage factor (accident induced leak rate to operational leak rate) throughout the period of application of the change.

In addition, the primary to secondary leakage in TS 3.1.C.1.d and TS 4.13.B is limited to 20 gallons per day (gpd) for the Unit I B SG for the Unit 1 Operating Cycle 23.

Page 3 of 16

Serial No.09-295 Docket No. 50-280 Attachment I 3.2 Unit I Inspection Results SG tube inspection results.from the Unit 1 Refueling Outage 21 (Fall 2007) and Unit I Refueling Outage 22 (Spring 2009) are discussed in the Structural Integrity Discussion in Section 4.0.

A summary of Unit 1 A, B, and C SG linear indications, tube maps of Unit 1 B SG permeability variation indications, and a summary of the Unit I B SG permeability variation indications from the Unit I Refueling Outage 22 are provided in Attachment'5.

Including tubes plugged during the Unit 1 Refueling Outage 22, the current tube plugging status is as follows:

" A SG: 38 tubes plugged B SG: 22 tubes plugged

" C SG: 26 tubes plugged 3.3 Unit 2 Inspection Results The Unit 2 SGs are similar to the Unit 1 SGs in terms of materials of construction, manufacture, and operating history.

Eddy current testing (ECT) data from diagnostic exams conducted in all three SGs during the Unit 2 Spring 2008 Refueling Outage 21 did not identify any flaws in the portion of the tubes within the upper 20 inches of the tubesheet. Fifty percent of the overexpansion (OXP) locations within the tubesheet on the hot leg side along with a sample of the larger OXPs on the cold leg side in B SG and C SG were inspected.

Additionally, a 20% plus point sample of the top of tubesheet from +3 inches to the tube end, 100% plus point of all expansions that extend above the top of the tubesheet, and 100% of the tube end locations in all three SGs were inspected.

The B SG was inspected during the 2006 Refueling Outage 20. During this exam a 21% sample of the hot leg OXPs were inspected within the tubesheet, and 2067 tubes (62%) top of tubesheets were inspected with a plus point examination.

4.0 TECHNICAL EVALUATION

TS 6.4.Q requires that a SG' program be established and implemented to ensure that SG tube integrity is maintained. SG tube integrity is maintained by meeting specified performance criteria (in TS 6.4.Q) for structural and leakage integrity consistent with the plant design and licensing bases. TS 6.4.Q requires a condition monitoring assessment be performed during each outage in which the SG tubes are inspected to confirm that the performance criteria are being met. TS 6.4.Q also includes provisions regarding the scope, frequency, and methods of SG tube inspections., Of relevance to the LAR, these provisions require that the number and portions of tubes inspected and methods of inspection be performed with the objective of detecting flaws of any type that may be Page 4 of 16

Serial No.09-295 Docket No. 50-280 present along the length of a tube, from the tube-to-tubesheet weld at the tube inlet to the tube-to-tubesheet weld at the tube outlet, and that may satisfy the applicable tube repair criteria. The applicable tube repair criterion, specified.in TS 6.4.Q.3, is that tubes found by an inservice inspection to contain flaws with a depth equal to or exceeding 40 percent of the nominal tube wall thickness shall be plugged.

Reference 5 provided the technical justification for an IARC that required full-length inspection of the tubes within the tubesheet but did not require plugging tubes if the extent of any circumferential cracking observed in the region greater than 17 inches below the top of the tubesheet (TTS) was less than a value sufficient to permit the remaining circumferential ligament to transmit the limiting axial loads [the greater of 3 times the normal operating (NOP) loads or 1.4 times the steam line break (SLB) end cap loads]. Axial cracks below 17 inches from the TTS are not relevant to the tube pullout arguments because axial cracks do not degrade the axial load carrying capability of the tube. Axial cracks do not require plugging if they are below 17 inches from the TTS. The limiting circumferential ligament was defined by calculation. The calculation assumed that friction loads between the tube and tubesheet from any source are zero.

This assumption avoids potential effects of uncertainties in tube and tubesheet material properties. Also, based on the same assumption that the contact pressure between the tube and tubesheet from any source is zero, this evaluation provided a basis for demonstrating that the accident induced leakage will always meet the value assumed in the plant's safety analysis if the observed leakage during normal operating conditions is within its allowable limits. The need to calculate leakage from individual cracks is avoided by the calculation of the ratio of accident induced leakage to normal operating leakage.

.In summary, the IARC technical basis relied upon a load path from the tube sheet clad through the tube-to-tubesheet weld to the tube to resist the pullout loads associated with the primary to secondary pressure differentials.

Due to questions concerning the variability of the coefficients of thermal expansion (CTE) for the tube material and for the tubesheet material, the technical basis for the IARC did not credit friction between the tube and tubesheet as a factor in resisting pullout. The analysis concluded that the load could be carried through the remaining ligament for one cycle if the crack size in the bottom inch of the tubes Was limited to 94 degrees. Furthermore, the NRC required a commitment to employ a leakage factor of 2.5 (accident induced leak rate to operational leak rate) when performing leak rate calculations.

During the Unit 1 Refueling Outage 22, 2299 tube ends in B SG exhibited significant permeability variation indications when examined with diagnostic eddy current techniques. These indications were confined to the bottom one-half inch of the affected tubes and were of sufficient magnitude to preclude the detection of tube degradation at those locations. Thus, this masking of any degradation that could be present precluded the ability to document the existence of the necessary remaining ligament as discussed.

As shown in the tube maps in Attachment 5, 1243 cold leg tube ends and 1056 hot leg tube ends exhibited these indications; a total of 1473 tubes are affected.

Page 5 of 16

Serial No.09-295 Docket No. 50-280 Subsequent to the completion of the IARC technical basis and -the resolution of associated NRC requests for additional information (lRAl), a study was performed to address CTE variability. The CTE values provided in the ASME Code were determined to be acceptable and conservative as-documented in Reference 4. Resolution of the CTE variability issue provides a basis for utilizing tube to tubesheet friction as the force to resist pullout rather than the remaining ligament basis discussed above.

Implementation of the frictional force basis would support leaving tubes in service with 360 degree through wall cracks located in the bottom one inch. This would resolve the permeability variability masking issue. Additionally, as part of this modified IARC for the Unit 1 B SG, the leakage factor is increased from 2.5 to 4.7 to provide additional margin to ensure that the accident induced leak rate limit is not exceeded. The 4.7 leakage factor of is applicable to all three Unit 1 SGs. Furthermore, the primary to secondary leakage in TS 3.1.C.1.d and TS 4.13.B is limited to 20 gallons per day (gpd) for the Unit 1 B SG for the Unit 1 Operating Cycle 23.

Discussion of Performance Criteria The following performance criteria from NEI 97-06, Rev. 2 are included in Surry's TS and are the bases for the analyses:

The structural integrity performance criterion is:

All in-service steam generator tubes shall retain structural integrity over the full range of normal operating conditions (including startup, operation in the power range, hot standby, cool down and all anticipated transients included in the design specification) and design basis accidents. This includes retaining a safety factor of 3.0 against burst under normal steady state full power operation primary-to-secondary pressure differential and a safety factor of 1.4 against burst applied to the design basis accident primary to secondary pressure differentials. Apart from the above requirements, additional loading conditions associated with the design basis accidents, or combination of accidents in accordance with the design and licensing basis, shall also be evaluated to determine if the associated loads contribute significantly to burst or collapse. In the assessment of tube integrity, those loads that do significantly affect burst or collapse shall be determined and assessed in combination with the loads due to pressure with a safety factor of 1.2 on the combined primary loads and 1.0 on axial secondary loads.

The structural performance criterion is based on ensuring that there is reasonable assurance that a steam generator tube will not burst during normal operation or postulated accident conditions. Since tube burst cannot occur within the tubesheet, the tube burst condition is equated to tube pullout.

The accident-induced leakage performance criterion (AILPC) is:

The primary to secondary accident induced leakage rate for any design basis accident, other than a Steam Generator tube rupture, shall not exceed the leakage Page 6 of 16

Serial No.09-295 Docket No. 50-280 rate assumed in the accident analysis in terms of total leakage rate for all Steam Generators and leakage rate for an individual steam generator. Leakage is not to exceed 1.gpm per Steam Generator, except for specific types of degradation at specific locations when implementing alternate repair criteria as documented in the Steam Generator Program technical specifications.

Primary to secondary leakage is a factor in the dose consequences outside containment resulting from a limiting design basis accident. The potential primary to secondary leak rate during postulated design basis accidents shall limit the offsite radiological dose consequences to within 10 CFR Part 100 guidelines or the radiological consequences to control room personnel required by GDC-19, or other NRC-approved licensing basis (e.g. 10 CFR 50.67).

Structural Integrity Discussion As defined in References 5 and 6, the bounding remaining structural ligament that meets the NEI 97-06, Rev. 2, Performance Criterion described above and is required for the tube to transmit, the operational loads is 235 degrees arc (360 minus 94 crack limit minus 31 for crack growth). This assumes that the residual ligament is not degraded. A small circumferential initiating crack is predicted to grow to a throughwall condition before it is predicted to reach a limiting residual ligament. A residual ligament in a part-throughwall condition is not a significant concern because it is assumed that all circumferential cracks detected are 100% throughwall.

References 5 and 6 documented that the 235 degree remaining ligament in the limiting area of the tube-to-tubesheet weld meets the structural integrity performance criteria. [Reference 7] documented that. the load carrying capability of the remaining 235 degree ligament at the limiting location of the tube-to tubesheet weld was 3200 lbs. This is the force that needs to be carried by the tube to tubesheet joint. The contact pressure between the tube and tube sheet combined with a conservative coefficient of friction between the contacting surfaces results in the force that resists tube pullout. provides two alternative approaches, both of which demonstrate the existence of a restraining force that exceeds 3200 lbs.

The first approach uses plant operating conditions that result in the lowest contact pressure (i.e., normal operating conditions and the lower limit of Tavg).

The analysis uses the limiting tube in the bundle, thus bounding all tubes. The analysis concludes that the available force to resist pullout due to contact pressure in the lower four inches of the tubes is 4869 Ibs, Which is sufficient to exceed the maximum tube pullout forces that were considered in the basis of the IARC.

The second approach uses the same plant operating, conditions. The minimum incremental contact pressure for all tubes at all axial locations was calculated using both 2-dimensional and 3-dimensional finite element models.

This minimum incremental value derived from the limiting axial location in the limiting tube was applied along the tube from one inch to seventeen inches below the top of the Page 7 of 16

Serial No.09-295 Docket No. 50-280 tubesheet.

The resistance to pullout due to contact pressure over this sixteen inch segment was calculated to be 8096 lbs, which is sufficient to exceed the maximum tube pullout forces that were considered in the basis of the IARC by a factor of greater than 2.-

J Both approaches assume the structural integrity of the tubes within the tubesheet above the bottom inch.

ECT data from diagnostic exams conducted in all three steam generators during Unit 1 Refueling Outages 21 and 22 have identified only one flaw in the portion of the tubes within\\the upper 20 inches of the tubesheet. This tube, one of a small population exhibiting high residual stress due to incomplete heat treatment, had an axial indication at the expansion transition, and was removed from service.

The remaining population (43) of the tier 1 high stress tubes in all three SGs were examined and found to be without flaws. A 20% sample of tier two tubes in the A and C SGs and a 100% sample of tier 2 tubes in the B SG were conducted with no additional flaws detected. Fifty percent of the overexpansion (OXP) locations within the tubesheet on the hot leg side along with a sample of the larger OXPs on the cold leg side in all three SGs have been examined over the past two inspections. Additionally, full tubesheet depth examination of a 20% sample of all of the tubes exhibiting permeability variations was conducted.

In summary, one flaw was documented over the two inspections in tubes within the tubesheet. These diagnostic examinations provide a high degree of confidence that the population of tubes with permeability variation within the tubesheet are without flaws above the bottom inch.

In summary, one approach demonstrates that the available axial force developed from contact pressure over the lower four inches of the tube is sufficient to exceed the maximum tube pullout forces that were considered in the basis of the IARC. A second approach demonstrates the available axial force developed in a sixteen inch segment of a tube is sufficient to exceed the maximum tube pullout forces that were considered in the basis of the IARC by a factor of greater than 2.

In both cases, the most conservative plant conditions and tube locations were used. Since this analysis was based upon and consistent with the IARC technical basis, the Structural Integrity Performance criteria continue to be met.

Consideration of Non Destructive Examination (NDE) Uncertainty NDE uncertainty was evaluated for the Unit 1 IARC since sizing of linear indications was required. This LAR for the modified IARC assumes that the circumferential indications in the bottom one inch are 360 degrees in extent, thus no NDE sizing is required. NDE uncertainty therefore does not need to be considered.

Consideration of Accident Induced Leakage In the case of the Unit 1 IARC, meeting the AILPC was supported by the commitment to use a conservative leakage factor of 2.5. The accident induced leak rate limit divided by 2.5 provided an operational leak rate limit that can be monitored on line. The technical basis for the modified IARC [Reference 7] concluded that the leakage factor of 2.5 is Page 8 of 16

Serial No.09-295 Docket No. 50-280 also appropriate for this LAR.

Thus, the AILPC continues to be met based upon the technical basis supporting this proposed change.

In addition, this request includes a commitment to use a leakage factor of 4.7 when performing leak rate calculations, thus adding additional conservatism. Also, the primary to secondary leakage in TS 3.1.C.1.d and TS 4.13.B is limited to 20 gallons per day (gpd) for the Unit 1 B SG for the Unit I Operating Cycle 23.

Consideration of Crack Growth Crack growth was a consideration in the IARC due to the need to maintain the required minimum ligament. Table 1.0 shows the application of crack growth to determine the critical ligament for the bottom one inch of the tubes.

The technical basis for this LAR assumes that any circumferential indications in the bottom one inch of the tubesheet are 100% throughwall and 360 degrees in extent.

Therefore, crack growth is no longer relevant.

Table 1.0 Calculation of Required Minimum Ligament for 18 Months Operating Period Bounding EFPY Growth Growth Growth Minimum Critical Structural (1)

(/n.IEFPY)

(Deg./EFPY) for Structural Ligament Ligament (2)

(3)

Operating Ligament (degrees)

Period (degrees)

(degrees) 18 1.5 0.12 20.65 31 235 94 Calendar Tubel Month Weld (CM)

Operation

1) It is conservatively assumed that 1 EFPY= 1 Calendar Year

2) 95% upper value of typical growth rates from Reference 5 and 6

3) Based on smallest (Model F) mean tubesheet bore dimension Primary to Secondary Leakage Discussion A commitment to a leakage factor of 2.5 was applied to that part of the observed normal operating leakage that cannot be associated with the degradation mechanisms outside the tubesheet expansion region to calculate the accident induced leakage from the tubesheet region [Reference 5] in conjunction with the Unit 1 IARC.

For integrity assessments, the ratio of 2.5 was committed to be used in completion of both the Page 9 of 16

Serial No.09-295 Docket No. 50-280 condition monitoring (CM),and operational assessment (OA) upon implementation of the IARC. For example, for the CM assessment, the component of leakage from the lower 4 inches for the most limiting steam generator during the prior cycle of operation would have been multiplied by a factor of 2.5 and added. to the total leakage from any other source and compared to the allowable accident analysis leakage assumption. For the OA, the difference' in 'leakage from the allowable limit during the limiting design basis accident minus the leakage from the other sources would have been divided by 2.5 and compared to the observed operational leakage. [Reference 7] concluded that this leakage factor is also appropriate in support of this LAR.

However, additional margin has been provided by increasing the leakage factor from 2.5 to 4.7. The leakage factor of 4.7 will be used in integrity assessments as described above. Additional margin is provided for the Unit I B SG by limiting the primary to secondary leakage to 20 gpd.

Reporting Requirements This LAR includes a proposed modification to the 180-day SG Report to include information on the location and extent of the permeability variation indications observed in the bottom one inch of the steam generator tubes in the Unit 1 B SG.

Inspection and Repair of Tubes No tubes in the Unit 1 B SG with linear indications that exceed the repair limit specified by the Unit I IARC TS were identified during Refueling Outage 22. Tubes in the B SG with permeability variation indications that may mask flaws in the bottom one inch of the tubesheet do not require plugging and will remain in service.

5.0 APPLICABLE REGULATORY REQUIREMENTSICRITERIA Steam Generator (SG) tube inspection and repair limits are specified in Surry TS 6.4.Q, "Steam Generator (SG) Program." The current TS require that flawed tubes be repaired if the depths of the flaws are greater than or equal to 40 percent through wall. During the initial plant licensing of Surry Power Station Unit 1, it was demonstrated that the design of the reactor coolant pressure boundary met the regulatory requirements in place at that time. The General Design Criteria (GDC) included in Appendix A to 10 CFR Part 50 did not become effective until May 21, 1971. The Construction Permits for Surry Units 1 and 2 were issued prior to May 21, 1971; consequently, these units were not subject to GDC requirements.

(Reference SECY-92-223 dated September 18, 1992.) However, the following information demonstrates compliance with GDC 14, 15, 30, 31, and 32 of 10 CFR 50, Appendix A. Specifically, the GDCstate that the Reactor Coolant Pressure Boundary (RCPB) shall have "an extremely low probability of abnormal leakage...'and gross rupture" (GDC 14), "shall be designed with sufficient margin" (GDCs 15 and 31), shall be of "the highest quality standards practical" (GDC 30), and shall be designed to permit "periodic inspection and testing... to assess...

Page 10 of 16

Serial No.09-295 Docket No. 50-280 structural and leak tight integrity" (GDC 32). Structural integrity refers to maintaining adequate margins against burst, and collapse of the steam generator tubing. Leakage integrity refers to limiting primary to secondary leakage during all plant conditions to within acceptable limits.

The TS repair limits ensure that tubes accepted for continued service will retain adequate structural and leakage integrity during normal operating, transient, and postulated accident conditions. The reactor coolant pressure boundary is designed, fabricated and constructed so as to'have an exceedingly low probability of gross rupture or significant uncontrolled leakage throughout its design lifetime.

Reactor coolant pressure boundary components have provisions for the inspection testing and surveillance of critical areas by appropriate means to assess the structural and leaktight integrity of the boundary componerits during their service lifetime. Structural integrity refers to maintaining adequate margins against burst and collapse of the steam generator tubing.

Leakage integrity refers to limiting primary to secondary leakage during all plant conditions to within acceptable limits.

6.0 BASIS FOR EMERGENCY TS CHANGE In a letter dated October 14, 2008 (Serial No. 08-0521) [Reference 1], Dominion requested a license amendment for Surry Unit I to incorporate an IARC into the provisions for SG tube repair for use during the Surry Unit 1 Refueling Outage 22 and the subsequent operating cycle.

A February 20, 2009 letter (Serial No.09-071) provided the response to an NRC request for additional information, including a commitment to use the 2.5 leakage factor [Reference 2].

The Unit 1 IARC was approved by the NRC on Apdl 8, 2009 by TS Amendment 263/-- [Reference 3], which was implemented on April 29, 2009.

The SG tube inspection scope for Unit 1 Refueling Outage 22 included planned inspection in the A and C SGs, as well as pre-planned scope expansion for the B SG, if required. As a result of tube ends cracks found in the A and C SGs, the pre-planned expansion of the SG tube inspection in the B SG was undertaken. The B SG tube inspection commenced on April 30, 2009 at 12:06 pm and was completed on May 3, 2009 at 06:10 am. Based on the Unit 1 IARC requirements, a first time inspection of the B SG tube ends was performed using a rotating eddy current probe. The B SG inspection identified a large number of permeability variation indications of significant signal strength requiring disposition. These indications are unique to the Unit 1 B SG.

The locations were reexamined using additional diagnostic techniques. Examinations included the use of magnetic bias probes, often useful in distinguishing permeability variations from flaws.

These examinations were not successful due to the lack of significant reduction in the voltage signal with the, magnetic bias probe and associated with the geometry of the location and the strength of the permeability signal.

In summary, the use of additional diagnostic techniques did not resolve the masking issue.

Preliminary disposition of the permeability variation indications concluded that these indications may mask flaws in the Unit 1 B SG tubes. A Condition Report in the Page 11 of 16

Serial No.09-295 Docket No. 50-280 Attachment I Corrective Action Program was issued on May 1, 2009 documenting the permeability variation indications and the potential masking of flaws. The number and location of these indications is identified in Section 3.2.

The proposed change is required to preclude unnecessary plugging of 1473 B SG tubes due to flaw masking by the permeability variation indications. The proposed change does not require plugging of SG tubes in the Unit I B SG with permeability variation indications in the bottom one inch of the tubesheet for the Unit 1 Refueling Outage 22 and the subsequent operating cycle.

As indicated in the Dominion letter dated October 14, 2008 [Reference 1] requesting NRC review of the Unit 1 IARC, the Unit 1 IARC TS amendment-was being implemented prior to increasing Reactor Coolant System (RCS) temperature above 200°F during startup of Surry Unit. 1 from Refueling Outage 22.

Similarly, implementation of the amendment approving the modified IARC for the Unit 1 B SG is needed to support the increase in RCS temperature above 200°F. The 200'F mode change for startup from the Unit I Refueling Outage 22 is currently scheduled to commence at 04:00 am on May 8, 2009; Dominion requests that the proposed change be processed as an emergency LAR to prevent delay in-either resumption of operation or of increase in power output up to the plant's licensed power level of Surry Unit 1.

Thus, NRC approval of the proposed LAR is requested by May 7, 2009.

7.0 NO SIGNIFICANT HAZARDS CONSIDERATION Dominion has evaluated whether a significant hazards consideration is involved with the proposed amendment by focusing on the three standards set forth in 10 CFR 50.92, "Issuance of Amendment," as discussed below:

(1) Does the proposed change involve a significant increase in the probability or consequences of an accident previously evaluated?

Response: No Of the various accidents previously evaluated, the proposed change only affects the steam generator tube rupture (SGTR), steam line break (SLB), and locked rotor evaluations. Loss-of-coolant accident (LOCA) conditions cause a compressive axial load to act on the tube. Therefore, since the LOCA tends to force the tube into the tubesheet rather than pull it out, it is not a factor in this amendment request. Another faulted load consideration is a safe shutdown earthquake (SSE); however, the seismic analysis of Model 51F steam generators has shown that axial loading of the tubes is negligible during an SSE.

At normal operating pressures, leakage from PWSCC below 17 inches from the TTS is limited by both the tube-to-tubesheet crevice and the limited crack opening permitted by the tubesheet constraint. Consequently, negligible normal operating leakage is expected from cracks within the tubesheet region.

Page 12 of 16

Serial No.09-295 Docket No. 50-280 For the SGTR event, the required structural margins of the steam generator tubes with circumferential flaws of any extent within the bottom one inch of the tubes are maintained by ensuring that the available axial force due to tube to tubesheet contact pressure and the coefficient of friction between the tube and the tubesheet exceeds the maximum pullout force for the limiting operating conditions. These forces were calculated and the results documented in Attachment 4 [Reference 7].

In all cases, the available axial forces are sufficient to offset tube pullout forces, thus maintaining tube integrity. Attachment 4 [Reference 7] further concludes that the performance criteria of NEI 97-06, Rev. 2, "Steam Generator Program Guidelines" and Regulatory Guide (RG) 1.121, "Bases for Plugging Degraded PWR Steam Generator Tubes" continue to be met.

Therefore, the margin against tube burst/pullout is maintained during normal and postulated accident conditions and the proposed change does not result in a significant increase in the probability or consequence of a SGTR.

The probability of a SLB is unaffected by the potential failure of a, SG tube as the failure of a tube is not an initiator for a SLB event. SLB leakage is limited by leakage flow restrictions resulting from the leakage path above potential cracks through the tube-to-tubesheet crevice. The leak. rate during postulated accident conditions (including locked rotor) -has been shown to remain within the accident analysis assumptions for circumferential flaws of any extent located in the bottom one inch of the tubes. Consistent with the 4.7 leakage factor, the primary to secondary leakage will be administratively limited to 100 gpd, the attendant accident condition leak rate, assuming all leakage to be from indications below 17 inches from the top of the tubesheet would be bounded by 470 gpd. This value is within the accident analysis assumptions for the limiting design basis accident for Surry, which is the postulated SLB event.

The reduction in the primary to secondary leakage limit from 150 gallons per day to 20 gallons per day for the Unit 1 B steam generator provides additional margin.

Based on the above, the performance criteria of NEI-97-06, Rev. 2 and Regulatory Guide (RG) 1.121 continue to be, met and the proposed change does not involve a significant increase in the probability or consequences of an accident previously evaluated.

(2) Does the proposed change create the possibility of a new or different accident from any accident previously evaluated?

Response: No The proposed change does not introduce any changes or mechanisms that create the possibility of a new or different kind of accident. Tube bundle integrity is expected to be maintained for all plant conditions upon implementation of the modified interim alternate repair criteria. The proposed change does not introduce Page 13 of 16

Serial No.09-295 Docket No. 50-280 any new equipment or any change to existing equipment. No new effects on existing equipment are created nor are any new malfunctions introduced.

The reduction in the primary to secondary leakage limit from 150 gallons per day to 20 gallons per day for the Unit 1 B steam generator cannot initiate an accident.

Therefore, based on the above evaluation, the proposed changes do not create the possibility of a new or different kind of accident from any accident previously evaluated.

(3) Does the proposed change involve a significant reduction in a margin of safety?

Response: No The proposed change maintains the required structural margins of the steam generator tubes for both normal and accident conditions. NEI 97-06, Rev. 2 and RG 1.121 are used as the basis in the development of the limited tubesheet inspection

,depth methodology for determining that steam.generator tube integrity considerations are maintained within acceptable limits. RG 1.121 describes a method acceptable to the NRC staff for meeting GDC 14, 15, 31, and 32 by reducing the probability and consequences of an SGTR. RG 1.121 concludes that by determining the limiting safe conditions of tube wall degradation beyond which tubes with unacceptable cracking, as established by inservice inspection, should be removed from service or repaired, the probability and consequences of a SGTR are reduced. This RG uses safety factors on loads for tube burst that are consistent with the requirements of Section III of the ASME Code.

For circumferential flaws of any extent in the bottom one inch of the tubes, [Reference 7] documents that tube to tubesheet contact pressure combined with a conservative coefficient or friction serve to provide the necessary resistance to tube pullout due to the pressure and thermally induced forces (with applicable safety factors applied). Additionally, it is shown that the existence of circumferential indications of any extent located in the bottom one inch of the tubes will not result in unacceptable primary to secondary leakage during all plant conditions.

The reduction in the primary to secondary leakage limit from 150 gallons per day to 20 gallons per day for the Unit 1 B steam generator does not result in a reduction in margin since operator intervention will be required at the lower leakage limit.

Based-on the above, it is concluded that the proposed change does not result in any reduction of margin with respect to plant safety as defined in the Updated Final Safety Analysis Report or bases of the plant Technical Specifications.

Page 14 of 16

Serial No.09-295 Docket No. 50-280 Attachment I Therefore, Dominion concludes that, the proposed change presents no significant hazards consideration under the standards set forth in 10 CFR 50.92(c) and, accordingly, a finding of "no significant hazards consideration" is justified.

8.0 ENVIRONMENTAL CONSIDERATION

Dominion has evaluated the proposed change for environmental considerations. The review has determined that the proposed change would change a requirement with respect to installation or use of a facility component located within the restricted area, as defined in 10 CFR 20, and would change'an inspection or surveillance requirement.

However, the proposed change does not involve (i) a significant hazards consideration, (ii) a significant change in the types or significant increase in the amounts of any effluent that may be released offsite, or (iii) a significant increase in individual or cumulative occupational radiation exposure. Accordingly, the proposed change meets the eligibility criterion for categorical exclusion set for in 10 CFR 51.22(c)(9). Therefore, pursuant to 10 CFR 51'.22(b), no environmental impact statement or environmental assessment need be prepared in connection with the proposed change.

9.0 CONCLUSION

Based on the considerations discussed above, (1) there is reasonable assurance that the health and safety of the public will not be endangered by operation in the proposed manner, (2) such activities will be conducted in compliance with the Commission's regulations, (3) the issuance of the amendment will not be inimical to the common defense and security or to the health and safety of the public with the implementation of the modified IARC for the Unit 1 B SG, and (4) no environmental impact statement or environmental assessment need be prepared in connection with the proposed change.

Page 15 of 16

Serial No.09-295 Docket No. 50-280

10.0 REFERENCES

1.

Virginia Electric and Power (Dominion) to NRC letter Serial No. 08-0521, dated October 14, 2008, Surry Power Station Unit I-Proposed License Amendment Request - Interim Alternate Repair Criteria (IARC) for Steam Generator (SG) Tube Repair

2.

Virginia Electric and Power (Dominion) to NRC letter Serial No.09-071, dated February 20, 2009, Surry Power Station Unit 1 - Proposed License Amendment Request - Interim'Alternate Repair Criteria for Steam Generator Tube Repair -

Request for Additional Information.

3.

NRC to Virginia Electric and Power letter, dated April 8, 2009, Surry Power Station Unit 1-Issuance of, Amendment Regarding Proposed License Amendment Request - Interim Alternate Repair Criteria for Steam Generator Tube Repair [TS Amendment 263/--]

4.

West-13-402, Revision 1, "An Evaluation of the Statistical Variability in the Coefficient of Thermal Expansion Properties of SA508 and Alloy 600," Structural Integrity Associates, Inc., Centennial, CO, December 2008

5.

Westinghouse Electric Company LLC letter LTR-CDME-08-11., "Interim Alternate Repair Criterion (ARC) for Cracks in the Lower Region of the Tubesheet Expansion Zone," dated January 31, 2008 [NOTE: This 'reference was included in Reference 1.]

6.

Westinghouse Electric Company LLC letter LTR-CDME-08-43 P-Attachment "Response to NRC Request for Additional Information 1 Relating to LTR-CDME-08-11 P-Attachment," dated March 18, 2009 [NOTE: This reference was included in Reference 1.]

7.

Westinghouse Letter LTR-SGMP-09-63, dated May 4, 2009, Assessment of Tube-end Indications at Surry Unit I

[NOTE: This reference is included in.]

Page 16 of 16

Serial No.09-295 Docket No. 50-280 ATTACHMENT 2 Mark-up of Unit I Technical Specifications Pages Surry Power Station Unit 1 Virginia Electric and Power Company (Dominion)

TS 3.1-13 C.

RCS Operational LEAKAGE Applicability The following specifications are applicable to RCS operational LEAKAGE whenever Tavg (average RCS temperature) exceeds 200'F (200 degrees Fahrenheit).

Specifications

1. RCS operational LEAKAGE shall be limited to:

a.. No pressure boundary LEAKAGE,

b. 1 gpm unidentified LEAKAGE,

c. 10 gpm identified LEAKAGE, and

d. 150 gallons per day primary to secondary LEAKAGE through any one steam generator (SGX F-p-r A\\~

2.a. If RCS operational LEAKAGE is not within the limits of 3.1.C.1 for reasons other than pressure boundary LEAKAGE or primary to secondary LEAKAGE, reduce LEAKAGE to within the specified limits within 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months .

b. If the LEAKAGE is not reduced to within the specified limits within 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months , the unit shall be brought to HOT SHUTDOWN within the next 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months and COLD.

SHUTDOWN within the following 30 hours3.472222e-4 days 0.00833 hours 4.960317e-5 weeks 1.1415e-5 months .

3. If RCS pressure boundary LEAKAGE exists, or primary to secondary LEAKAGE is not within the limit specified in 3.1.C.l.d, the unit shall be brought to HOT SHUTDOWN within 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months and COLD SHUTDOWN within the following 30 hours3.472222e-4 days 0.00833 hours 4.960317e-5 weeks 1.1415e-5 months .

Amendment Nos. 2-54-and--25

Insert A on pages TS 3.1.13a and TS 4.13-2 with the following exception. The primary to secondary LEAKAGE for the Unit 1 B steam generator will be limited to 20 gallons per day during Operating Cycle 23.

TS 3.1-14a 43-29--07 This LCO deals with protection of the reactor coolant pressure boundary (RCPB) from degradation and the core from inadequate cooling, in addition to preventing the accident analyses radiation release assumptions from being exceeded. The consequences of violating this LCO include the possibility of a loss of coolant accident (LOCA),

APPLICABLE SAFETY ANALYSES - Except for primary to secondary LEAKAGE, the safety analyses do not address operational LEAKAGE. However, other operational LEAKAGE is related to the safety analyses for LOCA; the amount of leakage can affect the probability of such an event. The safety analysis for an event resulting in steam discharge to the atmosphere assumes that primary to secondary LEAKAGE from all steam generators (SGs) is 1 gpm or increases to I gpm as a result of accident induced conditions. The LCO requirement to limit primary to secondary LEAKAGE through any one SG to less than or equal to 150 gallons per day is significantly less than the conditions assumed in the safety analysis.,

IM,5E-Primary to secondary LEAKAGE is a factor in the dose releases outside containment resulting from a main steam line break (MSLB) accident. Other accidents or transients involve secondary steam release to the atmosphere, such as a steam generator tube rupture (SGTR). The leakage contaminates the secondary fluid.

The UFSAR (Ref. 2) analysis for SGTR assumes the contaminated secondary fluid is released via power operated relief valves or safety valves. The source term in the primary system coolant is transported to the affected (ruptured) steam generator by the break flow. The affected steam generator discharges steam to the environment for 30 minutes until the generator is manually isolated. The 1 gpm primary to secondary LEAKAGE transports the source term to the unaffected steam generators. Releases continue through the unaffected steam generators until the Residual Heat Removal System is placed in service.,

The MSLB is less limiting for site radiation releases than the SGTR. The safety analysis for the MSLB accident assumes 1 gpm totalprimary to secondary LEAKAGE, including 500 gpd leakage into the faulted generator. The dose consequences resulting from the MSLB and the SGTR accidents are within the limits defined in the plant licensing basis, The RCS operational LEAKAGE satisfies Criterion 2 of 10 CFR 50.36(c)(2)(ii).

LIMITING CONDITIONS FOR OPERATION -RCS operational LEAKAGE shall be limited to:

a. Pressure Boundary LEAKAGE No pressure boundary LEAKAGE is allowed, being indicative of material deterioration.

LEAKAGE of this type is unacceptable as the leak itself could cause further deterioration, resulting in higher LEAKAGE. Violation of this LCO could result in continued degradation of the RCPB. LEAKAGE past seals and gaskets is not pressure boundary LEAKAGE.

Amendment Nos. 24--an--250

Insert B on pages TS 3.1-14a and TS 3.1-14b Due to the permeability variation indications in the Unit i B steam generator found during Refueling Outage 22, the primary to secondary leak rate for that steam generator is limited to 20 gallons per day for Operating Cycle 23.

TS 3.1-14b 03-29--M

b. Unidentified LEAKAGE One gallon per minute (gpm) of unidentified LEAKAGE is allowed as a reasonable minimum detectable amount that the containment air monitoring and containment sump level monitoring equipment can detect within a reasonable time period. Violation of this LCO could result in continued degradation of the RCPB, if the LEAKAGE is from the pressure boundary.

c. Identified LEAKAGE Up to 10 gpm of identified LEAKAGE is considered allowable because LEAKAGE is from known sources that do not interfere with detection of unidentified LEAKAGE and is well within the capability of the RCS Makeup System. Identified LEAKAGE includes LEAKAGE to the containment from specifically known and located sources, but does not include pressure boundary LEAKAGE or controlled reactor coolant pump (RCP) seal leakoff (a normal function not considered LEAKAGE). Violation of this LCO could result in continued degradation of a component or system.

d. Primary to Seconda LEAKAGE through Any One SG The limit of 150 gallons per day per SG is based on the operational LEAKAGE performance criterion in NEI 97-06, Steam Generator Program Guidelines (Ref. 3). The Steam Generator Program operational LEAKAGE performance criterion in NEI 97-06 states, 'TIhe RCS operational primary to secondary leakage through any one SG shall be limited to 150 gallons per day:' The limit is based on operating experience with SG tube degradation mechanisms that result in tube leakage. The operational leakage rate criterion in conjunction with the implementation of the Steam Generator Program is an effective measure for minimizing the frequency of steam generator tube ruptures.

I 5N s?--"

APPLICABILITY - In REACTOR OPERATION conditions where Tavg exceeds 2001F, the potential for RCPB LEAKAGE is greatest when the RCS is pressurized.

In COLD SHUTDOWN and REFUELING SHUTDOWN, LEAKAGE limits are not required because the reactor coolant pressure is far lower, resulting in lower stresses and reduced potentials for LEAKAGE.

LCO 3.1.C.5 measures leakage through each individual pressure isolation valve (PIV) and can impact this LCO. Of the two PIVs in series in each isolated line, leakage measured through one PIV does not result in RCS LEAKAGE when the other is leaktight. If both valves leak and result in a loss of mass from the RCS, the loss must be included in the allowable identified LEAKAGE.

Amendment Nos. 25-ed2

Insert B on pages TS 3.1-14a and TS 3.1-14b Due to the permeability variation indications in the Unit 1 B steam generator found during Refueling Outage 22, the primary to secondary leak rate for that steam generator is limited to 20 gallons per day for Operating Cycle 23.

TS 4.13-1 4.13 RCS OPERATIONAL LEAKAGE Applicability The following specifications are applicable to RCS operational LEAKAGE whenever Tavg (average RCS temperature) exceeds 200*F (200 degrees Fahrenheit).

Objective To verify that RCS operational LEAKAGE is maintained within the allowable limits.

Specifications A.

Verify RCS operational LEAKAGE is within the limits specified in TS 3.1.C by performance of RCS water inventory balance once every 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months . 1.2 B.

Verify primary to secondary LEAKAGE is < 150 gallons per day through any one SG once every 72 hourV'

/?Ir\\ApT-r C

Notes:

1. Not required to be completed until 12hours after establishment of steady state operation.

2.

Not applicable to primary to secondary LEAKAGE.

BASES SURVEILLANCE REQUIREMENTS (SR)

SR 4.13.A Verifying RCS LEAKAGE to be within the Limiting Condition for Operation (LCO) limits ensures the integrity of the reactor coolant pressure boundary (RCPB) is maintained. Pressure boundary LEAKAGE would at first appear as unidentified LEAKAGE and can only be positively identified by inspection. It should be noted that LEAKAGE'past seals and gaskets is not pressure boundary LEAKAGE. Unidentified LEAKAGE and identified LEAKAGE are determined by performance of an RCS water inventory balance.

The RCS water inventory balance must be performed with the reactor at steady state operating conditions (stable pressure, temperature, power level, pressurizer and makeup tank levels, makeup and letdown, and RCP seal injection and return flows). The surveillance is modified by two notes.

Note 1 states that this SR is not required to be completed until 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months after establishing steady state operation. The 12 hour1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months allowance provides sufficient time to collect and process all necessary data after stable unit conditions are established.

Amendment Nos. 2-ld

Insert C on pages TS 4.13-1

, with the following exception. The primary to secondary LEAKAGE for the Unit 1 B steam generator will be verified to be <20 gallons per day during Operating Cycle 23.

TS 4.13-2 d-Steady state operation is required to perform a proper inventory balance since calculations during maneuvering are not useful. For RCS operational LEAKAGE determination by water inventory balance, steady state is defined as stable RCS pressure, temperature, power level, pressurizer and makeup tank levels, makeup and letdown, and RCP seal injection and return flows.

An early warning of pressure boundary LEAKAGE or unidentified LEAKAGE is provided by the automatic systems that monitor the containment atmosphere radioactivity and the containment sump level. It should be noted that LEAKAGE past seals and gaskets is not pressure boundary LEAKAGE. These leakage detection systems are specified in the TS 3.1.C Bases.*

Note 2 states that this SR is not applicable to primary to secondary LEAKAGE because LEAKAGE of 150 gallons per day cannot be measured accurately by an RCS water inventory balance.

The 24 hour2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months frequency is a reasonable interval to trend LEAKAGE and recognizes the importance of early leakage detection in the prevention of accidents.

SR 4.13.B A

This SR verifies that p ary to secondary LEAKAGE is less than or equal to 150 gallons per day through any one SrSatisfying the primary to secondary LEAKAGE limit ensures that the operational LEAKAGE performance criterion in the Steam Generator Program is met. If this SR is not met, compliance with LCO 3.1.H, "Steam Generator Tube Integrity," should be evaluated.

The 150 gallons per day limit is measured at room temperature as described in Reference 4. The operational LEAKAGE rate limit applies to LEAKAGE through any one SG.

If it is not practical to assign the LEAKAGE to an individual ST,*iilthe primary to secondary LEAKAGE should be conservatively assumed to be from one Sq-JThe surveillance is modified by a Note, which states that the Surveillance is not required to be performed until 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months after establishment of steady state operation. For RCS primary to secondary LEAKAGE determination, steady state is defined as stable RCS pressure, temperature, power level, pressurizer and makeup tank levels, makeup and letdown, and RCP seal injection and return flows.

The surveillance frequency of 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months is a reasonable interval to trend primary to secondary LEAKAGE and recognizes the importance of early leakage detection in the prevention of accidents. The primary to secondary LEAKAGE is determined using continuous process radiation monitors or radiochemical grab sampling in accordance with the EPRI guidelines (Ref. 4).

REFERENCES

3.

UFSAR, Chapter 4, Surry Units 1 and 2.

4.

UFSAR, Chapter 14, Surry Units 1 and 2.

5.

NEI 97-06, "Steam Generator Program Guidelines."

6.

EPRI, 'Pressurized Water Reactor Primary-to-Secondary Leak Guidelines:'

Amendment Nos. 25-fated-250

Insert A on pages TS 3.1.13a and TS 4.13-2

, with the following exception. The primary to secondary LEAKAGE for the Unit 1 B steam generator will be limited to 20 gallons per day during Operating Cycle 23.

Insert D on page TS 4.13-2 for Unit I that leakage should be assumed to be through the B steam generator for Operating Cycle 23.

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~Aq-r-1 4 03-29-07 Q. Steam Generator (SG) Program A Steam Generator Program shall be established and implemented to ensure that SG tube integrity is maintained. In addition, the Steam Generator Program shall include the following provisions:

1. Provisions for condition monitoring assessments.

Condition monitoring assessment means an evaluation of the "as found" condition of the tubing with respect to the performance criteria for structural integrity and accident induced leakage. The "as found" condition refers to the condition of the tubing during an SQ inspection.outage, as determined from the inservice inspection results or by other means, prior to the plugging of tubes; Condition monitoring assessments shall be conducted during each outage during which the SQ tubes are inspected or plugged to confirm that the performance criteria are being met.

2. Performance criteria for SQ tube integrity. SQ tube integrity shall be maintained by meeting the performance criteria for tube structural integrity, accident induced leakage, and operational LEAKAGE.

a. Structural integrity performance criterion: All in-service steam generator tubes shall retain structural integrity over the full range of normal operating conditions (including startup, operation in the power range, hot standby, and cool down and all anticipated transients included in the design specification) and design basis accidents. This includes retaining a safety factor of 3.0 against burst under normal steady.state full power operation primary to secondary pressure differential and a safety factor of 1.4 against burst applied to the design basis accident primary to secondary pressure differentials. Apart from.

the above requirements, additional loading conditions associated with the design basis accidents, or combination of accidents in accordance with the design and licensing basis, shall also be evaluated to determine if the associated loads contribute significantly to burst or collapse. In the assessment of tube integrity, those loads that do significantly affect burst or collapse shall be determined and assessed in combination with the loads due to pressure with a safety factor of 1.2 on the combined primary loads and 1.0 on axial secondary loads.

b. Accident induced leakage performance criterion: The primary to secondary accident induced leakage rate for any design basis accident, other than a SQ tube rupture, shall not exceed the leakage rate assumed in the accident analysis in terms of total leakage rate for all SGs and leakage rate for an individual SQ.

Leakage is not to exceed 1.gpm for all SQ.

Amendment Nos. 251 and 250

PC)~ CHAM'j§e Ot-J Th4(S PAýC#-

TS 6.4-12 IIJcLUDrZ) FoR )M-0oR.A-T1o).J 05-16-08

c. The operational LEAKAGE performance criterion is specified in TS 3.1.C and 4.13, "RCS Operational LEAKAGE."

3. Provisions for SG tube repair criteria. Tubes found by inservice inspection to contain flaws with a depth equal to or exceeding 40% of the nominal tube wall thickness shall be plugged.

The following alternate tube.repair criteria shall be applied as an alternative to the 40% depth-based criteria:

a. For Unit 2 Refueling Outage 21 and the subsequent operating cycle, tubes with flaws having a circumferential component less than or equal to 203 degrees found in the portion of the tube below 17 inches from the top of the tubesheet and above 1 inch fromthe bottom of the tubesheet do not require plugging.

Tubes with flaws having a circumferential component greater than 203 degrees found in the portion of the tube below 17 inches from the top of the tubesheet and above-1 inch from the bottom of the tubesheet shall be removed from service.

Tubes with service-induced flaws located within the region from the top of the tubesheet to 17 inches below the top of the tubesheet shall be removed from service. Tubes with service-induced axial cracks found in the portion of the tube below 17 inches from the top of the tubesheet do not require plugging.

When more than one flaw with circumferential components is found in the portion of the tube below 17 inches from the top of the tubesheet and above 1 inch from the bottom of the tubesheet with the total of the circumferential components greater than 203 degrees and an axial separation distance of less than 1 inch, then the tube shall be removed from service, When the circumferential components of each of the flaws are added, it is acceptable to count the overlapped portions only once in the total of circumferential components.

When one or more flaws with circumferential components are found in the portion of the tube within. 1 inch from the bottom of the tubesheet, and the total of these circumferential components exceeds 94 degrees, then the tube shall be removed from service. When one or. more flaws with circumferential components are found in the portion of the tube within 1 inch from the bottom of the tubesheet and within 1 inch axial separation distance of a flaw above 1 inch from the bottom of the tubesheet, and the total of these circumferential Amendment Nos. -1258

TS 6.4-13 components exceeds 94 degrees, then the tube shall be removed from service.

When the circumferential components of each of the flaws are added, it is acceptable to count the overlapped portions only once in the total of circumferential components.

b.

For Unit 1 Refueling Outage 22 and the subsequent operating cycle, tubes with flaws having a circumferential component less than or equal to 203 degrees found in the portion of the tube below 17 inches from the top of the tubesheet and above 1 inch from the bottom of the tubesheet do not require plugging.

Tubes with flaws having a circumferential component greater than 203 degrees found in the portion of the tube below 17 inches from the top of the tubesheet and above 1 inch from the bottom of the tubesheet shall be removed from service.

Tubes with service-induced flaws located within the region from the top of the tubesheet to 17 inches below the top of the tubesheet shall be removed from service. Tubes with service-induced axial cracks found in the portion of the tube below ITinches from the top of the tubesheet do not require plugging.

When more than one flaw with circumferential components is found in the portion of the tube below 17 inches from the top of 'the tubesheet and above 1 inch from the bottom of the tubesheet with the total of the circumferential components greater than 203 degrees and an axial separation distance of less than I inch, then the tube shall be removed from service. When the circumferential components of each of the flaws are added, it is acceptable to count the overlapped portions only once in the total of circumferential components.

When one or more flaws with circumferential components are found in the portion of the tube within I inch from the bottom of the tubesheet, and the total of these circumferential components exceeds 94 degrees, then the tube shall be removed from service. When one or more flaws with circumferential components are found in the portion of the tube within 1 inch from the bottom of the tubesheet and within 1 inch axial separation distance of a flaw above 1 inch from the bottom of the tubesheet, and the total of these circumferential components exceeds 94 degrees, then the tube shall be removed from service.

When the circumferential components of each of the flaws are added, it is acceptable to count the overlapped portions only once in the total of circumferential components.

Amendment No.-26M-258

Insert E on page TS 6.4-13

c. For Unit I Refueling Outage 22 and the subsequent operating cycle, tubes in the B steam generator with permeability variation Indications that may mask flaws in the bottom one inch of the tubesheet do not require plugging.

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-0PR~c)0Q04-08

-09

4. Provisions for SG tube inspections. Periodic SO tube inspections shall be performed. The number and portions of the tubes inspected and methods of inspection shall be performed with the objective of detecting flaws of any type (e.g., volumetric flaws, axial and circumferential cracks) that may be present along the length of the tube, from the tube-to-tubesheet weld atthe tube inlet to the tube-to-tubesheet weld at the tube outlet, and that may satisfy the applicable tube repair criteria. The tube-to-tubesheet weld is not part of the tube. In addition to meeting the requirements of 4.a, 4.b, and 4.c below, the inspection scope, inspection methods, and inspection intervals shall be such as to ensure that SG tube integrity is maintained until the next SG inspection. An assessment of degradation shall be performed to determine the type and location of flaws to which the tubes may be susceptible and, based on this assessment, to determine which inspection methods need to be employed and at what locations.

a. Inspect 100% of the tubes in each SG during the first refueling outage following SO replacement.

b, Inspect 100% of the tubes at sequential periods of 120, 90, and, thereafter, 60 effective full power months. The first sequential period shall be considered to begin after the first inservice inspection of the SGs. In addition, inspect 50% of the tubes by the refueling outage nearest the midpoint of the period and the remaining 50% by the refueling outage nearest the end of the period. No SG shall operate for more than 48 effective full power months or two refueling outages (whichever is less) without being inspected.

c. If crack indications are found in any SG tube, then the next inspection for each SG for the degradation mechanism that caused the crack indication shall not exceed 24 effective full power months or one refueling outage (whichever is less). If definitive information, such as from examination of a pulled tube, diagnostic non-destructive testing, or engineering evaluation indicates that a crack-like indication is not associated with a crack(s), then the indication need not be treated as a crack.

5. Provisions for monitoring operational primary to secondary LEAKAGE.

Amendment No. 263/258

MI O CWAMG_ oh, TItL.S PA:

TS 6.6-3 IJCLUDeb FOR io f'tORMIrIol, 05-16-08

b. The results of specific activity analysis in which the primary coolant exceeded the limits of Specification 3.1.D.4. In addition, the information itemized in Specification 3.1.D.4 shall be included in this report.

3. Steam Generator Tube Inspection Report A report shall be submitted within 180 days after Tavg exceeds 200IF following completion of an inspection perf6rmed in accordance with the Specification 6.4.Q, Steam Generator (SG) Program. The report shall include:

a. The scope of inspections performed on each SG,

b. Active degradation mechanisms found,

c. Nondestructive examination techniques utilized for each degradation mechanism,

d. Location, orientation (if linear), and measured sizes (if available) of service induced indications,

e. Number of tubes plugged during the inspection outage for each active degradation mechanism,

f. Total number and percentage of tubes plugged to date,

g. The results of condition monitoring, including the results of tube pulls and in-situ testing, and

h. The effective plugging percentage for all plugging in each SG.

i. Following completion of a Unit 2 inspection performed in Refueling Outage 21 (and any inspections performed in the subsequent operating cycle), the number of indications and location, size, orientation, whether initiated on primary or secondary side for each service-induced flaw within the thickness of the tubesheet, and the total of the circumferential components and any circumferential overlap below 17 inches from the top of the tubesheet as determined in accordance with TS 6.4.Q.3.a, Amendment Nos. --/258

TS 6.6-3a

j. Following completion of a Unit 2 inspection performed in Refueling Outage 21 (and any inspections performed in the subsequent operating cycle), the primary to secondary LEAKAGE rate observed in each steam generator (if it is not practical to assign leakage to an individual SG, the entire primary to secondary LEAKAGE should be conservatively assumed to be from one steam generator) during the cycle preceding the inspection which is the subject of the report, and

k. Following completion of a Unit 2 inspection performed in Refueling Outage 21 (and any inspections performed in the subsequent operating cycle), the calculated accident leakage rate from the portion of the tube below 17 inches below the top of the tubesheet for the most limiting accident in the most limiting steam generator.

1. Following completion of a Unit 1 inspection performed in Refueling Outage 22 (and any inspections performed in the subsequent operating cycle), the number of indications and location, size, orientation, whether initiated on primary or secondary side for each service-induced flaw within the thickness of the tubesheet, and the total of the' circumferential components and any circumferential overlap below 17 inches from the top of the tubesheet as determined in accordance with TS 6.4.Q.3,

m. Following completion of a Unit 1 inspection performed in Refueling Outage 22 (and any inspections performed in the subsequent operating cycle), the primary to secondary LEAKAGE rate observed in each steam generator (if it is not practical to assign leakage to an individual SG, the entire primary to secondary LEAKAGE should be conservatively assumed to be from one steam generator) during the cycle preceding the inspection which is the subject of the report, and-

n. Following completion of a Unit 1 inspection performed in Refueling Outage 22 (and any inspections performed in the subsequent operating cycle), the calculated accident leakage rate from the portion of the tube 17 inches below the top of the tubesheet for the most limiting accident in the most limiting steam generator, 1 ~n" S5 T VAmendment No. 265Y258

Insert F on page TS 6.6-3a

o. Following completion of a Unit I Inspection performed In Refueling Outage 22 (and any other inspections performed in the subsequent operating cycle), for the B steam generator, the number of permeability variation indications including location and total circumferential extent.

Serial No.09-295 Docket No. 50-280 ATTACHMENT 3 Proposed Unit I Technical Specifications Pages Surry Power Station Unit I Virginia Electric and Power Company (Dominion)

TS 3.1-13 C.

RCS Operational LEAKAGE Applicability The following specifications are applicable to RCS operational LEAKAGE whenever Tavg (average RCS temperature) exceeds 200'F (200 degrees Fahrenheit).

Specifications

1.

RCS operational LEAKAGE shall be limited to:

a. No pressure boundary LEAKAGE,

b. 1 gpm unidentified LEAKAGE,

c. 10 gpm identified LEAKAGE, and

d. 150 gallons per day primary to secondary LEAKAGE through any one steam generator (SG), with the following exception. The primary to secondary LEAKAGE for the Unit 1 B steam generator will be limited to 20 gallons per day during Operating Cycle 23.

2.a. If RCS operational LEAKAGE is not within the limits of 3.1.C.1 for reasons other than pressure boundary LEAKAGE or primary to secondary LEAKAGE, reduce LEAKAGE to within the specified limits within 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months .

b. If the LEAKAGE is not reduced to within the specified limits within 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months , the unit shall be brought to HOT SHUTDOWN within the next 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months and COLD SHUTDOWN within the following 30 hours3.472222e-4 days 0.00833 hours 4.960317e-5 weeks 1.1415e-5 months .

3.

If RCS pressure boundary LEAKAGE exists, or primary to secondary LEAKAGE is not within the limit specified in 3.1.C.I.d, the unit shall be brought to HOT SHUTDOWN within 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months and COLD SHUTDOWN within the following 30 hours3.472222e-4 days 0.00833 hours 4.960317e-5 weeks 1.1415e-5 months .

Amendment Nos.

/250

TS 3.1-14a This LCO deals with protection of the reactor coolant pressure boundary (RCPB) from degradation and the core from inadequate cooling, in addition to preventing the accident analyses radiation release assumptions from being exceeded. The consequences of violating this LCO include the possibility of a loss of coolant accident (LOCA).

APPLICABLE SAFETY ANALYSES - Except for primary to' secondary LEAKAGE, the safety analyses do not address operational LEAKAGE. However, other operational LEAKAGE is related to the safety analyses for LOCA; the amount of leakage can affect the probability of such an event. The safety analysis for an event resulting in steam discharge to the atmosphere assumes that primary to secondary LEAKAGE from all steam generators (SGs) is 1 gpm or increases to 1 gpm as a result of accident induced conditions. The LCO requirement to limit primary to secondary LEAKAGE through any one SG to less than or equal to 150 gallons per day is significantly less than the conditions assumed in the safety analysis. Due to the permeability variation indications in the Unit 1 B steam generator found during Refueling Outage 22, the primary to secondary leak rate for that steam generator is limited to 20 gallons per day for Operating Cycle 23.

Primary to secondary LEAKAGE is a factor in the dose releases outside containment resulting from a main steam line break (MSLB) accident. Other accidents or transients involve secondary steam release to the atmosphere, such as a steam generator tube rupture (SGTR). The leakage contaminates the secondary fluid.

The UFSAR (Ref. 2) analysis for SGTR assumes the contaminated secondary fluid is released via power operated relief valves or safety valves. The source term in the primary system coolant is transported to the affected (ruptured) steam generator by the break flow. The affected steam generator discharges steam to the environment for 30 minutes until the generator is manually isolated. The 1 gpm primary to secondary LEAKAGE transports the source term to the unaffected steam generators. Releases continue through the unaffected steam generators until the Residual Heat Removal System is placed in service.

The MSLB is less limiting for site radiation releases than the SGTR. The safety analysis for the MSLB accident assumes 1 gpm total primary to secondary LEAKAGE, including 500 gpd leakage into the faulted generator. The dose consequences resulting from the MSLB and the SGTR accidents are within the limits defined in the plant licensing basis.

The RCS operational LEAKAGE satisfies Criterion 2 of 10 CFR 50.36(c)(2)(ii).

LIMITING CONDITIONS FOR OPERATION - RCS operational LEAKAGE shall be limited to:

a. Pressure Boundary LEAKAGE No pressure boundary LEAKAGE is allowed, being indicative of material deterioration.

LEAKAGE of this type is unacceptable as the leak itself could cause further deterioration, resulting in higher LEAKAGE. Violation of this LCO could result in continued degradation of the RCPB. LEAKAGE past seals and gaskets is not pressure boundary LEAKAGE.

Amendment Nos.

/250

TS 3.1-14b

b. Unidentified LEAKAGE One gallon per minute (gpm) of unidentified LEAKAGE is allowed as a reasonable minimum detectable amount that the containment air monitoring and containment sump level monitoring equipment can detect within a reasonable time period. Violation of this LCO could result in continued degradation of the RCPB, if the LEAKAGE is from the pressure boundary.

c. Identified LEAKAGE Up to 10 gpm of identified LEAKAGE is considered allowable because LEAKAGE is from known sources that do not interfere with detection of unidentified LEAKAGE and is well within the capability of the RCS Makeup System. Identified LEAKAGE includes LEAKAGE to the containment from specifically known and located sources, but does not include pressure boundary LEAKAGE or controlled reactor coolant pump (RCP) seal leakoff (a normal function not considered LEAKAGE). Violation of this LCO could result in continued degradation of a component or system.

d. Primary to Secondary LEAKAGE through-Any One SG The limit of 150 gallons per day per SG is based on the operational LEAKAGE performance criterion in NEI 97-06, Steam Generator Program Guidelines (Ref. 3). The Steam Generator Program operational LEAKAGE performance criterion, in NEI 97-06 states, "The RCS operational primary to secondary leakage through any one SG shall be limited to 150 gallons per day." The limit is based on operating experience with SG tube degradation mechanisms that result in tube leakage. The operational leakage rate criterion in conjunction with the implementation of the Steam Generator Program is an effective measure for minimizing the frequency of steam generator tube ruptures. Due to the permeability variation indications in the Unit 1 B steam generator found during Refueling Outage 22, the primary to secondary leak rate for that steam generator is limited to 20 gallons per day for Operating Cycle 23.

APPLICABILITY --In REACTOR OPERATION conditions where TaVg exceeds 200TF, the potential for RCPB LEAKAGE is greatest when the RCS is pressurized.

In COLD SHUTDOWN and REFUELING SHUTDOWN, LEAKAGE limits are not required because the reactor coolant pressure is far lower, resulting in lower stresses and reduced potentials for LEAKAGE.,

LCO 3.1.C.5 measures leakage through each individual pressure isolation valve (PIV) and can impact this LCO. Of the two PIVs in series in each isolated line, leakage measured through one PIV does not result in RCS LEAKAGE when the other is leaktight. If both valves leak and result in a loss of mass from the RCS, the loss must be included in the allowable identified LEAKAGE.

Amendment Nos.

/250

TS 4.13-1 4.13 RCS OPERATIONAL LEAKAGE Applicability The following specifications are applicable to RCS operational LEAKAGE whenever Tavg (average RCS temperature) exceeds 200'F (200 degrees Fahrenheit).

Objective To verify that RCS operational LEAKAGE is maintained within the allowable limits.

Specifications A.

Verify RCS operational LEAKAGE is within the limits specified in TS 3.1.C by performance of RCS water inventory balance once every 24 hour2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months s-'1 2 B.

Verify primary to secondary LEAKAGE is < 150 gallons per day through any one SG once every-72 hours, with the following exception. The primary to secondary LEAKAGE for the Unit 1 B steam generator will be verified to be < 20 gallons per day during Operating Cycle 23.1 Notes:

1.

Not required to be completed until 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months after establishment of steady state operation.

2.

Not applicable to primary to secondary LEAKAGE.

BASES SURVEILLANCE REQUIREMENTS (SR)

SR 4.13.A Verifying RCS LEAKAGE to be within the Limiting Condition for Operation (LCO) limits ensures the integrity of the reactor coolant pressure boundary (RCPB) is maintained. Pressure boundary LEAKAGE would at first appear as unidentified LEAKAGE and can only be positively identified by inspection. It should be noted that LEAKAGE past seals and gaskets is not pressure boundary LEAKAGE. Unidentified LEAKAGE and identified LEAKAGE are determined by performance of an RCS water inventory balance.

The RCS water inventory balance must be performed with the reactor at steady state operating conditions (stable pressure, temperature, power level, pressurizer and makeup tank levels, makeup and letdown, and RCP seal injection and return flows). The surveillance is modified by two notes.

Note I states that this SR is not required to be completed until 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months after establishing steady state operation. The 12 hour1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months allowance provides sufficient time to collect and process. all necessary data after stable unit conditions are established.

Amendment Nos.

/250

TS 4.13-2 Steady state operation is required to perform a proper inventory balance since calculations during maneuvering are not useful. For RCS operational LEAKAGE determination by water inventory balance, steady state is defined as stable RCS pressure, temperature, power level, pressurizer and

.makeup tank levels, makeup and letdown, and RCP seal injection and return flows.

An early warning of pressure boundary LEAKAGE or unidentified LEAKAGE is provided by the automatic systems that monitor the containment atmosphere radioactivity and the containment sump level. It should be noted that LEAKAGE past seals and gaskets is not pressure boundary LEAKAGE. These leakage detection systems are specified in the TS 3..C Bases.

Note 2 states that this SR is not applicable to primary to secondary LEAKAGE because LEAKAGE of 150 gallons per day cannot be measured accurately by an RCS water inventory balance.

The 24 hour2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months frequency is a reasonable interval to trend LEAKAGE and recognizes the importance of early leakage detection in the prevention of accidents.

SR 4.13.B This SR verifies that primary to secondary LEAKAGE is less than or equal to 150 gallons per day through any one SG, with the following exception. The primary to secondary LEAKAGE for the Unit 1 B steam generator will be limited to 20 gallons per day during Operating Cycle 23.

Satisfying the primary to secondary LEAKAGE limit ensures that the operational LEAKAGE performance criterion in the Steam Generator Program is met. If this SR is not met, compliance with LCO 3.1.H, "Steam Generator Tube Integrity," should be evaluated. The 150 gallons per day limit is measured at room temperature as described in Reference 4. The operational LEAKAGE rate limit applies to LEAKAGE through any one SG.

If it is not practical to assign the LEAKAGE to an individual SG, all the primary to secondary LEAKAGE should be conservatively assumed to be from one SG; for Unit I that leakage should be assumed to be through the B steam generator for Operating Cycle 23. The surveillance is modified by a Note, which states that the Surveillance is not required to be performed until 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months after establishment of steady state operation. For RCS primary to secondary LEAKAGE determination, steady state is defined as stable RCS pressure, temperature, power level, pressurizer and makeup tank levels, makeup and letdown, and RCP seal injection and return flows.

The surveillance. frequency of 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months is a reasonable interval to trend primary to secondary LEAKAGE and recognizes the importance of early leakage'detection in the prevention of accidents. The primary to secondary LEAKAGE is determined using continuous process radiation monitors or radiochemical grab sampling in accordance with the EPRI guidelines (Ref. 4).

Amendment NOs.

/250

TS 4.13-2a I

REFERENCES

1. UFSAR, Chapter 4, Surry Units 1 and 2.

2.

UFSAR, Chapter 14, Surry Units 1 and 2.

3.

NEI 97-06, "Steam Generator Program Guidelines."

4.

EPRI, "Pressurized Water Reactor Primary-to-Secondary Leak Guidelines."

Amendment Nos.,

/250

TS 6.4-13 components exceeds 94 degrees, then the tube shall be removed from service.

When the circumferential components of each of the flaws are added, it is acceptable to count the overlapped portions only once in the total of circumferential components.

b.

For Unit 1 Refueling Outage 22 and the subsequent operating cycle, tubes with flaws having a circumferential component less than or equal to 203 degrees found in the portion of the tube below 17 inches from the top of the tubesheet and above 1 inch from the bottom of the tubesheet do not require plugging.

Tubes with flaws having a circumferential component greater than 203 degrees found in the portion of the tube below 17 inches from the top of the tubesheet and above 1 inch from the bottom of the tubesheet shall be removed from service.

Tubes with service-induced flaws located within the region from the top ofthe tubesheet to 17 inches below the top of the tubesheet shall be removed from service. Tubes with service-induced axial cracks found in the portion of the tube below 17 inches from the top of the tubesheet do not require plugging.

When more than one flaw with circumferential components is found in the portion of the tube below 17 inches from the top of the tubesheet and above I inch from the bottom of the tubesheet with the total of the circumferential components greater than 203 degrees and an axial separation distance of less than I inch, then the' tube shall be removed from service. When the circumferential components of each of the flaws are added, it is acceptable to count the overlapped portions only once in the total of circumferential components.

When one or more flaws with circumferential components are found in the portion of the tube within 1 inch from the bottom of the tubesheet, and the total of these circumferential components exceeds 94 degrees, then the tube shall be removed from service. When one or more flaws with circumferential components are found in the portion of the tube within 1 inch from the bottom of the tubesheet and within 1 inch axial separation distance of a flaw above 1 inch from the bottom of the tubesheet, and the total of these circumferential components exceeds 94 degrees, then the tube shall be removed from service.

When the circumferential components of each of the flaws are added, it is acceptable to count the overlapped portions only once in the total of circumferential components.

c.

For Unit I Refueling Outage 22 and the subsequent operating cycle, tubes in the B steam generator with permeability variation indications that may mask flaws in the bottom one inch of the tubesheet do not require plugging.

Amendment Nos.

/258

TS 6.6-3a

j. Following completion of a Unit 2 inspection performed in Refueling Outage 21 (and any inspections performed in the subsequent operating cycle), the primary to secondary LEAKAGE rate observed in each steam generator (if it is not practical to assign leakage to an individual SG, the entire primary to secondary LEAKAGE should be conservatively.assumed to be from one steam generator) during the cycle preceding the inspection which is the subject of the report, and

k. Following completion of a Unit 2 inspection performed in Refueling Outage 21 (and any inspections performed in the subsequent operating cycle), the calculated accident leakage rate from the portion of the tube below 17 inches

.below the top of the tubesheet for the most limiting accident in the most limiting steam generator.

1. Following completion of a Unit 1 inspection performed in Refueling Outage 22 (and any inspections performed in the subsequent operating cycle), the number of indications and location, size, orientation, whether initiated on primary or secondary side for each service-induced flaw within the thickness of the tubesheet, and the total of the circumferential components and any circumferential overlap below 17 inches from the top of the tubesheet as determined in accordance with TS 6.4.Q.39 mn. Following completion of a Unit I inspection performed in Refueling Outage 22 (and any inspections performed in the subsequent operating cycle), the primary to secondary LEAKAGE rate observed in each steam generator (if it is not practical to assign leakage to an individual SG, the entire primary to secondary LEAKAGE should be conservatively assumed to be from one steam generator) during the cycle preceding the inspection which is the subject of the

report,

n. Following completion of a Unit 1 inspection performed in Refueling Outage 22 (and any inspections performed in the subsequent operating cycle), the calculated accident. leakage rate from the portion of the tube 17 inches below the top of the tubesheet for the mos t limiting accident in the most limiting steam generator, and Amendment Nos.

/5

/258

TS 6.6-3b I

o.

Following completion of a Unit I inspection performed in Refueling Outage 22 (and any other inspections performed in the subsequent operating cycle), for the B steam generator, the number of permeability variation indications including location and total circumferential extent.

Amendment Nos.

Serial No.09-295 Docket No. 50-280 ATTACHMENT 4 Westinghouse Letter LTR-SGMP-09-63, dated May 4, 2009 Virginia Electric and Power Company (Dominion)

Surry Power Station Unit I

Westinghouse Non-Proprietary Class 3 O Westinghouse To: D. Rogosky C. Nitchman cc:

D.A. Testa C.D. Cassino Date: May 4, 2009 G.W. Whiteman J.T. Kandra From:

Steam Generator Management Programs Ext 724-722-5082 Fax:

724-722-5889 Your retf Our ref: LTR-SGMP-09-63

Subject:

Assessment of Tube-end Indications at Surry Unit I

Reference:

This letter documents (an effort performed at the request of Dominion (Surry Unit 1) to provide a technical basis to suJpport an emergency change request to the plant's technical specifications.

Specifically, during the April-May 2009 inspection of Surry Unit 1, permeability variations were found at the tube-ends during the inspection to satisfy the conditions of the Interim Alternate Repair Criteria which were licensed for use at Surry. Permeability variation signals maymask real indications of degradation; therefore, if not resolved by Eddy Current techniques, the permeability signals must be considered real degradation. This evaluation addresses such a condition.

Information was provided by the plant regarding the results of the inspection and this evaluation is based in part on that information.

Please transmit this evaluation to Dominion (Surry Unit 1) through normal project channels.

Hermann 0. Lagally*

Fellow Engineer / SGMP Christopher D. Cassino*

Senior Engineer/ SGMP

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Attachment to LTR-SGMP-09-63 Surry Unit 1: Justification for Leaving Tubes with Tube-end Permeability Signals In Service References

1.

LTR-CDME-08-11, "Interim Alternate Repair Criterion (ARC) for Cracks in the Lower Region of the Tubesheet Expansion Zone", Westinghouse Electric Company, LLC, January 31, 2008

2.

LTR-CDME-08-43, Revision 3, "Response to NRC Request for Additional Information Relating to LTR-CDME-08-11, Revision 3 P-Attachment", Westinghouse Electric Company, LLC, June 3, 2008.

3.

ASME Boiler and Pressure Vessel Code,Section III, "Rules for Construction of Nuclear Power Plant Components," The American Society of Mechanical Engineers, New York, NY, 1989

4. West-13-402, Revision 1, "An Evaluation of the Statistical Variability in the Coefficient of Thermal Expansion Properties of SA508 and Alloy 600," Structural Integrity Associates, Inc., Centennial, CO,,

December 2008.

5.

Mark's Standard Handbook for Mechanical Engineers, 10 th Ed., Editors: E.A. Avallone, T, Baumeister I11, 2007.

A. Introduction During the spring 2009 inspection at Surry Unit 1, under the inspection program required to implement the Interim Alternate Repair Criteria (Reference l and Reference 2) for the tubesheet expansion region, multiple permeability variation signals were reported at the tube-ends in S-B. Permeability variations are not degradation of the tube material; however, if the permeability variations cannot be resolved by eddy current techniques, they may mask signals of real degradation. Therefore, if unresolved, these indications must be treated as if they are indications of actual degradation. The permeability variations were reported at approximately 0.2 inches above the tube ends, consistent with the location of axial and circumferential tube end indications reported at other plants that have applied the IARC. Because the permeability variations may mask signals that would require plugging many of the tubes with these signals, it is necessary to perform an engineering evaluation of this condition.

The data provided for this evaluation was principally through verbal communication which indicated that a large number of tubes in SG-B exhibited permeability indications of circumferential extent exceeding the criteria established In the IARC. Indeed, the indications were stated to be greater than 2700 circumferential extent. For this evaluation, it is assumed that the permeability indications are 100% throughwall circumferential cracks.

References I and 2 provided the technical basis for the Interim Alternate Repair Criteria (IARC) for potential degradation in the lower end of the tubesheet expansion region. The underlying basis of the IARC was that no credit was taken for interaction forces between the tubes and the tubesheet to restrain the tube from pullout from the tubesheet. Axial restraint of the tubes was entirely dependent on showing that a sufficient circumferential ligament remained In the structural load path to restrain the tube from axial motion. Criteria for permissible circumferential flaws were established that apply to either the tube or the

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Attachment to LTR-SGMP-09-63 tube-end weld. The most limiting criterion applies to the tube-end weld, which requires plugging a tube with a circumferential indication greater than 94 degrees.

The basis for the underlying assumption of zero restraining forces due to tube to tubesheet contact was uncertainty regarding whether tube to tubesheet contact forces could exist. From prior analyses, the principal source of tube interaction forces was believed to be differential thermal growth between the tube and the tubesheet. While this was supported by conventional data sources (Reference 3) for coefficient of thermal expansion, some alternate data suggested that it might be possible for the tubesheet material (SA508) coefficient of thermal expansion (CTE) to exceed that of the tubing material (A600). This issue was extensively studied in CTE tests of both materials and it was concluded that the use of the data from Reference 3 was applicable and conservative. Use of the alternate data could not be supported. The results of this study are documented in Reference 4.

Because a viable basis for thermal interaction forces between the tube and tubesheet exists as a result of the verification of the CTE of the tubesheet and tube materials, the underlying assumption of the IARC appears to be overly conservative. Consequently, a study was performed to relate the required circumferential ligament to retain the tube in the tubesheet to assumed values of available retarding forces due to tube to tubesheet interaction and to validate the assumed values of retarding forces by an independent analysis of thermal Interaction forces. The results of this evaluation are contained in the following sections.

B. Inspection Experience for Tube-End Indications It is extremely unlikely that the permeability variation reported at Surry Unit I represent actual tube end degradation. Tube end inspections have been performed by a number of operating plants that have applied the IARC since the spring outages in 2008, including Surry Unit 2. Compared to the number of tube ends inspected, the reported number of tube end indications is small. Among the tube end indications reported, the large majority are axially oriented. Axial flaws'in the lower 4 inches of thetubes are acceptable for continued operation in accordance with the requirements of the IARC. Among the circumferential indications reported, only'a small fraction of them have exceeded the 940 circumferential extent llmit specified by the IARC for indications at, or near, the tube ends. Almost all reported indications have been within 0.3 inch of the tube-end with isolated occurrences at greater distances up to 0.7 inch. No indications have been reported by any plant above 1 Inch above the tube end. Similarly, the indications at Surry Unit I were located predominantly below 0.3 inch from the tube-end with very few exceptions.

C.

Required Structural Ligament as a Function of External Retaining Forces References 1 and 2 provided a calculation of the minimum circumferential ligament required in the tube-proper and in the tube-end weld to restrain the tube from pullout under loading prescribed by the structural integrity performance criteria of NEI 97-06, Revision 2 conservatively applied to the postulated condition of a throughwall circumferential crack at, or near, the tube end. The conclusions documented in Reference 2 were that tubes with circumferential cracks in the tube-end weld should be plugged if their circumferential extent is 940, and that circumferential cracks In the tube a distance removed from the tube-end with circumferential extent of 2030 would require plugging the tube. These values included a growth allowance of 310 for an operating cycle of 18 months; therefore the as-found minimum remaining

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Attachment to LTR-SGMP-09-63 ligaments required to meet the structural performance criteria are 2350 (=3600-940-310) in the weld and 1260 (=3600-2030-31°) in the tube-proper. It is noted that this analysis assumed 100% throughwall conditions for all circumferential flaws.

An analysis was performed using the same methods described in References 1 and 2 to evaluate the required circumferential ligaments if external pullout resisting forces were present. In this analysis, it was assumed that the 3APNOP (4800 psi) loading was applied to the crack face of the, postulated'cracks, but the axial pull-out forces (i.e., end-cap loads) were reduced by an external retarding force assumed to be the result of tube to tubesheet interaction forces. Identically the same parameters used in References I and 2 for 0.875 inch (nominal) tubing diameter with 0.050 Inch (nominal) wall thickness were used in this evaluation.

Figure I shows the results of this evaluation. With zero external retarding force, the figure shows the required ligament of 2350 circumferential extent. As the external retarding force is increased, the required ligament decreases as expected. The figure terminates at approximately 400 required ligament because at this point the external forces are equal to the applied end cap loading under a 4800 psi pressure differential (3 x APNOý= 3 x 1600 psi = 4800 psi) across the tubes. However, it Is still assumed that the 4800 psi loading is applied to the face of the postulated crack; therefore, a further increase of external retarding forces is required to equilibrate the crack face loading. All axial loads that would tend to cause tube ejections are equilibrated with an external retarding force of about 3200 lbf based on the same dimensional parameters used in References I and 2.

Figure I Required Remaining Ligament in the Weld vs. Friction Force 2SO 200 00 0

SO 00 50 100 5

Friction Force (Ibi)

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Attachment to LTR-SGMP-09-63 D. Tube to Tubesheet Interaction Forces and Pullout Resisting Force Contact pressures between the tube and tubesheet are available from an independent analysis of the Model 51F tubesheet complex (channelhead, tubesheet, stub barrel) specific to the Surry plants. This analysis utilizes a comprehensive 3-dimensional (3D) finite element structural model to determine the interaction between the tubes and the tubesheet. Multiple different operating conditions were considered in this analysis, and it was determined that the condition that provides the least contact pressures in the Surry Unit 1 SG is at normal operating conditions (NOP), Low Tavg (Primary Fluid Temperature = 593.7 2F, AP = 1463 psi). Because the IARC applies only to the lower 4 inches of the tubesheet, contact pressures for the lower 4 Inches of the tube were calculated. Table 1 summarizes the unit length contact pressures for axial increments measured from the bottom of the tubesheet for approximately 4 Inches.

Also included In Table 1 are the Incremental axial forces resisting tube pullout and the cumulative axial forces resisting pullout based on a conservative coefficient of friction of 0.2. The equation for calculating axial force is shown in note 1 of the table. It is assumedthat a 3600 circumferential throughwall flaw exists at the tube end. Over the first inch of tube, the predicted contact pressure yields an axial restraining force of 1368 lbs. If it is assumed that all flaws are located at or below 0.5 inch from the tube-end, the incremental resisting force is reduced in the first increment from the tube end.

The coefficient of friction of 0.2 is a lower bounding value based on the open literature. This value is more conservative than the published value for greased Nickel on steel (Reference 5).

It Is concluded from Table 1 that axial friction forces accumulate rapidly primarily due to differential thermal expansion using a conservative value of coefficient of friction, and that the assumption of zero resisting forces is excessively conservative. The results in Table I are bounding for all tubes In the bundle as they were developed for the limiting tube radius in the limiting sector of the tube bundle. All other tube location will have greater axial forces. resisting tube pullout.

Table 1 Predicted Axial Restraining Force from Tube to Tubesheet Interaction Location Contact Coefficient Incremental Incremental Cumulative Axial from Bottom Pressure of Friction Axial Axial Restraining Force of (Pc)

(6)

Restraining Restraining Adjusted for Flaw Tubesheet (psi)

Force (Fr)

Force Adjusted Location (Ibs)

(inch)

(Ibs) for Flaw Location (Ibs) (3) 0 0

0 0'

0 1

2534 0.2 1386 693 693 2

2463 1349 1349 2042 4

2359 28271z' 2 8 2 7(z) 4869 Notes:

1.

Fr = Ri *(7c*d*AI*Pc), where Fr is the resisting axial force, d is the effective tube diameter and Al is the incremental length of tube.

2. This value is the incremental restraining force from 2 inches to 4 inchesabove the bottom of the tubesheet

3.

Flaw located <0.5 inch above the tube end

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Attachment to LTR-SGMP-09-63 An alternate approach Is available based on the same analysis discussed above. The minimum incremental contact pressure for all tubes in the bundle at all axial locations in the tubesheet was predicted to be 928 psi for the limiting operating conditions noted above. The contact pressure varies axially because of integral tubesheet displacement effects due to thermal and pressure loading. This value of contact pressure was validated by a separate 2-dimensional (2D) finite element analysis using the same tubesheet displacement at the location of the minimum contact pressure value from the 3D FEA analysis. The 2D model predicted a value of contact pressure of 877 psi, in close agreement with the 3D analysis results. If a value of contact pressure of 900 psi (approximately the average of the two predictions) is used, the resulting pullout resistance for the unit increment (1 inch) is 506 lbf/Inch. If there are 17 inches of undegraded tube available-the basis of the IARCt-the minimum pullout resisting force is calculated to be 8602 Ibf. If a conservative allowance of 1 inch is made for uncertainty regarding the first point of contact between the tube and the tubesheet at the top of the tubesheet, the pullout resisting force is 8096 Ibf.

It can also be shown, based on the 3D FEA discussed above, that a relatively short length of undegraded tubing, measured from the top of the tubesheet, will equilibrate the maximum loads applied to the tubes in accordance with the performance requirements of NEI 97-06, Revision 2. Contact pressures are predicted over the entire length of the tube in the tubesheet expansion region. If the resulting pullout resisting forces are integrated over the length of the tubing from the top of the tubesheet, It Is predicted that the applied

.load, including all applicable safety factors specified in NEI 97-06, Revision 2, will be effectively resisted by a length of undegraded tube of approximately 6.5 inches when the minimum contact pressure at the limiting position In the bundle is used as the basis of the calculation. RPC inspection of a 20% sample of tubes that exhibited tube end permeability signals in SG-B at Surry Unit 1 confirmed that the tubes are free of defects in the entire length of the tubesheet expansion region. Therefore, a safety factor of greater than 2.5 against tube pullout is available, even if degradation is assumed in the tube below 17 inches from the top of the tubesheet.

E. Impact on SG Reliability The principal intent of the performance criteria of NEI 97-06, Revision 2 is to establish margins against tube burst. A factor of safety of 3 is applied for normal operating loads and a factor of 1.4 is applied for accident condition loads to assure that tube burst does not occur. Accidentinduced leakage is limited to 470 gpd at Surry Unit 1, consistent with the leakage value assumed in the safety analysis.

Under the IARC, the acceptable extent of circumferential flaws is established to prevent tube pullout.

Similarly, a leakage factor of 2.5 is established which is the ratio of the accident induced leakage to the observed normal operating leakage. Application of the leakage factor may lead to adjustment of the administrative leakage limit depending on the plant licensing basis or if a source of leakage other than from the tubesheet region exist in the SGs.

Tube burst is not possible within the tubesheet expansion region due to the constraint provided by the tubesheet. However, for a postulated 3600 circumferential throughwall flaw, the potential for tube pullout is held equivalent to tube burst. Tube pullout for a postulated 3600 circumferential throughwall flaw near the tube-end is not possible. It has been shown by the argument above that significant margins against tube pullout exist due to structural Interaction between the tube and tubesheet even for a postulated 3600 circumferential throughwall flaw. Thesemargins are in addition to the inherent margins due to the load

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Attachment to LTR-SGMP-09-63 requirements form the performance criteria. Further, the additional margins apply specifically to the limiting radius in the limiting sector of the tubesheet. All other locations have significantly greater margins.

Therefore, for a postulated 3600 circumferential throughwall flaws at the tube-ends, there is negligible potential for tube pullout, or tube burst, to occur.

The leakage factor and its application to Condition Monitoring and Operational Assessment as prescribed in the IARC are not affected by the postulate of a 3600 circumferential throughwall flaw near the tube end.

The factor applies to leakage observed from the tubesheet region of the SG without regard to the flaws that result in leakage. If no leakage is observed, no accident induced leakage will be predicted from the tubesheet region. If leakage due to flaws in the lowermost 4 inches of the tubesheet region is observed, the leakage factor is applied as specified In the IARC, Since the leakage factor does not assume any specific type of flaw, a postulated 3600 circumferential throughwall flaw near the tube end will not affect the factor. Therefore, it is concluded that there is no potential for Increased accident induced leakage if the factor is applied as specified in the IARC.

F. Summary and Conclusions

1. It has been shown by materials testing that thermally induced contact pressures exist between the tubes and the tubesheet bores. The hydraulic expansion process utilized in the manufacture of the Surry SGs provides line on line contact between the tube and tubesheet bore surfaces as a minimum.

Therefore, the assumption underlying the IARC - that no friction forces exist to restrain the tube from pullout - is excessively conservative.

2. The limiting criterion established under the IARC - 94o throughwall circumferential flaw at the tube end-is highly sensitive to the available pullout resisting forces. The allowable circumferential extent Increases rapidly if mechanical pullout resisting forces are present.

3. An external pullout resisting force of approximately 3200 lbf permits the acceptable circumferential extent of a throughwall flaw at the tube-end to be 3600.

4. Detailed 3D FEA analyses predict that an axial pullout resisting force of approximately 4869 lbf exists due to thermal interaction and pressure loading in the first 4 inches from the tube-end, assuming that all potential flaws are located at, or less than, 0.5 inch from the tube-end. Therefore, the predicted external retarding forces in less than the first 4 inches from the tube end are sufficient to prevent tube pullout.

5.

Using the minimum predicted contact pressure for any radial or axial position in the tube bundle, the resulting pullout resisting force is 506 lbf/in. Therefore, approximately 6.5 inches of undegraded tubing above a potential circumferential flaw are required to permit the acceptable circumferential extent of a postulated flat to be 3600. Because the minimum predicted axially located contact pressure is used, this conclusion applies for a postulated circumferential flaw at the tube end, and provides reasonable validation of conclusion 4 above.

6.

The methods utilized to assess are based on conservative assumptions and inputs and the results represent the most limiting tube location in the tube bundle. All other locations will have additional margin than shown for the most limiting bundle condition.

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Attachment to LTR-SGMP-09-63

7. Full depth inspection of a significant sample (20%) of the tubes with permeability signals at the tube-ends has shown that the tubes are free of degradation. Therefore, the results of the evaluation of the external retarding forces are applicable for the tubes with permeability variations at the tube-ends.

8.

There is no impact on structural reliability of the SG because sufficient retarding forces are shown to exist to prevent tube pullout under the assumption that a 360 degree circumferential throughwall flaw exists at, or near, the tube-ends.

9. There is no impact on leakage reliability of the steam generator. The leakage factor provided in the licensed IARC for the lowermost 4 inches of the tubesheet does not depend on the source of the leakage in the tubesheet. Therefore, the leakage factor specified in the IARC is not impacted.

10. The structural and leakage performance criteria of NEI 97-06, Revision 2 are satisfied based on this analysis. Tube pullout (assumed to be equivalent to tube burst) cannot occur as a result of the external loading that resists tube motion due to thermal and pressure lockup, including application of the factors of safety specified in NEI 97-06, Revision 2. Application of the leakage factor and appropriate adjustment of the administrative shutdown leakage limit, if necessary, will assure that accident induced leakage does not exceed the leakage assumed on the Surry Unit I safety analysis.

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Serial No.09-295 Docket No. 50-280 ATTACHMENT 5 Summary of Unit I SG Linear Indications, Tube Maps of Permeability Variation Indications, and Summary of Permeability Variation Indications Virginia Electric and Power Company (Dominion)

Surry Power Station Unit I

Unit 1 Steam Generator Linear Indications Refueling Outage R22 I

A Steam Generator Linear Indications SG ID Row Column Indication Volts Location Extent 1A 1

5 SAS 2.12 TEH + 0.10 0.22 1A 1

34 SAS 2.93 TEH +0.13 0.19 1A I

38 SAS 4.82 TEH + 0.11 0.36 1A 1

49 SCI 1.67 TEH + 0.02 174 1A SCI 2.62 TEH + 0.03 1A 1

55 SAS 6.79 TEH + 0.11 0.25 1A 1

57 SAS 2.24 TEH + 0.10 0.28 1A 1

63 SAS 0.96 TEH + 0,08 0.17 1A 1

64 SAS 3.66 TEH + 0.06 0.25 1A 2

31 SCS 0.95 TEH + 0.02 38 1A 1

2 34 SAS 2.67 TEH + 0.08 0.25

.1A 2

62 SAS 2.31 TEH + 0.08 0.24 1A 2

63 SAS 3.41 TEH + 0.08 0.36 1A 3

52 SAS 1.58 TEH + 0.11 0.3 1A 6

61 SC 1.34 TEH + 0.05 118 1A.

SCI 1.21 TEH + 0.04 1A 7

59 SCS 0.73 TEH + 0.06 31 1A 8

56 SCS 1.67 TEH + 0.05 31 1A 8

58 SCS 1.15 TEH + 0.04 45 1A 9

33 MAS 3.13 TEH + 0.11 0.18 1A 9

59 SCS 4.04 TEH + 0.02 80 1A SCS 0.75 TEH + 0.05.

1A 9

69 MAS 2.57 TEH + 0.12 0.15 1A 10 51 SCS 1.48 TEH + 0.00 91 1A 11 1

44 SCS 1.11 TEH + 0.06 28 1A 11 51 SCS 1.03 TEH + 0.01 35 1A 11 54 SCS 2.63 TEH + 0.05 38 1A 12 53 SCS 1.32 TEH + 0.04 49 1A 12 55 SC0 2.33 TEH + 0.02 178 1A 13 I

49 SCS 0.99 TEH + 0.02 38 1A 13 51 SCS 3.78 TEH + 0.02 42 1A 13 52 SCS 1.47 TEH +0.05 28 1A 13 55 SCI 6.59 TEH + 0.01 171 1A SCI 2.82 TEH + 0.01 1A 13 57 SCS 3.96 TEH + 0.04 35' 1A 14 33 SCS 0.86 TEH + 0.00 31 1A 14 55 SCI 1.91 TEH + 0.07 114 1A SCI 1.23 TEH + 0.08 1A SCI 0.85 TEH + 0.06 1A 14 58 SCS 4.51 TEH + 0.05 76 1A 15 51 SCS 0.73 TEH + 0.01 77 1A

-SOS 0.47 TEH + 0.02 1A 16 35 SCS 1.83 TEH + 0.01 45 1A 18 55 SCS 0.98 TEH + 0.05 84 1A 18 58 SCS 2.09 TEH + 0.04 45 1A 19 57 SCS 1.4 TEH + 0.05 59 1A 19 62 SCI 0.8 TEH + 0.34 164 1A 23 49 SCI 3.56 TEH + 0.02 118 1A SCI 0.51 TEH + 0.03 1A 24 51 SCS 1.23 TEH + 0.05 59 1A 25 48 SCS 1.19 TEH + 0.05 70 1A 26 57 SCS 0.98 TEH + 0.05 77 2

A Steam Generator Linear Indications Tube Row 9 Column 69 SG ID Row Column Volts

%Thru-Wall Location 1A 9

69 0.00 0

TSH-0.29 IA 9

69 0.16 89 TSH-0.27 1A 9

69 0.24 88 TSH-0.24 1A 9

69 0.34 93 TSH-0.21 1A 9

69 0.49 98 TSH-0.19 1A 9

69 0.62 100 TSH-0.18 1A 9

69 0.91 80 TSH-0.13 1A 9

69 1.60 76 TSH-0,11 1A 9

69 2.62 88 TSH-0.08 1A 9

69 3.68 96 TSH-0.05 1A 9

69 4.25 96 TSH-0.02 1A 9

69 4.51 92 TSH-0.00 1A 9

69 4.24 92 TSH+0.03 1A 9

69 3.36 84 TSH40.06 1A 9

69 2.46 69 TSH+0.08 1A 9

69 1.52 59 TSH+0.11 1A 9

69 1.07 62 TSH+0.14 1A 9

69 0.72 76 TSH+0.16 IA 9

69 0.47 99 TSH+0.19 IA 9

69 0.38 97, TSH+0.22 1A 9

69 0.32 92 TSH+0.24 IA 9

69 0.22 97 TSH+0.27 1A 9

69 0.00 0

TSH+0.30 3

B Steam Generator Linear Indications SG ID Row Column Indication Volts Location Extent 1B 1

48 SCS 3.02 TEH + 0.07 52 1B 4

40 SCs 0.86 TEH + 0.12 38 1B 4

44 MCS 1.71 TEH + 0.06 63 1B 5

42 MCS 2.15 TEH + 0.00 63 1B 6

12 SCS 1.37 TEH + 0.09 56 1B 6

45 SCS 1.99 TEH + 0.11 45 1B 6

47 SCS 1.53 TEH + 0.09 45 1B 17 46 SCS 1.27 TEH + 0.11 87 1B 18 41 SCS 1.13 TEH + 0.07 31 C Steam Generator Linear Indications SG ID Row Column Indication Volts Location Extent IC 1

16.

SCS 1.15 TEH + 0.02 35 IC 1

29 SCS 0.89 TEH + 0.03 38 IC 1,

i 34 SCS 0.99 TEH + 0.10 31 1C 1

37 SCI 0.66 TEH + 0.06 188 IC 1

I 44 SCI 1.63 TEH + 0.01 318 1C 1

I 45 SCS 2.15 TEH + 0.58 77 1.0 2

I 65 SAS 2.49 TEH + 0.10 0.25 IC 3

31 SCS 1.9 TEH + 0.08 64 IC 3

34' SCS 1.98 TEH + 0.08 35 IC 3

i 60 SAS 4.66 TEH + 0.11 0.37 Ic 4

i 22 SCS 2.15 TEH + 0.07 80 1C 4

i 33 SCI 1.07 TEH +0.05 149 IC S

501 3.04 TEH + 0.07 IC 4

44 SAS 1.55 TEH + 0.13 0.27 IC 4

51 SCS 1.91 TEH +0.08 42 1C 4

I 55 SAS 2.27 TEH + 0.10 0.24 IC 5

57 SAS 1.82 TEH + 0.10 0.21 1C 6

.33 SCS 1.56 TEH + 0.07 66 1C 7

i 84 SCS 3.41 TEH + 0.05 70 IC 8

i 40 SCS 1.56 TEH + 0.02 70 IC 9

57 Sos 1.53 TEH + 0.04 38 1C 10 38 MCS 1.95 TEH + 0.00 73 1C 10 44 SCS 3.15 TEH + 0.02 38 IC 11 i

39 SCI 1.42 TEH + 0.04 98 IC 11 I

54 SCS 1.31 TEH + 0.05 38 IC 11 55 SCS 1.78 TEH + 0.04ý 38 1C 12 39 SCS 0.87 TEH + 0.03 45 1C 12 55 SCS 2.12 TEH + 0.06 69 SC SOS 0.78 TEH + 0.05 1C 14 I

56 SCs 2.06 TEH + 0.05 84 1C I

SOs 0.74 TEH + 0.07 1C 18 42 SCI

-2.72 TEH +0.03 204 IC 22 63 SCS 0.66 TEH + 0.02 56 IC 22 65 ScS 1.07 TEH + 0.06 38 1C 36 50 MAS 1.58 TEH+0.12 0.21 4

Unit 1 B Steam Generator Map Tube End Permeability Variation Indications Refueling Outage.R22 1

GROUP TUBES Surry Unit 1 TubeEnd PV 1243 Tube End PV Indications AR-VAFOMW m omd. Vemlm U S/G B TOTAL TUBES: 3342 COLD SELECTED TUBES: 1243 PRIMARY FACE OUT OF SERVICE (): NA SCALE: 0.084494 X Sun May 03 07:02:19 2009 46-00G0000000-46 00000000D00000000000000 0O00000000000000000O0000000000 0000$000000000~0000000000~0000000000 000000~00000000000000000000D00000000O000 oooaoooooo00@eooooooooo~oo0oooo~o 0c0000000000000000000D000000000D0000000000000000 0000~000000000$00000O00000000000000~000000000000oo000000 000O0000000000$0000000000000000O000000000000Q0c00Q0000Q0000 000000000c0000000000000000000t0O000000~000000000$00000000'000 0000000000000c00000000000000000ooo 00000 0000000000c0000000O0a000O 00000000"00000000OOOOOO00000 0000OOOOOOOOOOOOOOOOo000000OO00 0-OO0O0000000000$0O0000000800egg ggOOg..gG000OO

- 4000o0oo00o 00

~0000000000000000OOO0e 0OsOOOOOOesOOOesseeeOeOOOOOOO00000oooooooooo 30 -GEeeeeeeeeeeeeeee~eE)E.......0*Eee... soo so** ee~e*seeeeeeeeeeeeeeeeeeeeee - 30 O

00000000cDO000000000000OeO0.0c0000000.@.@.

000g0*D0......00000000c00000o0o0 0000O~00O000000DOOOOOOOOOOOOOOOOOOOOOOOOOOOOOOOOOOOOOOOO.OOOOOOOOOOOOOOOOO O0oO0000000000OOOOOOOOOOOOO*eOeOOOOOOO OOOOOOOOOOOOOOOOOOO0000000oo OOO 0000 000OOOOOOOOOOOOOO00000@OOO*OOOOe0OOe

@*O OOOO00OOOO0000 0000000000 0 0000000000000000oo000000*0ooooe eo0e o

oe@@0 S OSSOOO@OOOO.OOO00000000000000O 00000oooo000*000000O0000,000*sg**gog*O0gegoog00004o.000.g.0O00000ooooo0ooooo00000D0 00000000000oo00o000000oooogoo0.o..g.......o0o o

o...oooO00oo0 OOOO0000000000000.OOO 20 0-eeeeeeeeeeeeeeeeeeeeeeeesee~geeeeeeeeeeeeeeeee.....e....e.ee..eeeeeeeeeeeeeee-e..0 2

000000000O000OOO*0000o~eeooooooooooooooegoo..g@0@oOg.

ooo0 oooooooooooooooo G00000000000000000000O 0-0O00000000 o00o00O00o.........O oe o

oo000000oO 00000000

~00 00000cJ0000000000000@06 OOee OOO...*o0

.o*.OOoo.000 go eso@e000000 oeoo00000000oooo 0~000O00000000

@00000000@@@@O0O00oo...oa0o0o@OOOOO.OOOOO00OO O.OO O000000000O000000ocooo 0W000000000a0esg000O0eoeoge0.,o0oogoogooooacooogooo0o..0oo00000.......o...oogoooooo00o 0

o 0

00 OtflO00OO0tD@006@000*0*0*0*0*e00W**0000000000090000000*0000OU.0000~.JgggOggg.....

00.0 0

00 0000006000000D*0*00006

000000000*000000000006.o00o00$00000000000soo.

00000000000000000000 00000000000000000000000000000000*0

. 000*00000000000000000 Q000O000e0g0*00*0*0O0s0e000egg0080ggO0g000..000gO00000000000000..O.o..0....g...00..00O00000000 OOOOOOSO00OOOO~

OgOOeOoo@OeOOOOooeoooogoooooo..g000.

0.o@OOOa@@o@OO....OO.OOOOOOOOOOOoo OOOOOOOO0000eg000000000o00*00.000006000.0000000..0000000 *0*@****00000**********000000000o0000 OOO0cDOOO006000000000000000000e.00.0ceo0e.ooge00000..oooooo.000 0 0 0 0 0 0 '0 000.....o..g 0 0 0 0 0 0 0 0 0 0 0 0 0 00OOOOOO000*00g00*000000g0$00g00000g6g00g0.0.*0.00O0000000..g0g.OO..OOO........Oggooego 0oooooooo OO00000O0*0O00e*0@@0.g00ooDoo0.o00.*ggO000..g0*00oo0000000000~D.*.00..00.0O.00.g0000ooeo00ooooooo 0000G00000S oooo@@00*geo0o00g0ooooooooog@00.gg gogooooo.o...g.sooooooooo..O...

gO..oo~oooooooooo 000 OGOO 0000000eese 0eOQO00000006000000006000000 0000000000000@0000Co00600000000000000000 000000000o 000000000006000000000000000000060000000*000*000000000000*00000000000000000..00000.000000000000o 90 80 70 60 50 40 3

01 MAN WAY NOeZZLeE~ee~e~~e

V J V MANWAY NOZZLE

GROUP TUBES Surry Unit 1 Tube End PV 1056 Tube End PV Indications AP"VA.

DM ýp medA Vwabn 6.

S/G B TOTAL TUBES: 3342 HOT SELECTED TUBES: 1056 PRIMARY FACE OUT OF SERVICE (#):

NA SCALE: 0.084494 X Sun May 03 06:58:44 2009 46-0000000000-46 0000000000000D000000000 000o0000~0000000000o0000000000o0 oc~ooooooooocpoooooooooa~oooooooooo~oooooo 40 -eeeoeeeeeeeeeeeeeeeeeeeeeeeeeeeeeee~eeeeeeeeees-40 oo0000000000000000000oo00000000000o0000oooooo 000ooo00000000000o0000000000ooo0000000000000o0

0o 0000000000000ooo00000000000000ooo0000000oooooooo00000 00000000000000000o0000000000000000000o0000000000o00000 00000000000oo00000000000000000000000000000000000o000000000000 0 000000000000O0000000000000000000000*g00000000000000000000000000 ooo000oooo000000O0000000000000e00e00OOooooo00000000000O00o 0000000000 00000000000000000O0000000000e*00000000000oOOe@0o000000000000o0000000O000 000o0ooo0ooo0000o0ooooooooo00*egseogo0oeeoe0ooo0Oo oooe0g0000000000oo 000o 0o000o00oooo00oooo00 OO*O*Oooeeo0oee 0e@0@e000 oo0g0000o00g@@00000000000000 O-ooooooeoo000eoooO*Seeoe0O00O@s*e@OO oe@ooo~oooooeooeeeeee@oe@eooooooo0OOOOOO o4o00000ooo0oo000000@000oosooooeeeoeeee

@oeeeoooooooo00@@o@

0ooooooo000o0000 OO00000000000000000000*00@S@O*0000000eue0@S00 0O*0000O000OOO**000000000000000 000000000000o0a0*.*.000**..e*.o...**..eee..O0sess0e*.*.*0O..000OS0O00000a00000000 2 0-e o0000000e0e*soooosg**0o0oeee000000soeeeeOoooooosoegeee.

e.o0000000O0000000000 OOOO0eOOOOOO0000S.O*000e 000@@00*0*O OOOO00.0.eeoooo@oo 0.eQ00000.0G*e0000000DO00000000 00000000oo00000000o.~00...00.00@.000oJO..eo000*0c0O.00..000000@0S.c00@@O000000000000000 000000O0000000OS@*00O@*@oOOSO00@Se00O0000000000@000~oS@0eSS*0@**S000@0000G0000000000D00 00000000000*00040000000000000000000000e0ee...000eeD0.oOO0c000000000U?0e0ege00000000cDo~OO~

ooooooo00000oo.0..0o 0 *.ooo@*ooo...e. sooe0eooe sosoooooooooo0s...ee oooeOOocbOOOOOOOOO0oO ooooooo0oooo000oe0o0o0ee0*eoooooooooe**000De0e..ec0s0@*o0ooeoeee0Oe)O OOO.OOOOOOOOOOOOOO(D 00000O0000$00000OO0e$*0@*0QOOO0O@0sse0e@*.eo@S00SOO000000@0OU0SO00.s0@00*ooo00oooD000000000~00 0000000000oo0oo..o.*0o**odo*.oo.**.*00oooo0ooo0o000oO**oa000o0o*0*U000OO000eO000000000c~00 000000b00000O*0*,OO0OS0 0000000000S0S.000000~TO00OO000OO*@O@U0000000O0000000000000000000D000 000000000000 0ooooO0eee0ss0oeooee 0oeo...o00oeooou~oooooeoooooeoo00

~eee0000*000000000000000 000000000000000000ee*00se000000o0e0O0e.0oooo.00~00.*00000.0De000e00.eO@O@000OS0000000000000O000 OOOOOQOO$O0000000*OO*0000S0000@gDOOOgOOoOSc6000000000SO@00000000000000000000.00000000000o)000000 00000000000000000600eeOeeOO0eOc~eogoo~e@e*0OOOOOgOOeDOOO@00@eOS*000000s0*000*@000.ee00000000000000 000000000000900SSOSO00OOe000@@.goooeoocDoo0e0g0eO@ODO000.00@.0.000000O00@@00@000@OC0000O0000000000 000000000$00000000.s00eoe000000geo000.00.00000gososooocooooosoo..eoeoseeeesuoeseOOOQooo00c0oooO 00000000000*0ouooogego**o0o**o**ogoeooeegoooooooo0o60000000ggog00oo*****gg00e000000000ooa00000 10 20 30 40 50 60 70 80 90 NOZZLE MAN WAY*@*@*

NOZZLE MANWAY

Table of Unit I B Steam Generator Hot Leg Permeability Variation Indications Refueling Outage R22 I

Summary Unit I B Steam Generator Hot Leg Permeability Variations ROW 1

1 1

1 COL 6

14

15 16 17 19 20 21 22 23 25 27 29 30 31 32 33 35 36 37 38 43 44 46 62 63 65 66 69 70 71 72 73 74 75 76 78 79 80 84 85 15 16 17 19 20 21 22 23 25 26 29 30 33 35 36 VOLTS 2.00

1.56 9.65 9.26 18.42 3.10 9.18 14.38 4.62 13.45 16.68 1.16 10.32 7.24 5.23 2.33 2.20 3.07 9.71 8.19 10.84 5.62 5.06 2.34 1.69 6.32 2.96 7.76 10.13 2.80 1.46 10.58 1.65 6.55 8.05 8.81 2.65 1.26 11.83 7.48 4.83 7.81 6.17 5.04 18.87 2.43 19.91 12.86 9.64 16.90 19.10 15.94 1.39 8.93 1.24 15.03 10.82 DEG IND 46 PVN 93 PVN 72 PVN 62 PVN 69 PVN 78 PVN 54 PVN 68 PVN 88 PVN 70 PVN 59 PVN 60 PVN 78 PVN 70 PVN 48 PvN 80 PVN 51 PVN 70 PVN 64 PVN 49 PVW 63 PVN 52

'PVN 81 PVN 49 PVN 35 PVN 61 PVN 55 PVN 75 PVN 56 PVN 34 PVN 29 PVN 63 PVN 63 PVN 69 PVN 65 PVN 49 PVN 73 PVN 75 PVN 52 PVN 68 PVN 89 PVN 66 PVu 66 PVN 83 PVN 78 PVN 69 PVN 59 PVN 60 PVN 73 PVN 68 PVN 66 PVN 75 PVN 48 PVN 74 PVN 65 PVN 65 PVN 45 PVN 9sTW LOCATION TEH

+0.06 TEH

+0.02 TEH

+0.07 TEH

+0.02 TEH

+0.16 TEH

+0..07 TEH

+0.02 TEH

+0.09 TEH

+0.05 TEH

+0.20 TEH

+0.17 TEH

+0.13 TEH

+0.12 TEH

+0.01 TEH

+0.05 TEH

+0.12 TEH

+0.07 TEH

+0.09 TEH

+0.05 TER

+0.03 TEH

+0.04 TEH

+0.02 TEH

+0.08 TEE

+0.03 TER

+0.01 TEE

+0.01 TEH

+0.06 TEH

+0.04 TEH

+0.01 TER

+0.00 TEH

+0.o0 TEH

+0.02 TEH

+0.01 TEH

+0.01 TEE

+0.04 TEH

+0.06 TER

+0.04 TEH

+0.02 TEH

+0.06 TEH

+0.11 TER

+0.04

TER

+0.09 TER

+0.02 TER

+0.07 TEH

+0.13 TEE

+0.01 TEE

+0.11 TEH

+0.10 TER

+0.02 TEE

+0.05 TEE

+0.02 TER

+0.05 TER

+0.12 TER.

+0.06 2

EXT EXT TEE TEH TEH TEH TER TEE TEH TEE TEE TEH TEH TEH TEH TEH TEH TEH TRH TEH TEH TE-TEH TEE.

TEH TEH TEH TEH TEH TEH TER TEH TEE TEH TEH TEH TEH TEH TEH TEH TEH TEH TEH TEH TEH TEE TEH TEH TEH TEH TEH TEH TEH TEH TEE TEH TEH TEH TEH TEH TEH TEH TEH TEH TEH TEH TEH TEH TEH TEH TEH TEH TEH TEH TEH TEH TEH TEE TEH TEE TEH TEH TER TEE TER TEH TEE TEH TER TEH TEE TEH TEH TEH TEH TEH TEH TEH TEH TEH TEH TEH TEH TEH TEH. TEH TEH TEH TEH TEH TEH TEH TEH TEH

.TEH TEH Circ.Extent 249 276 231 290 129 73 187 238 125 80 157 101 143 245 283 136 199 234.

294 280 178 190 128 95 95 93 101 133 211 62 305 339 118 90 294 204 100 114 190 252 104 104 101 183 175 84 280 325 242 98 147 322 147 190 161 276 287 I

2 2

2 2) 22 2

2 3

3 3

3 33.

4 4

37 40 43 44 59 60 62 63 65 66 67 69 70 71 72 73 74 75 76 78 79 80 11 15 16 17 19 20 21 22 26 28 30 32 35 36 37 38 42 44 46 47 48 49 51 55 58 59 60 62 69 70 71 73 74 75 78 79 80 12 14 5.68 1.20 2.55 7.59 5.49 11.37 1.85 4.05 3.74 11.23 15.46 5.72 5.32 12.88 1.49 11.32 6.72 11.26 2.02 10.05 21.09 2.95 8.44 13.87 15.45 13.25 7.00 0.84 6.67 9:38 6.47 0.76 7.13 0.66 18.17 2.53 10.54 13.10 4.09 4.09 6.19 11.12 13.44 11.52 8.54 6.78 9.70 4.21 3.10 8.56 11.04 11.87 9.63 13.53 7.03 9.38 16.22 0.84 2.42 13.00 6.76 54 47 49 77 50 72 52 36 65 82 64 63 77 69 70 70 75 64 41 54 61 62 77 58 74 70 74 72 60 71 49 57 66 55 63 51 59 62 69 37 59 62 57 67 61 59 59 56 61 59 68 69 63 76.

77 63 75 74 60 66 67 PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVx PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVI*

PVN PVN PVN PVN TEN TEE TEN TER TEH TEH TEH TEH TEH TEE TEE TEN TEN TEH TEH TEN TEH TEE TEN TEN TEN TEN TEN TEH TEN TEH TEE TEE TEH TEH TEE TEE TEE TEH TEH TEE TEH TEN TEH TEE TEH TEN TEE TEE TEE TEH TEH TEH TEE TEE TEH TEH TEN TEH TEN TEH TEH TEE TEN TEH TEH

+0.09

+0.06

+0.10

+0.01

+0.00

+0.034

+0.04

+0.08

+0.03

+0.06

+0.01

+0.05

+0.07

+0.06

+0.08

+0.06

+0.02

+0.01

+0.09

+0.08

+0.01

+0.03

+0.00

+0.03

+0.07

+0.06

+0.02

+0.05

+0.02

+0.07

+0.02

+0.08

+0.01

+0.16

+0.00

+0.11

+0.09

+0.01

+0.02-

+0.06

+0.11

+0.05

+0.07

+0.06

+0.04

+0.03

+0.01

+0.00

+0.04

+0.07

+0.08

+0.06

+0.03

+0.06

+0.05

+0.03

+0.09

+0.06

+0.01

+0.05 TEH TEH TEN TEN TEH TEH TEN TEN TEH TEN TEH TEN TEN TEE TEH TEN TEE TEN TEE TEN TEN TEE TEH TEE TEH TEH TEN TEN TEH TEE TEN TEH TEH TEN TEN TEE TEH TEE TEE TEE TEE TEN TEN TEN TER TEN TEE TEH TEN TEH TEN TEE TEH TEN TEE TEE TEH TEH TEN TEE TEE TEN TEE TEH TEN TEH TEH TEH TEH TEH TEN TEH TEN TEH TEH TEN TEN TEN TEH TEH TEN TEH TEH TEH TEN TEN TEN TEN TEH TEN TEN TEH TEN TEN TEN TEN TEH TEH TEN TEN TEH TEH TEH TEH TEN TEN TEH TEH TEH TEN TEN TEE TEN TEH TEN{ TEN TEN TEH TEH TEH 320 62 178 119 101 255 40 164 108 183 136 70 142 196 253 199 315 235 194 132 241 252 115 178 318 217 164 318 330 248 329 178 164 73 245 252 320 126 136 119 252 140 112 168 115 206 178 101 206 208 121 210 256 267 182 183 157 260 235 187 152 3

15 16 17 20 21 22 26 27 29 31 33 34 35.

36 37 38 46 47 48 49 54 57 58 59 60 62 66 69 70 71 72 73 74 75 78 79 80 6

12 15 16 17 20 21 22 23 24 27 30 31 36 37 38 39 48 54 57 58 59 61 14.24 8.13 16.57 5.'15 11.24 12.49 8.35 10.29 2.51 1.07 13.71 1.40 3.05 3.45 13.25 4.46 8.92 2.34 8.59 10.19 9.01 8.85 14.46 3.82 8.41 5.26 11.57 16.70 11.39 11.93 9.49 0.39 15.94 11.25 16.89 9.48 14.23 4.89 5.90 14.25 10.24 8.65 16.95 2.31 12.07 7.36 12.31 3.12 13.41 12.52 10.55 6.09 8.61 3.01 16.78 3.14 2.87 1.00 3.18 10.94 8.75 53 82 63 71 72 77 74 45 59 53 67 76 69 42 64 72 57 77 65 75 77 58 59 75 61 69 66 64 65 61 56 43 61 61 69 52 64 63 76 63 45 60 55 75 72 69 62 65 75 76 66 71 83 53 60 39 67 70 50 69 65 PVN PVx PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN

.PVN PVN PVN PVN PVN PVN PVN PVN PVN

.PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVw PVN TEH TEH TEH TEH TEH TEH TEH TEH TEH TEH TEH TEH TEH TEH TEH TEH TEH TEH TEH TEH TEH TEH TEH TEH TEH TEH TEH TEH TEH TEH TEH TEH TEH TEH TEH TEH TEH TEH TEH TEH TEH TEH TEH TEH TEH TEH TEH TEH TEH TEH TEH TEH TEH TEH TEH TEH TEH TEH TEH TEH TEH

+0.04

+0.01

+0.11

+0.00

+0.01

+0.12

+0.01

+0.11

+0.17

+0.13

+0.12

+0.02

+0.16

+0.02

+0.05

+0.08

+0.04

+0.03

+0.02

+0.01

+0.00

+0.02

+0.04

+0.06

+0.04

+0.07

+0.01

+0.05

+0.08

+0.01

+0.04

+0.08

+0.01

+0.02

+0.01

+0.04

+0.02

+0.07

+0.05

+0.02 40.03

+0.02

+0.08

+0.03

+0.02

+0.04

+0.05

+0.00

.+0.06

+0.15

+0.06

+0.07

+0.01

+0.04

+0.02

+0.01

+0.08 TEH TEH TEH TEH TEH TEH TEH TEH TEH TEN TEH TEH TEH TEH TEH TEH TER TEH TEH TEH TEH TEH TEH TEH TEN TEH TEH TEH TEH TER TEH TEH TEH TEH TEH TEH TEH TEH TEH TEH TEH TEH TEH TEH TEH TEH TEH TEH TEH TEH.

TEH TEH TEH TEH TEH TEH TEH TEH TEH TEH TEH TEN TEH TEH TEN TEH TEH TEH TEH TEH TEH TEH TEH TEH TEH TEH TEH TEH TEH TEH TEH TEH" TEH TEH TEH TEH TEH TEH TEH TEH TEH TEH TEH TEH TEH TEH TEH TEH TEH TEH TEH TEH TEH TEH TEH TEH TEH TEH TEH TEH TEH TEH TEH TEH TEH TEH TEH TEH TEH TEH TEH TEH 231 156 227 94 66 329 218 343 66 175 105 147 87 147 150 273 159 87 227 182 164 101 143 136 248 103 234 215 300 235 108 180 360 318 206 215 224 49 204 231 196 267 196 231 300 145 129 52 203 199 154 217 101 320 91 105 161 66 261 227 83 4

5 5

6 5

5 6

6 6

6 66 6

6 7

7 77 7

7 7

.7 7

7 62 66 68 69 70 71 72 73 74 75 78 79 8o 14 15 16 17 20 21 22 23 26 27 29 31 33 35 38 39 50 53 58 61 65 68 69 70 71 72 73 74 78 79 15 16 17 18 20 21 22 23 24 26 27 31 1.97 8.84 1.29 17.72 11.04 9.77 15.17 10.07 12.06 5.09 17.13 1.88 1.66 3.47 11.03 3.01' 13.98 11.01 13.90 14.22 6.82 12.28 9.91 25.21 16.85 1.28 9.73 1.23 14.79 15.09 5.63 2.82 3.58 10.93 8.95 1.91 10.47 9.18 10.06 13.07 12.01 9.33 6.79 9.65 13.02 11.14 7.85 15.95 16.42 28.47 1.38 11.62 11.24 16.70 13.60 16.07 8.50, 25.70 24.05 10.53 7.75 65 57 29 55 58 57 68 64 65 67 70 83 46 58 63 93 65 37 71 50 71 73 62 68 7-1 53 69 46 77 64 74 35 63 59 61 69 91 56 76 68 67 81 65 48 65 73 77 42 74 62.

76 62 65 63 65 70 60 62 57 60 68 PVN PVN PVN PVN PVN' PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVm PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN" PVN PVN PVN PVN PVN PVN PVN PVN TER TEH TEM TEH TEH TER TEH TEH TEH TER TEH TEN TEH TEH TER TER TEH TEH TER TER TEH TEE TEH TEN TEH TEH TEH TEN TEN TEH TEN TEN TEN TEN TEH TEH TEN TEE TEH TEH TEH TEN TEE TEE TEN TEN TEN TEN TEE TEN TEH TEN TEN TEN TEH TEN TEN TEH TEN TEN TEH

+0.03

+0.02

+0.03

+0.06

+0.08

+0.04

+0.01

+0.05

,+0.04

+0.03

+0.07

+0.06

+0.04

+0.01

+0.07

+0.03

+0.05

+0.02

+0.04

+0.01

+0.13

+0.05

+0.01

+0.10

+0.08

+0.14

+0.06

+0.10

+0.04

+0.01

+0.04

+0.08

+0.05

+0.06

+0.07

+0.02

+0.04

+0.05

+0.01

+0.06

+0.01

+0.00

+0.04

+0.02

+0.02,

+0.00

+0.05

+0.00

+0.04

+0.03

+0.04

+0.05

+0.04

+0.02

+0.05

+0.03

+0.02

+0.10

+0.03 TEN TEN TEH TEE TEN TEN TEN TEE TEN TE1 TEE TEE TEE TEH.

TEE TEN TEN TEE TEN TEH TEH TEN TEE TEE TEN TEN TEH TEH TEN TEN TEN TEH TEE TEN TEN TEH TEN TEN TEN TEE TEE TEE TEN TEN TEN TER TEN TEN TEN TEN TEN TEN TEN TEN TEN TEN TEE TEH TER TEN TEN TEN TEH TEN TEN TEH TEN TEH TEH TEH TEN TEN TEE TEN

'JEH TEH TEH TEN TEN TEH TEN TEN TEN TEN TEN TEN TEH TEH TEN TEN TEN TEN TEN TEH TEH TEN TEN TEN TEN TEN TEN TEN TEN TEH TEN TEN TEN TEN TEN TEN TEN TEN TEN TEN TEN TEN TEN TEN TEN TEN TEN TEN 45 121 38 263 276 149 59 284 133 152 217 208 173 122 149 122 360 189 256 304 187 80 217 3-01 262 115 213 140 238 360 276 112 77 203 163 52 142 360 246 227 138 360 249 280 220 182 135 180 129 157 90.

161 241 263 217 147 108 122 125 308 91 5,

7 32 5.24 60 PVN TER

+0.01 TER TEH 132 9.57 63 PVN TER

+0.03 TEN TEN 136 7

36 2.25 37 PVN TER

+0.10 TER TEN 266 7

37 11.63 64 PVN TEH

+0.04 TEH TEH 185 7

38 3.09 38 PVN TEN

+0.09 TEN TEN *196 7

39 5.48 45 PVN TEN

+0.06 TEN TEN 360 7

40 2.30 62 PVN TEN

+0.16 TEH TEH 266 7

57 10.98 76 PVN TEH

+0.07 TEN TEN 227 7

60 3.57 62 PVN TEN

+0.00 TEN TEN 101 7

61 5.05 59 PVN TER

+0.06 TENTEN 163 7

65 15.50 69 PVN TEH

+0.03 TER TEN 322 7

68 9.51 58 PVN TEH

+0.02 TEN TEH 239 7

69 6.94 70 PVN TEH

+0.07 TEN TEN 270 7

70 15.88 67 PVN TEH

+0.03 TER TEH 241 7

71 1.24 41 PVN TER

+0.02 TEN TER 104 7

72 9.41 67 PVN TEN

+0.04 TEN TEN 192 7

73 7.01 52 PVN TER

.+0.08 TEN TEN 322 7

74 10.01 68 PVN TEH

+0.03 TEN TEN 126 7

77 9.57 66 PVN TEN

+0.05 TEN TEH 59 7

78 10.18 56 PVN TER

+0.05 TEN TEN 360 7

79 2.68 51 PVN TEH

+0.08 TEN TEN 253 8

15 1.98 46 PVN TEN

+0.05 TEN TEN 118 8

16 13.62 82 PVN TEN

+0.02 TEN TEH 330 8

17 7.09 65 PVN TEN

+0.09 TEN TEN 118 8

18 7.35 69 PVN TEN

+0.10 TEN TEN -171 12.94 64 PVN TEN

+0.06 TEN TEN 201 8

22 8.66 62 PVN TEN

+0.04 TEN TEN 211 8

23 7.70 78 PVN TEN

+0.10 TEN TEH 59 8

24 7.65 65 PVN TEH

+0.04 TEN TEN 98 16.68 69 PVN TEN

+0.04 TER TEN 135 8

27 14.40 84 PVN TEN

+0.11 TEN TEN 304 8

28 9.26 64 PVN TEH

+0.07 TEN TEN 145 8

29 1.84 42 PVN TEN

+0.08 TEN TEN 224 8

32 4.41 78 PVN TEH

+0.01 TEN TEN 152 8

36 11.48 84 PVN TER

+0.01 TEN TEN 168 8

38 6.38 69 PVN TEN

+0.04 TEN TEN 80 8

39 9.37 45 PVN TER

+0.00 TEH TEN 239 8

40 4.73 73 PVN TEH

+0.07 TEN TEN 276 8

41 14.57 55 PVN TEN

+0.01 TEN TEN 294 8

57 6.00 47 PVN TEN

+0.05 TEH TEH 157 8

60 8.13 64 PVN TEH

+0.07 TEH TEH 275 8

61 2.82 66 PVN TER

+0.00 TEH TEN 87 8

65 11.39 74 PVN TEH

+0.03 TEH TEN 224 8

67 11.88 79 PVN TEH

+0.03 TEN TER 80 8

68 4.79 63 PVN TER

+0.06 TEN TEH 225 8

69 5.99 60 PVN TEH

+0.03 TEN TEN 360 8

70 5.14 60 PVN TEH

+0.03 TEN TEN 149 8

71 7.73 67 PVN TEN

+0.01 TEN TEN 63 8

72 6.39 54 PVN TER

+0.05 TEN TEN 312 8

73 10.72 64 PVN TEH

+0.01 TEN TER 192 8

74 5.29 70 PVN TEN

+0.00 TEN TEN 48.

8 77 20.06 68 PVN TER

+0.03 TEN TEN 168 8

78 1.89 51 PVN TEN

+0.10 TEN TEH 239 8

79 12.82 75 PVN TEN

+0.01 TEN TEN 231 9

15 3.54 56 PVN TEN

+0.01 TEN TEN 84 9

16 8.97 81 PVN TEN

+0.08 TEN TEN 322 9

17 13.53 40 PVN TEN

+0.01 TEN TEN 290 9

18 8.47 84 PVN TEN

+0.03 TEN TEH 196 9

21 7.47 65 PVN TEN

+0.02 TEN TEN 199 9

22 16.46 62 PVN TEH

+0.03 TEN TEN 291 9

23 11.12 67 PVN TEN

+0.05 TEH TEH 190 6

9 9

9, 9

9 9

9 99 9

10 10 10 10 10 10 10 10 10 10 10 10 10 10 10 10 10 10 10 10 10 10 10 10 10 10 10 10 10 10 10 10 1o 10 10 10 11 11 24 27 28 32 33 36 37 38 39 40 55 59 60 67 68 69 71 73 74 77 78 79 15 16 17 18 19 21 22 23 24 26 28 29 31 33 34 38 39 40 41 42 54 55 56 58 59 64 66 67 68 69 71 72 73 77 78 79 16 17 26.17 10.88 9.24 19.72 12.20 4.47 1.96 6.40 17.20 9.83 15.99 15.13 15.94 16.23 5.95 14.91 8.95 7..20 7.42 15.43 8.53 12.10 9.16 19.71 10.09 8.42 17.54 14.88 6.21 14.60 12'.58 2.38 10.98 14.44 1.18 11.42 8.38 12.14 3.13 10.60 9.74 6.63 12.37 4.39 3.71 4.02 8.72 14.38 15.81 14.08 11.03 6.07 13.41 6.01 9.79.

15.28 6,67 7.51 6.94 7;.77 8.84 59 72 84 65 63 52 53 49 66 78 56 63 66 72 67 70 78 63 76 57 75 78 72 65 69 74 54 73 91 67 72 70 71 65 60 54 54 58 54 57 60 62 67 62 84 62 73 64 65 78 51 67 72 72 76 60 82 56 72 64 68 PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PmN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PvN PVN PVN PVN PVN PVN TEN TEN TEH TEN TEN TER TEH TER TEH TEN TEH TEN TEN TER TEN TEN TEN TER TEH TEN TER TER TER TER TEN TEH TEN TER TEl TEH TEH TEH TEH TEH TEH TEH TEH TEN TER TEN TEH TEN TEH TEH TEN TEN TER TEN TEN TEN TER TER TEH TEN TEN TER TEH TEN TEN TER TER

+0.19

+0.06

+0.14

+0.15

+0.07

+0.06

+0.05

+0.08

+0.03

+0.01

+0.00

+0.06

+0.00

+0.04

+0.09

+0.05

+0.03

+0.07

+0.03

+0.01

+0.03

+0.05

+0.07

+0.05

+0.04

+0.12

+0.13

+0.03

+0.13

+0.03

+0.01

+0.04

+0.15

+0.07

+0.14

+0.02

+0.06

+0.02

+0.07

+0.05

+0.10

+0.03

+0.01

+0.07

+0.04

+0.06

+0.07

+0. 02

+0.05

+0.02

+0.04

+0.01

+0.04

+0.05

+0.04

+0.10

+0.04 TEN TER TEN TEN TEN TEN TEN TEN TER TEN TEN TEN TER TEN TEN TEN TER TER TER TEN TEN TER TEN TEN TEH TEN TEN TEH TEH TEN TEH TEN TEH TEN TEN TEN TEN TEN TEN TEH TEN TEN TEH TER TEN TEH TEN TEH TEH TEH TEN TEN TEH TEN TER TEN TER TER TEH TER TEN TEN TEN TEN TER TEN TER TEN TEN TEN TER TEN TEN TEN TEN TEN TEN TEN TEN TEH TEN TEN TSH TEN TEN TER TEN TEN TEN TEN TEN TER TEN TEN TEN TEN TEN TEH TER TEN TEH TEH TEN TEH TEN TEH TEH TEH TEH TEH TEH TEN TEN TEH TER TER TEN TEN TEN TEN TEN TEN 189 118 304 276 175 182 42 269 255 280 238 241 269 199 135 332 100 322 108 267 164 199 119 196 168 173 126 203 187 276 320 100 248 164 259 192 119 152 62 276 260 232 150 234 140 175 189 227 256 83 350 180 231 87 166 220' 300 266 48 206 238 7

11 12 12 12 12 12 12 12 11 11 11 11 11 12 12 12 12 12 1i ii 11 11 11 11 11 11 11 11 11 11 11 11 11 11 11 11 11 11 11 12 12 12 12 12 12 12 12 12 12 12 12 12 12 12 12 12 12 18 19 21 22 23 24 25 26 28 29 30 33 34 35 37 38 39 41 42 43 44 45 46 47 49 51 54 55 57 58 62 63 66 67 68 70 71 72 73 76 77 16 17 18 19 20 25 26 27 29 30 33 34 35 36 38 39 41 42 1.55 18.28 3.44 11'.63 16.20 11.59 17.29 6.29 20.92 15.62 9.67 13.14 6.33 15.87, 1.23 3.73 7.71 8.25 14.20 7.38 14.76 13.68 12.02 10.56 1.88 13.42 2.98 2.57 10.42 10.67 6.74 1.91 7.93 9.80 9.76 9.40 8.40 9.11 3.63 13.99 15.25 12.90 10.18 5.79 17.72 11.69

13. 27 15.96 1.34 8.56 27.15 12.35

.21.53 5.33 19.11 8.85 19.55 2.30 5.25 5.88 8.60 33 61 70 69 63 80 65 61 75 77 64 68 64 71 86 56 74 57 69 60 62 71 58 52 36 68 52 45 72 60 75 67 56 57 76 70 61 57 56 80 58 69 73 56 51 61 62 45 47 66 64 49 57 63 68 50 59 70 48 63 56 PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PUN PUN PUN PUN PUN TEN TER TER TEH TER TEH TEH TER TEH TEH TEH TEH TEH TEH TEH TER TER TER TEH TER TER TEH TER TER TEH TER TER TEH TEH TER TER TER TER TEH TEN TEH TEH TER TEH TEN TEN TEH TEH TEH TER TEN TEH TER TEN TER TEN TEN TER TEH TEN TEN TEH TEN TEN TEH

+0.05

+0.07

+0.06

+0.04

+0.10

+0.01

+0.05

+0.03

+0.10

+0.00

+0.02

+0.01

+0.02

+0.04

+0.02

+0.07

+0.02

+0.08

+0.00

+0.05

+0.07

+0.02

+0.06

+0.05

+0.03

-0.00

+0.03

+0.04

+0.01

+0.03

+0.00

+0.07

+0.04

+0.01

+0.05

+0.06

+0.08

+0.02

+0.04

+0.10

+0.06

+0.03

+0.04

+0.05

+0.10

+0.07

+0.13

+0.10

+0.05

+0.02

+0.12

+0.01

+0.12

+0.10

+0.02

+0.10

+0.04

+0.06 TEN TEH TEH TER TER TER TEN TER TEN TEH TEH TER TEN TEH TEN TEN TEN TEN TEH TEN TEH TEN TEN TEH TEH TEH TEH TEN TEN TER TEN TER TEH TEH TEN TEN TEH TEN TEH TEN TER TEH TEH TEH TEH TEH TEN TEH TER TEH TEN TEN TEN TEH TER TER TEH TER TEN TEH TEH TEH 248 TEN 245 TEN 83 TEN 133 TEN 301 TEN 304 TEN 171 TEN 45 TEN 133 TEN 259 TEN 122 TEN 143 TEN 336 TEN 128 TEN 120 TEN 175 TEN 119 TEN 150 TER 320 TEH 280 TEH 199 TEH 136 TEN 168 TEN 98 TEN 112 TEN 211 TSH 100 TEN 178 TEH 266 TEN 269 TEN 84 TEN 189 TEN 242 TEN 340 TEN 225 TER 66 TEN 112 TEN 269 TEH 159 TEN 164 TEN 225 TEN 224 TEH 126 TEN 108 TEN 152 TEH 241 TEN 70 TEN 339 TEN '62 TEH 143 TEN 241 TEN 301 TEN 325 TEN 259 TEN 222 TEN 336 TEH 115 TEN 25 TEN 227 TEN 213 TEN 360 8

12 12 12 12 12 12 12 12 12 12 12 12 12.

12 12 12 12 12 12 12 12 12 12 12 13 13 13 13 13 13 13 13 13 13 13 13 13 13 13 13 13 13 13 13 13 13 13 13 13 13 13 13 13 13 13 13 13 13 13 14 43 44 45 46 47 48 49 51 52 53 54 55 56 57 59 63 65 66 67 68 69 70 76 77 16 17 18 19 20 25 26 30 31 35 36 37 38 39 40 43 44 45 47 48 49 50 52

.59 60 64 65 66 67 68 69 70 75 76 77 18 12.88 3.23 13.09 10.50 7.95 6.25 8.80 8.23 2,58 5.56 4.96 2.07 8.36 12.93 1.59 10.37 18.01 6.35 14.45 8.85 6.80 15.00 8.70 4.82 5.11 11.18 1.77 9.45 25.79 14.16 10.95 14.81

12. 87

16. 06 31.39 9.86 15.32 5.11 3.94 9.11 8.31 7.90 1.70 16.02 5.07 3.27 3.34 2.19 4.71 7.76 14.51 11.19 5.73 18.47 3.47 6.90 9.81 12.43 13.02 10.47 2.92 64 63 74 71 86 49.

60 67 46 53 63 57 67 70 59 61 67 55 60 61 62 58 52 73 91 86 63 42 61 75 76 71 58 65 59 59 56 80 38 76 70 65 53 46 66 55 32 67 67 75 61 54 59 66 49 74 70 56 56 66 38 PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PV9 PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN FVN PVN FVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PvN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN

-PVI PVN TER TEH TER TEH TER TER TEH TEH TEH TEH TEN TEN TEH TER TEN TER TEH TEH TEN TEH TEN TEH TEN TEH TEH TEN TEN TEN TEH TEN TER TEH TEH TEN TEH TEN TEN TEH TEH TEN TEM TEH TEH TEH TEH TEH TEH TEH TER TEH TEH TER TEH TEH TEH TEH TEH TEN TEH TEH TEH

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+0.10 TEH TER TEH TEN TEN TER TEn TER TER TER TEN TEN TER TER TEN TEN TER TER TER TEM TER TER TEN TEH TEN TEH TEN TER TEN TEN TEN TEN TEN TEN TEN TEH TEH TEN TEN TEH TEH TEH TER TEH TEH TER TEN TER TEN TEN TEN TEN TEN TEN TEH TEN TER TEH TEN TEN TEN TEN TEN TEN TER TEN TEN TER TEN TEH TEN TEN TEN TEN TEN TEN TEN TEN TEH TEN TEN TEN TEN TEN TEH TEN TEN TEN TEN TEN TER TEN TEM TEN TEN TEN TEN TEN TER TEH TEN TEH TER TEN TEN TER TEN TEN TER TER TEH TEN TEH TEN TEN TEN TEH TEN TEH TSH TEN TEH 234 115 245 227 360 256 287 228 91 236 199 112 224 227 45 66 157 232 320 142 70 305 312 192 87 193 259 213 199 343 187 227

248 234 273 185 122 280 91 206 129 301 115 360 239 197 129 270 280 105 135 220 201 204 93 170 263 145 320 256 252 9

14 14 14

.4 14 14 14 14 14 14 14 14 14 14 14 14 14 14 14 14 14 14 14 14 14 14 14 14 14 14 14 14 15 15 15 15 15 15 15 15 15 15 15 i5 15 15 15 15 15 15 15 15 15 15 15 15 19 20 21 23 24 25 26 27 28 29 30 31 32 35 36 37 38 42 43 48 59 63 64 65 66 67 68 69 70 71 75 76 18 19 20 21 23 24 25 26 27 28 29 30 31 32 33 35 36 37 38 39 40 42 46 55 16.72 13.06 14.64 15.87 11.54 10.74 15.17 11.87 6.95 18.71 6.83 7.42 11i 03 26.98 15.87 25.81 11.01 18.01 2.94 15.23 2.10 2.15 5'72 5.27 15.14 10.91 12.37 13.01 9.02 2.46 12.27 7.26 7.90 14.21 12.49 5.86 6.16 12.82 15.10 28.69 5.75 7.08 5.95 9.52 2.81 9.10 14.76 9.10 15.40 12.56 10.53 16.87 7.15 3.77 7.06 18.51 3.66 5.23 2.70 2.86 12.65 74 52 54 67 61 59 51 91 49 65 72 84 57 64 55 55 75 52 49 68 72 24 65 62 67 59 57 52 78 59 69 69 71 55 73 68 66 50 57 65 66 71 78 55 62 60 64 68 81 91 49 56 73 61 64 58 61 61 41 58 67 PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVIN PV1N PVN PVN FVN PVN PVN PVN PVN PVN TEN TEH TEN TEN TEN TEN TEN TEH TEN TEH TEN TEN TEN TEH' TEH TEN TEN TEH TEH TEN TEH TER TEN TEN TEH TEN TEN TEN TEN TEN TEE TEN TEN TEN TEN TEN TEH TEH TEH TEN TEN TEH TER TER TEN TEH TEN TEN TEN TEN TEE TER TEN TEN TEN TEN TEN TEN TEN TEH TEN

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+0.02 TEH TEH TEN TEN TEN TEN TEN TEH TEN TEN TEN TEN TEN TEN TEH TER TEE TEH TEN TEH TEH TEE TEE TEH TER TEE TEN TEN TEN TEE TEH TEN TEH TEN TEH TEE TEN TEN TEN TEN TEN TEE TEN TEH TEN TEHN TEN TEH TEH TEN TEH TEN TEN TER TEN TEN TEN TEH TEN TEH TER TEH TEN TEN TEE TEH TEE TEH TEH TEN TSH TEH TEN TEN TEH TEN TEN TEN TEN TEN TEN TEH TEN TEH TEH TEN TEH TEN TEN TEN TEE TEN TEH TEH TEE TEH TEE TEN TEH TEN TEH TEH TEH TEN TER TEH TEH TEN TEN TEE TEH TEN TEN TEE TEN TEE TEE TEE TEE TEN TEH TEN 308 308 133 63 241 329 336 270 145 149 209 84 136 190 283 241 308 360 300 189 180 266 232 84 77 235 143 339 77 52 231 218 66 308 239 122 168 209 224 252 42 325 300 206

ý245 304 94 252 255 206 168 224 130 126 129 310 360 269 229 129 164 10

15 15 15 15 15 15 15i 15 15 15 15 15 15 15 15 15 16 16 16 16 16 16 16 16 16 16 16 16 16 16 16 16 16 16 16 16 16 16 16 16 16 16 16.

16 16 16 16 17 17 17 17 17 17 17 17 17 56 57 58 59 62 63 64 65 66 68 69 70 71 74 75 77 18 19 20 21 22 25 26 27 28 31 33 34 36 37 39 40 41 42 43 52 56 57 58 61 63 64 65 67 68 73 74 18 19 20 21 22 26 27 28 29 7.30 8.50 17.01 10.54 14.98 9.09 5.96 10.70 8.41 8.06 2:2.52 12.74 3.77 15.65 11.40 5.58 6.60 14.55 12.13 7.23 7.63 15.43 18.18 8.06 8.92 20.73 13.57 16.37 8.69 17.33 13.15 18.16 11.21 3.85 14.29 14.63 7.14 17.05 15.83 2.22 14.89 10.93 15.18 30.44 8.00 10.89 15.44, 5.23 10.21 3.46 9.49 2.26 14.90 13.36 19.12 6.30 5.33 1.50 13.95 8.86 16.47 59 62 61 60 72 53 57 49 75 62 68 65 69 74 72 60 94 70 57 75 45 55 66 90 58 56 61 68 77 57 50 73 71 73 69 62 60 59 65 55 62 63 50 64

`85 59 73 87 62

.54 50 63 61 52 68 45 53 82 74 63 70 PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN TEH TEH TER TER TER TEH TER TER TEH TEH TEH TEH TEH TEH TER TEH TEH TEH TEN TEN TEN TEH TEN TEN TEN TEH TEN TEN TEH TEH TEH TEH TER TEH TEH TEH TER TEN TEH TEE TEH TEH TEN TER TEN TEN TEH TEH TEN TER TEN TEN TEN TEN TER TEN TEN TEN TEN TER TER

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+0.12 TER TER TEH TEN TEN TER TER TEH TEH TEH TEH TEH TER TEH TEE TEH TER TEN TER TEH TEN TER TEH TEH TEH TEH TEN TEH TEN TEH TER TEH TEH TER TEN TEN TER TEN TEN TEH TEN TEH TER TEN TER TEN TEN TEH TEN TEN TEN TEH TER TEN TEN TEH TEH TER TEH TEN TEN TER TEN TEN TEN TER TEN TEN TEN TER TEN TEH TEN TER TER TER TEH TER TEN TEH TER TEH TEN TEN TEH TER TEH TEN TER TEN TER TEN TER TEN TEN TEN TEN TEN TEN TEN TEH TER TEN TER TER TEN TEH TEN TEN TEN TEN TER TEN TEN TEH TEN TEN TEH TEN TEN TEN TEN 245 217 210 185 94 360 277 245 142 222 320 226 52 171 168 31 171 204 241 305 287 115 149 185 301 183 304 284 154 216 220 253 136 213 140 248 224 220 103 80.

304 241 262 199 249 118 188 209 315 66 150 182 329 210 170 276 217 227 177 320 260 11

17 17 17 17 17 17 17 17 17 17 17 17 17 17 17 17 17 17 17 17 17 17 17 18 18 18 18 18 18 18 18 18 18 18 18 18 18 18 18 18 18 18 18 18 18

-18 18 18 18 18 18 18 18 18 18 18 18 18 19 19 19

. 33 36 37 41 42 43 44 53 54 56 57 60 61 62 63 64 66 67 68 69 73 74 75 19 20 21 22 23 26 27 28 29 30 33 34 35 36 37 38 47 50 52 53 54 55 58 60 61 63 65, 66 67 68 72 73 74 75 76 19 20 21 22.06 12.31, 10.76 6.38 16.55 11.69 8.66 9.91 23.90 19.22 13.31 27.42 15.32 8.65 16.06 8.10 11.27 11.87 5.10 15.67 20.55 9.29 11.34 13.61 6.87 3.03 10.54 16.90 2.94 17.40 13.45 13.10 25.48 8.02 10.55 12.31 7.16 19.35 8.01 5.28 5.85 12.78 18.94 19.85 24.31 15.05 16.46 9.67 13.62 11.84 10.34 8.60 11.49 7.96 16.98 14.08 6.37 7.72 8.07 12.62 6.37 59 62 81 68 61 67 53 78 61 54 71 64 65 54 54 59 60 64 78 67 69 63 54 55

.72 48 68 57 66 67 64 64 61 68 81 80 44 56 74 75 70 76 68 64 57 68 45 49 69 73 59 64 72 60 70 66

.61 66 98 69 51 PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVK PVx PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN TEN TEN TEH TEN TER TEN TEN TEE TEH TER TEN TEE TEE TEN TEH TEH TEH TEE TER TEH TEH TEN TEN TEH TEN TEN TEH TEH TEE TEE TEN TEN TEH TEH TEN TEH TEN TEN TEH TEN TEN TER TEH TEN TEE TEN TEN TEN TEN TEH TEN TEN TEN TEE TEH TEN TER TEN TEN TEH TEE

+0.04

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+0.01

-0.00

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+0.04

+0.06 TEE TEH TEN TER TEN TEN TEH TEN TEN TEH TER TER TEH TEH TER TEH TEN TEN TEN TEN TEH TEE TEN TER TEH TEN TEN TEE TEE TEE TEE TER TEH TEH TEH TEH TEE TEE TEE TEH TEH TEE TEH TEH TEH TEH TEN TEH TER TEE TER TEH TER TEN TER TEN TEE TEN TEN TEN TEE TEE TEH TEN TEH TEH TEN TER TEN TEH TEH TEE TEN TEH TEN TEN TEN TEH TEN TEH TER TEH TEH TEN TEN TEH TEH TEE TEE TEH TEN TEE TEN TEN TEH TER TEH TEN TEH TEN TEN TSH TEN TEN TEN TEN TEH TEH TEE TEE TEN "TEH

TEH TEH TEE TEE TEH TSH TEH TEE TEN TEN 238 260 263 94 203 252 340 132 262 269 125 238 277 192 266 164 206 255 273 241 235 90 118 196 267 266 121 234 149 196 267 301 266 190 211 283 245 211 52 104 196 211 224 267 112 161 249 300 114 220 350 300 190 170 320 320 87 42 62 266 218 12

19 22 6.41 65 PVN TEH

+0.03 TEH TEH 308 13.80 64 PVN TEH

+0.07 TEZHTEH 318 19 24 22,00 59 PVN TEH

+0.08 TEH TEH 210 19 27 6.60 67 PVN TEH

+0.10 TEH TEH 204 19 28 9.36 72 PVN TEH

+0.07 TEH TEH 189 19 29 9.33 61 PVN TER

+0.10 TER TEN 239 19 30 4.64 56 PVN TEH

+0.05 TEH TEH 245 19 31 16.71 60 PVN TEH

+0.09 TEH TEH 273 19 32 13.45 64 PVM TEh

+0.05 TEH TEH 94 19 34 8.72 61 PVN TEH

+0.03 TEH TEH 269 19 35 16.46 50 PVN TEH

+0.11 TEH TEH 246 19 36 19.53 46 PVN TEH

+0.05 TEH TEH 280 19 37 13..97 56 PVN TEH

+0.08 TEH TEH 305 19 38 3.79 57 PVN TEH

+0.08 TEH TEH 194 19 39 14.48 68 PVN TEH

+0.09 TEH TEH 183 19 40 11.17 67 PVN TEH

+0.07 TEH TEH 105 19 44 5.29 83 PVN TEN

+0,05 TEH TEH 126 19 45 12.82 73 PVN TEH

+0.04 TEH TEM 156 19 50 0.89 66 PVN TEH

+0.04 TEH TSH 73 19 52 11.63 74 PVN TEHN

+0.06 TEH TEH 63 19 57 19.85 61" PVN TEH

+0.01 TEH TEH 273 19 58 10.86 44 PVN TEN

+0.03 TEH TEH 187 19

-59 18.22 56 PVN TEH

+0.13 TEHNTEH 242 19 60 12.43 62 PVN TEH

+0.00 TEN TEH 287 19 61 10.05 84 PVN TEH

+0.13 TEH TEH 238 19 62 2.'29 59 PVN TEH

+0.04 TEH TEH 159 19 63 4.66 66 PVN TEH

+0.02 TEH TEH 50 19 64 12.42 80 PVN TEH

+0.05 TEH TEH 252 19 65 8.24 52 PVN TEH

+0.03 TEH TEH 177 19 66 10'.24 72 PVN TEH

+0.05 TEH TEH 150 19 67 8,39 68 PVN TEH

+0,00 TEHTEH 177 19 71 19.01 67 PVN TEH

+0.02 TEH TEH 125 19 72 18.76 58 PVN TEH

+0.01 TEH TEH 330 19 73 3.99 40 PVN TEH

+0.00 TEH TEH 239 19 74 6.30 68 PVN TEH

+0.03 TEH TM_!

73 20 11 6.81 94 PVN TEH

+0.02 TEH TEH 157 20 12 5.62 79 PVN TEH

+0.03 TEN TEH

.80 20 20 10.69 64 PVN TEH

+0.02 TEH TEH 157 20 21 7.36 50 PVN TEH

+0.05 TEH TEH 283 20 22 10.76 71 PVN TEH

+0.07 TEH TEH 125 20 23 10.68 66 PVN TEH

+0.11 TEH TEH 206 20 24 10.04 83 PVN TEH 40.14 TEH TEN 301 20 25 13.64 67 PVN TEH

+0.07 TEHNTEN 161 20 29 13.92 72 PVN TEH

+0.04 TEH TEH 196 20 30 14.71 42 PVN TEH

+0.02 TEH TEH 207 20 31 16.28 64 PVN TEH

+0.12 TEH TEH 223 20 32 9.15 91 PVN TEH

+0.15 TEH TEH 301 20 33 11.79 64 PVN TEH

+0,10 TEH TEH 128 20 35 10.81 73 PVN TEH

+0.07 TEH TEH 270 20 36 15.30 69 PVN TEH

+0.10.

TEH TEH 175 20 37 11.54 90 PVN TEH

+0.06 TEH TEH 211 20 38 19.39 63 PVN TEH

+0.01 TEH TEH 301 20 39 10.20 63 PVN TEH(

+0.05 TEH TEH 203 20 40 15.13 59 PVN TEH

+0.09 TEH TEH 340 20 41 15.56 55 PVN TEH

+0.09 TEH TEH 280 20 42 16.43 62 PVN TEH

+0.06 TEH TEH 224 20 43 22.31 65 PVN TEH

+0.07 TEH TEH 291 20 44 13.38 62 PVN TEH

+0.08 TEH TEH 142 20 45 7.97 61 PVN TEH

+0.04 TEH TEH 149 20 46 5.56 70 PVN TEH

+0.01 TEH TEH 232 20 50 3.00 46 PVN TEH

+0.02 TEH TEH -107 13

20 20 20 20 20 20 20 20 20 20 20 20 20 20 20 20 20 20 20 21 21 21 21 21 21 21 21 21 21 21 21 21 21 21 21 21 21 21 21 21 21 21 21 21 21 21 21 21 21 21 21 21 21 21 21 21 21 21 21 21 21 52 53 54 55 56 57 58 59 60 61 62 63 64 65 66 70 71 72 73 21 23 24 25 26 29 30 31 32 33 34 35 37 38 39 40' 41 42 43 44 45 46 47 48 50 51 52 53 54 55 56 57 58 59 60 61 62 63 64 65 69 70 3.49 9.33 15.35 3.43 13.61 7.01 12.13 18.26 8.76 3.87 4.76 8.23 8.18 10.66 10.33 23.49 10.36 16.70 16.09 7.81 11.18 7.95 11.27 21.17 11.85 19.78 12.42 15.18 14.64 15.43 1.95 14.62 8.21 7.04 10.12 15.96 10.42 5.13 6.88 14.80 9.37 15.15 8.69 11.62 21.72 3.89 14.75 15.12 13.76 18.64 8.36 11.82 1.21 12,.72 9.49 13.40 9.26 9.96 8,67 21.87 7.36 59 75 77 52 69 61 54 69 65 82 79 68 65 55 56 63 44 47 66 71 59 57 65 60 72 63 60 62 71 57 48 63 64 64 56 69 52 60 51 68 55 56 72 66 66 56 72 67 47 60 76 51 34.

64 73 71 68 72 66 63 55 PVN PVN PYN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN TEN TER TER TER TER TER TER TER TEH TEN TEN TEN TEN TEN TEN TEN TEN TEH TEH TEN TEN TEH TEN TEN TEH TEN TEH TEH TEA TEX TEH TEN TEH TEN TEN TEN TEH TEN TEN TER TEN TEN TEH TER TER TEN TEN TEH TEH TEN TEN TER TER TER TEN TEH TEN TEN TEN TEN TEN

+0.07

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-+0.08

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+0.11

+0.11 TEN TEN TEN TEN TEX TEN TEN TEN TEH TEN TER TEN TEN TEN TEN TEN TEN TEN TEN TEN TEN TEN TEN TEH TEN TEN TEN TEN TEN TEN TEN TEN TEN TEN TEN TEN TEN TEN TEN TEN TEN TEN TEN TEN TEN TEN TEN TEH TEN TEN TEH TEN TEN TEN TEH TEN TEN TEH TEN TEN TEN TER TEN TEN TER TEH TER TER TER TER TEN TEN TEN TEN TEN TEN TEH TEN TEN TEN TEN TEH TEN TEN TEN TEN TEN TEN TEN TEN TEN TEN TEN TEN TEN TER TEN TEN TEN TEN TEN TEN TEN TER TEN TEH TEN TEN TER TEN TEN TEN TEN TEN TER TEN TEN TEN TEN TEH TEN TEN 45 126 203 287 360 255 180 220 1il 101 93 225 295

.157 150 142 217 222 266 128 287 273 204 152 104 225 287 276 199 217 45 304 77 189 283 360 259 320 213 360 280 259 325 166 270 330 277 149 235 300 249 360 69 287 187 320 133 192 211 100 270 14

21 21 22 22 22 22 22 22 22 22 22 22 22 22 22 22 22 22 22 22 22 22 22 22 22 22 22 22 22 22 22 22 22 22 22 22 22 22 22 22 23 23 23 23 23 23 23 23 23 23 23 23 23 23 23 23 23 23 23 23 71 72 24 25 26 27 30 31 33 34 35 36 37 40 41 42 44 45

'46 48 49 50 51 52 53 54 55 56 57 58 59 60 61 62 63.

68 69 70 71 72 24 25 26 27 28 31 34 36 37 38 39 41 42 43 44 45 46 47-48 49 10.65 13.65 9.75 22.30 14.99 26.24 8.13 10.87 14.52 8.87 14.15 14.62 8.19 6.69 11.80 11.25 8.77 11.81 4.72 2.80 5.42 2.59 1.46 5.26 4.65 12.73 15.45 12.33 9:85 10.56 17.26 6.22 4.50 14.26 2.84 22.22 13.86 9.18 10.58 3.66 11.05 2.62 15.19 15.96 17.80 23.96 5.27 12.86 14.37 9.56 17.04 8.33 9.29 11.66 2.52 4.'08 4.52 18.43 2.96 6.91 9.25 50 67 71 59 48 55 77 63 63 89 68 83 68 78 46 84 68 64 54 58 52 52 60 53 39 64 71 45 83 67 70 67 64 63 70 68 55 47 63 64 71 42 69 60 71 58 66 66 71 75 61 54 58 80 58 61 60 64 64 69 88 PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN TEH TER TER TEN TEN TEN TEN TEH TER TEN TEM TEN TEN TER TEN TEN TEN TEH TEN TEN TEN TEN

,TEH TEH TEH TEH TEN TEH TEN TEN TEH TEH TEN TEH TEH TEH TEH TEH TER TER TEN TEN TEN TEN TEN TEN TEN TEN TEE TEN TEN TEN TEN TEN TEE TEN TEN TEE TEN TEN TEN

+0.14

+0.04

+0.11

+0.03

+0.02

+0.08

+0.06

+0.08

+0.04

+0.06

+0.04

+0.03

+0.02.

+0.02

+0.05

+0.03

+0.06

+0.08

+0.10

+0.08

+0.11

+0.10

+0.07

+0.08

+0.05

+0.04

+0.00

+0.04

+0.01

+0.08

+0.02

+0.06

+0.13

+0.03

+0.08

+0.05

+0.04

+0.07

+0.10

+0.02

+0.04

+0.07,

+0.11

+0.05

+0.04

+0.06

+0.10

+0.06

+0. 05

+0,03

+0. 02

+0 09

+0. 05

+0.06

+0.03

+0.08

+0.05

+0.01 TEN TEN TEH TEN TEN TEN TEN TEN TEN TEE TEN TEE TEN TEH TEN TEN TEN TEN TEN TEN TEH TEN TEN TEH TEE TEH TEE TEE TEN TEN TEN TEN TEN TEN TEN TEN TEN TEE TEN TEN TEN TEN TEE TEN TEN TEN TEN TEN TEN TEN TEN TEN TEE TEH TEE TEN TEN TER TEE TEE TEN TEN TEN TEE TEN TEH TEN TER TEN TEN TEN TEH TEN TEN TEH TEN TEN TEN TEN TEN TEN TEN TEN TEN TEN TEN TEH TEN TEN TEN TEN TEN TEN TEH TEH TEN TEN TEN TEN TEE TER TEN TEN TSH TSH TEN TEH TEN TER TER TEH TEE TEE TSH TEN TEN TEE TEN TEE TEN TEN TEN 360 287 228 294 203 184 238 304 260 185 290 168 35 159 249 263 150 260 360 290 248 238 310 340 260 241 294 256 220 154 206 308 136 224 55 125 182 280 300 28 287 315 139 225 336 140 62 210 206 318 213 87 170 214 300 63 242 173 249 166 152 15

23

.23 23 23 23 23 23 23 23 23 23 23 23 23 23 23 24 24 24 24 24 24 24 24 24 24 24 24 24 24 24 24 24 24 24 24 24 24 24 24 24 24 24 24 24 24 25 25 25 25 25 25 25 25 25 25 25 25 25 25 25 50 51 52 53 54 56 57 58 59 60 61 62 67 68 69 70 26 27 28 29 32 35 36 37 38 39 40 41 42 43 44 52 53

.54 55 56 57 58 59 60 62 66 67 68 69 70 28 29 30 31 36 37 38 39 40 41 42 43 44 45 46 12.23 8.37 9.07 16.26 6.30 5.38 17.54 15.34 8.83 11.02 12.80 11.83 23.47 10.32 16.58 7.35 13.20 7.14 10.98 19.21 4.09 11.53 5.32 13.52 7.14 14.45 12.98 17.60 17.83 20.40 3.74 12.06 16.60 15.19 12.78 18.39 11.21 13.39 4.65 16.65 5.75 28.61 9.92 16.98 11.97 14.86 9.38 12.49 14.96 22.63 9.23 3.41 14.79 6.79 12.82 9.63 4.22 10.77 8.98 10.11 16.50 68 72 62 59 78 58 73 57 81 65 72 69 67 59 60 67 77 57 44 69 74 71 68 71 72 58 63 59 68 60 55 72 61 77 60 73 70 68 70 76 73 60 47 52 65 72 52 73 56 62 67 66 66 79 66 63 71 59 68 57 67 PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN mVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVJN TEH TEH TEH TEH TEH TEH TEH TEH TEX TEN TEH TEH TEH TEX TEX TEH TEX TEN TEX TEN TEH TEN TEX TEH TEN TEX TEX TEH TEN TEJ3 TEN TEX TEH TEN TEN TEX TEN TEX TEN TEN TEN T-H TEX TEH TEN TER TEX TEH TEX TEH TEH TEH TEN TEN TEN TEN TEH TEN TEH TEN TEN

+0.04

+0.02

+0.03

+0.04

+'0.03

+0.06,

+0.09

+0.01

+0.04

+0.03

+0.02

+0.05

+0.08

+0.05

+0.11

+0.01

+0.13

+0.11

+0.06

+0.09

+0.07

+0.04

+0.03

+0.04

,+0.05

+0.06

+0.05

+0.08

+0.01

+0.08

+0.04

+0.05

+0.06

.+0.01

+0.06

+0.04

+0.06

+0.01

+0.15

+0.00

+0.05

+0.01

+0.09

+0.08

+0.01

+0.07

+0.08

+0.06

+0.13

+0.01

+0.03

+0.04

+0.08

+0.02

+0.05

+0.08

+0.01

+0.04

+0.07

+0.03 TEX TEH TEX TEX TEH TEX TEN TEH TEH TEX TEN TEN TEH TEN TEH TEN TEN TEN TEX TEH TEH TEH TEN TEN TEN TEH TEH TEH TEH TEH TEH TEH TEX TEX TEH.

TEH TEN TEX TEX TEN TEH TEN TEX TEN TEX TEN TEN TEX TEN TEN TEH TEN TEX TEH TEX TEN TEX TEX TEH TEH TEH TEX TEN TSH TEH TEH TEN TEH TEH TEX TEN TEN TEN TEH TEN TEX TEN TEX TEN TEX TEX TEH TEH TEX TEX TEX TEX TEX TEN TSH TEH TEX TEN TEN TEX TEN TEH TEN TEN TEX TEH TEN TEN TEX TEN TEH TEX TEN TEN TEH TEN TEH TEN TEN TSH TEH TEX TEX TEX TEX TEX TEH 235 194 170 308 87 87 194 249 135 340 121 98 135 330 241 294 270 231 235 224 76 150 224 150 170 360 360 210 170 198 87 85 112 189 266 322 266 185 126 232 156 234 227 196 231 157 269 267 163 104 59 101 192 159 315 297 359 360 320 245 273 16

25 25 25 25 25 25 25 25 25 25 25 25 25 25 25 25 25 25 26 26 26 26 26 26 26 26 26 26 26 26 26 26 26 26 26 26 26 26 26 26 26 26 26 26 26 26 26 27 27 27 27 27 27 27 27 27 27 27 27<

27 27 47 48 49 50 51 52 53 54 55 56 57 64 65 66 67 68 69 70 28 29 30 31 32 39 40 41 42 43 44 45 46 49 50 51 52 53 54 55 63 64 65 66 67 68 69 70 71 29 30 32 33 34 40 41 45 46 50 51 53 54 56 8.81 21.39 14.03 14.62 18.74 10.43 7.34 8.28 15.05 10.02 4.08 15.96 13.43 5.87 8.00 6.09 15.63 8.02 21.49 10.38 5.79 1.47 18.61 4.56 3.19 15.02 9.16 19.11 11.78 6.46 6.56 8.23 6.20 11.85 8.66 11.76 8.11 15.35 4.01 14.71 12.86 12.28 1.56 20.04 8.79 3.01 11.97 18.82 3.78 16.50 19.23 1.72 8.31 5.06 12.16 8.57 9.36 4.32 5.36 6.21 58 66 68 69 74 69 59 59 70 69 71 77 79 71 67 67 61 86 63 59 56 69 64 76 60 65 51 61 55

'64 71 61 56 59 62 74 72 66 73 72 61 69 74 50 70 54 69 73 73 51 61 59 64 64 54 72 64 69 64 97 69 PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVw PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVw PVN TEH TEH TEH TEH TEH TEH TEH TER TEH TEH TEH TEH TER TEH TEH TEH TEH TEH TEH TEH TEH TEH TEH TEE TEH TER TEH TEH TER TEH TEE TEE TEH TEH TEE TEH TEH TEH TEH TEH TEH TEH TEH TEH TER TEH TEH TEH TEH TEH TEH TEH TEH TEH TEH TEH TEH TEH TEH TEH TEE

+0.12

+0.08

+0.06

+0.04

+0.03

+0.04

+0.08

+0.01

+0.06

+0.03

+0.02

+0.04

+0.09

+0.05

+0.11

+0.12

+0.16

+0.14

+0.00

+0.05

+0.01

+0.05

+0.07

+0.05

+0.07

+0.05

+0.13

+0.08

+0.06

+0.04

+0.03

+0.11

+0.02

+0.07

+0.03

+0.05

+0.02

+0.03

+0.04

+0.10

+0.13

+0.12

+0.02

+0.09

+0.05

+0.03

+0.06

+0.01

+0.05

+0.02

+0.07

+0.01

+0.01 TEH TER TEE TEH TEH TEH TEH TEH TEH TEH TEH TEH TEH TEE TEH TEH TEH TEH TEH TEE TEH TEH TEH TEH TEH TEH TEH TEH TEH TEH TEH TEH TEH TEH TEH TEH TEH TER TEH TEH TEH TEH TEH TEH TEH TEH TEH TEH TEH TEH TEH TEH TEH TEH TEH TEH TEH TEH TEH TEH TEE TEH TEH TEH TEH TEH TEH TSH TEH TSH TEH TEH TEH TEH TEH TEH TEH TEH TEH TEH TEH TEH TEH TEH TEH TEH TEH TEH TEH TEH TSH TEH TEH TEH TEH TEH TEH TEH TSH TEH TEH TEH TEH TEH TEH TEH TEH TEH TEH TEH TEH TEH TEH TEH TEH TEH TEH TEH TEH TEH TEH TEH 241 248 284 315 256 178 201 97 276 248 90 150 298 249 246 330 87 90 190 234 241 175 239 111 66 335 287 340 287 320 196 248 297 262 180 298 161 253 234 152 310 310 171 48 291 189 129 107 263 171 231 203 112 336 215 121 108 76 84 170 91 17

27 27 27 27 27 27 27 27 27 27 28 28 28 28 28 28 28 28 28 28 28 28 28 28 28 28 28 28 28 28 28 28 28 28 28 28 29 29 29 29 29 29 29 29 29 29 29 29 29 29 29 29 29 29 30 30 30 30 30 30 30 60.

61 62 63 64 65 66 68 69 70 31 32 33 34 35 36 37 43 45 47 48 50 51 52 53 58 59 60 61 62 63 64 66 67 65 69 33 34 35 36 37 39 40 41 55 56 57 58 59 60 61 62 63 66 35 37 38 39 40 41 42 9.72 8.47 7.65 4.75 15.33 7.40 12.57 17.35 16.37 18.03 12.92 13.89 21.20 8.25 8.04 11.58 21.40 19.06 10.72 1.79 11.19 5.57 9.68 17.89 10.56 7.76 23.96 15.26 15.28 3.80 11,.41 14.55 6.61 7.82 8.85 13.76 17.32 14.28 16.87 12.33 8.20 11.53 13.15 18.38 14.92 21.36 6.33 14.60 5.01 6,50 3.83 14.04 8.32 8.95 14.39 15.39 8.51 13.51 10.06 8.00 12.62 75 86 59 64 38 65 78 58 52 75 61' 40 58 48 65 68 62 61 65 43 68 64 69

.60 85 73 64 48 60 70 79 78 80 66 47 74 72 66 65 83 53 52 54 69 67 68 72 48 43 64 49 69 82 63 66 53 62 74 42 78 50 PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PvN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVK PVN PVN PVN PVN PVN PVN PVN PVx PVN.

PVN PVN PVN PVN TER TEH TER TEH TEH TER TER TER TER TEH TER TEH TER TEH TER TEN TEN TEH TEN TEH TEH TEH TER TER TEH TER TEH TEH TER TER TEH TEH TEN TEN TEH TER TEN TEH TEH TEH TEH TEN TEH TEN TEH TEH TEH TEH TEH TER TEH TEN TER TER TER TER TEH TER TEN TEH TEN

+0.03

+0.02

+0.08

+0.04

+0.02

+0.01

+0.07

+0.00

+0.05

+0.07

+0.10

+0.01

+0.07

+0.05

+0.10

+0.08

+0.04

+0.12

+0.04

+0.02

+0.03

+0.02

+0.03

+0.05

+0.08

+0.11

+0.01

+0.05

+0.02

+0.06

+0.10

+0.05

+0.09

+0.07

+0.05

+0.04

+0.03

+0.02

+0.01

+0.05

+0.03

+0.11

+0.03

+0.04

+0.07

+0.10

+0.01

+0.04

+0.05 18 TEH TEN TEN TEH TEN TEH TEH TEH TEN TEH TEH TEN TEH TEN TEH TEH TEH TEN TEH TEN TER TEN TEX TEN TEH TEN TEN TEN TEH TEN TEH TEH TEH TER TER TER TEN TEN TER TEN TEH TEN TEH TEN TEH TEN TEN TEN TER TSH TER TEH TEN TEN TEH TER TEN TER TEH TER

'TEH TEN TEN TEN TER TEH TEN TEN TEN TEN TEN TEN TEN TEN TEN TEN TEN TER TEN TEN TEN TEN TEN TEN TEN TEH TEN TEN TEN TEN TEN TEH TEN TEH TEN TER TER TEN TEN TEE TER TEN TEN TEN TEN TEH' TEN TEN TEN TEN TEN TEN TER TEH TEN TEN TEN TEN TEN TER TEN TEN 63 135 290 360 320 270 156 192 183 163 189 252 199 310 178 220 166 239 128 2.26 249 98 224 253 166 83 213 294 255 263 182 197 87 252 183 126 196 241 308 297 287 203 147 66 142 224 308 300 291 300 225 210 66 173 119 215 320 284 263 240 318

30 30 30 30 30 30 30 30 30 30 30 30 30 30 30 39 30 30 31 31 31 31 31 31 31 31 31 31 31 31 31 31 31 31 31 31 31 32 32 32 32 32 32 32 32 32 32 32 33 35 43 44 45 46 47 48 49 50 51 52 53 54 55 56 57 58 60 61 38 39 40 41 42 43 44 45 46 47 48 49 50 52 53 54 55 56 79 42 43 44 45 46 47 48 49 50 51 52 24 60 19.54 24.63 19.25 21.82 18.82 21.01 22.43 18.59 16.97 25.91 9.72 17.33 2.24 13.70 10.92 12.76 13.09 9.51 6.51 10.68 8.50 9.86 12.56 9.05 18.20 10.92 10.49 8.50 10.13 10.19 13.16 13.31 4.35 11.37 4.05 9.63 1.50 6.74 3.05 11.61 11.30 18.67

15. 09 11.17 13.16 12.27 3.88 15.06 7.97 4.30 65 55 57 63 65 64 60 76 58 62 52 66 42 67 79 88 70 76 75 73 72 63 67 51 56 67 61 56 73 72 68 51 40 69 55 62 33 63 64 80 83 64 68 60 67 68 61 76 48 41 PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN TEN TEN TEN TEN TEN TEH TEN TEN TEN TEN TEH TEH TEH TEN TEN TEH TEH TEH TEH TEN TEN TEH TEH TEN TEH TEH TEH TEH TEH TER TER TEN TEH TEH TEH TEH TEH TEN TEH TEH TEH TEH TEH TEH TEN TEH TEH TEH TEH TEH

+0.03

+0. 09

+0.05

+0.04

+0.05

+0.01

+0.05

+0.04

+0.07

+0.04

+0.10

+0.07

+0.05

+0.01

+0.02

+0.01

+0.02

+0.06

+0.04

+0.01

+0.02

+0.01

+0.03

+0.04'

+0.02

+0.01

+0.02

+0.07

+0.o05

+0.01

+0.08

+0.06

+0.12

+0.08

+0.07

+0.12

+0.10

+0.05

+0.10

+0.05

+0.09

+0.07

+0.12

+0.03

+0.08 TEN TEN TEN TER TEN TER TEN TEN TEN TEN TEN TEN TEH TEH TEH TEN TEH TER TEH TEH TEN TEN TEN TEH TE-TER TEH TEN TEN TER TEN TEN TER TEN TEN TEH TER TEH TEH TEN TER TEN TEH TEN TER TEN TEN TEN TEN TER-TEM TSH TEH TEN TEN TEH TEN TEH TEN TEN TEN TEN TEN TEN TEN TEN TEN TEN TEN TEN TER TEH TEN TEH TEH TEN TEN TEN TEN TEN TEN TEN TSH TEN TEN TEN TEN TEN TEN TER TEN TEN TEN TER TER TEN TEN TEH TEN TEN 277 249 218 182 168 171 154 154 213 260 224 248 208 320 340 310 206 98 135 249 189 215 329 332 315 291 267 213 209 294 228 360 253 196 70 273 14 112 118 210 276 308 325 300 245 227 180 197 87 119 19

Table of Unit I B Steam Generator Hot Leg Permeability Variation Indications Refueling Outage R22 I

Summary Unit I B Steam Generator Cold Leg Permeability Variations ROW COL VOLTS DEG IND %TW LOCATION EXT EXT Circ.Extent 1

6 6.02 79 PVN TEC

+0.02 TEC TEC 108 1

13 8.58 67 PVN TEC

+0.02 TEC TEC 129 1

14 10.95 59 PVN TEC

+0.04 TEC TEC 329 1

15 10.83 51 PVN TEC

+0.05 TEC TEC 140 1

17 15.21 72 PVN TEC

-0.00 TEC TEC 150 1

19 2.45 43 PVN TEC

+0.08 TEC TEC 192 1

20 14.94 59 PVN TEC

+0.01 TEC TEC 290 1

21 10.61 54 PVN TEC

+0.03 TEC TEC 182 1

22 13.48 62 PVN

TEC,

+0.02 TEC TEC 227 1

25 13.01 69 PVN TEC

+0.00 TEC TEC 150 1

29 10.12 77 PVN TEC

+0.02 TEC TEC 147 1

30 13.81 54 PVN TEC

+0.04 TEC TEC 304 1

35 14.83 58 PVN TEC

+0.00 TEC'TEC 354 1

36 10.25 69 PVN TEC

+0.00 TEC TEC 360 1

37 4.33 79 PVN TEC

+0.01 TEC TEC 129 1

39 10.28 70 PVN TEC

+0.05 TEC TEC 143 1

51 8.04 70 PVN TEC

+0.00 TEC TEC 115 1

55 3.05 51 PVN TEC

+0.04 TEC TEC 66 1

61 7.37 60 PVN TEC

+0.00 TEC TEC 360 1

63 11.10 71 PVN TEC

+0.01 TEC TEC 126 1

65 6.37 63 PVN TEC

+0.01 TEC TEC 31 1

66 8.95 56 PVN TEC

+0.04 TEC TEC 74 1

70 9.41 63 PVN TEC

+0.04 TEC TEC 88 1

71 10.93 75 PVN TEC

+0.00 TEC TEC 161 1

73 10.23 63 PVN TEC

+0.01 TEC TEC 108 1

74 8.01 57 PVN TEC

+0.04 TEC TEC 261 1

75 14.03 65 PVN TEC

+0.02 TEC TEC 266 1

78 14.46 61 PVN TEC

+0.06 TEC TEC 115 1

79 8.74 50 PVN TEC

+0.04 TEC TEC 245 1

80 10.46 62 PVN TEC

+0.02 TEC TEC 259 1

83 13.32 67 PVN TEC

+0.01 TEC TEC 143 1

84 14.84 58 PVN TEC

+0.05 TEC TEC 136 1

85 5.09 70 PVN TEC

+0.00 TEC TEC 255 2

13 2.06 72 PVN TEC

+0.06 TEC TEC 73 2

14 12.23 62 PVN TEC

+0.02 TEC TEC 332 2

15 11.11 54 PVN TEC

+0.07 TEC TEC 329 2

16 9.94 65 PVN TEC

+0.07 TEC TEC 322 2

17 19.01 72 PVN TEC

+0.13 TEC TEC 213 2

19 4.79 69 PVN TEC

+0.09 TEC TEC 80 2

20 11.73 77 PVN TEC

+0.04

.TEC TEC 325 2

21 15.20 69 PVN TEC

+0.11 TEC TEC 231 2

22 6.34 74 PVN TEC

+0.02 TEC TEC 255 2

23 9.70 84 PVN TEC

+0.00 TEC TEC 213 2

25 14.77 67 PVN TEC

+0.00 TEC TEC 150 2

26 9.85 64 PVN TEC

+0.03 TEC TEC 301 2

29 7.96 62 PVN TEC

+0.02 TEC TEC 77 2

30 6.54 55 PVN TEC

+0.11 TEC TEC 290 2

33 2.48 49 PVN TEC

+0.03 TEC TEC 146 2

34 10.17 55 PVN TEC

+0.02 TEC TEC 300 2

35 10.82 64 PVN TEC

+0.00 TEC TEC 360 2

36 15.72 62 PVN TEC

+0.02 TEC TEC 360 2

37 16.74 67 PVN TEC

+0.05 TEC TEC 283 I

2 2

2 3

3 3

3 33 40 43 44 45 51 52 53 54 55 56 60 61 62 63 64 67 71 73 74 75 77 78 79 80 83 13 14 15 16 17 19 20 21 22 23 25 26 30 34 35 36 37 38 40 46 49 51 53 54 55 56 57 61 62 63 67 73 10.51 69 5.39 57 9.49 60 1.31 54 5.71 74 2.32 49 7.14 74 12.90 68 14.57 66 12.84 61 4.22 51 14.71 65 13.50 76 11.93 72 10.69 67 13.55 65 6.30 68 8.13 75 7.74 54 6.63 76 5.23 70 15.84 84 11.16 61 9.06 83 12.83 88 11.96 57

'11.09 53 11.23 51 6.53 55 19.64 64 12.73 57 13.25 69 11.75 55 10.76 64 8.47 61 9.48 66 5.78 55 9.15 61 7.39 68 12.82 82 11.34 78 16.03 48 13.64 61 7.12 74 11.08 60 5.19 80 17.70 66 20.70 62 16.75 49 10.96 57 15.23 66 12.33 69 10.69 62 11.59 64 13.33 64 17.61 51 15.05 60 PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC

+0.02

+0.01

+0.09

+0.02

+0.00

+0.03

+0.00

+0.06

+0.00

+0.07

+0.06

+0.00

+0.07

+0.03

+0.07

+0.05

+0.02

+0.03

+0.01

+0.00

+0.05

+0.06

+0.01

+0.11

+0.03

+0.05

+0.08

+0.03

+0.07

+0.03

+0.08

+0.05

+0.02

+0.00

+0.02

+0.09

+0.05

+0.00

+0.03

+0.07

+0.04

+0.02

+0.04

+0.02

+0.07

+0.03

+0.02

+0.05

+0.03

+0.02

+0.03

+0. 02

+0.08

+0.05

+0.10 TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC 175 180 213

'30 133 59 178 162 199 325 60 238 314 248 180 294 129 129 142 190 45 165 213 227 199 119 329 220 339 192 168 276 248 157 105 119 287 322 333 355 360 360 120 109 140 120 226 205 328 265 229 222 360 307 220 269 283 2

74 75 76 78 79 80

.83 84 85 86 14 15 16 17 20 21 22 25 26 27 30 31 33 34 35 36 37 38 50 51 53 54 55 56 57 59 60 61 62 67 73 74 75 76 78 79 80 83 84 85 10 11 14 15 16 17 19 11.86 11.17 3.56 17.40 11.52 12.20 12.76 5.08 15.44 11.81 9.36 10.16 10.57 19.14 8.96 i3.17 9.22 6.81 9.04 5.10 9.41 17.73 3.55 8.21 12.20 17.64 11.06 8.48 19.48 13.69 7.24 11.80 6.63 4.95 7.87 10.88 11.74 12.44 7.55 13.08 11.03 14.15 12.32 8.33 22.04 14.07 6.36 8.16 16.14 12.01 10.11 13.52 9.78 8.13 5.80 10.37 11.99 63 64 89 72 80 84 58 52 71 63 70 49 58 71 70 72 75 59 51 61 67 65 60 66 65 61 62 66 56 53 68 57 44 66

'72 72 63 66 74 46 74 72 66 70 59 75 70 73 77.

74 65 70 77 51 65 44 59 PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC

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20 21 22 23 24 25 26 30 31 34 35 36 37 38 39 48 50 51 53 55 58 59 60 61 64 67 72 73 78 79 80 83 84 85 86 87 10 11

.14 15 16 17 19 20 21 22 23 25 26 27 30 31 32 33 35 36 38 6.86 10.83 7.07 16.24 3.09 7.95 14.00 6.92 9.75 5.60 8.23 11.76 14.77 13.58 12.17 4.88 13.42 14.04 19.00 12.32 7.53 14.14 4.89 11.34 5.20 18.97 6.03

11. 90 13.70 16.02 13.00 2.33 13.09 5.59 12.39 2.56 8.06 12.64 12.46 14.20 9.30 17.91 12.06 10.61 18.66 10.67 7.91 7.40 13.55 18.56 8.89 12.24 8.76 7.49 7.70 16.19 13.77 58 69 68 60 54 62 65 63 59 43 53 62 59 53 64 75 71 55 52 48 56 54 58 88 64 69 80 63 68 61 73 36 60 81 69 67 72 53 72 58 59 47

.79 62 57 71 61 72 51 64 56 66 54 61 63 66 68 PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC

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+0.03 TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC

'283 269 139 91 172 347 276 231 217

.273 325 290 233 360 56 131 184 320 360 226 152 360 244 134 81 245 106 205 276 203 210 161 140 168 161 77 ill 147 206 157 343 252 122 301 273 269 164 294 280 259 150 320 133 276 340 234 161 4

39 40 50 51 52 53 54 55 58 59 64 65 69 73 77 78 79 80 83 84 85 86 10 11 15 16 17 18 19 20 21 22 23 24 25 26 27 31 32 33 34 35 36 37 39 40 41 48 49 50 51 53 57 59 60 63 64 7.49 4.60 7.08 10.71 10.41 5.61 13.21 2.59 9.00 13.91 18.08 13.87 13.47 8.78 3.00 22.24 15.14 22.02 6.89

12. 88

12. 17 11.74 13.08 11.32 13.07

12. 12 7.32 26.96 5.04 9.37 6.86 13.46 15.37 10.62 8.51 12.21 5.09 10.76 4.49 10.17 6.93 6.64 13.57 13.49 11.46 3.79 1.40 6.37 13.75 8.41 9.54 12.56 8.49 13.09 9.65 7.44

11. 62 68 37 84 67 72 62 67 66 63 60 62 59 68 68 55 63 53 67 86 65 57 80 92 59 71 65 50 64 64 82 58 70 62 76 58 54 49 56 56 66 74 61 49 78 72 44 63 67 75 61 50 56 60 42 59 72 48 PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN pvJN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC

<TEC TEC TEC TEC TEC TEC TEC TEC TEC

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+0.01 TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC 165 77 180 276 275 87 251 94 141 222 275 178 91 94 66 287 189 150 115 206 360 276 164 198 266 318 199 150 77 220 259 329 220 185 308 171 108 206 287 260 217 297 350 102 176 146 189 113 290 247 340

-140 102 320 152 108 252 5

69 70 72 73 78 79 80 82 83 84 85 7

10 11 15 16 17 18 20 21 22 23 24 25 26 27 33 36 37 40 41 42 49 50 51 52 53 54 58 59 63 64 69 70 72 73 78 79 80 86 11 12 15 16 17 18 20 21.95 14.27 10.14 7.67 11.92 15.36 34.18 3.51 5.14 4.22 10.45 3.57 5.07 10.68 5.28 6.29 15.72 14.29 2.89 5.14 9.42 16.40 17.24 5.01 8.11 9.77 8.90 17.11 12.51 5.27 7.96 10.81 14.71 13.92 11.74 9.92 10.53 6.07 13.06 12.81 21.17 15.43 7.41 13.32 16.20 13.65 15.04 17.22 31.07 8.15 10.97 6.86 9.55 8.36 12.55 15.54 2.56 62 51 58 63 85 48 53 62 43 66 84 69 67 72 59 54 35 78 53 68 82 66 78 65 67 67 62 57 74 48 64 63 59 70 59 80 68 94 71 87 57 73 68 60 60 61 60 57 62 65 77 63 69

-30 58 71 63 PVN PVN PVN PVN PVN PVN PVN PVN PVN

PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC

'TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC

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TEC TEC 230 233 205 273 238 290 164 59 144 140 150 59 38 133 311 350 301 224 294 108.

171 176 98 101 283 325 133 157 262 140 180 56 290 289 259 219 248 236 240 213 283 234 290 131 215 243 266 283 178 66 154 150 332 223 230 332 126 6

9 9

9 10 10 10 10 10 10 10io 10 10 10 10 10 10 10 10 10 10 10 10 21 22 23 24 25 26 27 28 32 33 34 36 37 38 41 42 47 51 52 53 57 58 59 62 63 67 68 69 71 73 74 78 80 82 83 85 86 10 11 12 15 16 17 18 19 21 22 23 24 26 27 28 29 33 34 35 38 4.39 11.62 16.09 15.09 6.71 7.81 11.22 9.04 5.12 9.00 6.52 9.72 14.11 9.94 7.05 9.41 6.52 13.24 9.47 4.65 19.19 9.45 5.12 10.41 8.99 3.16 17.54 9.79 14.08 12.60 13.53 12.03 30.99 5.86 3.10 10.75 16.48 11.58 1.90 1.57 14.59 20.43 10.84 8.60 24.95 10.84 13.83 13.12 2.10 11.06 12.99 10.70 11.29 5.22 4.23 2.06 9.51 61 50 58 74 87 62 70 65 60 72 66 66 54 70 49 51 40 81 79 41 64 69 59 67 64 41 58 81.

63 70 74 65 61 58 70 74 62 77 59 56 65 43 56 51 66 57 69 58 46 66 55 55 70 79 55 51 67 PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC

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+0.04 TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC 238 308 210 203 77 320 287 262 290 163 304 360 187 240 122 106 113 194 109 95 236 310

? 64 162 280 160 205 285 115 280 236 276 164 59 140 210 171 269 160 158 227 248 196 294 161 209 352 227 227 185 259 360 196 210 308 84 161 7

10 39 12.20 68 PVN TEC

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TEC

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+0.07 TEC TEC 241 10 73 10.76

53.

PVN TEC

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+0.01 TEC TEC 308 11 18 12.54 68 PVN TEC

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+0.16 TEC TEC 255 11 24 17.57 58 PVN TEC

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+0.00 TEC TEC 81 11 37 9.71 58 PVN TEC

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+0.00 TEC TEC 265 11 39 15.13 62 PVN TEC

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.43 20.13 67 PVN TEC

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+0.01 TEC TEC 320 11 56 6.79 85 PVN TEC

+0.01 TEC TEC 127 8

II II 12 12 12 12 12 12 12 12 12 12 12 12 12 12 12 12 12 12 12 12 12 12 12 12 12 12 12 12 12 12 12 12 12 12 12 12 12 12 12 12 12 12 12 12 12 12 12 12 12 13 13 61 62 66 67 68 70 72 73 77 78 79 80 11 16 17 18 19 20 25 27 28 29 30 32 33 34 35 36 37 38 39 41 42 43 48 49 50 51 52 53 54 55 59 60 61 65 66 67 68 70 73 77 78 79 13 16 17 16.79 12.13 3.18 15.78 4.46 7.04 10.48 9.09 4.55 18.83 9.88 17.50 8.11 6.75 5.27 9.48 17.01 3.21 14.64 17.95 18.12 17.11 12.99 3.69 3.07 8.41 6.48 11.01 5.01 8.46 7.63 10.31 6.24 12.34 5.45 8.73 3.22 11.25 9.91 10.66 8.78 9.13 8.79 12.87 9.03 3.01 13.41 10.21 8.05 17.85 6.76 19.16 10.77 9.61 2.74 5.06 6.34 4.8 68

-55 60 62 90 68 79 60 59 47 63 76 77 75 57 59 67 66 64 39 66 52 76 69 75 52 76 79 61 64 77 73 69 57 70 91 59 64 52 57 82

'69 64 69 54 69 66 65 57 48 67 72 73 71 70 60 PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC

+0.02

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+0.08 TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC 300 145 131 236 136 109 161 290 56 287 287 122 220 175 108 318 203 87 280 217 360 171 252 84 273 185 294

122, 238 248 280 224 91 304 113 234 106 343 224 360 233 129 52 122 208 163 233 320 192 243 192 192 266 192 168 129 157 9

13 13 13 13 13

.13 13 13 13 13 13 13 13 13 13 13 13 13 13 13 13 13 13 13 13 13 13 13 13 13 13 13 13 13 13 13 13 14 14 14 14 14 14 14 1.4 14 14 14 14 14 14 14 14 14 14 14 14 18 19 20 22 25 26 28 29 30 31 35 36 37 38 39 44 46 47 48 49 50 51 52 59 60 64 65 66 67 69 70 73 77 78 79 86 87 9

13 17 18 19 20 21 23 24 25 27 28 29 30 31 32 35 36 37 38 4.42 4.28 15.91 1.48 11.37 19.22 19.35 18.20 18.74 9.77

.9.77 6.77 9.73 10.65 12.70 6.08 7.70 14.82 11.37 7.38 5.67 3.52 8.54 10.21 18.72 6.79 16.04 13.05 7.56 13.28 11.88 10.11 10.05 12.93 7.53 11.38 10.59 2.56 5.21 5.23 9.81 10.75 12.38 20.29 14.82 10.95 12.01 20.98 8.65 15.83 16.94 15.07 14.75 4.93 15.10 11.39 14.84 55 46

.68 69 76 66 62 58 66 65 89 78 68 66 72 67 54 66 67 69 77 76 79 60 62 87 75 72 60 61 71 53 52 63 63 80 62 68 71 64 70 68 59 63 56 56 81 57 65 47 50 68 67 62 62 63 72 PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC

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+0.08 TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TSC TEC TEC TEC TEC TEC TEC TEC TEC TEC 315 217 133 329 147 259 294 360 220 140 224 360 148 206 250 133 261 295 287 229 173 169 99 360 180 199 300 311 255 171 127 224 209 234 206 129 178 126 168 154 308 161 332 84 248 360 234 140 217 287 276 287 178 150 171 283 199 10

14 14 14 14 14 14 14 14 14 14 14 14 14 14 14 14 14 14 14 14 14 14 14 15 15 15 15 15 15 15 15 15 15 15 15 15 15 15 15 15 15 15 15 15 15 15 15 15 15 15 15 15 15 15 15 15 15 39 41 42 44 48 49 57 58 59 63 64 65 66 67 69 70 71 72 74 76 77 79 82 9

18 19 20 21 23 24 25 26 27 28 29 30 31 32 33 38 39 40 42 46 55 56 57 63 64 65 66 68 69 70 71 76 77 10.45 3.64 3.00 5.74 12.70 7.70 2.95 3.27 8.17 5.54 11.09 17.82 11.49 1.34 9.72 7.35 4.77 8.05 14.18 16.80 7.26 6.70 6.40 10.80 7.71 3.20 8.80 19.84 9.71 14.24 11.67 2.88 11.70 6.72 20.63 6.05 27.09

5. 68 11.05 16.35 8.63 17.86 8.38 3.45 20.57 13.71 15.67 4.46 15.78 10.38 6.75 6.65 14.54 7.76 3.36 6.31 6.78 77 58 38 50 62 86 63 73 74 79 70 71 49 43 63 83 67 71 73 72 70 64 59 80 50 60 49 74 60 70 70 67 77 59 52 43 54 85 62 65 79 62 62 48 66 67 64 44 5.5 50 55 51 65 66 53 62 59 PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC

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+0.07 TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC.

TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC

)TEC TEC TEC TEC 238' 101 102 297 95 70 168 236 101 140 203 255 247 52 199 275 181 150 233 182 189 70 133 255 295 164 231 213 189 290 224 283 101 73 203 245 318 266 150 233 208 166 138 102 176 360 212 175 245 268 106 270 249 198 125 220 213 I1

15 16 16 16 16 16 16 16 16 16 16 16 16 16 16 16 16 16 16 16 16 16 16 16 16 16 16 16 16 16 16 16 16 16 16 16 16 17 17 17 17 17 17 17 17 17 17 17 17 17 17 17 17 17 17 78 18 19 20 21 22 25 26 28 30 31 32 33 34 39 40 41 42 43 52 53 54 55 56 61 62 63 64 65 67 68 69 70 71 75 76 77 18 19 20 21 22 24 26 27 28 29 30 31 32 33 34 35 36

.43 13.91 61 14.55 68 11.17 68 16.10 55 12.79 52 26.10 56 9.91 54 3.75 63 17.10 61 20.48 67 16.47 44 25.65 61 7.91 73 4.71 48 9.28 73 4.59 71 9.68 67 7.59 75 6.90 63 11.26 66 14.58 61 10.08 51 9.89 48 10.18 57 6.52 78 2.51 59 6.58 90 13.81 51 9.93 69 12.46 58 2.85 50 7.53 77 7.52 68 4.12 80 7.89 70 12.02 65 19.48 60 10.69 58 11.14 66 6.10

.64 4.32 58 4.24 51 6.74 50 13.33 66 6.15 91 6.22 74 5.80 60 8.03 53 7.56 47 2.42 84 10.51 66 14.79 65 11.80 77 9.44 67 11.01 69 2.31 79 7.63 72 PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC

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+0.08

+O.Oi

+0.04

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+0.01

+0.04 TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC 192 213 283 154 157 196 192 290 269 161 360 320 248 136 101 136 300 150 150 122 140 199 245 283 168 105 248 254 283 359 66 206 360 52 106 241 199 360 252 101 273 224 168 241 52 224 136 164 273 27.3 147 304 360 220 276 30 255 12

17 17 17 17 17 17 17 17 17 17 17 17 17 17 17 17 17 17 17 17 17 17 17 17 18 18 18 18 18 18 18 18 18 18 18 18 18 18 18 18 18 18 18 18 18 18 18 18 18 18 18 18 18 44 46 47 48 49 50 51 52 53 54 59 60 61 62 63 64 66 67 68 69 70 71 74 76 19 20 21 22 23 25 26 28 29 30 31 32 33 34 35 36 4.6 47 48 49 50 58 59 60 61 62 63 65 67 10.64 13.60 10.99 15.42 14.86 16.17 12.68 10.00 14.49 16.68 11.16 3.53 8.96 19.92 6.78 16.82 15.23 13.68 15.32 11.38 14.32 12.04 11.4 6 7.38 4.77 10.85 13.51 12.51 16.09 20.57 28.78 9.18 13.46 9.59 13.67 14.24 4.80 5.75 11.56 5.30 7.45 3.64 11.88 7.47 10.35 3.06 11.66 6.52 13.18 11.80 5.83 10.86 9.52 12.18 15.21 10.84 13.-77 74 76 56 68 66 69 63 63 57 69 80 110 73 61 72 48 42 88 60 57 59 50 70 80 55 72 70 69 76 66 59 76 62 71 67 77 55 63 85 56 80 72 80 88 83 87 69 92 71 67 62 51 54 49 62 77 63 PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC

+0.02

+0.13

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+0.04 TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TSC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TSC TEC TEC TEC TEC TEC TEC TEC TEC TEC 266 255 255 217 266 260 180 178 345 213 206 266 140 301 340 314 210 154 169 300 330 320 289 147 52 77 182 213 269 357 231 147 283 175 252 276 73 91 294 164 163 146 126 154 196 91 101 227 213 220 224 150 310 293 150 196 245 13

18 18 18 18 18 18 18 19 19 19 19 19 19 19 19 19 19 19 19 19 19 19 19 19 19 19 19 19 19 19 19 19 19 19 19 19 19 19 19 19 20 20 20 20 20 20 20 20 20 20 20 20 20 20 2.0 20 68 70 74 75 76 80 81 19 20 21 22 23 24 27 29 30 31 34 35 36 37 40 44 55 56 57 58 59 60 61 64 65 66 67 68 69 73 75 79 80 20 21 22 23 24 2.5 27 28 29 30 31 32 33 35 36 37 12.59 8.16 16.35 11.97 13.92 14.28 11.46 3.96 5.69 12.15 7.42 5.67 19.30 6.19 9.89 4.90 11.89 6.47 4.14 16.15 11.73 2.86 3.02 18.59 15.14 10.44 16.12 15.69 16.94 6.38 12.97 16.62 6.93 13.53 4.77 7.85 11.82 14.32 2.22 16.43 15.60 4.40 14.13 11.27 10.42 14.00 19.25' 5.65.

8.66 15.74 8.77 9.25 8.09 3.56 11.04 9.25 9.18 61 65 39 72 74 59 78 80 68 65 51 37 57 71 59 56 64 56 55 75 76 64 81 65 66 64 62 61 62 45 78 62 68 63 79 78 63 65 59 77 66 76 61 45 39 60 68 58 63 67 64 74 75 66 72 62 75 PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN.

PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN TEC TEC TEC TEC TEC TEC TEC TEC TEC

TEC, TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC

+0..00

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+0.02

+0.04 TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC 287 198 273 227 203 311 143 216 122 229 269 147 140 73 203 252 168 231 329 210 231 94 98 133 203 203 309 339 260 260 175 262 360 293 307 185 269 224 31 231 280 91 171 343 248 203 136 30 73 220 318 190 171 105 112 196 160 14

20 38 15.17 66 PVN TEC

+0.03 TEC TEC 305 2.23 60 PVN TEC

+0.10 TEC TEC 199 20 39 18.68 68 PVN TEC 40.03 TEC TEC 245 20 40 15.33 70 PVN TEC

+0.00 TEC TEC 320 20 41 9.57 69 PVN TEC

+0.07 TEC TEC 180 20 42 12.30 69 PVN TEC

+0.03 TEC TEC 199 20 43 17.06 73 PVN TEC

+0.05 TEC TEC 133 20 52 9.52 65 PVN TEC

+0.00 TEC TEC 129 20 53 15.06 59 PVN TEC

+0.03 TEC TEC 185 20 54 15.39 61 PVN TEC

+0.00 TEC TEC 280 11.10 53 PVN TEC

+0.07 TEC TEC 283 20 55 9.14 40 PVN TEC

+0.08 TEC TEC 122 20 56 11.45 68 PVN TEC

+0.06 TEC TEC 255 20 57 10.19 53 PVN TEC

+0.02 TEC TEC 360 20 58 14.91 78 PVN TEC

ý+0.08 TEC TEC 320 7.82 68 PVN TEC

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+0.03 TEC TEC 143 20 60 9.25 70 PVN TEC

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+0.01 TEC TEC 53 20 63 8.33 77 PVN TEC

+0.00 TEC TEC 331 20 64 9.39 62 PVN TEC

+0.00 TEC TEC 340 20 65 16.78 47 PVN TEC

+0.03 TEC TEC 129 20 66 7.78 93 PVN TEC

+0.04 TEC TEC 187 20 67 14.52 60 PVN TEC

+0.05 TEC TEC 164 20 68 8.66 68 PVN TEC

+0.00 TEC TEC 262 20 72 13.95 76 PVN.

TEC

+0.00 TEC TEC 175 20 73 10.23 61 PVN TEC

+0.06 TEC TEC 227 20 75 12.41 80 PVN TEC

+0.01 TEC TEC 129 20 78 19.23.65 PVN TEC

+0.04 TEC TEC 182 20 79 8.92 67 PVN TEC

+0.05 TEC TEC 360 20 80 14.73 73 PVN TEC

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+0.03 TEC TEC 129 21 22 12.32 57 PVN TEC

+0.05 TEC TEC 311 21 23 14.21 50 PVN TEC

+0.06 TECTEC 175 21 24 10.39 42 PVN TEC

+0.02 TEC TEC 259 21 25 11.03 53 PVN TEC

+0.01 TEC TEC 360 21 26 11.03 64 PVN TEC

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+0.01 TEC.TEC 213 21 30 9.79 63 PVN TEC

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+0.07 TEC TEC 320 21 38 11.53 75 PVN TEC

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+0.00 TEC TEC 293 21 51 11.19 60 PVN TEC

+0.07 TEC TEC 270 21 52 2.79 74 PVN TEC

+0.03 TEC TEC 176 21 53 7.36 55 PVN TEC

+0.00 TEC TEC 320 15

21 21 21 21 21 21 21 21 21 21 21 21 21 21 21 21 21 21 21 21 22 22 22 22 22 22 22 22 22 22 22 22 22 22 22 22 22 22 22 22 22 22 22 22 22 22 22 22 22 22 22 22 22 22 22 22 54 55 56 57 58 61 62 63 64 65 66 67 69 71 72 73 74 77 78 79 7

22 23 24 25 26 27 29 30 31 32 33 34 35 36 38 39 40 41 42 43 44 45 46 47 48 49 50 51 52 53 54 55 56 59 60 19.52 10.87 11.47 9.07 17.46 10.00 13.54 7.72 8.37 8.47 9.30 14.89 6.74 16.60 12.81 3.65 14.27 11.27 10.98 17.22 1.39 14.03 11.78 6.97 9.33 9.92 28.06 10.54 8.97 19.41 10.48 3.75 2.13 12.77 21.98 5.66 4.95 9.03 13.66 7.38 8.20 19.73

15. 60 16.97 18.41 14.41 11.83 16.76 17.09 14.65 15.40' 16.31 8.33 15.26 13.51 10.82 10.39 58 48 56 62 61 61 66 86 72 73 61 63 63 69 60 55 67 76 37 64 44 74 76 83 49 71 55 72 83 64 67 85 61 70 67 68 65 72 76 55 54' 47 57 60 61 71 58 61 61 65 62 56 35 66 68 85 75 PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC.

TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC

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+000

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+0.03

+0.05 TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC 210 360 231 315 161 147 330 280 196 270 215 273 77 143 252 143 213 66 224 199 136 171 238 231 360 196 122 157 301 310 203 143 154 297 241 80 63 175 245 273 297 301 315 300 231 300 268 360 248 360 240 241 260 262 157 140 281 16

22 22 22 22 22 22 22 22 22 22 22 22 22 22 23 23 23 23 23 23 23 23 23 23 23 23 23 23 23 23 23 23 23 23 23 23 23 23 23 23 23 23 23 23 23 23 23 23 23 23 23 23 23 23 23 23 61' 62 63 64 65 66 67 68 70 71 72 73 77 78 24 25 26 27 28 31 32 34 35 36 37 38 39 41 42 43 44 45 46 47 48 49 50 51 52 53 56 57 58 59 60 61 62 63 64 65 69 70 71 72 73 76 9.07 8.67 13.18 6.48 12.71 0.94 4.04 3.80 15.07 15.53 11.29 11.53 29.60 22.34 11.24 5.15 7.81 6.68 2.99 10.14 5.67 3.67 4.07 3.74 14.43 10.19 23.14 13.84 7.62 3.49 8.28 7.62 10.18 8.54 14.03 13.79 9.40 14.51 6.78 9.84 13.82 8.65 20.43 14.40 9.52 8.15 7.58 7.24 6.44 10.37 5.37 21.59 13.65 8.60 9.33 5.75 13.03 54 54 63 66 56 57 59 58 73 57 71 62 57 70 62 53 77 45 61 52 68 63 82 57 80 58 57 69 83 61 56 87 60 78 59 64 80 59 74 73 63 76 67 61 77 67 71 69 52 80 78 66 53 63 68 53 71 PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC

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+0.03 TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TSC TEC TEC TSC TEC TSC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TSC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TSC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC 260 355 252 77 238 63 91 80 115 360 234 227 275 269 360 252 325 234 234 199 217 91 213 248 269 310 238 140 224 60 273 178 168 115 259 164 199 245 203 231 300 56 224 280 220 299 320 245 143 147 105 164 360 320 178 56 91 17

23 23 24 24 24 24 24 24 24 24 24 24 24 24 24 24 24 24 24 24 24 24 24 24 24 24 24 24 24 24 24 24 24 24 24 24 24 25 25 25 25 25 25 25 25 25 25 25 25 25 25 25 25 25 25 25 77 11.00 78 6.58 24 11.28 25 9.64 26 16.07 27 10.97 28 13.46 29 18.85 33 9.38 35 15.26 36 8.32 37 5.62 38 8.09 39 16.29 40 11.53 41 22.77 42 13.44 43 16.16 44 7.69 47 1.18 52 10.37 53 18.40 54 14.79 55 9.64 56 12.77 57 12.37 58 8.22 59 9.89 60 10.93 61 14.05 62 10.18 63 12.62 64 6.03 68 21.50 69 18.34 70 15.37 71, 12.92 25 5.65 26 9.57 27 14.15 28 2.03 29 15.50 30 10.27 31 23.80 35 7.25 36 7.20 37 3.56 38 11.90 39 4.90 40 10.26 41 11.65 42 10.80 43 7.01 44 11.10 45 9.62 7.35 46 13.53 67 61 66 64 56 64 43 69 78 66 67 65 79 59 64 67 72 78 66 61 70 55 67 77 57 69 66 65 62 62 76 59 58 65 61 46 67 81 66 67 44 41 57 54 58 62 87 79 51 63 67 63 44 86 63 64 74 PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC

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+0.08 TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TSC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TSC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TSC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC 252 63 196 269 318 238 360 210 168 276 227 168 320 320 248 186 129 140 1"61 60 129 119 220 254 310 182 185 320 294 206 224 229 155 196 337 346 290 122 319 332 269 273 339 133 234 122 154 171 336 234 300 276 290 262 294 171 300 18

25 25 25 25 25 25 25 25 25 25 25 25 25 25

.25 25 25 25 25 25 25 26 26 26 26 26 26 26 26 26 26 26 26 26 26 26 26 26 26 26 26 26 26 26 26 26 26 26 26 26 26 26 26 26 26 47 48 49 50 51 52 53 54 55 56 57 58 59 60 61 62 67 68 69 70 71 16 26 27 28 29 30 31 32 33 35 36 37 38 39 40 41 42 43 44 45 46 49 50 51 52 53 54 55 56 57 58 59 60 61 20.47 21.11 18.12 17.16 16.43 10.71 13.43 8.08 11.46 13.48 12.51 11.84 7.01 7.52 1.87 8.67 16.14 14.18 8.67 9.25 4.89 2.83 8.78 8.02 12.33.

7.99 10.28 8.54 23.22 5.47 6.82 6.67 10.42 6.35 9.16 8.52 4.08 12.01 4..85 10.98 14.84 5.55 13.32 13.09 12.16 17.66 8.62 12.36 3.12 13.25 11.77 8.66 9.28 12.60 12.38 5.56 4.43 52 58 58 58 62 64 52 70 56 61 82 68 62 54 43 71 81 49 73 73 68 55 69 63 76 51 37 52 58 62 68 82 68 67 83 78 32 72 50 63 50 53 70 71 61 58 65 45 56 62 61 64 63 73 70 74 61 PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PYN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC

+0.07

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+0.16

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+0.07

+0.02

+0.02 TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC Tsc TEC TSC TEC TEC TSC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TSC TEC TEC TEC TEC TEC TEC TEC TEC TSC TEC TEC TEC TEC TEC TEC 248 276 293 260 320 245 224 107 245 276 300 259 195 143 80 129 224 345 185 276 50 140 147 290 220 360 304 320 213 101 56 175 127 142 122 129 192 206 30 315 320 283 199 290 290 259 290 203 227 300 318 168 252 310 196 108 161 19

26 26 26 26 26 26 27 27 27 27 27 27 27 27 27 27 27 27 27 27 27.

27 27 27 27 27 27 27 27 27 27 27 27 27 27 27 27 27 27 28 28 28 28 28 28 28 28 28 28 28 28 28 28 28 28 28 28 62 65 66 67 68 69 27 28 29 30 31 32 33 34 35 38 39 40 41 43 44 45 46 49 50 51 52 53 56 57 58 59 60 61 64 65 66 67 68 28 29 30 31 32 33 34 35 36 37 41 43 47 48 49 50 51 52 8.57 1.82 21.78 4.43 9.60 13.34 2.79 2.29 3.93 6.68 8.50 3.47 22.54 20.14 3.37 2.86 4.47 3.81 7.60 3.31 7.56 9.86 6.79 4.00 8.66 8.81 12.67 6.25 11.66 9.60 6.78 14.31 13.66 12.80 21.80 16.66 11.28 11.26 8.54 2.61 3.08 6.72 13.77 12.55 2.46 12.94 11.19 19.61 22.16 10.41 11.29 4.59 13.51 3.74 5.77 4.29 6.74 81 55 61 66 41 75 73 58 59 55 46 53 51 70 66 85 73 49 75 76 65 70 72 98 71 69 75 68 79 69 49 68 65 75 62 39 52 63 63 63 65 38 58 48.

54 75070 62 67 62 69 52 66 74 41 51 84 PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC

+0.02

+0.03

+0.05

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+0.00

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.+0.05

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+0.00

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+0.00

+0.04

+0.03

+0.00 TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TIEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TSC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC 126 34 273 336 325 164 80 178 301 360 360 355 320 203 91 192 84 91 300 136 66 203 129 94 122 206 122 185 150 231 320 310 321 140 175 266 360 360 140 63 59 360 315 360 350 360 320 273 164 63 105 84 290 66 87 164 147 20

28 28

,28 28 28 28 28 29 29 29 29 29 29 29 29 29 29 29 29 29 29 29 29 29 29 29 29 29 30 30 30 30 30 30 30 30 30 30 30 30 30 30 30 30 30 30 30 30 30 30 30 30 30 30 30 30 30 57 59 62 63 64 66 67 26 27 28 30 31 32 33 34 35 36 37 38 39 40 41 59 60 61 62 63 64 28 29 32 33 34 35 36 37 38 39 40 41 42 43 44 45 46 47 48 49 50 51 52 53, 54 57 58 59 60 7.88 9.56 25.62 12.29 6.37 14.03 11.52 4.87 12.04 11.25 5.01 2.17 7.63 13.34 3.16 2.66 13.94 17.26 13.88 26.02 15.46 16.48 2.54 21.86 13.25 12.99 16.89 12.29 10.01 13.81 7.68 12.06 12.15 8.07 11.00 17.39 12.85

11. 94 11.26 8.86 10.98 22.75 20.02 21.74

18. 64 23.14 28.22 25.61 14.06 16.06 26.11 14.52 24.45 11.75 16.44 11.88 5.71 57 74 61 62 54 69 72 73 63 63 74 30 49

.44 41 59 63 58 49 65 72 65 62 62 65 60 61 74 64 61 71 53 55 47 62 49 67 46 66 68 55 59 64 72 65 61 58 58 64 58 55 67 66 68 61 71 66 PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN-PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC

+0.04

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+0.01*

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+,0.07

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+0.04

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+0.04

+0.06 TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC

TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC "TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TSC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TSC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC 98 87 164 304 185 283 84 105 269 84 115 350 360 320 360 360 260 262 248 259 175 133 52 206 224 320 283 294 287 143 126 294 259 280 300 320 330 330 264 320 320 290 234 210 178 182 192 196 185 203 276 311 241 150 150 300 219 21

30 30 30 31 31 31 31 31 31 31 31 31 31 31 31 31 31 31 31 31 31 31 31 31 31 31 31 31 31 32 32 32 32 32 32 32 32 32 32 32 32 32 32 32 32 32 32 32 32 32 32 32 32 33 33 33 33 61 62

.63 34 35 36.

37 38 39 40 41 42 43 44 45 46 47 48 49 50 51 52 53 54 55 56 57 58 61 32 36 37 38 39 40 41 42 43 44 45 46 47 48 49 50 51 52 53 54 55 56 57 58 39 41 42 44 9.37 12.50 3.57 8.81 9.85 6.77 9.59 8.45 8.16.

9.20 11.23 8.10 8.01 15.53 13.24 8.49 8.49 10.68 14.33 14.30 10.68 10.63 11.45 11.64 12.11 18.80 7.57

11. 63 2.42 4.91 2.28 10.52 4.80 12.06 6.21 9.45 12.61 2.40 13.74 12.35 4.71 12.46 7.72 10.46 13.77 10.81 6.68 11.52 7.79 10.43 7.55 9.45 4.90 5.57 9.22 10.15 15.24 52 69 57 85 81 67 55 65 71 89 61 70 60 54 61 62 55 57 51 54 49 64 51 60 70 58 64 77 56 62 63 75 51

.72 68 66 73 5o 65 59 55 62 43 50 62 66 52 74 67 69

.70 85 74 57 56 72 68 PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC

+0.09

+0.04

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+0.06

+0.00

+0.02

+0.00

+0.03

+0.00

+0.05

+0.04

+0.05 TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TE C TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TSC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC 300 252' 42 108 231 301 360 315 360 300 273 300 360 308 320 250 320 320 320 340 260 240 276 280 206 290 132 147 38 198 45 129 330 294 340 280 178 290 320 300 320 330 360 300 259 185 210 245 227 297 241 246 101 66 227 161 255 22

33 33 33 33 33 33 33 33 34.

45 45 45 46 47 48 50 51 53 56 50 46 49 7.63

11. 92 9.74 2.03 10.41 12.90 5.91 3.18 3.12 3.08 2.39 72 63 65 56 71 72 68 71 61 66 69 PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN PVN TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC

+0.03

+0.06

+0.02

+0.01

+0.09

+0.05

+0.01

+0.02

+0.04

+0.01 TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC TEC 101 234 241 77 175 245 87 38 45 38 59 23

v t e Letter Sequence Request
TAC:ME2898, (Approved, Closed)
Initiation Request, Request, Request, Request, Request Acceptance... Administration Questions Answers 7 June 2010 Results Approval Other:
MONTHYEAR2009-02-27 [Table View]

ML091270444

Text

SUMMARY

3.1 Background

4.0 TECHNICAL EVALUATION

8.0 ENVIRONMENTAL CONSIDERATION

9.0 CONCLUSION

10.0 REFERENCES

Subject:

Reference:

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