10983104-Pipe-Stress-p48

BARRACUDA AND CARATINGA CRUDE OIL FIELDS PRODUCTION

FACILITIES PROJECT

Document Title PIPING STRESS ANALYSIS PHILOSOPHY

Project Document Number I-PH-FGG-GENL-PI-T.08-001

Owner Document Number I-MD-3010.00-1223-200-IES-001

FieldG

UnitF

Copy CodeXX

CS ApprovalN

Owner ApprovalY

Lifecycle CodeFL

B03 14-Sep-01 Released for Design / Revisedwhere shaded

DAM MH NLCO RAC JG

B02 20-July-01 Released for Design /Revised where shaded

DAM MH NLCO RAC JG

B01 30-May-01 Released for Design /Revised where shaded- ADP 0426/01

DAM NLCO NLCO RAC JG

A01 24-Apr-01 For Comment/Revised where shaded

MH NLCO NLCO RAC JG

001 26-Mar-01 INTER-DISCIPLINE CHECK MH NLCO NLCO RAC JG

Rev Date Description Originator Checked DisciplineLead

Mgmt KBR Owner

Released*

*Printed initials in the approval boxes confirm that the document has been released. The originals are held within Document Management.

BARRACUDA AND CARATINGA CRUDE OIL FIELDS PRODUCTION FACILITIES PROJECT of 20

PIPING STRESS ANALYSIS PHILOSOPHY – I-PH-FGG-GENL-PI-T.08-001 Rev. B03

CONTENTS

SHEETS

1.0 INTRODUCTION 4

1.1 Purpose 4

1.2 Scope 4

2.0 CODES, STANDARDS AND REGULATIONS 4

2.1 International Codes 4

2.2 Petrobrás Codes 5

2.3 Project Documentations 5

3.0 TECHNICAL REQUIREMENTS 5

3.1 Critical Line Selection Criteria 5

3.2 Stress Calculation Methods 6

3.3 Fatigue Considerations 6

3.4 Structural Deflections 7

3.5 Inertial Accelerations 7

3.6 Wind and Wave Loads 7

3.7 Transportation 8

3.8 Blast Loading Analysis 8

3.9 Slug Flow 8

3.10 PSV Valve Piping Systems 8

3.11 Flange Leakage Check 9

4.0 STRESS ANALYSIS PROCEDURE 9

4.1 General Informations 9

4.2 Piping Stress Analysis Report 11

4.3 Load Combinations 11

P-43 BARRACUDA & P-48 CARATINGA 14- Sep-01

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5.0 PIPING SUPPORT 12

5.1 Calculation of Span Between Supports 12

5.2 Calculation of Loads on Supports 14

6.0 EQUIPMENT NOZZLE LOADING 15

7.0 PLASTIC PIPE DESIGN 15

Appendix 1 - Maximum Span Between Pipe Supports

Appendix 2 - Allowable Nozzle Loads for Pressure Vessels, Columns, Shell &Tube Heat Exchangers and Equipment Packages Tie-ins

Appendix 3 - API Equipment - Allowable Nozzle Loads

Appendix 4 - Procedure for Stress Analysis of Piping Systems on FPSO, using Caesar II Program.

Appendix 5 - Procedure for Stress Analysis of Glass Reinforced Vinyl Ester and Epoxy Piping (FRP) on FPSO, using Caesar II Program.

Appendix 6 - Procedure for Blast Analysis of Piping Systems on FPSO, using Caesar II Program.

Appendix 7 - Blast Design Criteria

Appendix 8 - Simplified Methodology for Fatigue Analysis

Appendix 9 - Expansion Joints Dimensional Drawing.


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1.0INTRODUCTION

1.1 Purpose

1.1.1 The purpose of this document is to define the Piping Stress Analysis Philosophy of the Floating, Production, Storage and Offloading FPSO Unit P-43 at Barracuda Field and FPSO Unit P-48 at Caratinga Field.

1.2Scope

1.2.1 It consists of balancing efforts and tensions in a system through the location of supports, guides, transverse guides and anchorages, so that satisfies acceptable conditions for the Code ASME B31.3.

1.2.2 This Philosophy is prepared to assist Piping Stress Engineers working on the project and packaged equipment Suppliers in carrying out the task of piping stress analysis in accordance with the guidelines and procedures presented here, it is intended to achieve the following objectives:

• To assure that all piping stress analysis and piping support design calculations comply with Piping Engineering Standard and Piping Specification, and all applicable regulatory codes referenced within.

• To assure that all calculations are performed in accordance with uniform analysis procedures and methods.

• To establish that the stress analysis problems are properly reviewed for code and specification compliance.

1.2.3 The following piping calculations are included in this document:

• Stress analysis• Span between supports• Loads on supports• Equipment nozzle loading• Fatigue Analysis• Blast Analysis• Plastic Pipe Analysis

2.0 CODES, STANDARDS AND REGULATIONS

2.1International Codes


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• American Society of Mechanical Engineers (ASME)ASME B16.5

Pipe flanges and flanged fittings;

ASME B16.47

Large Diameter Steel Flanges (NPS 26” through NPS 60”);

ASME B31.3

Process piping;

ASME Section VIII Pressure vessels.


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• American Petroleum Institute (API)API RP 14E

Recommended Practices for Design and Installation of Offshore Production Platform Piping System;

API STD 6AF

Bulletin on Capabilities of API Flanges Under Combinations of Loads;

API STD 610 Centrifugal pumps for petroleum, heavy duty chemical and gas Industry services;

API STD 616 Gas Turbine;API STD 617 Centrifugal compressors for petroleum, chemical and gas

industry services.

• Welding and Research Council (WRC)WRC-107 Local stresses in spherical and cylindrical shells due to external

loading.

• Classifications Notes DNV Note no.30.2 Fatigue strength analysis for mobile offshore units.ABS ABS Rules for Building and Classing Steel Vessels 2000.

• Standard of Expansion Joint Manufacturers Association ( EJMA )

2.2PETROBRAS Codes

• N-1673 – Piping mechanical calculation criteria.

2.3 Project Documentations

• I-ET-3010.00-1223-200-IES-001- Piping Specification mechanical calculation criteria.• I-DE-3010.00-1223-293-IES-001- Piping Standard Support Drawing.

3.0 TECHNICAL REQUIREMENTS

3.1Critical Line Selection Criteria

3.1.1 Critical lines are defined as lines that require a stress analysis. They shall be selected in accordance with following selection criteria:

• ND 4 in and smaller with design temperature over 260 ºC (500 ºF)• ND 6 in and larger with design temperature over 204 ºC (400 ºF) and less than -73 ºC

(-100 ºF)• ND 16 in and larger• Lines having substantial concentrated loads such as valves, fittings, vertical piping.• ND 3 in and larger closed pressure relief system piping, where design temperature exceeds

93 ºC (200 ºF) or is less than -73 ºC (-100 ºF)• ND 3 in and larger connected to:- Rotating equipment such as pumps and compressors.P-43 BARRACUDA & P-48 CARATINGA 14- Sep-01

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- Piping to reciprocating pumps and compressors. - Plate and frame heat exchanger piping.- Gas turbine piping.


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• Blowdown and flare header or vent piping.• Piping with pressure surge, slug and two phase flow.

• Normally dry firewater piping and normally charged firewater ring main piping.

• Piping subject to short term variations such as steam out or purge piping.

• Piping between riser support and pig receiver and launcher.

• Relief valve piping reaction forces.

• Lines effected by deck deflection, platform settlement, wellhead movement or any other significant displacement.

• Lines subjected to vacuum conditions.

• Lines, which may create large forces or moments on structures or skid, base.

• Unbalanced piping configuration, such as a long run of pipe with a short branch connected to anchor.

• Piping subjected to high cyclic temperature conditions.

• All piping with t > D/6 or P/SE > 0.385.

• ND 4 in & larger with t > 10% OD.

• FRP ND 12 in and larger.

• Lines with special design requirements.

• In addition, the piping effects of other conditions such as temperature gradients that could cause thermal bowing or where piping is connected to equipment with significant thermal growth may cause a piping engineer to analyse a line.

3.2Stress Calculation Methods

3.2.1 In general, formal computer analysis shall be performed for critical lines. However, after having reviewed a particular piping layout, the Piping Stress Engineer may apply engineering judgements and past experiences to qualify that piping system by simple calculations using nomograph charts or by visual inspection method. Even when formal computer analysis is not required, a report with all approved lines or systems shall be issued.

3.2.2 For formal computer analysis method the software Caesar II, version 4.2, must be used.

3.2.3 The axis orientation for modelling Caesar II are: “X” axis is longitudinal to ship, positive forward, “Y” axis is vertical, positive to up and “Z” axis is transverse, according to right hand rule.

3.3Fatigue Considerations

3.3.1 The FPSO vessel will be exposed to constant environment loads. These conditions will cause inertial accelerations and deflections to both the hull and topsides structures. Piping systems have to adequately withstand such loads throughout the design life. Sufficient piping flexibility must be designed so that equipment loading and pipe stresses are maintained at acceptable levels. The Weibull parameter given by the structural department based on DNV Classification Notes No 30.7 is 1,10. Fatigue of piping will be based on the S-N fatigue approach under the assumption of linear cumulative damage (Palmgrens-Miner rule from DNV Classification Notes 30.7 paragraph 1.4.


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3.3.2 Detail instruction for modelling fatigue in combination with other significant load combinations is given in Appendix 4, follow the orientation of DNV Classification Note N.30.2, August 1984.

3.4Structural Deflections

3.4.1 Structural deflections shall be considered for both maximum displacement stress range criteria and fatigue criteria.

3.4.2 Structural deflections will be given by Structural group.

3.5Inertial Accelerations

3.5.1 Inertial accelerations due to ship motions shall be considered for both maximum sustained stress criteria and fatigue criteria.

3.5.2 Inertial accelerations will be given by Structural group.

3.6Wind and Wave Loads

3.6.1 Wind load shall be considered in static analysis (occasional loads). Caesar II Wind Load spreadsheet will be used to calculated wind load, once for “X” direction winds and once for “Z” direction winds. The analyst is responsible to determine which direction results in the more conservative design.

In general, wind speed of 40.03 m/s with 1 minute at 37m elevation shall be considered. This value is considered the most critical condition (storm). Use pipe shape factor of 0.70.

3.6.2 Effects of wave loads on riser pipes or piping inside the cargo tanks, wherever applicable, shall be considered in stress calculation. Caesar II Wave Load spreadsheet will be used to calculate wave loads. “Green Water Wave” shall be considered as follows:For all items located below an elevation of 2 meter above the Main Deck, a hydrostatic head of 2 meter and a wave velocity of 9 meter/sec horizontally in any direction shall be applied. Equipment attached to the Main Deck of the vessel shall be considered for uplift due to the buoyancy load.The green water loading shall only be considered for the 100 year centenary condition. Allowable yield stress shall be as considered for the 100 year environmental cases. Green water loading shall be considered as an additional environmental load with no increase in yield.Green Water Evaluation is described in Document I-RL-DGG-GENL-PM-BRY-004. The following are loads to be applied to various diameters.


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3.7Transportation

3.7.1 Transportation shall be considered in piping stress analysis by applying applicable accelerations given by the Preliminary Design Methodology, for pipes ND 6” and larger.

3.7.2 For FPSO, shall be considered per Specification I-ET-FGT-GENL-ST-C.06-001 TOPSIDES STRUCTURAL DESIGN PREMISSE.

3.7.3 Pipe support configuration shall be arranged and designed for both operation and transportation so that temporary supports for transportation can be kept to minimum. Temporary support for transportation shall be clearly annotated on fabrication isometrics and shall be removed after transportation.

3.8 Blast Loading Analysis

Piping systems required to hold integrity during a blast occurrence will be identified by the Safety / Loss Control Group. Those piping systems will be then designed and arranged accordingly. Blast load on piping systems will be modelled as a “drag force” proportional to the density of the vapour cloud ignited, velocity of the shock front during ignition and the projected area / drag coefficient of the piping system. For design criteria, see I-ET-FGT-GENL-ST-BRY-103.-Blast Design Criteria for Vendor Equipment and Piping.Definition of systems to be analysed is found in Appendix 7-Blast Design Criteria

3.9 Slug Flow

Piping systems subjected to slugging will be identified by Process group. Slug force shall be applied at changes of direction to determine stress and pipe support loads.

3.10 PSV Valve Piping Systems

PSV force will be calculated as per API 520 or taken from Relief Valve Thrust Loads, provided by Instrumentation group, times 2.0 Dynamic Load Factor (DLF). This force shall be applied at PSV valve to obtain the stress and pipe support loads.


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3.11 Flange Leakage Check

Flanges shall be located at locations that are subjected to the least external bending moments possible. The following criteria shall be used to check for flange leakage.

For API flanges, external combined bending moment and axial force shall be compared and kept within the allowable given by API 6AF;

For ASME B16.5 & B16.47 flanges, where the sustained stress do not exceed 0.25 x Sh and the displacement stress do not exceed 0.20 x SA, no further checks will be required. Otherwise, Caesar II flange leakage analysis shall be used. The analysis is based on ASME Section VIII Div. 1 and Div. 2, with Section VIII Appendix 2 flange rigidity. All allowable stress multipliers are 1.0. The flange is considered not to leak if the flange stresses are within allowable sustained load for the flange material and the rigidity factor is less than 1.

4.0 STRESS ANALYSIS PROCEDURE

4.1General Informations

4.1.1 The flexibility analysis due to the thermal expansions (or contractions) to the motion of the extreme piping points or to the combination of such effects, shall be made as required by ASME B31.3. This study can be made through general analytical method or graphical methods.

4.1.2 The analysis is mandatory to all critical lines that must be selection in accordance to the critical line selection criteria and a list with these lines will be prepared. This list will be used as Critical Line Index to control the progress of stress analysis activities.

4.1.3 The piping flexibility shall be obtained with an adequate non-straight lay out and the use of expansion joint shall be restricted.

4.1.4 Design temperature and design pressure shall be used in the stress analysis. Except for rotating equipment where operating temperature can be used for equipment nozzle loading qualifications.

4.1.5 Line properties, valves, material and other stress analysis input data pertaining to each problem shall be documented in the stress analysis report.

4.1.6 Valve data (weights) and special items shall be taken from one of the potential suppliers and shall be verified once the final supplier has been selected and provide the informations. It is important that the correct weight for each valve is input to the analysis of critical piping systems, such as line to / from gas compressors and pumps, and any piping system that requires spring hangers.

4.1.7 Spring hangers/supports shall be used for exceptional cases only since they may not behave consistently with inertial accelerations. Combination of snubber restraints and spring hangers/supports may have to be considered.

4.1.8 The loads and movements calculation for selection and sizing the spring supports shall be based on the general analytic method or computation method, to guarantee a better accuracy.


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4.1.9 The flexibility analysis must include the determination of all loads carried out by the piping on the fixed points (anchoring and extreme piping points), as well as on every existing motion restraints devices (longitudinal, transverse or double guides).

4.1.10 The movements imposed by equipment nozzles, on the piping system, as well as the various alternatives regarding operation start up and shutdown conditions, shall be considered on the flexibility analysis.

4.1.11 Model equipment and vessels using rigid elements of zero weight to connect nozzlenode to equipment and vessel anchors. Use 1x10 E12 lbs/in stiffness for equipment anchors to the platform.

4.1.12 Use a connecting node to anchor the piping to equipment or vessel nozzles.Use modified Caesar II default stiffness for connecting node anchor stiffness to account for nozzle flexibility.

4.1.13 For rigid pipe supports, anchors and guides (to allow for steel flexibility), use stiffness factor of 1x10 E5 lbs/in. For angle iron, use stiffness factor of 50000 lbs/in, and at least, one anchor in the system shall have a restraint stiffness of 1x10E12 lbs/in.

4.1.14 Hydrostatic Test load analysis are needed for loads on supports, for all gas lines for which formal computer analysis is performed.

4.1.15 When the use of expansion joints is necessary, these shall be calculated according to EJMA standard. The designer shall obligatorily consider the loads, due to the internal pressure reaction, bellows, stiffness, direction changes and friction forces on the supports over the adjacent restraints (anchoring nozzles).


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4.2 Piping Stress Analysis Report

4.2.1 After completion of piping stress analysis using the Caesar II software, a report will be prepared with:

• Cover sheet• Introduction• Objective• Loading Cases• Design data for input• Others calculations / informations for input• Reference documents• Conclusions• Recommendations (optional)• Isometric with Piping and Valve Data input and all supports• Computer input print from Caesar II• Computer output from Caesar II - Displacement report- Restraint report- Stress summary- Fatigue assessment

4.3Load Combinations

4.3.1 Piping systems shall be analysed for the effects of static and dynamic loadings, asapplicable to each stress analysis problem. The types of loads to be considered in the analysisfor each individual case shall be determined by the Piping Engineer.

• Operating Load Case (W+P+T+D) • Sustained Load Case (W+P) (Un)

• Expansion Load Case (T+D)

(Dn)

• Occasional and Miscell. Load Cases - Wind Bow to Stern - Wind Port to

Starboard - Transport, with pipes empty - Wave Loads on Riser Pipes - Wave Loads on pipes in cargo tanks. - Hydrostatic Test (1.5 times design pressure

at ambient temperature) - Safety Valve Reaction - Blast Loads - Slug Flow


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• Fatigue Loading (See Appendix 4)


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Where,-W= Weight of pipe (and piping components), fluid and insulation-P= Internal design pressureT= Temperature gradient (based on design temperature minus min./ max. site temperature, whichever gives the maximum differential.)-D= Movement at nozzles, skid limits and anchor points-Un= Acceleration due ship motions – 3 directions-Dn= Structural Deflection due ship motions – 3 directions

Stress levels shall be checked as follows:

TYPE OF LOAD ASME B 31.3 REF. PARA. ALLOWABLE STRESS1. Sustained (W+P) 302.3.5 SL <= SH

SL=SD+SP

2. Expansion (Thermal) SE

302.3.5 SE <= SA

SA = f (1.25 SC+0.25 SH) or SA = f [1.25 ( SC+SH) - SL ]

3. Occasional(Wind,etc) SB

302.3.6 SB <= (1.33) x SH - SL or SB + SL <= (1.33) x SH

4. Fatigue) N/A- Use DNV 30.2 APPENDIX 4

Where,SD = Stress due to deadweightSP = Longitudinal Pressure StressSE = Stress due thermal and externally imposed displacementsSL = Longitudinal Stress due to weightSB = Stress due to occasional loadsSC, SH, SA = Allowable Stress as defined in ASME B31.3f = 1 (See Appendix 4 for Fatigue Analysis)

5.0 PIPING SUPPORT

5.1Calculation of the Span Between Supports

5.1.1 The maximum spans between pipe supports shall usually have the values set up in Appendix “1” depending on the diameter, wall thickness, material and temperature. For piping not included in the table of Appendix “1”or further,subject to irregular loading, the maximum span between supports on straight pipe sections shall be calculated as described in the following item:


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5.1.2 Loads

• Uniform load (q): Sum of the following loads.

- dead weight of piping with all its fittings;- weight of contained fluid or water weight (whichever is greater);- weight of thermal insulation or any other lining or coating or heating system;- weight of other parallel small diameter piping occasionally supported by the pipe;

• Concentrated loads: Sum of the following loads:- additional overload (W);- added weight of valves, other piping fittings, of non-support deviations or others, supported

pipes, existing on the considered section (Q). There must be considered for every steel piping an additional overload of W = 1000 N applied on the span center.

• Dynamic loads:- Blast Loads produce body forces on piping which require consideration of additional constraints, especially in horizontal direction. - Fatigue Loads primarily caused by storm conditions, can cause additional loading in all

directions, requiring additional restraints and supports.

5.1.3 In the case of piping with uniform loads only, the maximum span between supports can be calculated through the formula:

ZδaL = 10q

Where:L = maximum span between supports, in m;Z = section modulus of pipe, in cm3;δa= allowable bending stress, in kgf/cm2;q = sum of the uniform loads, in kgf/m.

The allowable stress δa shall be the allowable stress for the material at the considered temperature according to the proper ASME code.

5.1.4. For the general case of piping with uniform and concentrated loads, the maximum span between supports can be calculated through the formulas:

10L δa = [qL + 2(Q + W)] Z

Where:δa = allowable bending stress, in kgf/cm2;L = maximum span between supports, in m;Z = section modulus of pipe, in cm3;q = sum of the uniform loads, in kgf/m;Q = concentrated load, in kgf;W = overload on span center, in kgf.


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5.1.5 The maximum deflection shall be 8 mm. If the calculated deflection exceeds the limits, the span shall have to be reduced in order to comply with these conditions. The maximum deflection can be calculated approximately through the formula:

240000 L3 Q + W qL δ = + EI 3 4

Where:δ = maximum deflection, in mm;L = maximum span between supports, in m;E = elasticity modulus, in kgf/cm2;I = moment of inertia, in cm4;Q = concentrated load, in kgf;W = overload on span center, in kgf;q = sum of the uniform loads, in kgf/m.

5.1.6 The maximum span calculation between supports, do not apply to piping with too large diameter (ND > 48”) or thin walls (D/e > 100), for which the possible collapsing effect on the area in contact with the supports is to be verified.

5.1.7 For vacuum working piping the collapsing effect on the area in contact with the supports shall be verified.

5.1.8 Special attention must be given for fiberglass reinforced pipe. The span between supports must be fixed in accordance with manufacturers recommendation.

5.2Calculation Of Loads On Supports

5.2.1 For calculating the weights, friction and anchor forces acting on the pipe supports are to be considered. Also the uniform and concentrated loads specified on item 5.1.2 and the loads of internal pressure reaction of expansion joint, concerning every piping placed on the referred support must be included in support calculation. In case of supports for various piping, it is not necessary to consider the added weight of all piping containing water (situation of hydrostatic test), being sufficient, at the designer’s discretion, to consider the water weight in some piping which may be tested simultaneously, and considering the others which are empty or the weight of all piping containing operating fluid, whichever is greater. The 1000N overload referred on item 5.1.2 is to be considered as one for each support and not for each piping on the same support.

5.2.2 For calculating the weights on pipe racks, half the total weight of piping and fittings existing on the span comprised between two consecutive supports can be admitted as actuating on each support, except when the configuration is adverse to the concept above. In case of supports for a large number of pipes, it may be admitted that the weights are distributed uniformly along the support extension, since the differences among the pipe weights are not too great. These simplifying calculating conditions can not be used for the weight calculation on spring supports.


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5.2.3 The friction forces shall be calculated on all supports where a pipe motion may occur, regarding the support on the piping with ND > 3”. For the metal-to-metal movement a friction coefficient of 0.3 shall be considered. When necessary, another material shall be used such as PTFE, for reduction of friction coefficient, as indicate in manufacturer table. In any case, the friction forces shall be considered as acting in both directions. When the pipe has a lateral displacement on the support, the friction force rising from this displacement should also be considered.

5.2.4 On the piping anchors there is the simultaneous action of the reactions due to the thermal expansion and friction reactions resulting from the friction forces developed on the supports near the considered anchor. The following procedure for calculating these reactions is recommended.• calculate the reaction due to the expansion on each anchor, as if there were no friction on

the supports;• calculate the total of the friction reactions on every support located after each anchor;• consider the resultant of the two values above;• a simultaneous factor should be considered by the criteria of the designer, the practice

recommended value is 70%

5.2.5 For sizing of supports, support and restraints shall be considered the loads due to wind and to thermal expansion. For piping eventually submitted to a higher temperature then the normal operation condition, regarding operational excursions, such as steam out and others, the supporting solution shall consider the eventual character of this transitory conditions, operational security and cost. Preferentially, the permanently regime solution shall be adopted, showing in the design through specific notes on the plant, drawings and others documents that a provisory supporting or relief of restraints due to thermal expansion (disconnecting nozzles), is be used at the moment that occur the eventual conditions. In these notes shall be defined the design responsibility and execution of temporary supports.

6. EQUIPMENT NOZZLE LOADING

6.1 Appendix “2” shows minimum design nozzle loading for pressure vessels, columns, shell & tube heat exchangers and equipment package tie-ins. Note that the Vendor shall have to anchor his equipment package tie-ins. If this becomes unfeasible, the Vendor shall have to specify the movements at the tie-ins and apply allowable nozzle loading given by the Appendix 2 at the tie-ins stress analysis.

6.2 Piping loads shall be kept within the values by Appendix 2. However, if either the piping loads or the equipment nozzles or equipment package tie-ins can not comply to the values given by Appendix 2, actual piping loads will be submitted to the Vendor for an evaluation for nozzle/tie-in load approval.

6.3 The maximum allowable stress values for rotating equipment are given in Appendix 3:

6.4 For special equipments, the maximum allowable stress shall be obtained from theequipment manufacture.

7. PLASTIC PIPE DESIGN

7.1 Appendix “5” outlines the procedure for the analysis of Glass Reinforced Vinyl and Epoxy thermoset piping. All other thermoplastics shall be designed to their respective vendors recommended practices.P-43 BARRACUDA & P-48 CARATINGA 14- Sep-01

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10983104-Pipe-Stress-p48