contoh - pipe stress design basis

Contract: PJC-GEN09_BE03 COMPANY Document No.

ID-SN2-ALL-1070-250001PIPING STRESS DESIGN BASIS

Revision: 05 Status: AFD

Doc type: SPE Syst. / S-Syst. : N/A Discipline: PVV Revision Date: 20-Jul-10

Originator Document No. : N/A Page : 1 of 24

This document is the property of TOTAL and it shall not be disclosed to third parties or reproduced without permission of the COMPANY.Electronic Filename: ID-SN2-ALL-1070-250001_rev05.doc

This document has been generated by an Electronic Document Management System. When it its printed, it shall be considered as “For information only copy”.The controlled copy is the screen version, and thus, it is the holder’s responsibility to make sure that he/she holds the latest valid version.

PIPING STRESS DESIGN BASIS

05 20-Jul-10 AFD ACCEPTED FOR DESIGN DA SD/SK CL04 07-Jul-10 AFD ACCEPTED FOR DESIGN DA SD/SK CL03 25-Jun-10 AFT APPROVED FOR CFT PURPOSE DA SD/SK CL02 16-Jun-10 IFA ISSUED FOR APPROVAL DA SD/SK CL01 01-Jun-10 IFC RE-ISSUED FOR COMMENT DA SD/SK CL00 14-May-10 IFC ISSUED FOR COMMENT DA SD/SK CL0Z 06-May-10 IDC INTER – DISCIPLINE CHECK DA SD/SK CL

Rev. Date Status Revision Memo Issued Checked Approved COMPANY

SISI-NUBI FIELD DEVELOPMENTPROJECT – PHASE 2B







TABULATION OF REVISED PAGES

REVISIONS REVISIONSSHEET

00 01 02 03 04 05 06 07 SHEET

00 01 02 03 04 05 06 071 X 512 X 523 X X 534 X X 545 X 556 X X X 567 X X 578 589 X 5910 X 6011 X 6112 X X 6213 6314 X 6415 X 6516 6617 6718 6819 6920 X 7021 X 7122 7223 7324 X 7425 7526 7627 7728 7829 7930 8031 8132 8233 8334 8435 8536 8637 8738 8839 8940 9041 9142 9243 9344 9445 9546 9647 9748 9849 9950 100







COMMENTS RESPONSE SHEETDOCUMENT REF. :

No Document/Page Ref. Company Comments Contractor Response Initial Remarks

1. 9

Please check if paragraph 11“Others Verification” of GS EPPVV 107 is not applicable forSN2

GS EP PVV 107 rev. 05paragraph 11 “OthersVerification” is checked. OnlyBlast Load is applicable for SN2and the verification shall beperformed during detailedengineering stage.

DA







REVISION DETAIL TABULATION

DATE PAGE REVISION REVISION DETAILS

01-June-10 6 01 Addition of TOTAL specification as references01-June-10 7 01 Addition of standard reference01-June-10 9 01 Revised the criticality of lines01-June-10 11 01 Revised the definition of wellhead displacement01-June-10 11 01 Revised the term “Train” to “Pump”01-June-10 11 01 Revised heat insulation and personal protection01-June-10 12 01 Revised the hydrotest pressure for topside pipeline section01-June-10 12 01 Revised the allowable loads for API 610 pump01-June-10 14 01 Added note for the flange check pressure (if failed)25-June-10 6 03 CAESAR version changed from 5.0 to 5.219-July-10 7 05 Added API 610 edition19-July-10 12 05 Revised to include blast loads verification

19-July-10 21 05 Revised to include additional information to be furnished with stressreport during detailed engineering.







TABLE OF CONTENTS

1. PURPOSE ................................................................................................................................................................6

1.1 DEFINITION .......................................................................................................................................................6

2. REFERENCES ........................................................................................................................................................6

2.1 TOTAL SPECIFICATIONS ..................................................................................................................................62.2 PROJECT SPECIFICATIONS .................................................................................................................................72.3 OTHERS .............................................................................................................................................................72.4 ABBREVIATIONS ................................................................................................................................................8

3. SCOPE .....................................................................................................................................................................9

4. DESIGN BASIS .....................................................................................................................................................10

4.1 BASIC ENGINEERING .......................................................................................................................................104.2 DETAILED ENGINEERING.................................................................................................................................104.3 DESIGN CONDITIONS .......................................................................................................................................10

4.3.1 PSV Reaction......................................................................................................................................104.3.2 Wind...................................................................................................................................................104.3.3 Earthquake..........................................................................................................................................104.3.4 Wellhead displacement........................................................................................................................114.3.5 Differential displacement due to seismic..............................................................................................114.3.6 Differential displacement due to special operating case........................................................................114.3.7 Friction effects ....................................................................................................................................114.3.8 Bourdon effect ....................................................................................................................................114.3.9 Stress Stiffening due to pressure ..........................................................................................................114.3.10 Heat insulation & personal protection ..................................................................................................114.3.11 Hydrostatic test conditions ..................................................................................................................114.3.12 Blast conditions ..................................................................................................................................124.3.13 Mounting temperature .........................................................................................................................124.3.14 Slug effect ..........................................................................................................................................124.3.15 Allowable nozzle loads on equipment..................................................................................................124.3.16 Flange leakage check ..........................................................................................................................124.3.17 Stress Intensification Factor (SIF)........................................................................................................18

4.4 LOAD CASES ....................................................................................................................................................194.4.1 Code Compliance Cases (typical) ........................................................................................................19

4.5 PIPING DEFORMATION .....................................................................................................................................204.5.1 Occasional loads .................................................................................................................................204.5.2 Sustained loads ...................................................................................................................................20

4.6 CALCULATION NOTE .......................................................................................................................................204.6.1 Basic engineering................................................................................................................................204.6.2 Detailed engineering ...........................................................................................................................20

4.7 NON-METALLIC PIPING ....................................................................................................................................214.8 PIPING STRESSES REQUIREMENTS FOR ASME B31-3.......................................................................................224.9 PIPING STRESSES REQUIREMENTS FOR ASME B31.8 .......................................................................................224.10 PIPING SUPPORTS.............................................................................................................................................234.11 ORIENTATION OF DIRECTION OF FORCES AND MOMENTS ON VESSELS.........................................................24







1. PURPOSE

1.1 Definition

The purpose of this document is to define the scope and the project data for stress analysisof the piping under thermal, wind and seismic loads for Sisi Nubi phase 2B project.

This document is applicable to piping stress calculations related to a topside of wellheadplatforms under code ASME B31.3 and ASME B31.8. Sealine and Riser stress calculationare not covered by this specification.

The computer calculation program used is CAESAR II, Ver 5.2, elaborated by, COADE Inc,USA. Global axis used for model as below:

2. REFERENCES

2.1 TOTAL Specifications

• GS EP PVV 107 Rev. 05 Flexibility Analysis

• GS EP PVV 111 Rev. 08 Piping design specification

• GS EP PVV 119 Rev. 05 Metallic piping support design

• GS EP PVV 149 Rev. 02 Spring hangers and supports

• GS EP PVV 211 Rev. 06 Design and fabrication of pressure vessel according

To ASME VIII

• GS EP MEC 271 Rev. 02 Centrifugal Pumps for the Petroleum, Chemicaland Gas Industry services according to API STD610 10th

• GS EP PVV 771 Rev. 05 Thermal insulation (Hot Service)

Platform North Y

X

Z







2.2 Project Specifications

• ID-SN2-ALL-1070-250002 Piping Material Classes• ID-SN2-ALL-1070-255001 Piping Supports Standard• ID-SN2-ALL-1070-222001 Equipment Design Conditions• ID-SN2-ALL-1070-222101 Structural Design Basis

• ID-SN2-WPS2-1070-256001 WPS2 – Line List• ID-SN2-WPN3-1070-256001 WPN3 – Line List

• ID-SN2-WPS2-1070-256002 WPS2 – Critical Line List• ID-SN2-WPN3-1070-256002 WPN3 – Critical Line List

• ID-SN2-WPS2-1070-290002 WPS2 – Platform Seismic Analysis• ID-SN2-WPN3-1070-290002 WPN3 – Platform Seismic Analysis

2.3 Others

• ASME B31.3 - 2008 Process Piping

• ASME B31.8 - 2007 Gas Transmission and Distribution PipingSystems

• API RP 2A-WSD - 2000, 21st edition Recommended Practice for Planning,Designing and Constructing fixed OffshorePlatforms – Working Stress Design, 1st

edition

• API RP 520 Part II – 2003, 5th edition Sizing, Selection, and Installation ofPressure Relieving Devices in Refineries

• ASME VIII Div 1 - 2007 Rules for Construction of Pressure Vessels

• ASME VIII Div.2 App.4 - 2007 Design Based on Stress Analysis

• API 610 – 2004 10th edition Centrifugal Pumps for Petroleum,Petrochemical, and Natural Gas Industries

• API 6AF - 2008, 3rd edition Technical Report on Capabilities of APIFlanges under Combinations of Load

• ASME B16.5 - 2008, 3rd edition Pipe Flanges and Flanged Fittings

• ASME B16.47 - 2008, 3rd edition Large Diameter Steel Flangs







2.4 Abbreviations

D1 = Thermal displacement / Wellhead displacement

D2 to D9 = Structure displacements

EXP = Expansion loads

F1 to F3 = Forces due to dynamic loads (PSV relief, vent tip relief or slug for example)

H = Spring hanger

HP = Pressure in hydro test

OCC = Occasional loads

P1 = Design Pressure

P2 = Service Pressure

PGA = Peak Ground Acceleration

PSF = Piping Support Frame

Peq = Equivalent pressure

SA = Allowable stress for thermal loads

SAL = Liberal stress allowable

Sc = Basic allowable stress at Ambient Temperature

SE = Calculated stress for thermal loads

Sh = Basic allowable stress at Design Temperature

SL = Calculated stress for sustained loads

SLE = Strength Level Earthquake

SO = Calculated stress for occasional loads

SUS = Sustained loads

Sy = Yield strength at Ambient Temperature

T1 = Design Temperature

T2 = Service Temperature

T3 = Minimum Design Temperature

RIE = Rare Intense Earthquake

U1, U2, U3= Earthquake Following X, Y and Z direction

W = Weight

WNC = Empty Weight

WIN1 = Wind following X direction

WIN2 = Wind following Y direction

WW = Weight in hydro test

ƒ = Stress range reduction factor







3. SCOPE

Lines which are categorized into criticality level 2 and 3 of topsides of platformsshall be reported in critical line list.

This critical line list shall be updated during detailed engineering in accordancewith process modification.

The CONTRACTOR and Package's VENDOR shall check all lines as per methodsdescribed in the specification "Flexibility analysis" GS EP PVV 107.

Criticality level of line shall be determined as per Appendix 1 of GS EP PVV 107and in particular:

• Lines which shall be subjected to platforms or piping support differentialdisplacement under seismic and/or differential displacement due to specialoperating cases will be checked as per level 3 lines.

• Lines, which shall be subjected to wellhead displacement, will also be checkedas per level 3 lines.

All piping stress calculation notes of level 3 lines shall be submitted to COMPANYspecialist for approval.

Input data for all Piping Stress Calculation Notes (in electronic files) will betransmitted to COMPANY for check.

The CONTRACTOR shall check that the piping shall be able to withstand externalforces, moments and vibrations effects due to PSV relief, vent relief effect (inoccasional loads).







4. DESIGN BASIS

4.1 Basic Engineering

• Special care shall be taken to design the piping routing in a proper way to allow a goodflexibility and to avoid any major changes when piping stress calculations is done.

• Level 3 lines identified in critical line list shall be analyzed.

4.2 Detailed Engineering

• All piping stress calculation notes of level 2 and 3 lines, as specified in critical line list, asper GS EP PVV 107, shall be submitted to COMPANY for approval.

• The CONTRACTOR shall check that at any time of the fabrication (i.e. load-out,transportation, lifting, partial hydrotest), the piping is able to withstand applied loadswithout permanent deformations.

• CONTRACTOR shall check that lowest natural frequency of each piping system is atleast half or twice of structure natural frequency of the deck and not less than 4 Hz. Thelowest natural frequency results shall be submitted to COMPANY for approval.

4.3 Design Conditions

4.3.1 PSV Reaction

The Pressure Safety Valve induces a reaction force due to thrust load. At Basic Engineeringstage, the PSV reactions will be calculated in accordance with API 520. At the time ofDetailed Engineering, the PSV reactions will be the loads as defined by the vendors.

4.3.2 Wind

Wind will be taken in X or Y axis whichever is the more stringent.

Maximum wind speed will be taken as 20.4 m/s (3 second gust for 100 years return) with awind shape factor 0.8 as per maximum value of “Equipment Design Conditions” ID-SN2-ALL-1070-222001.

4.3.3 Earthquake

Earthquake acceleration at each deck extracted from respective seismic in-place analysisstructural reports shall be considered for analysis.

The spectral acceleration in X and Y axis shall include a safety coefficient of 1.3 for pipingdumping.

The vertical maximum spectral acceleration will be taken as two third of horizontalacceleration.







4.3.4 Wellhead displacement

Wellheads are subject to vertical displacement of +100 mm.

4.3.5 Differential displacement due to seismic

The differential displacements on piping due to seismic effect shall be taken into accountbetween deck and vent boom.

4.3.6 Differential displacement due to special operating case

Special operation case such as one pump in operation (hot) when other pump is in shutdown (cold), shall be taken into account for analysis.

4.3.7 Friction effects

A friction factor equal to 0.3 (Carbon steel on Carbon steel) to be considered in thecalculation, except for sliding plate: friction factor is equal to 0.1 (stainless steel on Teflon).

4.3.8 Bourdon effect

The Bourdon Effect causes straight pipe to elongate, and bends to “OPEN UP” axial along aline connecting the curvature end points.The Bourdon effect is considered for all critical lines calculated.

4.3.9 Stress Stiffening due to pressure

This is pressure stiffening effects in straight pipes. The pressure applies the stress stiffeningmatrix to the elemental stiffness matrices (of straight pipes only) using an axial force P equalto the internal pressure times the internal area of the pipe.

Note that other internal forces (due to thermal or imposed mechanical loads) are notincluded in the P force as this is not a non-linear effect.Note that stress stiffening is currently available for service pressure.

4.3.10 Heat insulation & personal protection

The density 140 kg/m3 (including external metal coversheet) of heat insulation shall be takeninto account for analysis. Thickness of insulation shall be as per GS PVV 771.

Personnel protection is achieved by wire mesh and may be neglected.

4.3.11 Hydrostatic test conditions

For hydrotest, the test pressure will be taken as follows:

• For piping rating > 600#Test pressure = 1.5 * Design pressure

• For piping rating ≤ 600#Test pressure = 1.5 * Max. pressure rating (as per piping material classes@370C)







Spring supports are considered “locked-out” on the field during hydro test to preventexcessive deflection and over-stressing of the system.

For topsides pipelines, 1.4 times the design pressure shall be considered as test pressureas per ASME B31.8 chapter VIII.

4.3.12 Blast conditions

Blast load verification for applicable piping system shall be performed as per GS EP PVV107 rev. 05 clause 11.4 during detailed engineering stage.

4.3.13 Mounting temperature

Mounting temperature of + 27°C will be taken into account.

4.3.14 Slug effect

Slugs in the line will create dynamic forces in the elbows at 45° of upstream flow and theselines as advised by process department will be identified in the critical line list. The force willbe calculated as below;

FR = .a.V². DLF Where: FR = Resultant force as slug strikes elbow = Specific gravity of the heaviest fluid a = Cross sectional area of the pipe V = Fluid velocity DLF = Dynamic Load Factor (DLF=2)

4.3.15 Allowable nozzle loads on equipment

Calculated loads on vessel nozzle including pig trap shall remain with equation given in GSEP PVV 211 – Appendix 1 according to ASME VIII div.1. When calculated loads exceed theallowable values, they shall be submitted to equipment supplier for acceptance.

Piping loads on centrifugal pumps shall be restricted within two times the allowable valuespecified in table 4 of API 610. Other pumps allowable loads shall be as defined by vendor.

4.3.16 Flange leakage check

The risk of flange leakage shall be evaluated by the methods defined here after, from thesimplest to the most complicated.

All flanges on critical lines connects to process equipment shall be checked for leakageduring detailed engineering.

4.3.16.1 Check using tabulated values

This first check consists in comparing the flanges loads (in operating conditions) to theallowable loads defined in appendix-2 of GS EP PVV 107.







If the criteria of the GS EP PVV 107 are not satisfied, then the second method shall beapplied.

4.3.16.2 Check using the equivalent pressure method (Peq)

4.3.16.2.1 Scope:

This method is applicable for flanged connection on equipment and piping satisfying thefollowing conditions:

• Type: Carbon steel, stainless steel and duplex stainless steel welding neck flanges withmetallic pipe and vessels, rotating machines, valves, etc.

• Codes: ASME B16.5 and B16.47

This method is not applicable to type connections: ’Hub connectors’, ‘Proprietary design’,Flanges on Wellhead (code API 6AF), etc.

For Hub connector, the calculated axial load and bending moment shall be checked with theallowable value furnished by vendor.

For API flanges, the loads shall be verified using API 6AF.

4.3.16.2.2 Calculation of equivalent pressure (Peq):

Peq =23 G

FA x4GMf x16

⋅+

⋅ ππ

[units US (Peq in lbf/sq.in)] with Mf in lbf.in, FA in lbf, and G in inch]

Peq = 23 GFA x127

GMf x509296

+

[units SI (Peq in bar)] with Mf in DaN.m, FA in DaN, and G in mm]

Mf = Resultant Bending Moment in Design Conditions.FA = Axial Force in Design Conditions.G = Effective Gasket Diameter.

4.3.16.2.3 Check of complete pressure in the flange:

Peq + P < PASME

PASME = Working Pressure at Design Temperature (B16.5, B16.47) in bar.

P = Operating Pressure in bar.







Peq = Equivalent Pressure in bar.

Note : Change in piping support type or piping routing or increase of flange rating shall beconsidered to comply with above equation.

Forces and moments applied on flanges:

Permanent Static loads:

Weight: including fluid and metal density at OPERATING temperature and pressure.

Pressure: maximum OPERATING Pressure.

Thermal: maximum OPERATING Temperature.

Occasional Dynamic loads:

Acceleration: Loads without sign.

Restraint movements due to dynamic loads: Loads without sign.

Wind: Loads without sign.

Relief valve opening: Loads with sign.

Surge: Loads without sign.

External Loads = P. Static Loads + [Loads with sign]

External Loads = P. Static Loads + [Loads without sign]

External Loads = P. Static Loads + [Loads with sign] ± [Loads without sign]

Typical combinations (not exhaustive)

Com

bination

Com

bination

Com

bination

Com

bination

Com

bination

Static loads X X X X XAcceleration XRestraint movement due to dynamic loads XWind XRelief valve opening XSurge X







4.3.16.3 Check using Enhanced Equivalent pressure method:

4.3.16.3.1 Scope:

This method is applicable for all flanges connection on equipment and piping satisfying thefollowing conditions:

• Type: Carbon steel and stainless steel Welding Neck flanges with metallic pipe andvessels, rotating machines, valves, etc

• Codes: ASME B16.5 and B16.47• Important : this method is valid for temperature 120 oC• Duplex and Inconel Welding Neck flanges can be treated in the same way than

Carbon steel.

This method is not applicable to type connections: ’Hub connectors’, ‘Proprietary design’,Flanges on Wellhead (code API 6AF), etc.

For flanges out of hypothesis above a full check by ASME VIII Div.2 App.4 shall beperformed.

For Hub connector, the calculated axial load and bending moment shall be checked with theallowable value furnished by vendor.

For API flanges, the loads shall be verified using API 6AF.

4.3.16.3.2 Check of complete pressure in the flange

Peq + P /β < PASME

PASME = Working Pressure at Design Temperature (B16.5, B16.47) in bar.

P = Operating Pressure in bar.

Peq = Equivalent Pressure in bar.

β = Coefficient

Note : Change in piping support type or piping routing or increase of flange rating shall beconsidered to comply with above equation.







Beta Coefficients (β)

Carbon Steel Flanges

DN 150# 300# 600# 900# 1500# 2500#Inch ASME/ Peq+P ASME/ Peq+P ASME/ Peq+P ASME/ Peq+P ASME/ Peq+P ASME/ Peq+P

2 1.30 1.50 1.203 1.30 1.50 1.204 1.30 1.50 1.206 1.30 1.50 1.208 1.40 1.20 1.50 1.10

10 2.30 1.40 1.20 1.20 1.1012 2.20 2.00 1.20 1.20 1.20 1.1014 2.00 2.00 1.20 1.20 1.1016 2.00 1.80 1.15 1.15 1.1018 2.00 1.80 1.15 1.15 1.1020 2.00 1.80 1.15 1.15 1.1024 1.90 1.50 1.15 1.15 1.1026 1.90 1.50 1.15 1.1528 1.80 1.20 1.10 1.1530 1.70 1.20 1.10 1.1532 1.60 1.20 1.10 1.1534 1.60 1.20 1.10 1.1536 1.80 1.40 1.30 1.3038 1.40 1.10 1.0040 1.30 1.10 1.0042 1.30 1.10 1.00

>42 Note 1 Note 1 Note 1

Note 1: A check (of complete pressure in the flange or as per ASME VIII) shall be performed,for all combinations flanges diameter / pressure rating not included in tables above.

Note 2: For heterogeneous connections, check shall be performed with Stainless Steel table







Stainless Steel Flanges

DN 150# 300# 600# 900# 1500# 2500#Inch ASME/ Peq+P ASME/ Peq+P ASME/ Peq+P ASME/ Peq+P ASME/ Peq+P ASME/ Peq+P

2 1.10 1.40 1.103 1.10 1.40 1.104 1.10 1.40 1.106 1.10 1.40 1.108 1.20 1.10 1.40 1.00

10 1.60 1.20 1.10 1.10 1.0012 1.60 1.40 1.10 1.10 1.10 1.0014 1.30 1.20 1.10 1.10 1.0016 1.30 1.20 1.10 1.00 1.0018 1.30 1.20 1.10 1.00 1.0020 1.30 1.20 1.10 1.00 1.0024 1.30 1.20 1.10 1.00 1.0026 1.30 1.20 1.10 1.0028 1.30 1.10 1.00 1.0030 1.30 1.10 1.00 1.0032 1.30 1.10 1.00 1.0034 1.30 1.10 1.00 1.0036 1.20 1.10 1.00 1.0038 1.20 1.00 1.0040 1.20 1.00 1.0042 1.20 1.00 1.00

>42 Note 1 Note 1 Note 1

Note 1: A check (of complete pressure in the flange or as per ASME VIII) shall be performed,for all combinations flanges diameter / pressure rating not included in tables above.

Note 2: For heterogeneous connections, check shall be performed with Stainless Steel table







4.3.17 Stress Intensification Factor (SIF)

4.3.17.1 Tees at 90°

For tee connections at 90°, the standard Stress Intensification Factor (SIF) as per ASMEB31.3 and B31.8 are applicable.

4.3.17.2 Oblique connections at 45°

In case of oriented tees, Stress Intensification Factor (SIF) are higher due to the angle ofconnection between branch and header.

a) For Forged connection, this SIF shall be calculated as per equation below (header andbranch element):

h = 4.4 ( T / r2 )i0 = 0.9 / [ h 2/3 ( sin α ) 3/2 ]iI = ( 3 io / 4 ) + 0.25

b) For Un-reinforced Fabricated Tee, this SIF shall be calculated as per equation below(Pipe to Pipe for header and branch element) as per Appendix-D of ASME B31.3:

h = T / r2

i0 = 0.9 / [ h 2/3 ( sin α ) 3/2 ]iI = ( 3 io / 4 ) + 0.25

Where :

- h is for Flexibility Characteristic.- io is for Stress Intensification Factor Out-of-Plane.- iI is for Stress Intensification Factor In-Plane.- T is for Thickness of pipe header.- r2 is for Radius of pipe header.- Sin α is for Sinus of small Angle between header and branch.







4.4 Load Cases

CONTRACTOR and package’s VENDOR shall check the following load cases for operatingconditions.

4.4.1 Code Compliance Cases (typical)

4.4.1.1 Elementary load cases

Case 1n = Thermal In design condition (T1 to T5)Case 2n = Thermal in service condition (T6 to T9)Case 3 = Pipe acceleration along X direction due to the earthquake (U1)Case 4 = Pipe acceleration along Y direction due to the earthquake (U2)Case 5 = Pipe acceleration along Z direction due to the earthquake (U3)Case 6 = Displacements along X direction dues to the deflection

of structure with earthquake (D2)Case 7 = Displacements along Y direction dues to the deflection

of structure with earthquake (D3)Case 8 = Displacements along Z direction dues to the deflection

of structure with earthquake (D4)Case 9 = Thermal displacements (D1)Case 10 = Wind only along X direction (WIN1)Case 11 = Wind only along Y direction (WIN2)Case 12 = Forces due to the Dynamic loads (Fn)Case 16 = Weight empty (WNC)

4.4.1.2 Combination load cases (typical)

Case 17 = sustained in design condition (W + P1)Case 18 = sustained in service condition (W + P2)Case 19 = design condition (W + P1+ T1 to T5 + D1)Case 20 = service condition (W + P2 + T6 to T9 + D1)

Case 21 = Secondary stresses in Displacements ( DnΣ ²)= (D2²+D3²+D4²) 0.5

Case 22 = Occasional stresses in Earthquake ( UnΣ ²)= (U1²+U2²+U3²) 0.5

Case 24 = thermal condition with Displacements (T1 to T5 + D1 + DnΣ ²)Case 25 = Occasional stresses with Wind along X direction (W+P1+WIN1)Case 26 = Occasional stresses with Wind along Y direction (W+P1+WIN2)

Case 27 = occasional stresses with Earthquake (W + P1+ UnΣ ²)Case 28 = occasional stresses with Dynamic load (W + P1 + Fn)Case 30 = hydrotest (WW + HP)







4.4.1.3 Non code combination cases for support loads only (typical)

CONTRACTOR and package's VENDOR shall perform following non-code combinationcases to define loads on equipment and structure.

Case 100 Operating (W +P1 +T1 to T5 +D1 + DnΣ ² + Fn ± UnΣ ²)

Case 200 Operating (W + P2 + T6 to T9 +D1 + DnΣ ² + Fn ± UnΣ ²)

4.5 Piping deformation

4.5.1 Occasional loads

Piping deformation under occasional loads shall be limited to 20 mm in horizontal andvertical direction including piping weight effect.

4.5.2 Sustained loads

Under sustained loads deformation of piping shall be limited to 10 mm.

4.6 Calculation Note

4.6.1 Basic engineering

The piping stress calculation notes shall be simplified report for each system and contain theessential information of:

- Introduction, assumption, conclusion and recommendation.- Basic design data and conditions of lines analysed.- Stress isometric for the complete piping system analysed indicating support positions

and types.- Additional requirements for acceptance (e.g.: branch connection reinforcements).- Maximum stresses for each stress check cases and code allowable stress.- Caesar II input.- Caesar II output for load cases, code compliance, forces and moments.- Load verification on equipment nozzles.

4.6.2 Detailed engineering

The piping stress calculation notes shall be comprehensive report for each system and atleast contain the essential information of:

- Introduction, conclusion and recommendation.- Basic design data and conditions of lines analysed.- Additional requirements for acceptance (e.g.: branch connection reinforcements).- Maximum stresses for each stress check cases and code allowable stress.- Caesar II input.- Caesar II output for load cases, code compliance, displacement, forces and moments.- Load verification on equipment nozzles with actual vendor data.- Leak verification for flanges connected to process equipment.







- Stress verification for transportation loads on piping.- Actual PSV reaction force obtained from vendor.- Piping natural frequency check results with comparison to structural natural

frequencies.- Blast Load verification.- CONTRACTOR Engineering in-charge of the detail engineering shall ensure that a

new piping stress analyses (Up-date, Re-run & Re-issue) will be performed for anychange in pipe routing, location of support and change in support function during theconstruction phase.

- Stress isometric for the complete piping system analysed indicating support positionsand types.

- Snapshot of CAESAR 3D view as below:

4.7 Non-metallic piping

Stress analysis of non-metallic piping such as GRE, GRP etc, shall be performed by vendorduring detailed engineering considering the surge and water hammer effect.







4.8 Piping stresses requirements for ASME B31-3TYPICAL TABLE FOR EXAMPLE

Node calculatedstresses Allowable Stresses

Load cases Casen° Node

SL SE SO+SL Sh 1.33 Sh 0,9 Sy Sy SA SAL Ratio

Sustained (W + P1) X X

Thermal (Tn + D1) X X

Thermal + DnΣ ²) X X

Sustained + WIN X X

Sustained + Earthquake X X

Sustained + Force X X

Hydrotest (WW + HP) X X

Sh = See ANSI B31.3 table Appendix A

SA = f (1.25 Sc + 0.25 Sh) } Note that f = stress range reduction

SAL= f (1.25 (Sc + Sh) - SL) } factor (see B31.3, table 302.3.5)

Sy = yield strength at ambient temperature

4.9 Piping stresses requirements for ASME B31.8TYPICAL TABLE FOR EXAMPLE

Node calculated stresses Allowable StressesLoad cases Case

n°Node

SL SE SL+SO SL+SE+SO 0.75 Sy 0.72 Sy Sy Ratio

Sustained (W + P1) X X

Thermal (Tn + D1) X X

Sustained + WIN X X

Sustained + Earthquake X X

Sustained + thermal Tn +worst wind + Earthquake X X

Hydrotest (WW + HP) X X

Temperature derating factor T for steel pipe (see table 841.116A, ASME B 31.8)Temperature in °F: 250 °F (121.11°C) or less = Temperature derating factor T = 1.00For intermediate temperature, interpolate for derating factor.

For all the above casesstressAllowable

stressCalcRatio .= shall be less than 1.0







4.10 Piping supports

Support symbolisation

Remark on supports: support types are shown on isometric views.

Spring Support(Hanging up)

Transversal Guide(free in verticaldirection)

Base Support

Longitudinal Guide(free in vertical direction)

(Main Anchor)

Directional Anchor(free moments)(free rotations)

Vertical Guide

Hanger Support

Spring Support(Hanging down)

Rigid Strut

Anti-Lift-Up Support

Adjustable Support

Weight support forHydrostatic Test onlySupport for Hydrotest(Dismantling after test)







4.11 Orientation Of Direction Of Forces And Moments On Vessels.

Mz (Torsional)

Fz (Axial)

Fy (Circumferential)My (Longitudinal)

Mx (Circumferential)

Fx(Longitudinal)

MyMx

Mz (Torsional)

FyFx

Fz (Axial)

Fx (Axial)

Mx (Torsional)

Fz (Longitudinal)

Mz (Circumferential)

My (Longitudinal)Fy (Circumferential)

contoh - pipe stress design basis

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