Total Piping Stress Analysis
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Piping Stress Analysis...
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Exploration & Production
GENERAL SPECIFICATION PIPING VALVES VESSELS GS EP PVV 107
Piping Stress Analysis
04
10/07
New version – Integrated GS EP PVV 109
03
10/05
Addition of "EP" root to GS identification
02
10/04
General review
01
12/03
Change of Group name and logo
00
03/01
First issue
Rev.
Date
Notes
This document is the property of Total. It must not be stored, reproduced or disclosed to others without written authorisation from the Company.
Exploration & Production General Specification
Date: 10/2007
GS EP PVV 107
Rev: 04
Contents
1. Scope ....................................................................................................................... 4 2. Reference documents............................................................................................. 4 3. Design basis ............................................................................................................ 6 3.1
General ..............................................................................................................................6
3.2
Design Data .......................................................................................................................7
3.3
Method of Analysis ............................................................................................................7
4. Critical Line List ...................................................................................................... 8 4.1
Critical Line List for Basic Engineering ..............................................................................8
4.2
Critical Line List for Detailed Engineering..........................................................................8
5. Piping Stress Analysis.......................................................................................... 10 5.1
List of calculation reports .................................................................................................10
5.2
Screening or hand calculations........................................................................................10
5.3
Computerized analysis ....................................................................................................10
5.4
Units.................................................................................................................................11
6. Design Conditions................................................................................................. 11 6.1
Design Pressure ..............................................................................................................11
6.2
Calculation Temperature .................................................................................................11
6.3
Thermal Effects................................................................................................................12
6.4
Snow loads - Ice ..............................................................................................................13
6.5
Dynamic Effects...............................................................................................................13
6.6
Weight Effects..................................................................................................................15
6.7
Effects of Supports and Structural Deflections ................................................................15
6.8
Hydrostatic test conditions...............................................................................................17
7. Caesar model......................................................................................................... 17 7.1
Boundary conditions ........................................................................................................17
7.2
Piping supports ................................................................................................................17
7.3
Thermal displacements....................................................................................................18
7.4
Imposed displacements ...................................................................................................18
This document is the property of Total. It must not be stored, reproduced or disclosed to others without written authorisation from the Company.
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Date: 10/2007 Rev: 04
7.5
Friction effects .................................................................................................................18
7.6
Stress Intensification Factor (SIF) for oblique connections .............................................18
7.7
Bourdon effects................................................................................................................19
8. Load Cases ............................................................................................................ 19 8.1
Elementary load cases ....................................................................................................19
8.2
Combination load cases ..................................................................................................20
9. Acceptance Criteria............................................................................................... 20 9.1
Allowable stress...............................................................................................................20
9.2
Piping deformation...........................................................................................................21
9.3
Allowable loads on equipments .......................................................................................22
9.4
Support reaction ..............................................................................................................22
10. Flange leakage check ........................................................................................... 23 10.1
Check using tabulated values..........................................................................................23
10.2
Check using the equivalent pressure method (Peq)........................................................23
10.3
Enhanced equivalent pressure method ...........................................................................25
10.4
Flange verification according to ASME VIII Division 1.....................................................26
10.5
Case of the specific flanges.............................................................................................26
11. Other verifications................................................................................................. 26 11.1
Vibration analysis.............................................................................................................26
11.2
Vortex shedding (wind) ....................................................................................................26
11.3
Fatigue assessment for pipes..........................................................................................26
11.4
Blast loads .......................................................................................................................27
11.5
Glass Reinforced Plastics pipes (GRP) ...........................................................................27
12. Calculation Notes .................................................................................................. 28 12.1
General ............................................................................................................................28
12.2
Calculation Note for basic engineering ............................................................................28
12.3
Calculation note for detailed engineering ........................................................................29
12.4
Engineering supervision plan...........................................................................................30
Appendix 1
Stress analysis level requirements ....................................................................31
Appendix 2
Allowable loads on flanges ................................................................................33
Appendix 3
Beta Coefficients (β) ..........................................................................................35
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Exploration & Production General Specification
Date: 10/2007
GS EP PVV 107
Rev: 04
1. Scope This document sets the rules for the piping stress analysis of the process and utilities piping systems of onshore and offshore petroleum installations. Its scope is essentially the same as that of ASME Code B31.3. The following are specifically excluded: onshore and offshore pipelines, furnaces and boilers piping, building heating and ventilation piping, etc. This document does not include the structural attachment between piping supports and the main structure.
2. Reference documents The reference documents listed below form an integral part of this General Specification. Unless otherwise stipulated, the applicable version of these documents, including relevant appendices and supplements, is the latest revision published at the EFFECTIVE DATE of the CONTRACT. Process and utilities piping shall comply with the requirements of ASME Code B31.3. This document clarifies or complements some requirements of ASME Code B31.3 when deemed necessary considering COMPANY experience. Piping systems covered by this specification shall be designed and analysed in accordance with this Code and with the documents listed hereafter. Any divergence between any of the Reference Documents, or between this specification and any Reference Document, shall be reported to the COMPANY for decision. In such a case, and unless otherwise agreed or decided by the COMPANY, it is understood that the more stringent requirement shall apply. Exceptions to, or deviations from this specification are not permitted unless previously accepted in writing by the COMPANY. For this purpose, requests for substitutions or changes of any kind shall be completed with all pertinent information required for the COMPANY assessment. Standards Reference
Title
ASME B16.5
Pipe Flanges and Flanged Fittings (NPS ½ through NPS 24)
ASME B16.47
Large Diameter Steel Flanges NPS 26 through NPS 60
Professional Documents Reference
Title
CONCAWE Report n° 87/59
The prediction of noise radiated from pipe systems - an engineering procedure for plant design
EJMA
Standards of the Expansion Joint Manufacturers Association
NEMA SM 23
Steam Turbines for Mechanical Drive Service
This document is the property of Total. It must not be stored, reproduced or disclosed to others without written authorisation from the Company.
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GS EP PVV 107
Rev: 04
Reference
Title
WRC 107
Welding Research Council Bulletin 107 - Local Stresses in Spherical and Cylindrical Shells due to External Loadings
WRC 297
Welding Research Council Bulletin 297 - Local Stresses in Cylindrical Shells due to External Loadings on Nozzles Supplement to WRC Bulletin 107
Regulations If the country of installation has its own regulation, it must be applied wherever more stringent than the Basic Code. Reference
Title
Not applicable
Codes Reference
Title
API 520 Part 2
Sizing Selection and installation of Pressure relieving devices in refineries
API 610
Centrifugal Pumps for General Refinery Service
API 617
Centrifugal Compressors for General Refinery Service
API 661
Air-Cooled Heat Exchangers for General Refinery Service
API 662
Plate Heat Exchangers for General Refinery Service
API RP 2A-WSD
Recommended Practice for Planning, Designing and Constructing Fixed Offshore Platforms - Working Stress Design
ASME B31.1
Power Piping
ASME B31.3
Process Piping
ASME III Div. 1 Subsection NB
Rules for Construction of Nuclear Facility Components Class 1 Components
ASME VIII Div. 1
Rules for Construction of Pressure Vessels
BS 7159
Design and Construction of Glass-Reinforced Plastics (GRP) Piping Systems for Individual Plants or Sites
UKOOA
Specifications and Recommended practice for the Use of Glass Fibre Reinforced Plastic Piping Offshore
PD 5500
Specification for Unfired Fusion Welded Pressure Vessels
This document is the property of Total. It must not be stored, reproduced or disclosed to others without written authorisation from the Company.
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Exploration & Production General Specification
Date: 10/2007
GS EP PVV 107
Rev: 04
Other documents Reference DNV RP C203
Title Fatigue Design of Offshore Steel Structures
Total General Specifications Reference
Title
GS EP PVV 111
Piping Design Specification
GS EP PVV 112
Piping Material Classes
GS EP PVV 119
Metallic Piping Support Design
GS EP PVV 149
Spring Hangers and Supports
GS EP PVV 178
Design and Erection of Glass Reinforced Plastic (GRP) Piping System
GS EP PVV 211
Design and fabrication of pressure vessels according to ASME VIII
GS EP PVV 212
Design and fabrication of pressure vessels according to PD 5500
3. Design basis 3.1 General Piping systems shall have sufficient flexibility to prevent thermal expansion or contraction from causing: •
Failure of piping or supports from overstress or fatigue
•
Leakage at joints
•
Detrimental stresses or distortion in piping and valves or in connected equipment.
Piping systems shall be designed in accordance with the requirements of the ASME B31.3 Code and the present specification. They shall take into account all the different conditions expected during their lifetime: operating conditions, environmental conditions, occasional and accidental conditions. All piping shall be adequately supported (anchors, guides, limit stop, etc.) to prevent excessive stresses from the different expected conditions. Pipe stress analysis shall be carried out at pressure and temperature conditions as stated in the Critical Line List. The purpose of this General Specification is to: •
Categorise piping systems into Critical stress levels
•
Define criteria and coefficients so that loading conditions may be applied
•
State allowable stress levels to ensure safe plant operations.
This document is the property of Total. It must not be stored, reproduced or disclosed to others without written authorisation from the Company.
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3.2 Design Data The main design data of each line shall be taken from the following documents: •
Line list: Operating and design pressures, operating and design temperatures, type and thickness of insulation (if any), type of hot tracing (if any), test conditions (pressure, fluid, etc.)
•
Piping material classes: Material, diameter, wall thickness, type of fittings, flanges and valves
•
Project Specification: Site data e.g. the minimum/maximum ambient temperature, the maximum solar temperature, the wind data such as wind speed for each grade level, the earthquake data, etc.
3.3 Method of Analysis The piping layout shall be analysed by the individual consideration of each line affected by restraints (temperature, imposed displacements, etc.) to determine the reactions produced at anchors and terminal points and the stresses in the piping. The methods of analysis are classified into three Stress Analysis Levels. The levels of requirements and the corresponding methods of analysis are defined as follows: 3.3.1 Level 1: Visual inspection (or by analogy) It is an approximate, visual inspection method. It shall be restricted to lines that are similar to other calculated lines, or lines having a clear and adequate flexibility. If not, these lines shall be classified as level 2 or 3. No actual values of forces and moments acting on supports are requested for a level 1 analysis. 3.3.2 Level 2: Simplified analysis This method includes the use of charts, nomographs and simplified formulae which may only be accepted if they are used in the range of configuration for which their accuracy is acceptable. In case of doubt, the line shall be classified as level 3. The result of a level 2 analysis may be shown only on the calculation isometric, or in a simplified report including isometric and a computer calculations output restrain summary. 3.3.3 Level 3: Comprehensive analysis It is a comprehensive method by computer calculations exclusively that shall meet the requirements of the piping code. A complete calculation report shall be issued (refer to the § 12). The accuracy level selection shall be indicated in a document called "Critical Line List". This document shall include all the lines to be reviewed by the stress analyst and shall be submitted to the COMPANY for approval.
This document is the property of Total. It must not be stored, reproduced or disclosed to others without written authorisation from the Company.
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3.3.4 Exemptions A stress calculation needs not to be performed on the piping systems that meet one of the following requirements according to ASME B31.3, paragraph 319.4.1: •
Piping systems which are duplicated, or are revised without significant changes of successfully operating operations
•
Piping systems which can be readily judged adequate by comparison with previously analyzed systems.
4. Critical Line List All lines of accuracy levels 2 and 3 shall be reported in the Critical Line List. These lines must be classified in accordance with the criteria shown on Appendix 1 (General Chart and Specific Cases). This requirement applies also to lines included in packages. To facilitate tie-ins and assign responsibilities, vendors will be responsible for the pipework design within their package and an anchor support must be provided at the limit of all packages.
4.1 Critical Line List for Basic Engineering At the Basic Engineering stage, a special care shall be taken to design the piping routing in a proper way to allow a good flexibility and to avoid any major changes during the detailed engineering when the piping stress analysis is finalised. Lines of level 3 to be calculated at Basic Engineering shall be identified in Critical Line List. This Critical Line List shall be updated during the Detailed Engineering in accordance with the possible modifications or Project up-dating. Unless otherwise required by the project, diameter 18” and above lines which are submitted to differential displacements (platforms or pipe racks differential displacements due to earthquake or to special operating cases) shall be checked as per level 3 lines. Piping stress analysis level 3 shall also include: •
Lines submitted to wellhead displacement
•
Lines with oblique connections
•
Lines with expansion bellows
• •
Carbon Steel and Low Temperature Carbon Steel lines used at a temperature lower than the minimum shown on the Piping Class GRP lines larger than a diameter to be defined for each project.
4.2 Critical Line List for Detailed Engineering At the Detailed Engineering stage, the flexibility of all the piping systems shall be checked in the different conditions expected during their lifetime. The piping systems shall be able to withstand applied loads without permanent deformations at any time of the fabrication (i.e. load-out, transportation, lifting, partial hydrostatic test, etc.).
This document is the property of Total. It must not be stored, reproduced or disclosed to others without written authorisation from the Company.
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GS EP PVV 107
Rev: 04
Lines of levels 2 and 3 to be calculated at Detailed Engineering shall be identified in the Critical Line List. This Critical Line List shall be regularly updated in accordance with the possible modifications. In addition to the Appendix 1 (General Chart and Specific Cases), the following criteria shall be considered in order to finalize the checking level: •
Lines having substantial concentrated loads such as valves, fittings, unsupported vertical risers and branches
•
3” and larger closed pressure relief system piping, where design temperature exceeds 93°C (200°F) or is less than -73°C (-100°F)
•
Lines having local reduction in strength due to installation of special fittings (i.e. oblique connections)
•
Piping 3” and larger connected to: - Rotating equipment such as pumps, blowers and compressors - Air cooler - Plate and frame heat exchanger - Gas turbine.
•
Blowdown and flare header or vent piping, but not atmospheric vent piping
•
Piping with pressure surge, slug and two phases flow
•
Normally dry firewater piping and normally water-filled firewater ring main piping
•
Piping subject to short term variations such as steam-out or purge piping
•
Pig receiver and launcher lines up to and including off-shore riser support
•
Relief valve or rupture disc piping reaction forces
•
Expansion bellows
•
Lines affected by deck deflection, platform settlement, wellhead movement or any other significant displacement
•
Lines subject to vacuum conditions
•
Cryogenic lines: - It is considered as cryogenic service all applications below -46°C
• •
Lines which may create large forces or moments on structure or skid base Unbalanced piping configuration, such as a long run of pipe with a short branch connected to anchor
•
Piping subjected to severe cyclic temperature conditions
•
GRP lines larger than a diameter to be defined for each project
•
Lines with special design requirements
This document is the property of Total. It must not be stored, reproduced or disclosed to others without written authorisation from the Company.
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Exploration & Production General Specification GS EP PVV 107
•
Date: 10/2007 Rev: 04
In addition, the effect on piping of other conditions such as temperature gradients that could cause thermal bowing or where piping is connected to equipment with significant thermal growth
•
Lines design to B31.3 chapter IX
•
All piping with t > OD/6 or P/SE > 0.385
•
4” and larger with t > 10% OD
•
Lines with OD/t > 120
Where: •
OD is the piping Outside Diameter
•
t is the piping thickness
•
P is the Design Pressure
•
SE is the Allowable Stress as per defined in the ASME B31.3 code for the thickness calculation.
5. Piping Stress Analysis 5.1 List of calculation reports A list of the calculations reports shall be issued and regularly updated. The lines which are subject to approximate or comprehensive analysis methods (levels 2 and 3) shall be registered on this list which shall include the following information: •
Line number, including revision and date
•
Calculation number
•
Type of analysis
•
Revision and date of issue.
5.2 Screening or hand calculations All level 1 and level 2 lines shall be checked by piping and/or supporting engineers. Screening or hand calculations shall be used to verify that enough inherent flexibility exists in the piping system to prevent excessive thrusts, stresses and distortion. Differential displacements shall be considered. All piping stress calculation notes of level 2 lines shall be submitted to COMPANY for review.
5.3 Computerized analysis Comprehensive computer analysis shall be performed for critical lines level 3 (or assimilated level 3). The calculation program used shall be CAESAR II, 4.50 or 5.0 version, developed by COADE Inc. (Houston - Texas USA). The lines shall be calculated, including branch lines up to the first anchor or acceptable boundary condition when branch diameter ≥ half header diameter.
This document is the property of Total. It must not be stored, reproduced or disclosed to others without written authorisation from the Company.
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GS EP PVV 107
Rev: 04
When small size lines (branch) connected to main lines (header) are to be calculated separately (when branch diameter < half header diameter) the linear and angular movements of the junction point shall be calculated or estimated for proper analysis of the branch line. Axis for piping stress analysis shall be the same as for the structure calculation, normally: Onshore site or offshore platform
FPSO unit
X = North direction
X = Horizontal axis parallel to the FPSO longitudinal axis (forward)
Y = Transversal axis (toward West)
Y = Horizontal axis perpendicular to X (toward portside)
Z = Vertical Axis (upward)
Z=
Vertical Axis (upward)
All piping stress calculation notes of level 3 (or assimilated) shall be submitted to COMPANY specialist for acceptance once the CONTRACTOR has approved them. Input data for all Piping Stress Calculation Notes (in electronic files) will be transmitted to COMPANY for check. The computer outputs shall be submitted to the COMPANY for review.
5.4 Units Unless otherwise specified by the Project requirements, the unit system shall be the metric system.
6. Design Conditions The following paragraphs detail the design conditions, the Caesar model, the load cases and the acceptance criteria to be considered.
6.1 Design Pressure The design pressure of each component in the piping system shall be equal to the most severe design conditions expected, indicated in the Critical Line List. In particular cases, the design pressure specified in the Critical Line List may be replaced by the maximum operating pressure upon COMPANY approval.
6.2 Calculation Temperature The basic temperature for the flexibility analysis shall be the Design temperature; the temperature for the occasional conditions such as start-up, cool-down, shutdown, regeneration, depressurisation and other special conditions shall also be considered. This temperature shall be taken from the process and utilities list and shall be specified on the Critical Line List. The following rules shall be taken into account: 6.2.1 Nozzles and supports The maximum operating temperature shall be considered for nozzle loads on rotating equipment and air coolers. This temperature is taken from the process and utilities lines list.
This document is the property of Total. It must not be stored, reproduced or disclosed to others without written authorisation from the Company.
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Rev: 04
The thermal displacement of the equipment nozzles shall be calculated using the relevant line temperature. The temperature homogeneity shall be met between piping and equipment. The operating temperature may be applied for the calculation of the loads on the supports. 6.2.2 Solar heating temperature The solar heating temperature shall be used for the design of the exposed un-insulated lines when the operating temperature is lower than the solar heating temperature. The value of the solar heating temperature to be considered shall be specified in the Project environmental conditions (i.e. 60°C for exposed pipes in Africa). 6.2.3 Dry out and steam out Dry out and steam out temperatures (if any) shall be taken from the process and utilities list. In case of steam traced lines, the operating temperature of the traced line or 70% of the steam temperature, whichever is greater, shall be considered. For jacketed lines, the operating temperature of the heated line or the steam temperature, whichever is greater, shall be considered. 6.2.4 “Dead branch” For the lines which do not have flow, such as piping connected to the spare pumps, by-pass, etc., the following value shall be considered: •
Insulated line: 50% of the operating temperature in the dead branch
•
Non-insulated line: plant temperature in the dead branch
•
Steam traced line: 70% of the operating temperature of the steam line in the dead branch
•
Warm-up by-pass of the spare pumps: 70% of the operating temperature of the line.
6.2.5 Plant temperature The plant temperature is defined by considering the Project environmental conditions: •
For cold piping stress, the installation temperature is the maximum air temperature
•
For hot piping stress, the installation temperature is the minimum air temperature.
6.2.6 Line with a dual operating temperature For lines subject to dual operating temperature (both above and below the installation temperature), the thermal effects shall be checked by considering the full thermal range: •
From the installation temperature to the hot temperature and
•
From the cold temperature to the installation temperature.
6.3 Thermal Effects The following thermal effects, combined with loads and forces from other cases, shall be taken into account for the design of piping: •
Thermal loads due to restraints or anchors
•
Loads due to temperature gradients (bowing effect)
This document is the property of Total. It must not be stored, reproduced or disclosed to others without written authorisation from the Company.
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•
Date: 10/2007 Rev: 04
Loads due to difference in expansion characteristics.
ASME B31.3 code requires to check the “Displacement Stress Range” including the stresses induced by both the thermal effects (range) and the support displacements.
6.4 Snow loads - Ice The analysis for snow or ice loads depends of the climatic conditions specified in the Project environment conditions. For un-insulated cold lines where ice formation is anticipated, the additional sustained load due to ice shall be considered for relevant stress evaluation and piping support design. Note: heat traced lines shall be considered too (in case of a possible failure of the heating system).
6.5 Dynamic Effects 6.5.1 Surge effects The loads generated by overpressure in the lines due to water hammer effect shall be taken into account where applicable. They shall be based on Process data (transient rate). Data obtained from a process simulation model which can predict valve Cv as a function of time shall be used as input to the CEASAR model. The method and the model used for the surge effects study shall be submitted to the COMPANY acceptance before calculation. An equivalent static stress analysis shall be performed where the force due to the pressure surge is applied at appropriate locations (changes of direction). The forces shall be modelled acting on straight part of pipe (at the inlet node of the elbows for example). Piping supports and their attachment to the main structure shall be designed to withstand these loads. A force spectrum dynamic analysis shall be performed when high surge pressure fluctuations and high stress level (or high loads on supports) are obtained from the static stress analysis. The lines submitted to the surge effects shall be identified on the Critical Line List. 6.5.2 Slug effects The slug force shall be applied at change of direction (in the middle of the elbows for example) for the calculation of the stresses and pipe support loads. Piping supports and structure shall be designed to withstand these loads. The lines submitted to the slug effects shall be identified on the Critical Line List. Calculations of slug loads on 90° bends shall be based on the following simplified calculation which assumes equal inlet and outlet velocities and no change in pressure FR = ρ.a.V2.DLF Where: FR is the resultant force as slug strikes elbow ρ is the density of the fluid a is the internal surface of the pipe
This document is the property of Total. It must not be stored, reproduced or disclosed to others without written authorisation from the Company.
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V is the slug velocity DLF is the Dynamic Load Factor (DLF = 2). 6.5.3 Wind The effect of wind loading shall be taken into account in the design of an exposed piping system. Wind will be taken in X or Y axis whichever is the more stringent according to the prevailing wind direction. Maximum wind speed shall be taken from the Project environment conditions. The wind shape factor shall be 0.8 unless otherwise specified by the Project specifications. Generally wind loads are derived from API RP2A WSD rules. 6.5.4 Earthquake 6.5.4.1 Accelerations Piping shall be designed for earthquake-induced forces. Generally the accelerations correspond to the seismic site conditions. Accelerations to be considered shall be defined by the structure studies (platforms and racks). Envelop values can be used on a first step however they shall comply with the structure final calculations. The structural deflections induced by the earthquake shall also be considered. 6.5.4.2 Deflections Structural deflections and equipment displacements due to earthquake accelerations shall be introduced in case of significant relative displacement. Estimated values can be considered at the stage of the Basic Design in accordance with the Project environment conditions. However at final stage, the estimated values of the structures displacements shall be compared with the results of the global calculation performed by the Structure discipline. If the final values are higher than the preliminary one, piping stress analysis shall be rerun. Otherwise the estimated values can be kept. Differential displacements due to earthquake shall be considered. 6.5.5 Discharge reactions - Safety valves Forces and moments due to Pressure Safety Valve discharge shall be taken from the Instrumentation PSV data. If such data are not available estimation can be made according to: •
ASME B31.1 Appendix II using a Dynamic Load Factor (DLF) of 2.0.
•
API 520 Part ll section 2.4.1 using a Dynamic Load Factor (DLF) of 2.0
This hypothesis shall be confirmed then by the PSV data sheet. In case of several PSV connected on the same upstream header, the DLF shall be applied on one valve at a time, in order to avoid the over design of the structure.
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Acoustical induced vibrations shall be checked according to the CONCAWE report n° 87/59 or to another relevant rule to submit to COMPANY. 6.5.6 Inertial accelerations 6.5.6.1 Accelerations during the transport The accelerations corresponding to the transport shall be considered (towing, transport of modules, etc.). As far as possible, the piping supports shall be designed in order to avoid additional seafastening during the tow-out. The cooling water lines and the fire water lines are to be calculated full of water during the transport. The other lines shall be empty. 6.5.6.2 Accelerations during operation (Offshore conditions) These accelerations correspond to the swell or hull motion on site. The accelerations values shall be defined by the Naval or Structure discipline and shall comply with the structure final calculations. Envelop values can be used on a first step however they shall be conservative. For the lines connected on sensitive equipment (i.e. compressors) more accurate local accelerations can be used. In that case, they shall be clearly indicated in the calculation report.
6.6 Weight Effects The following weight effects, combined with loads and forces from other causes, shall be taken into account in the design of piping. 6.6.1 Live loads These loads include the weight of the medium transported or the medium used for test. Snow and ice loads due to both environmental and operating conditions shall be considered. 6.6.2 Dead loads These loads consist of the weight of piping components, insulation, and other superimposed permanent loads supported by the piping like valves, flanges, etc.
6.7 Effects of Supports and Structural Deflections The effect of movements of piping supports, anchors, structure and connected equipment shall be taken into account in the design of the piping. These movements may result from the flexibility of equipment, supports, or anchors; and from settlement, tidal movements, or wind sway. All imposed deflections applicable to the loading conditions shall be considered: 6.7.1 Deflections due to inertial accelerations Structural deflections and equipment displacements due to accelerations shall be introduced in case of significant relative displacement.
This document is the property of Total. It must not be stored, reproduced or disclosed to others without written authorisation from the Company.
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6.7.1.1 Basic Design Estimated values of horizontal and vertical deflections to be used for preliminary calculations shall be defined in early stage with the Structural Analysis Group. These values shall be compatible with the current displacements imposed to the piping system. An integrated model considering both the structure and the piping may be necessary for the estimation of these values. In case of a pipe installed through several structures, the worst case to be considered is “first structure” moving, “second structure” without displacement, “third structure” moving, and so on… For the design of the piping attached on the hull (risers, etc.), the deflection of the topside floor shall be introduced in the calculation. 6.7.1.2 Detailed Design The same procedure may be used for the Detailed Design, but at final stage, the estimated values of the structure displacements shall be compared with the results of the global calculation performed by the Structural Analysis Group. If the final values are higher than the preliminary one, piping stress analysis shall be rerun. Otherwise the estimated values can be kept. 6.7.2 Deflections due to hogging and sagging (Floating Units) Differential displacements between the deck and the topsides modules structures (or between two modules) due to the swell, the hull motion, and the differential tank filling shall be taken into account for the maximum displacement stress range check. In the case of a Floating Unit, the longitudinal differential displacements (X axis) due to the hogging and sagging shall be considered. The transverse differential displacements (Y axis) due to the hull hogging and sagging are usually not significant, but should be considered if piping is rigidly supported transversely from the hull. Consideration shall also be given to the construction methodology: construction on-shore followed by load-out to a floating condition can result in larger deflections of the hull than would occur in tow or in service. CONTRACTOR shall propose a method for the combination of the different displacements (in phase or out of phase). 6.7.2.1 Envelope values for Basic Design The following values can be used at the Basic Design stage: •
Sagging deflection at the middle of the hull/platform = -400 mm on a flexural length of 200 m
•
Hogging deflection at the middle of the hull/platform = +400 mm on a flexural length of 200 m
•
Longitudinal strain of the hull deck should assume 1 mm/m.
Other values can be considered if justified but they shall be submitted to the COMPANY for acceptance.
This document is the property of Total. It must not be stored, reproduced or disclosed to others without written authorisation from the Company.
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Exploration & Production General Specification GS EP PVV 107
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6.7.2.2 Detailed Design The values used for the Basic Design are normally conservative and shall be updated for the Detailed Design. For base-anchored elevated equipment, rotations shall be taken into account. Final values of displacements shall be evaluated from the global model calculation (deck + structure + pipe) by Structure discipline and compared with preliminary one. If the final values are higher than the preliminary ones, used at the basic engineering stage, piping stress analysis shall be rerun. Otherwise the preliminary values can be kept. The cases to be analysed shall consider tow, 1-year and 100-year operating cases (on site). Accident conditions, including accidental inclination of the hull of a floating structure shall be considered. 6.7.3 Differential displacements Inter and intra platform (deck or module) relative movements are required for the design of the concerned piping. The differential displacements for seismic effect, swell (or hull) effect and operating effect shall be considered between platforms (decks or modules) and between each structure (or module) within the same area (air coolers structure, pipe racks, etc.). CONTRACTOR shall provide a method explaining the differential displacements considered with the justification of their value. These hypotheses shall be defined in the Piping Stress Design Basis.
6.8 Hydrostatic test conditions For the hydrostatic test, the test pressure shall be taken as follow: •
For rating 600# and below: 1.5 time the Piping Class Maximum Pressure
•
For rating 900# and above: 1.5 time the Maximum Design Pressure.
It will be specified on the calculation note that spring supports and expansion joints are “locked-out” on the field to prevent any excessive deflection and over-stressing of the system.
7. Caesar model 7.1 Boundary conditions A level 2 line or a level 1 line connected to a level 3 line shall be included in input data of the level 3 line calculation note with partial routing at the appreciation of Pipe Stress Engineer for boundaries conditions only. These partially calculated lines shall not be included in the Critical Line List.
7.2 Piping supports Except the case of the spring supports, piping supports shall be included in the piping stress analysis by considering them as rigid elements into CAESAR model. Characteristics of the spring supports shall be specified in the relevant calculation note (movements, operating & calibration loads, spring rate, hydrotest loads & travel stop).
This document is the property of Total. It must not be stored, reproduced or disclosed to others without written authorisation from the Company.
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Any other specific piping support shall be submitted to COMPANY for acceptance.
7.3 Thermal displacements The thermal displacements shall be included in the piping stress analysis by considering the equipments as rigid elements into CAESAR model.
7.4 Imposed displacements The effects of movements of piping supports, anchors, and connected equipment shall be taken into account in the design of the piping for the “displacement stress range” check (including thermal and displacements effects). The movements may result from: •
The flexibility and/or the thermal expansion of equipment, supports or anchors
•
The topsides structure movements due to accelerations
•
The wind sway
•
The piping displacements at the connection point of the calculated line on another line
•
The hull motions
•
The dynamic loads impacts
•
Etc.
7.5 Friction effects Except for special calculation cases, friction factor shall not be taken into account in the final computer runs, but a separate check shall be performed in order to determine the impact of the friction effect on the stresses and on the equipment nozzles. In those cases, the following friction factors shall be applied: Surfaces
Friction factor
Steel to steel
0.3
Steel on polyethylene shim
0.2
Stainless steel to PTFE
0.1
PTFE to PTFE
Shall not be used
The modelling of the supports shall be done without gap except if it is necessary for particular condition. In that case the modelling of the support with gap shall be submitted to the COMPANY for acceptance. In seismic case, friction and gaps shall not be considered.
7.6 Stress Intensification Factor (SIF) for oblique connections In case of oriented tees, Stress Intensification Factor (SIF) are higher due to the angle of connection between branch and header.
This document is the property of Total. It must not be stored, reproduced or disclosed to others without written authorisation from the Company.
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Exploration & Production General Specification GS EP PVV 107
Date: 10/2007 Rev: 04
7.6.1 Forged connection For forged connection, this SIF shall be calculated as per equation below (header and branch element): h = 4.4 (T / r2) iO = 0.9 / [h2/3 (sin α)3/2] iI = (3 iO / 4) + 0.25 7.6.2 Un-reinforced Fabricated Tee For un-reinforced fabricated tee, this SIF shall be calculated as per equation below (Pipe to Pipe for header and branch element): h = T / r2 iO = 0.9 / [h2/3 (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.
7.7 Bourdon effects The Bourdon Effect causes straight pipe to elongate, and bends to “Open Up” axially along a line connecting the curvature end points. Option #1 (translation only) of Special Execution Parameters of CAESAR II shall be used. This option includes only translational effects on the straight pipes. The Bourdon effect shall be considered for all critical lines calculated.
8. Load Cases In view of their combinations such as to represent loading conditions, the loads shall be classed according to the following principles.
8.1 Elementary load cases The elementary load cases shall be defined as a set of indivisible loads of the same type acting concomitantly on the piping system, such as but not limited to: •
Design Pressure
•
Hydrostatic Test Pressure
•
Weight
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Exploration & Production General Specification GS EP PVV 107
•
Thermal in design condition
•
Thermal in service condition
•
Pipe accelerations due to the earthquake
•
Pipe accelerations due to the transport
•
Pipe accelerations during the operations
•
Thermal displacements
•
Structure displacements
•
Wind
•
Forces due to the Dynamic loads
•
Weight empty for structure
•
Etc.
Date: 10/2007 Rev: 04
Both calculation note and computer model file shall fully document and trace in detail the origin of each load input in the model. As such, individual loads pertaining to each piece of itemised equipment shall be related to the equipment reference number.
8.2 Combination load cases The loads defined in the previous paragraph shall be combined to develop the appropriate loading conditions such as to produce the most severe effects on the piping system. The combinations of the elementary load cases shall comply with the ASME B31.3. Other combinations may be necessary for other verifications. All the load cases applicable to the project shall be considered. The following combination load cases are given as example; the different combination load cases shall be defined exhaustively at the beginning of the project in the Piping Stress Design Basis. •
Combination load cases for ASME B31.3
•
Combination cases for structure and equipments
•
Combination cases for support loads only
•
Combination cases for flanges
•
Etc.
Note that the type of combination (Square Root Square Sum, Absolute, or Algebraic) shall be the most appropriate for each combined load case.
9. Acceptance Criteria 9.1 Allowable stress Basic allowable stresses for piping materials shall be taken from the ASME B31.3: •
Sc: basic allowable stress at maximum (cold) temperature
•
Sh: basic allowable stress at maximum (hot) temperature
This document is the property of Total. It must not be stored, reproduced or disclosed to others without written authorisation from the Company.
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Exploration & Production General Specification GS EP PVV 107
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The allowable stress value for each calculated stress shall be taken as the following: 9.1.1 Sum of longitudinal stresses (primary stress): SL •
Sustained loads case SL ≤ Sh (where thickness of pipe is the nominal thickness minus mechanical tolerance and corrosion allowance)
•
Occasional loads cases SL ≤ 1.33 Sh
9.1.2 Displacement stress range (secondary stress): SE SE ≤ f(1.25 Sc + 0.25 Sh) Where: •
SL is the sum of longitudinal stresses caused by internal pressure, self load and other imposed loads
•
SE is the displacement stress range caused by thermal expansion and contraction and anchor movements
•
f is the stress range reduction factor for cyclic conditions for total number of full temperature cycles over expected life (as per defined in the ASME B31.3 § 302.3.5).
9.1.3 Hydrostatic Test SL ≤ 0.9 Sy (Yield Strength at ambient temperature)
9.2 Piping deformation 9.2.1 Sustained loads The vertical deformation of piping shall have no counter-slope under the sustained loads in Design Conditions. Supports must be arranged so that the vertical deflection under its own weight is limited to a range from 5 mm to 10 mm. 9.2.2 Occasional loads Unless otherwise specified, the piping deformation shall be limited to 20 mm in the horizontal and the vertical direction under the occasional loads (seismic acceleration, wind effect, wave effect, etc.) including the piping weight effect. 9.2.3 Piping natural frequency The first dynamic mode shall be checked for each calculation note. Piping layout and supporting shall be developed in order to ensure that the lowest natural frequency of the network is at least half or twice the structure natural frequency of the deck and not less than 4 Hz. These criteria shall be satisfied for all networks. If these criteria are not respected, results shall be submitted to COMPANY for approval.
This document is the property of Total. It must not be stored, reproduced or disclosed to others without written authorisation from the Company.
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Exploration & Production General Specification GS EP PVV 107
Date: 10/2007 Rev: 04
9.3 Allowable loads on equipments The allowable forces and moments on equipment nozzles shall be checked and comply with the allowable value given by the project specification. If such data are not available, the forces and moments induced by piping on the nozzles of equipment shall not exceed the values stated defined here after. When the calculated loads exceed these values, they shall be submitted to the equipment supplier for acceptance. 9.3.1 Centrifugal compressors The piping loads shall be combined as per API 617 Appendix 4E for the suction and the discharge nozzles and for the combined resultants of the forces and the moments. Generally the allowable forces and moments on compressor nozzles are limited to 5 NEMA. 9.3.2 API 610 pumps For centrifugal pumps, the piping loads shall be checked as per API 610 latest edition for the suction and the discharge nozzles and for the combined resultants of the forces and the moments. 9.3.3 Pressure vessels On pressure vessels (columns, vessels, shell and tube heat exchangers, scrubbers, etc.) the allowable loads on equipment’s nozzles are defined in the Appendix 1 of the General Specifications GS EP PVV 211 and GS EP PVV 212. All of the defined loads act at the equipment shell/nozzle interface. 9.3.4 Air coolers The allowable forces and moments acting on air cooler’s nozzles shall meet the criteria of API 661 Table 4. 9.3.5 Plate heat exchangers The allowable forces and moments acting on plate heat exchanger’s nozzles shall meet the criteria of API 662 Table 2 “Severe service nozzle loading”. 9.3.6 Packaged units The allowable loads at package units tie-in points shall be the same as the ones defined for the pressure vessels (refer to § 9.3.3).
9.4 Support reaction The stress analysis reports shall locate and indicate the type of supports on the lines. The reactions in each restraint direction shall be specified in these reports. The maximum loads resulting from the Piping Stress Analysis shall be considered (imposed loads and displacements). The following points shall be checked: •
There shall not be any excessive forces and moments in the supports
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GS EP PVV 107
•
Rev: 04
Piping shall not disengage from its supports (comparison of the piping displacements with the supports length).
Any unusual loads or unusual support dimensions shall be specified and checked by the Structure discipline (impact on the structure if any). The design of the supports and their attachment to the main structure are not included in the scope of the piping stress analysis. Such studies shall be detailed in another separate document.
10. Flange leakage check The risk of flange leakage shall be evaluated according the methods defined here after, from the simplest to the most complicated. These methods are applicable for steel welding neck type flange assemblies under the simultaneous effect of the internal pressure, the axial load and the external bending moments. All flange assemblies of the piping system submitted to stress analysis - “in-line” flanges as well as connected flanges on equipments - shall be checked. The verification of the most loaded flange, for each flange diameter, shall be included in the calculation report.
10.1 Check using tabulated values This first check consists in comparing the calculated flange loads (in operating conditions) to the allowable loads defined in Appendix 2. If the calculated loads exceed the allowable criteria, then the second method shall be applied.
10.2 Check using the equivalent pressure method (Peq) This method is a simplified checking method, which consists of defining the “Equivalent Pressure” due to external loads as per ASME III Div. 1. Axial force and external bending moments shall be converted into an equivalent pressure Peq. This equivalent pressure shall then be added to the internal maximum operating pressure and compared to the maximum allowable pressure on the flange. 10.2.1 Scope This method is applicable for all flanges connection (both on equipments and on piping system) satisfying the following conditions: • •
Type: Carbon steel and stainless steel Welding Neck flanges with metallic pipe and vessels, rotating machines, valves, etc. Codes: ASME B16.5 and B16.47.
This method is not applicable to the following type connections: “Hub connectors”, “Proprietary design”, Flanges on Wellhead (code API 6AF), etc. For flanges out of hypothesis above, a full check by specific code shall be performed. 10.2.2 Calculation method by equivalent pressure (Peq) Peq (in bar) =
509296 x Mf 3
G
+
127 x FA G2
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Where: Mf = Resultant Bending Moment in daN.m in Operating Conditions FA = Axial Force in daN in Operating Conditions (ignore when compressive) G
= Effective Gasket Diameter in mm.
10.2.3 Check of complete pressure in the flange Peq + P < PASME Where: PASME = Working Pressure at Design Temperature (B16.5, B16.47) in bar P
= Operating Pressure in bar
Peq
= Equivalent Pressure in bar.
10.2.4 Loads to be applied on flanges The load cases to be considered for the calculation of the external loads on the flanges shall be the following: 10.2.4.1 Permanent static load cases Weight: including fluid and metal density at operating temperature and pressure Pressure: maximum operating pressure Thermal: maximum operating temperature. These cases shall be algebraically combined. 10.2.4.2 Occasional dynamic load cases Acceleration:
Loads without sign
Restraint movements due to dynamic loads:
Loads without sign
Structure displacement under effect of “pitch and roll” (based on 100 year wave):
Loads without sign
Hogging and sagging:
Loads with sign
Wind:
Loads without sign
Relief valve opening, slug:
Loads with sign
Surge:
Loads without sign
External loads shall be calculated as follow: •
External loads = Permanent static loads + [Loads with sign]
•
External loads = Permanent static loads + [⏐Loads without sign⏐]
•
External Loads = Permanent static loads + [Loads with sign] ± [⏐Loads without sign⏐]
These loads shall be combined to develop the appropriate loading conditions such as to check the flange connections (most severe effects).
This document is the property of Total. It must not be stored, reproduced or disclosed to others without written authorisation from the Company.
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Rev: 04
If the equation is not satisfied, that is to say if Peq + P > PASME, then the isometric shall be optimized: •
Change the location of the piping flanges
•
Add or modify the supports in the vicinity of the flanges
•
Modify the piping routing (where possible).
After these modifications, if the equation remains unsatisfied (Peq + P > PASME), then the enhanced equivalent pressure method can be applied.
10.3 Enhanced equivalent pressure method 10.3.1 Scope This method is applicable for all flanges connection (both on equipments and on piping system) satisfying the following conditions: •
Type: Carbon steel and stainless steel Welding Neck flanges with metallic pipe and vessels, rotating machines, valves, etc.
•
Codes: ASME B16.5 and B16.47
•
Important: this method is valid for temperature ≤ 120°C
•
Duplex and Inconel Welding Neck flanges can be treated in the same way than Carbon steel.
This method is not applicable to the following type connections: “Hub connectors”, “Proprietary design”, Flanges on Wellhead (code API 6AF), etc. For flanges out of hypothesis above, a full check by specific code shall be performed. 10.3.2 Check of complete pressure in the flange: This method is a simplified checking method that is based on the equivalent pressure as defined in the previous paragraph using a β coefficient. This coefficient takes into account the margin existing between a standard flange and a calculated one. The enhanced method equation becomes: (Peq + P) / β < PASME Where: PASME = Working Pressure at Design Temperature (B16.5, B16.47) in bar P
= Operating Pressure in bar
Peq
= Equivalent Pressure in bar
β
= Coefficient defined in Appendix 3
β coefficient is applicable only in the diameter and rating ranges defined in the Appendix 3. If this enhanced method does not lead to satisfactory results, the flange shall be calculated in accordance with the ASME Code Section VIII Division 1.
This document is the property of Total. It must not be stored, reproduced or disclosed to others without written authorisation from the Company.
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10.4 Flange verification according to ASME VIII Division 1 When the previous methods do not give a satisfactory result, a complete calculation of the flange shall be performed in accordance with the ASME Code Section VIII Division 1. The external loads acting on the flange shall be considered. At last, if the results are still not satisfactory and if there is no other possibility to change the pipe routing and/or its supports, the rating of the flange shall be changed (increase of one rating only).
10.5 Case of the specific flanges The above described methods are not applicable to specific flange assemblies such as “hub connectors”, “proprietary design”, etc. In that case the allowable loads, or the methods to define the allowable loads, shall be provided by the flanges’ supplier and submitted to the COMPANY for acceptance.
11. Other verifications 11.1 Vibration analysis Piping shall be designed, arranged and supported so as to eliminate excessive and harmful effects of vibration which may arise from such sources as impact, pressure pulsation, turbulent flow vortices or resonance with a vibrating equipment. At the beginning of the project, Mechanical (or Rotating Equipment) discipline shall check if a vibration analysis is required and the piping system to be considered. Generally a Vibrating Equipment List is issued and a vibration study shall be performed on the connected piping. For each selected equipment, a modal analysis study shall be performed on the first 20 meters of the line(s) connected to this equipment. The analysis shall be done up to the fourth or fifth vibration mode of the line. The results shall be compared to the excitation frequency of the equipment.
11.2 Vortex shedding (wind) Local verification of piping shall be done against vortex shedding due to the wind. By principle vortex induced vibrations (V.I.V.) shall be avoided. In case of V.I.V., fatigue damage shall be evaluated taking into account sensitivity of the damping factors and the full range of the environmental loads up to 100 years return period. This study concern mainly the small piping (small diameter) that are exposed to the wind (flare, top of the packages).
11.3 Fatigue assessment for pipes Fatigue analysis shall be performed for the lines submitted to high cyclic loads (such as cyclic pressure variation). The piping systems shall be able to withstand such fatigue loads throughout their design life. These lines shall be identified by Process discipline and specified on the Critical Line List. Fatigue analysis shall be evaluated in offshore conditions (inertial accelerations, hull and topsides deflections, etc.) in accordance with the DNV RP C203 Fatigue Design of Offshore
This document is the property of Total. It must not be stored, reproduced or disclosed to others without written authorisation from the Company.
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Exploration & Production General Specification GS EP PVV 107
Date: 10/2007 Rev: 04
Steel Structures or other code to submit to the COMPANY. Design fatigue factors for each condition will be approved by COMPANY.
11.4 Blast loads The blast loads on the piping system shall be modelled as a “drag force” applied along the concerned pipes, one direction checked at a time. As the blast is an accidental event, induced stresses correspond to one cycle, and stress intensification factors defined in the ASME B31.3 code shall not be used for this verification (they are defined for cyclic events). As the purpose is to check the risk of pipe failure (rupture is not acceptable but plastic deformations are authorized), the calculation stress, including normal operating stress (thermal + weight + pressure) and the stress induced by blast, shall be kept less than 0.8 the Specified Minimum Tensile Strength. Generally the verification shall be performed during the detailed studies and it is not required at the basic engineering stage. The piping blast design requires a specific lines list (“Lines exposed to blast”) to be established in the early phase of the detailed engineering design. This list must be submitted to the COMPANY for approval. It is independent from the Piping Stress Critical Line list and it shall consider all exposed lines, with respect to blast, whatever their size. The blast parameters (pressure, drag coefficient, etc.) shall be defined by the Safety discipline during the detailed engineering. If this information is not available at early stage, a preliminary calculation can be performed using the following model: •
Blast pressure = 0.3 bar
•
Pulse duration = 0.2 second
•
Drag coefficient = 1.2 (from API RP 2A-WSD for cylindrical shape).
Piping supports and structure shall be checked when submitted to these loads. “Hold down” should be installed on the piping supports of the lines which shall resist to the blast effect. Where plastic strains are incurred under the design explosion event, the post-accident integrity of the damaged piping system shall be inspected.
11.5 Glass Reinforced Plastics pipes (GRP) Preliminary calculations for GRP pipes shall be performed according to BS 7159 and UKOOA codes with the characteristics given by the GRP pipes’ Supplier. Piping stress analysis on GRP lines shall be done in accordance with this General Specification and performed by the GRP supplier (or at least validated by him). A “single-point” responsible shall be clearly identified at the beginning of the project. His responsibility shall cover the design, the pre-fabrication and the site erection of the GRP piping network.
This document is the property of Total. It must not be stored, reproduced or disclosed to others without written authorisation from the Company.
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A pseudo-static study shall be done for the water hammer effect. It shall be qualified and quantified from the pump characteristics applicable on the piping system. GRP supplier shall provide guaranteed allowable stresses σ in pipes, fittings and joints. A reducing ratio shall then be defined and applied to each allowable stress σ. It results in an allowable stress threshold value “X”. The joints having a calculated stress value σcal exceeding the threshold “X” shall be considered as critical joints and shall be made during the prefabrication. All critical joints to be prefabricated shall be clearly identified on the isometrics.
12. Calculation Notes All these requirements are applicable as much to the CONTRACTOR as to the SUB-CONTRACTORS like package suppliers. CONTRACTOR shall issue a Piping Stress Design Basis and shall make it applicable to all SUB-CONTRACTORS. He shall also check that all the calculation notes issued for the project comply with the Piping Stress Design Basis and have the same presentation (including the ones issued by the SUB-CONTRACTORS).
12.1 General The studies shall be supported by all the documents required for the complete definition of the piping systems: piping stress analysis, loads on nozzles and supports, flange leakage check, vibration analysis, fatigue assessment, blast, GRP, etc. This list is not exhaustive. The assumptions and methods used at each stage of the calculations must be collected in a document named “Piping Stress Design Basis” submitted to the COMPANY for approval before starting any calculations. The CONTRACTOR should be responsible for collecting all the necessary information as required from others (construction, transport, structure, equipments, etc.). All the results of the piping stress analysis shall be presented in a calculation note for each system (including the computer outputs) and shall be submitted to the COMPANY. CONTRACTOR shall constantly check that the isometrics used for the piping stress analysis comply with the ones used for the design and for the fabrication: piping routing, components, inline items, supports, etc. Unless otherwise specified by the Project requirements, the Calculation Notes shall be issued in English.
12.2 Calculation Note for basic engineering At basic engineering stage, the piping stress calculation notes can be simplified reports. However all essential information shall be included: •
Cover sheet
•
Introduction, conclusion, recommendations
• •
Basic design data and conditions (including the mechanical characteristic of the piping system) Load cases and combinations considered
This document is the property of Total. It must not be stored, reproduced or disclosed to others without written authorisation from the Company.
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•
Rev: 04
Isometric layout of the complete piping system being analysed with supports configuration
•
CAESAR II input
•
CAESAR restrain summary with forces, moments and displacements at supports
•
CAESAR maximum stresses per load case
•
Loads on equipment nozzles when exceed allowable criteria
•
Additional requirements for acceptance (e.g.: branch connection reinforcements).
12.3 Calculation note for detailed engineering At detailed engineering stage, the piping stress calculation notes shall be a comprehensive reports including as a minimum the information listed here after. The method and detail of handover to Operations of documentation is outside the scope of this document, but the COMPANY representative must discuss with the affiliate and Project, a suitable numbering system such that when the installation becomes operational, all information to enable future pipe modifications may be easily retrieved. The format of the stress reports should be as follows: •
Cover sheet
•
Introduction, summary -
Purpose, general statement stating the objective of the report
-
Process description: brief description of function of pipework, design temperatures and pressures, materials, module description, location, etc.
-
Basic design data (including the mechanical characteristic of the piping system)
-
Calculation Description: codes used, state any assumptions made in calculation method.
•
Content Tables and isometrics -
List of all lines in calculation report, criticality level, extract from line list, isometric numbers, CAESAR calculation number
-
Isometric layout of the complete piping system being analysed showing all supports and nodes necessary for the calculation
-
Support positions and types
-
Load cases, combinations and calculated member stresses
-
Imposed displacements
-
Additional requirements for acceptance (e.g.: branch connection reinforcements).
•
Analysis Results -
Simple graphic of analysed line
-
Boundary conditions with calculation numbers for continuity if applicable
This document is the property of Total. It must not be stored, reproduced or disclosed to others without written authorisation from the Company.
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-
List of all load cases analysed with table showing % of allowable stress for each stress and at which node this occurs (Maximum calculated stresses)
-
Displacements, forces, moments and stresses at all supports, nozzles and particular points of the piping system for all load case
-
Nozzle equipment loads compliance
-
Combination loads on pipe supports with cross reference to project pipe support document
-
The worst flanges verification Flange tightness compliance, with equivalent method or ASME VIII method
-
Dynamic compliance with slugs and fundamental natural frequency or subsequent harmonics if connected to rotating equipment.
•
Detailed Calculations -
Particular Calculations required to justify non compliance or vendor calculations
-
Other verifications (if applicable): fatigue, vibration, blast analysis
-
Additional requirements for acceptance (e.g.: branch connection reinforcements).
•
CAESAR Input file
•
Drawings -
Stress sketches, isometrics, marked up P+IDs, piping components e.g. valves, meters, etc.
•
CAESAR II output
•
Conclusion, recommendations.
12.4 Engineering supervision plan The COMPANY shall, as a minimum, require a Hold Point or a Review Point on the following activities (to be completed after review of the CONTRACTOR’s Quality Plan): • Critical Line List:
Hold Point
• Piping Stress Design Basis:
Hold Point
• List of Calculation Reports:
Review
• First and Second Calculation Notes: (Representative steel piping systems)
Hold Point
• First and Second Calculation Notes GRP (Representative Calculations)
Hold Point
• Other Calculations Notes
Review
This document is the property of Total. It must not be stored, reproduced or disclosed to others without written authorisation from the Company.
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Rev: 04 Appendix 1
Appendix 1
Stress analysis level requirements General Chart
Design Temperature (°C) 250
Level 3 200
150
Level 2 100
50
Level 1
Line size (inches)
0 1
2
3
4
6
8
10
-30
12
14
16
18
20
22
24
Level 2
-50
Level 3
This document is the property of Total. It must not be stored, reproduced or disclosed to others without written authorisation from the Company.
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Specific Cases
Connection type Rotating Machine or sensitive equipment Reciprocating machine B (pumps and compressors) C Expansion joint Heater-Transfert D Line Compressor / Turbine A
E Cryogenic (1) High Pressure (Piping Class ≥ 600 Lbs HP relief lines to and from G PSV (or bursting discexpansion joint lines) H Non-ferrous materials I Non-metallic materials (2) F
J GRP (3) K Buried Lines
Line Maximum Pipe Size below -46 (Inches) ∅ ≤ 3" ∅ > 3"
-46
Design Temperature (°C) Ambient 50 80 100
above
Level 3 Level 3
All ∅ ∅ ≤ 3" ∅ > 3" ∅ ≤ 18" ∅ > 18" 3" < ∅ ≤ 12" ∅ > 12"
Level 3 Level 2 Level 3 Level 2 Level 3 Level 2 Level 3
∅ > 3" All ∅ All ∅ ∅ ≤ 8" ∅ > 8" ∅ ≤ 12" ∅ > 12"
250
Level 2 Level 2
All ∅
Level 3
150
Level 3
Level 3 Level 2 Level 2 Level 2 Level 3
Level 3 Level 3 N.A. N.A. Level 2 Level 3
Notes: (1) Above ambient temperature, the General Chart or the Specific Cases shall be applied (2) GRP excluded (3) Size to be confirmed for each project
This document is the property of Total. It must not be stored, reproduced or disclosed to others without written authorisation from the Company.
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Rev: 04 Appendix 2
Appendix 2
Allowable loads on flanges
Allowable loads on flanges up to and including 600 lbs rating y
x z y is the axis of the pipe Nozzle Nominal Diameter
Direct Loads (kN)
Moment Loads (kN.m)
(Inches)
(mm)
Fx
Fy
Fz
Mx
My
Mz
2
50
1.0
1.4
1.0
0.4
0.5
0.4
3
80
1.4
1.8
1.4
0.7
0.9
0.7
4
100
1.8
2.2
1.8
0.7
1.1
0.7
6
150
2.2
3.1
2.2
1.8
2.7
1.8
8
200
3.5
4.4
3.5
3.6
5.4
3.6
10
250
4.9
6.7
4.9
4.5
6.8
4.5
12
300
5.3
7.1
5.3
5.4
8.1
5.4
14
350
5.3
8.0
5.3
6.4
9.5
6.4
16
400
5.8
8.4
5.8
7.2
10.8
7.2
18
450
6.7
8.9
6.7
8.1
12.2
8.1
20
500
6.7
8.9
6.7
9.1
13.5
9.1
24
600
8.9
11.1
8.9
9.1
13.5
9.1
This document is the property of Total. It must not be stored, reproduced or disclosed to others without written authorisation from the Company.
Page 33/36
Exploration & Production General Specification
Date: 10/2007
GS EP PVV 107
Rev: 04 Appendix 2
Allowable loads on flanges 900 lbs and above rating y
x z y is the axis of the pipe Nozzle Nominal Diameter
Direct Loads (kN)
Moment Loads (kN.m)
(Inches)
(mm)
Fx
Fy
Fz
Mx
My
Mz
2
50
1.0
1.4
1.0
0.4
0.5
0.4
3
80
1.4
1.8
1.4
0.7
0.9
0.7
4
100
2.7
3.3
2.7
1.1
1.7
1.1
6
150
3.3
4.7
3.3
2.7
4.0
2.7
8
200
5.3
6.7
5.3
5.4
8.1
5.4
10
250
7.4
10.1
7.4
6.8
10.2
6.8
12
300
8.0
10.7
8.0
8.1
12.2
8.1
14
350
8.0
12.0
8.0
9.6
14.3
9.6
16
400
8.7
12.7
8.7
10.8
16.2
10.8
18
450
10.1
13.4
10.1
12.2
18.3
12.2
20
500
10.1
13.4
10.1
13.7
20.2
13.7
24
600
13.4
16.7
13.4
13.7
20.2
13.7
This document is the property of Total. It must not be stored, reproduced or disclosed to others without written authorisation from the Company.
Page 34/36
Exploration & Production General Specification
Date: 10/2007
GS EP PVV 107
Rev: 04 Appendix 3
Appendix 3
Beta Coefficients (β)
For Carbon Steel Flanges DN Inch
150#
300#
600#
900#
1500#
2500#
ASME/ Peq+P
ASME/ Peq+P
ASME/ Peq+P
ASME/ Peq+P
ASME/ Peq+P
ASME/ Peq+P
2
1.30
1.50
1.20
3
1.30
1.50
1.20
4
1.30
1.50
1.20
6
1.30
1.50
1.20
1.40
1.20
1.50
1.10
2.30
1.40
1.20
1.20
1.10 1.10
8 10 12
2.20
2.00
1.20
1.20
1.20
14
2.00
2.00
1.20
1.20
1.10
16
2.00
1.80
1.15
1.15
1.10
18
2.00
1.80
1.15
1.15
1.10
20
2.00
1.80
1.15
1.15
1.10
24
1.90
1.50
1.15
1.15
1.10
26
1.90
1.50
1.15
1.15
28
1.80
1.20
1.10
1.15
30
1.70
1.20
1.10
1.15
32
1.60
1.20
1.10
1.15
34
1.60
1.20
1.10
1.15
36
1.80
1.40
1.30
1.30
38
1.40
1.10
1.00
40
1.30
1.10
1.00
42
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
This document is the property of Total. It must not be stored, reproduced or disclosed to others without written authorisation from the Company.
Page 35/36
Exploration & Production General Specification
Date: 10/2007
GS EP PVV 107
Rev: 04 Appendix 3
For Stainless Steel Flanges DN Inch
150#
300#
600#
900#
1500#
2500#
ASME/ Peq+P
ASME/ Peq+P
ASME/ Peq+P
ASME/ Peq+P
ASME/ Peq+P
ASME/ Peq+P
2
1.10
1.40
1.10
3
1.10
1.40
1.10
4
1.10
1.40
1.10
6
1.10
1.40
1.10
1.20
1.10
1.40
1.00
1.60
1.20
1.10
1.10
1.00 1.00
8 10 12
1.60
1.40
1.10
1.10
1.10
14
1.30
1.20
1.10
1.10
1.00
16
1.30
1.20
1.10
1.00
1.00
18
1.30
1.20
1.10
1.00
1.00
20
1.30
1.20
1.10
1.00
1.00
24
1.30
1.20
1.10
1.00
1.00
26
1.30
1.20
1.10
1.00
28
1.30
1.10
1.00
1.00
30
1.30
1.10
1.00
1.00
32
1.30
1.10
1.00
1.00
34
1.30
1.10
1.00
1.00
36
1.20
1.10
1.00
1.00
38
1.20
1.00
1.00
40
1.20
1.00
1.00
42
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
This document is the property of Total. It must not be stored, reproduced or disclosed to others without written authorisation from the Company.
Page 36/36
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