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Submarine Pipeline System Modules

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CALCULATOR MODULE : Beam Vibration Added Mass   ±

Calculate submerged beam added mass coefficient and added mass from gap height.

Added mass is included in the unit mass for submerged beams to account for the fluid which is displaced by the beam. The added mass coefficient can be calculated in accordance with DNVGL RP F105. The equation is suitable for undamped vibration of circular beams in a still fluid. For other beam profiles use the beam width. The method may not be valid for other profiles (engineering judgment is required). The gap height is measured along the axis of vibration and is assumed to be perpendicular to the adjacent surface.

Use the Result Table and Result Plot options to display tables and plots. Refer to the help pages for more details about the tools.

References :

Shock And Vibration Handbook, Cyril M Harris, McGraw Hill
Roark's Formulas For Stress And Strain, Warren C Young, McGraw Hill

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CALCULATOR MODULE : Line Pipe Unit Mass And Weight   ±
CALCULATOR MODULE : ASME B31.4 Oil And Liquid Pipeline   ±
CALCULATOR MODULE : ASME B31.4 Liquid Pipeline Wall Thickness   ±

Calculate ASME B31.4 oil and liquid pipeline wall thickness from hoop stress for onshore and offshore pipelines.

Select the appropriate line pipe schedule (ASME or ISO etc) and stress table (API, ASM, DNV etc), and material. Wall thickness is calculated using Barlow's formula. For offshore pipelines either the pipe outside diameter or the mid wall diameter can be used to calculate wall thickness. The wall thickness should be checked for all elevations. Use the Result Plot option to plot required wall thickness versus elevation, or hoop stress versus elevation for user defined wall thickness.

Reference : ANSI/ASME B31.4 : Pipeline Transportation Systems For Liquids And Slurries (2012)

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CALCULATOR MODULE : ASME B31.4 Liquid Pipeline Hoop Stress   ±
CALCULATOR MODULE : ASME B31.4 Liquid Pipeline Hydrotest Pressure   ±

Calculate ASME B31.4 oil and liquid pipeline test pressure and hoop stress check for onshore and offshore pipelines.

Select the appropriate line pipe schedule (ASME or ISO etc) and stress table (API, ASM, DNV etc), and material. Hoop stress is calculated using Barlow's formula. For offshore pipelines either the pipe outside diameter or the mid wall diameter can be used to calculate hoop stress. The test pressure and hoop stress should be checked for all elevations. Use the Result Plot option to plot the required test pressure versus elevation, or hoop stress verus elevation for user defined test pressure.

Reference : ANSI/ASME B31.4 : Pipeline Transportation Systems For Liquids And Slurries (2012)

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Related Modules :

CALCULATOR MODULE : ASME B31.4 Liquid Pipeline Allowable Stress   ±

Calculate ASME B31.4 oil and liquid pipeline allowable stress for onshore and offshore pipelines.

Select the appropriate stress table (API, ASM, DNV etc), and material. Use the Result Table option to display the results for the selected stress table (click the Result Table button on the plot bar, then click the make table button). For metal pipeline the pressure design thickness equals the nominal wall thickness minus the corrosion allowance. Fabrication tolerance is ignored.

Reference : ANSI/ASME B31.4 : Pipeline Transportation Systems For Liquids And Slurries (2012)

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CALCULATOR MODULE : ASME B31.4 Liquid Pipeline Yield Stress   ±
CALCULATOR MODULE : ASME B31.4 Liquid Pipeline Ripple Defect   ±
CALCULATOR MODULE : ASME B31.4 Liquid Pipeline Local Pressure   ±
CALCULATOR MODULE : ASME B31.4 Liquid Pipeline Branch Reinforcement   ±
CALCULATOR MODULE : ASME B31.4 Liquid Pipeline Design Pressure   ±

Calculate ASME B31.4 oil and liquid pipeline maximum allowable design pressure from pressure design wall thickness and allowable stress.

For subsea pipelines the allowable pressure is the maximum allowable local pressure difference across the pipe wall. The pressure difference equals the internal pressure minus the external pressure. For onshore pipelines the allowable pressure is the maximum allowable local internal pressure. The local internal and external pressure varies with elevation. Use the Result Table option to display the allowable pressure for the selected pipe diameter schedule.

Reference : ANSI/ASME B31.4 : Pipeline Transportation Systems For Liquids And Slurries (2012)

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CALCULATOR MODULE : ASME B31.4 Liquid Pipeline Mass And Weight   ±

Calculate ASME B31.4 liquid pipeline unit mass (mass per length), unit weight (weight per length), and total mass. The mass per joint can be calculated from the joint length. Construction quantities can be calculated from the total pipe length. Pipe unit mass and pipe unit weight (weight per length) can be calculated for multi layer pipelines (dry empty, dry full, wet empty and wet full pipelines). For multi layer pipelines, the first internal layer is the line pipe. Change the number of layers on the setup page. The line pipe diameter and thickness are calculated from the pipe schedule.

Use the Result Table option to display a table of pipe mass versus schedule wall thickness for the selected diameter.

Reference : ANSI/ASME B31.4 : Pipeline Transportation Systems For Liquids And Slurries (2012)

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CALCULATOR MODULE : ASME B31.4 Liquid Pipeline Fluid Volume And Mass   ±

Calculate ASME B31.4 liquid pipeline fluid density, fluid volume and fluid mass for two phase gas liquid pipelines, and three phase black oil pipelines (gas water and oil).

The two phase fluid calculator can be used for single phase gas, single phase liquid, or two phase gas and liquid. The three phase black oil calculator can be used for single phase oil, single phase water, two phase oil and water, and three phase oil, water and gas. Water cut is the volume fraction of water in the liquid phase (ignoring the gas phase). Gas oil ratio (GOR) is the ratio of gas moles to liquid volume (ignoring the water phase). Gas moles are commonly measured as gas volume at standard conditions, eg SCM (Standard Conditions Meter) or SCF (Standard Conditions Feet).

Reference : ANSI/ASME B31.4 : Pipeline Transportation Systems For Liquids And Slurries (2012)

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CALCULATOR MODULE : ASME B31.4 Liquid Pipeline Fluid Velocity And Flow Rate   ±

Calculate ASME B31.4 liquid pipeline fluid velocity and flow rate for two phase gas liquid piping, and three phase black oil piping (gas water and oil).

The two phase fluid calculator can be used for single phase gas, single phase liquid, or two phase gas and liquid. The three phase black oil calculator can be used for single phase oil, single phase water, two phase oil and water, and three phase oil, water and gas. Water cut is the volume fraction of water in the liquid phase (ignoring the gas phase). Gas oil ratio (GOR) is the ratio of gas moles to liquid volume (ignoring the water phase). Gas moles are commonly measured as gas volume at standard conditions, eg SCM (Standard Conditions Meter) or SCF (Standard Conditions Feet).

Reference : ANSI/ASME B31.4 : Pipeline Transportation Systems For Liquids And Slurries (2012)

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CALCULATOR MODULE : ASME B31.8 Gas Pipeline   ±
CALCULATOR MODULE : ASME B31.8 Gas Pipeline Allowable Stress   ±

Calculate ASME B31.8 gas pipeline allowable stress from temperature for onshore and offshore pipelines.

Select the appropriate stress table (API, ASM, DNV etc), and material. Use the Result Table option to display the results for the selected stress table (click the Result Table button on the plot bar, then click the make table button). For metal pipeline the pressure design thickness equals the nominal wall thickness minus the corrosion allowance. Fabrication tolerance is ignored.

Reference : ANSI/ASME B31.8 : Gas Transmission And Distribution Piping Systems (2018)

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CALCULATOR MODULE : ASME B31.8 Gas Pipeline Wall Thickness   ±

Calculate ASME B31.8 gas pipeline wall thickness from hoop stress for onshore and offshore pipelines.

Select the appropriate line pipe schedule (ASME or ISO etc), and stress table (API, ASME or DNV), or use the user defined options. Pipe pressure can either be calculated from elevation, or user defined. For metal pipeline the pressure design thickness equals the nominal wall thickness minus the corrosion allowance. Fabrication tolerance is ignored. The wall thickness should be checked for all pipeline elevations. A wall thickness should be specified which is greater than or equal to the maximum calculated wall thickness (usually by selecting the next highest schedule thickness). Use the Result Plot option to plot the calculated wall thickness versus elevation, and the hoop stress versus elevation for the specified wall thickness.

Reference : ANSI/ASME B31.8 : Gas Transmission And Distribution Piping Systems (2018)

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CALCULATOR MODULE : ASME B31.8 Gas Pipeline Hoop Stress   ±

Calculate ASME B31.8 gas pipeline hoop stress from wall thickness for onshore and offshore pipelines.

Pipe pressure can either be calculated from elevation, or user defined. Select the appropriate line pipe schedule (ASME or ISO etc), and stress table (API, ASME or DNV), or use the user defined options. For metal pipeline the pressure design thickness equals the nominal wall thickness minus the corrosion allowance. Fabrication tolerance is ignored.

Reference : ANSI/ASME B31.8 : Gas Transmission And Distribution Piping Systems (2018)

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CALCULATOR MODULE : ASME B31.8 Gas Pipeline Hydrotest Pressure   ±

Calculate ASME B31.8 gas pipeline test pressure and hoop stress check for onshore and offshore pipelines.

Select the appropriate line pipe schedule (ASME or ISO etc), and stress table (API, ASME or DNV), or use the user defined options. For metal pipeline the pressure design thickness equals the nominal wall thickness minus the corrosion allowance. Fabrication tolerance is ignored. Pipe pressure can either be calculated from elevation, or user defined. The test pressure should be checked for all pipeline elevations. A test point test pressure should be specified which is greater than or equal to the maximum calculated test pressure (usually by rounding up the maximum test pressure). Use the Result Plot option to plot the test pressure versus elevation, and the hoop stress versus elevation for the specified test pressure.

Reference : ANSI/ASME B31.8 : Gas Transmission And Distribution Piping Systems (2018)

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Related Modules :

CALCULATOR MODULE : ASME B31.8 Gas Pipeline Plastic Component   ±

Calculate ASME B31.8 plastic piping wall thickness, hoop stress, test pressure and MAOP.

Select the appropriate plastic pipe schedule (ASME or ISO etc), or use the user defined options. For plastic piping the pressure design thickness equals the nominal wall thickness minus the mechanical allowance. The mechanical allowance includes allowances for threads, gluing, crimping, erosion, corrosion, and mechanical damage. The dimension ratio (SDR or SIDR) is calculated from the pressure design wall thickness. Elevation and external pressure are ignored for the plastic piping calculations.

Reference : ANSI/ASME B31.8 : Gas Transmission And Distribution Piping Systems (2018)

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CALCULATOR MODULE : ASME B31.8 Gas Pipeline Ripple And Dent Defect   ±
CALCULATOR MODULE : ASME B31.8 Gas Pipeline Maximum Allowable Operating Pressure   ±

Calculate ASME B31.8 gas pipeline MAOP from the design pressure and the test pressure.

The design pressure is the minimum value of allowable pressure at all points on the pipeline. If the design pressure is not known, use the hoop stress calculators to calculate the design pressure. Use the goal seek option to calculate the allowable pressure at the allowable stress at all points on the pipeline. The minimum value of allowable pressure is the design pressure. Use the pressure design wall thickness for the hoop stress calculations.

The test pressure is the minimum value of the local test pressure at all points on the pipeline. If the minimum test pressure is not known (only the test pressure at the test location is known), use the test pressure calculators to calculate the local test pressure from the test pressure at the test location, at all points on the pipeline. Use the minimum value of local test pressure as the test pressure.

Reference : ANSI/ASME B31.8 : Gas Transmission And Distribution Piping Systems (2018)

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CALCULATOR MODULE : ASME B31.8 Gas Pipeline Branch Reinforcement   ±
CALCULATOR MODULE : ASME B31.8 Gas Pipeline Sour Gas Service   ±
CALCULATOR MODULE : ASME B31.8 Gas Pipeline Charpy Toughness   ±
CALCULATOR MODULE : ASME B31.8 Gas Pipeline Temperature Derating   ±
CALCULATOR MODULE : ASME B31.8 Gas Pipeline Local Pressure   ±
CALCULATOR MODULE : ASME B31.8 Gas Pipeline Design Pressure   ±

Calculate ASME B31.8 gas pipeline maximum allowable design pressure from allowable stress and pressure design wall thickness.

For onshore pipelines and offshore platform piping the allowable pressure is the maximum allowable design pressure for the pipeline location class and facility type. For submerged offshore pipelines the allowable pressure is the maximum allowable pressure difference (internal pressure minus external pressure). Use the Result Table option on the plot bar to display the allowable pressure for the selected pipe diameter.

Reference : ANSI/ASME B31.8 : Gas Transmission And Distribution Piping Systems (2018)

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CALCULATOR MODULE : ASME B31.8 Gas Pipeline Fluid Velocity And Flow Rate   ±

Calculate ASME ASME B31.8 gas pipeline fluid velocity and flow rate for two phase gas liquid piping, and three phase black oil piping (gas water and oil).

The two phase fluid calculator can be used for single phase gas, single phase liquid, or two phase gas and liquid. The three phase black oil calculator can be used for single phase oil, single phase water, two phase oil and water, and three phase oil, water and gas. Water cut is the volume fraction of water in the liquid phase (ignoring the gas phase). Gas oil ratio (GOR) is the ratio of gas moles to liquid volume (ignoring the water phase). Gas moles are commonly measured as gas volume at standard conditions, eg SCM (Standard Conditions Meter) or SCF (Standard Conditions Feet).

Reference : ANSI/ASME B31.8 : Gas Transmission And Distribution Piping Systems (2018)

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CALCULATOR MODULE : ASME B31.8 Gas Pipeline Mass And Weight   ±

Calculate ASME B31.8 gas pipeline unit mass (mass per length), unit weight (weight per length), and total mass for metal and plastic pipe.

The mass per joint can be calculated from the joint length. Construction quantities can be calculated from the total pipe length. Pipe mass and pipe unit weight (weight per length) can be calculated for multi layer pipelines (dry empty, dry full, wet empty and wet full pipelines). For multi layer pipelines, the first internal layer is the line pipe. Change the number of layers on the setup page. The line pipe diameter and thickness are calculated from the pipe schedule.

Plastic pipe wall thickness can be defined by wall thickness or diameter ratio (DR or IDR). Select standard diameter ratios from the plastic pipe schedule (SDR or SIDR), or use user defined diameter ratios (DR or IDR). Plastic pipe is generally only used in low pressure distribution systems.

Use the Result Table option to display a table of pipe mass versus schedule wall thickness for the selected diameter.

Reference : ANSI/ASME B31.8 : Gas Transmission And Distribution Piping Systems (2018)

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CALCULATOR MODULE : ASME B31.8 Gas Pipeline Fluid Volume And Mass   ±

Calculate ASME B31.8 gas pipeline fluid density, fluid volume and fluid mass for two phase gas liquid piping, and three phase black oil piping (gas water and oil).

The two phase fluid calculator can be used for single phase gas, single phase liquid, or two phase gas and liquid. The three phase black oil calculator can be used for single phase oil, single phase water, two phase oil and water, and three phase oil, water and gas. Water cut is the volume fraction of water in the liquid phase (ignoring the gas phase). Gas oil ratio (GOR) is the ratio of gas moles to liquid volume (ignoring the water phase). Gas moles are commonly measured as gas volume at standard conditions, eg SCM (Standard Conditions Meter) or SCF (Standard Conditions Feet).

Reference : ANSI/ASME B31.8 : Gas Transmission And Distribution Piping Systems (2018)

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CALCULATOR MODULE : Pipeline Local Pressure   ±
CALCULATOR MODULE : DNVGL ST F101 Submarine Pipeline Line Pipe Schedule   ±

Calculate DNVGL-ST-F101 subsea pipeline schedules for diameter, wall thickness, mass, weight, and stress.

Use the Result Table option to display schedule tables. Refer to the links below for other options.

Reference : DNVGL-ST-F101 : Submarine Pipeline Systems (Download from the DNVGL website)

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CALCULATOR MODULE : DNVGL ST F101 Submarine Pipeline Wall Thickness   ±

Calculate DNVGL-ST-F101 submarine pipeline wall thickness from local incidental pressure.

Local incidental pressure can be calculated from the design pressure, calculated from the reference incidental pressure, or can be user defined. External pressure should be calculated for the minimum local water depth. The pipeline wall thickness must be calculated for the maximum pressure differential at all points on the pipeline or pipeline section. For submarine pipelines where the internal fluid density is less than the external fluid density, the maximum pressure differential occurs at the highest submerged location for the pipeline or pipeline section. For the platform zone the highest differential pressure occurs at the riser splash zone. Use the Result Plot option to plot the required wall thickness versus elevation.

Reference : DNVGL-ST-F101 : Submarine Pipeline Systems (Download from the DNVGL website)

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CALCULATOR MODULE : DNVGL ST F101 Submarine Pipeline Hydrotest Pressure   ±

Calculate DNVGL-ST-F101 submarine pipeline system test pressure and mill test pressure.

The system test pressure is calculated from the local incidental pressure. The required system test pressure and mill test pressure should be calculated for all points on the pipeline or pipeline section. Use the Result Plot option to plot the test pressure and hoop stress from minimum to maximum elevation.

Reference : DNVGL-ST-F101 : Submarine Pipeline Systems (Download from the DNVGL website)

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CALCULATOR MODULE : DNVGL ST F101 Submarine Pipeline Collapse Pressure   ±

Calculate DNVGL-ST-F101 submarine pipeline external collapse pressure and propagating buckle pressure.

The external pressure should be calculated for the maximum water depth. Propagating buckles are only a problem if collapse has occurred. Buckle arrestors may be required to minimse the risk of propagating buckling.

Reference : DNVGL-ST-F101 : Submarine Pipeline Systems (Download from the DNVGL website)

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CALCULATOR MODULE : DNVGL ST F101 Submarine Pipeline Local Buckling   ±

Calculate DNVGL-ST-F101 submarine pipeline local buckling checks for combined loading.

The load controlled calculators should only be used for elastic deformation (check that the equivalent stress is less than the yield stress).

The displacement controlled calculators can be used for compressive elastic and plastic deformation. Elastic strains are calculated using the elastic modulus, and should not be used in the plastic range. Plastic strains should be calculated using finite element analysis (FEA). Use the allowable stress design (ASD) calculators for displacement controlled loads which include torsion.

Reference : DNVGL-ST-F101 : Submarine Pipeline Systems (Download from the DNVGL website)

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CALCULATOR MODULE : DNVGL ST F101 Submarine Pipeline Bend Allowable Stress Design (ASD)   ±

Calculate DNVGL-ST-F101 submarine pipeline allowable stress design (ASAD) check for combined loading. The allowable stress design (ASD) check can be used for pipeline induction bends with combined loading which includes a torsion load. The allowable stress design (ASD) check is a von Mises equivalent stress check.

Reference : DNVGL-ST-F101 : Submarine Pipeline Systems (Download from the DNVGL website)

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CALCULATOR MODULE : DNVGL ST F101 Submarine Pipeline Axial Load   ±

Calculate DNVGL-ST-F101 submarine pipeline axial load from temperature and pressure. The axial load calculations are valid in the elastic range only (check that the equivalent stress is less than the yield stress). The calculators include a combined load controlled check, displacement controlled check, allowable stress design check (ASD), and an equivalent stress check (von Mises).

Reference : DNVGL-ST-F101 : Submarine Pipeline Systems (Download from the DNVGL website)

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CALCULATOR MODULE : DNVGL ST F101 Submarine Pipeline Ovality   ±

Calculate DNVGL-ST-F101 submarine pipeline ovality from the out of roundness tolerance, or measured maximum and minimum diameter. Pipe ovalisation can be calculated from the initial ovality and the bending strain.

Reference : DNVGL-ST-F101 : Submarine Pipeline Systems (Download from the DNVGL website)

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CALCULATOR MODULE : DNVGL ST F101 Submarine Pipeline Temperature Derating   ±

Calculate DNVGL-ST-F101 submarine pipeline temperature derating stress from temperature.

Derating is valid for temperatures up to 200 C. Material specific test data should be used if it is available. For low temperature pipelines, fracture toughness should also be considered.

Reference : DNVGL-ST-F101 : Submarine Pipeline Systems (Download from the DNVGL website)

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CALCULATOR MODULE : DNVGL ST F101 Submarine Pipeline Incidental Pressure   ±

Calculate DNVGL-ST-F101 submarine pipeline incidental pressure from design pressure and elevation.

The reference incidental pressure (the incidental pressure at the reference elvation) is calculated from the design pressure at the reference elevation. The local incidental pressure (the incidental pressure at the local elvation) is calculated from the reference incidental pressure and the relative elevation. Use the Result Plot option to plot local pressure and reference pressure versus elevation.

Reference : DNVGL-ST-F101 : Submarine Pipeline Systems (Download from the DNVGL website)

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CALCULATOR MODULE : DNVGL ST F101 Submarine Pipeline Flotation   ±

Calculate DNVGL-ST-F101 submarine pipeline flotation and vertical stability.

Select either the empty pipe or full pipe option. For vertical stability, the pipe specific gravity should be greater than or equal to 1.1.

The number of pipe internal and external layers, and the names of the layers can be changed on the setup page. The first internal layer is the line pipe. The line pipe wall thickness can either be selected from the pipe schedule, or the input value is used as the user defined value.

Reference : DNVGL-ST-F101 : Submarine Pipeline Systems (Download from the DNVGL website)

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CALCULATOR MODULE : DNVGL ST F101 Submarine Pipeline Tolerances   ±

Calculate DNVGL-ST-F101 submarine pipeline out of roundness tolerance, diameter tolerance, and wall thickness tolerance.

Reference : DNVGL-ST-F101 : Submarine Pipeline Systems (Download from the DNVGL website)

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CALCULATOR MODULE : DNVGL ST F101 Submarine Pipeline Hoop Stress   ±

Calculate DNVGL-ST-F101 submarine pipeline hoop stress from local incidental pressure.

The local incidental pressure can either be calculated, or user defined. For temporary conditions the actual local pressure can be used (eg for system pressure test). External pressure should be calculated for the minimum local water depth (lowest astronomical tide minus storm surge). For temporary conditions storm surge can be ignored. For pressure containment use wall thickness t1. For other cases use wall thickness t2.

Reference : DNVGL-ST-F101 : Submarine Pipeline Systems (Download from the DNVGL website)

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CALCULATOR MODULE : DNVGL ST F101 Submarine Pipeline Carbon Equivalent   ±

Calculate DNVGL-ST-F101 submarine pipeline carbon equivalent from material composition. Carbon equivalent is a useful indicator of weldability, and fracture toughness.

Reference : DNVGL-ST-F101 : Submarine Pipeline Systems (Download from the DNVGL website)

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CALCULATOR MODULE : DNVGL ST F101 Submarine Pipeline Dent Depth   ±

Calculate DNVGL-ST-F101 maximum allowable dent depth.

Reference : DNVGL-ST-F101 : Submarine Pipeline Systems (Download from the DNVGL website)

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CALCULATOR MODULE : DNVGL ST F101 Submarine Pipeline Design Pressure And Burst Pressure   ±

Calculate DNVGL-ST-F101 submarine pipeline maximum allowable design pressure and burst pressure from the pressure design wall thickness (nominal wall thickness minus fabrication allowance and corrosion allowance).

For platform piping the allowable pressure is the maximum allowable local incidental pressure. For subsea pipelines the allowable pressure is the maximum allowable local pressure difference (local incidental pressure minus local external pressure). Use the Result Table option to display the results for the selected pipe schedule and pipe diameter.

Reference : DNVGL-ST-F101 : Submarine Pipeline Systems (Download from the DNVGL website)

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CALCULATOR MODULE : DNVGL ST F101 Submarine Pipeline Transition Length At Code Break   ±

Calculate DNVGL-ST-F101 submarine pipeline transition length at code breaks.

The minimum transition length for pipeline components at a code break is four times the elastic length.

Reference : DNVGL-ST-F101 : Submarine Pipeline Systems (Download from the DNVGL website)

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CALCULATOR MODULE : DNVGL ST F101 Submarine Pipeline Design Load Effect   ±

Calculate DNVGL-ST-F101 submarine pipeline design load effect.

The design load effect can be calculated for ultimate limit state (ULS), fatigue limit state (FLS), and accident limit state (ALS). The ULS type a check is only required for system loads.

Reference : DNVGL-ST-F101 : Submarine Pipeline Systems (Download from the DNVGL website)

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CALCULATOR MODULE : DNVGL ST F101 Submarine Pipeline Expansion Spool   ±

Calculate DNVGL-ST-F101 submarine expansion spool local buckling and fatigue check.

The expansion spool is modelled as a simple beam with fixed ends, with a uniform distributed load due to friction and a lateral displacement at one end due to expansion. Pipe cross section properties are calculated for a single pipe layer with no coatings. For pipes with internal liner or external coatings use the user defined cross section properties option.

Reference : DNVGL-ST-F101 : Submarine Pipeline Systems (Download from the DNVGL website)

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CALCULATOR MODULE : DNVGL ST F101 Submarine Pipeline Mass And Weight   ±

Calculate DNVGL-ST-F101 subsea pipeline unit mass (mass per length), and total mass from length.

The mass per joint can be calculated from the joint length. Construction quantities can be calculated from the total pipe length. Pipe unit mass (mass per length) and pipe unit weight (weight per length) can be calculated for multi layer pipelines (dry empty, dry full, wet empty and wet full pipelines). For multi layer pipelines, the first internal layer is the line pipe. Change the number of layers on the setup page.

Use the Result Table option to display a table of pipe mass and weight versus schedule wall thickness for the selected diameter.

Reference : DNVGL-ST-F101 : Submarine Pipeline Systems (Download from the DNVGL website)

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CALCULATOR MODULE : DNVGL ST F101 Submarine Pipeline Fluid Mass And Volume   ±

Calculate DNVGL-ST-F101 subsea pipeline fluid volume and mass for two phase gas and liquid, and three phase oil, water and gas (black oil).

The two phase fluid calculator can be used for single phase gas, single phase liquid, or two phase gas and liquid. The three phase black oil calculator can be used for single phase oil, single phase water, two phase oil and water, and three phase oil, water and gas. Water cut is the volume fraction of water in the liquid phase (ignoring the gas phase). Gas oil ratio (GOR) is the ratio of gas moles to liquid volume (ignoring the water phase). Gas moles are commonly measured as gas volume at standard conditions, eg SCM (Standard Conditions Meter) or SCF (Standard Conditions Feet).

Reference : DNVGL-ST-F101 : Submarine Pipeline Systems (Download from the DNVGL website)

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CALCULATOR MODULE : DNVGL ST F101 Submarine Pipeline Fluid Velocity And Flowrate   ±

Calculate DNVGL-ST-F101 subsea pipeline fluid velocity and flowrate for two phase gas and liquid, and three phase oil, water and gas (black oil).

The two phase fluid calculator can be used for single phase gas, single phase liquid, or two phase gas and liquid. The three phase black oil calculator can be used for single phase oil, single phase water, two phase oil and water, and three phase oil, water and gas. Water cut is the volume fraction of water in the liquid phase (ignoring the gas phase). Gas oil ratio (GOR) is the ratio of gas moles to liquid volume (ignoring the water phase). Gas moles are commonly measured as gas volume at standard conditions, eg SCM (Standard Conditions Meter) or SCF (Standard Conditions Feet).

Reference : DNVGL-ST-F101 : Submarine Pipeline Systems (Download from the DNVGL website)

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CALCULATOR MODULE : API RP 1111 Pipeline Limit State Design Line Pipe Schedule   ±
CALCULATOR MODULE : API RP 1111 Pipeline Wall Thickness   ±

Calculate API RP 1111 limit state pipeline wall thickness from local pressure.

The pipe wall thickness should be calculated for the maximum pressure difference at all points on the pipeline or pipeline section. Internal pressure is calculated from reference pressure and elevation. The internal fluid density is assumed constant. External pressure should be calculated for the minimum local water depth (lowest astronomical tide and allowance for storm surge etc). API RP 1111 should only be used for line pipe with a weld joint factor = 1.0.

Note : The derated yield stress and tensile stress are used in the API RP 1111 calculations.

Reference : API RP 1111 : Design, Construction, Operation, and Maintenance of Offshore Hydrocarbon Pipelines (Limit State Design) (2011)

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CALCULATOR MODULE : API RP 1111 Pipeline Hoop Stress   ±
CALCULATOR MODULE : API RP 1111 Pipeline Test Pressure   ±
CALCULATOR MODULE : API RP 1111 Pipeline Axial Load   ±
CALCULATOR MODULE : API RP 1111 Pipeline Collapse Pressure   ±
CALCULATOR MODULE : API RP 1111 Pipeline Ovality   ±

Calculate API RP 1111 limit state pipeline out of roundness and ovality from tolerances, or from maximum and minimum diameter.

Out of roundness is equal to the maximum diameter minus the minimum diameter measured at the same cross section. Out of roundness ratio equals the out of roundness divided by either the nominal diameter or the mean diameter. DNV or ISO ovality is equal to the out of roundness ratio. API ovality is equal to half the DNV ovality (DNV or ISO ovality is equal to 2 x API ovality).

`Davg = (Dmax + Dmin) / 2 `
`OOR = (Dmax - Dmin) `
`ro = (OOR) / (Davg) `
`fa = (Dmax - Dmin) / (Dmax + Dmin) = (OOR) / (2.Davg) = (ro) / 2 `
`fd = 2.(Dmax - Dmin) / (Dmax + Dmin) = (OOR) / (Davg) = 2.fa = ro `

where :

OOR = out of roundness
ro = out of roundness ratio
Dmax = maximum diameter
Dmin = minimum diameter
Davg = average or mean diameter
fa = API ovality
fd = DNVGL or ISO ovality

Reference : API RP 1111 : Design, Construction, Operation, and Maintenance of Offshore Hydrocarbon Pipelines (Limit State Design) (2011)

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CALCULATOR MODULE : API RP 1111 Pipeline Combined Loading   ±

Calculate API RP 1111 limit state pipeline combined loading check.

For the external pressure check, the external pressure should be calcuated for the maximum water depth (highest astronomical tide plus storm surge). The internal pressure should be the maximum sustainable pressure (normally zero).

For the axial load check, the axial load can be calculated for either fully constrained pipeline, unconstrained pipeline, or user defined loads.

Reference : API RP 1111 : Design, Construction, Operation, and Maintenance of Offshore Hydrocarbon Pipelines (Limit State Design) (2011)

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CALCULATOR MODULE : API RP 1111 Pipeline Burst Pressure   ±
CALCULATOR MODULE : API RP 1111 Pipeline Temperature Derating   ±
CALCULATOR MODULE : API RP 1111 Pipeline Local Pressure   ±
CALCULATOR MODULE : API RP 1111 Pipeline Design Pressure   ±

Calculate API RP 1111 limit state pipeline maximum allowable design pressure from wall thickness and burst stress.

Burst stress is calculated from the average of the yield stress and the ultimate tensile stress. Burst pressure can be calculated from either equation 4, or equation 5. The maximum test pressure, incidental pressure and design pressure are calculated from the burst pressure. The allowable pressure is calculated so that the hoop stress equals the allowable stress. For submerged pipelines the allowable pressure equals the pressure difference (internal pressure minus external pressure).

Reference : API RP 1111 : Design, Construction, Operation, and Maintenance of Offshore Hydrocarbon Pipelines (Limit State Design) (2011)

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CALCULATOR MODULE : API RP 1111 Pipeline Mass And Weight   ±

Calculate API RP 1111 limit state pipeline unit mass (mass per length), unit weight (weight per length), and total mass.

The mass per joint can be calculated from the joint length. Construction quantities can be calculated from the total pipe length.

Pipe unit mass (mass per length) and pipe unit weight (weight per length) can be calculated for multi layer pipelines (dry empty, dry full, wet empty and wet full pipelines). The pipe diameter can be defined by either the outside diameter or the inside diameter. For multi layer pipelines, the first internal layer is the line pipe. The line pipe diameter and thickness are calculated from the pipe schedule. Change the number of layers on the setup page.

Use the Result Table option to display a table of pipe mass versus wall thickness for the selected diameter.

Reference : API RP 1111 : Design, Construction, Operation, and Maintenance of Offshore Hydrocarbon Pipelines (Limit State Design) (2011)

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CALCULATOR MODULE : API RP 1111 Pipeline Fluid Volume And Mass   ±

Calculate API RP 1111 limit state pipeline fluid volume and fluid mass for two phase gas liquid piping, and three phase black oil piping (gas water and oil).

The two phase fluid calculator can be used for single phase gas, single phase liquid, or two phase gas and liquid. The three phase black oil calculator can be used for single phase oil, single phase water, two phase oil and water, and three phase oil, water and gas. Water cut is the volume fraction of water in the liquid phase (ignoring the gas phase). Gas oil ratio (GOR) is the ratio of gas moles to liquid volume (ignoring the water phase). Gas moles are commonly measured as gas volume at standard conditions, eg SCM (Standard Conditions Meter) or SCF (Standard Conditions Feet).

Reference : API RP 1111 : Design, Construction, Operation, and Maintenance of Offshore Hydrocarbon Pipelines (Limit State Design) (2011)

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CALCULATOR MODULE : API RP 1111 Pipeline Fluid Velocity And Flow Rate   ±

Calculate API RP 1111 limit state pipeline fluid velocity and flow rate for two phase gas liquid piping, and three phase black oil piping (gas water and oil).

The two phase fluid calculator can be used for single phase gas, single phase liquid, or two phase gas and liquid. The three phase black oil calculator can be used for single phase oil, single phase water, two phase oil and water, and three phase oil, water and gas. Water cut is the volume fraction of water in the liquid phase (ignoring the gas phase). Gas oil ratio (GOR) is the ratio of gas moles to liquid volume (ignoring the water phase). Gas moles are commonly measured as gas volume at standard conditions, eg SCM (Standard Conditions Meter) or SCF (Standard Conditions Feet).

Reference : API RP 1111 : Design, Construction, Operation, and Maintenance of Offshore Hydrocarbon Pipelines (Limit State Design) (2011)

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CALCULATOR MODULE : API 5L Line Pipe Diameter Tolerance   ±

Calculate API 5L line pipe maximum and minimum diameter from nominal diameter and tolerance.

Tolerances can be calculated from API 5L, or specified as either a diameter allowance or a diameter fraction.

References :

API 5L : Specification for Line Pipe (2007)
ISO 3183 : Petroleum and Natural Gas Industries - Steel Pipe For Pipeline Transportation Systems (2007)

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CALCULATOR MODULE : API 5L Line Pipe Out Of Roundness Tolerance   ±

Calculate API 5L line pipe out of roundness and ovality from diameter and tolerance.

Out of roundness is equal to the maximum diameter minus the minimum diameter measured at the same cross section. Out of roundness ratio equals the out of roundness divided by either the nominal diameter or the mean diameter. DNV or ISO ovality is equal to the out of roundness ratio. API ovality is equal to half the DNV ovality (DNV or ISO ovality is equal to 2 x API ovality).

`Davg = (Dmax + Dmin) / 2 `
`OOR = (Dmax - Dmin) `
`ro = (OOR) / (Davg) `
`fa = (Dmax - Dmin) / (Dmax + Dmin) = (OOR) / (2.Davg) = (ro) / 2 `
`fd = 2.(Dmax - Dmin) / (Dmax + Dmin) = (OOR) / (Davg) = 2.fa = ro `

where :

OOR = out of roundness
ro = out of roundness ratio
Dmax = maximum diameter
Dmin = minimum diameter
Davg = average or mean diameter
fa = API ovality
fd = DNVGL or ISO ovality

Out of roundness can be calculated from API 5L, from user defined out of roundness, or from user defined maximum and minimum diameter. For diameter D ≥ 0.2191 m, the out of roundness can be calculated from the inside diameter. For D < 0.0603 m the out of roundness is included with the diameter tolerance. For D ≥ 1.422 m the out of roundness tolerance is to be agreed with the supplier. All tolerances should be entered as positive (+ve) values.

References :

API 5L : Specification for Line Pipe (2007)
ISO 3183 : Petroleum and Natural Gas Industries - Steel Pipe For Pipeline Transportation Systems (2007)

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CALCULATOR MODULE : API 5L Line Pipe Wall Thickness Tolerance   ±

Calculate API 5L line pipe maximum and minimum wall thickness from tolerance.

Wall thickness tolerance can be calculated from API 5L, or specified as either a wall thickness fraction, or a wall thickness allowance.

References :

API 5L : Specification for Line Pipe (2007)
ISO 3183 : Petroleum and Natural Gas Industries - Steel Pipe For Pipeline Transportation Systems (2007)

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CALCULATOR MODULE : DNVGL RP F101 Corrosion Line Pipe Schedule   ±

Calculate DNVGL-RP-F101 pipeline diameter and wall thickness schedule for corrosion.

The minimum wall thickness equals the nominal wall thickness minus the fabrication allowance. The pressure containment wall thickness equals the nominal wall thickness minus the fabrication allowance, and minus the corrosion allowance. Fabrication tolerance can be defined by either a fabrication allowance, or a fabrication fraction. The pipe diameter can be defined by either the outside diameter or the inside diameter. Use the Result Table option to display a table of pipe wall thickness versus schedule wall thickness for the selected diameter.

The pipe diameter can also be calculated from the measured circumference. Measuring the circumference is often the most convenient way to measure the pipe diameter.

Reference : DNVGL-RP-F101 : Corroded Pipelines (Download from the DNVGL website)

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CALCULATOR MODULE : DNVGL RP-F101 Single Corrosion Defect   ±

Calculate DNVGL RP F101 allowable pressure for single corrosion defects.

Allowable pressure can be calculated for pressure load only for single longitudinal defects. For circumferential defects, or defects with compressive axial load use the combined pressure and compression load calculator. For circumferential defects the defect width is greater than the defect length. The allowable pressure can be calculated using either the calibrated safety factor (CSF) in section 3, or allowable stress design (ASD) in section 4. The system effect factor accounts for the measurement uncertainty when there are multiple defects of a similar size.

Reference : DNVGL-RP-F101 : Corroded Pipelines (Download from the DNVGL website)

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CALCULATOR MODULE : DNVGL RP F101 Interacting Corrosion Defect   ±

Calculate DNVGL RP F101 allowable pressure for interacting corrosion defects with internal pressure load only.

Single defects which are closer together than the minimum defect spacing should be treated as interacting defects. The allowable pressure can be calculated using either the calibrated safety factor (CSF) in section 3, or allowable stress design (ASD) in section 4. The system effect factor accounts for the measurement uncertainty when there are multiple defects of a similar size. Use the Result Plot option to plot the dimesionless defect (1-d/t versus X/L), and the critical defect. The results for each n, m, combination are tabled at the bottom of the page.

Reference : DNVGL-RP-F101 : Corroded Pipelines (Download from the DNVGL website)

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CALCULATOR MODULE : DNVGL RP F101 Complex Corrosion Defect   ±

Calculate DNVGL RP F101 allowable pressure for complex corrosion defects with internal pressure load only.

The defect should be entered as a "river bottom" profile, with the maximum depth at each cross section. The pressure resistance can be calculated for either calibrated safety factor (CSF), or allowable stress design (ASD). The system effect factor accounts for the measurement uncertainty when there are multiple defects of a similar size. Use the Result Plot option to plot the dimesionless defect (1-d/t versus X/L), and the critical defect. The results for each depth increment are tabled at the bottom of the page.

Reference : DNVGL-RP-F101 : Corroded Pipelines (Download from the DNVGL website)

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CALCULATOR MODULE : DNVGL RP F101 Maximum Defect Depth   ±
CALCULATOR MODULE : DNVGL RP F101 Temperature Derating   ±

Calculate DNVGL RP F101 yield stress and ultimate stress temperature derating from temperature.

The derating stress is calculated in accordance with DNV OS F101 submarine pipeline systems. The derating stress is valid for temperatures less than or equal to 200 degrees C. Material tests should be performed for operating temperatures above 200 C.

Reference : DNVGL-RP-F101 : Corroded Pipelines (Download from the DNVGL website)

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CALCULATOR MODULE : DNVGL RP F101 Local Incident Pressure   ±

Calculate DNVGL RP F101 local incident pressure and local external pressure from design pressure and elevation.

The local incident pressure is calculated from the design pressure and the elevation. Fluid density is assumed constant. Use the Result Plot option to plot local pressure and reference pressure versus elevation.

Reference : DNVGL-RP-F101 : Corroded Pipelines (Download from the DNVGL website)

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CALCULATOR MODULE : DNVGL RP F101 Pipeline Longitudinal Stress   ±

Calculate DNVGL RP F101 pipeline longitudinal stress from axial stress and bending stress.

The longitudinal stress is calculated from the nominal diameter and wall thickness. The axial stress can either be calculated from the pipeline temperature and pressure, or user defined.

Reference : DNVGL-RP-F101 : Corroded Pipelines (Download from the DNVGL website)

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CALCULATOR MODULE : AS 2885.1 Pipeline Wall Thickness   ±

Calculate AS 2885.1 pipeline wall thickness from hoop stress for dry and submerged pipelines.

Pipe wall thickness is governed by the maximum internal pressure for dry pipelines, or the maximum pressure difference for wet pipeline sections. For dry pipelines, the maximum internal pressure occurs at the lowest point on the pipeline or pipeline section. For wet oil and gas pipelines with internal fluid SG less than 1, the maximum pressure difference occurs at the highest submerged elevatin (eg the water surface). The required wall thickness should be calculated for each different section based on the primary and secondary location class. For each section, a wall thickness should be selected which is greater than or equal to the required wall thickness for the whole section.

Use the Result Plot option to plot either the calculated wall thickness versus elevation, or the hoop stress versus elevation for the selected wall thickness. Wall thickness is calculated using Barlow's formula. The fabrication allowance is required for pipes where the fabrication tolerance exceeds the relevant specification (for example some seamless pipe).

Reference : Australian Standard AS 2885.1 : Pipelines - Gas And Liquid Petroleum Part 1 : Design And Construction (2015)

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CALCULATOR MODULE : AS 2885.1 Pipeline Hoop Stress   ±

Calculate AS 2885.1 pipeline hoop stress from wall thickness and internal pressure.

Hoop stress is calculated using Barlow's formula. Hoop stress can be calculated for either the nominal wall thickness, the minimum wall thickness (nominal thickness minus fabrication allowance), or the pressure design wall thickness (nominal wall thickness minus fabrication allowance and general allowance). The fabrication allowance is only required for pipes where the fabrication tolerance exceeds the relevant specification (for example some seamless pipe).

Reference : Australian Standard AS 2885.1 : Pipelines - Gas And Liquid Petroleum Part 1 : Design And Construction (2015)

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CALCULATOR MODULE : AS 2885.1 Pipeline Hydrotest Pressure   ±

Calculate AS 2885.1 pipeline test pressure and hoop stress check.

The required test pressure at the test point (the location where the test pressure is measured) is calculated from the local test pressure. The maximum test point pressure corresponds to the highest point on the pipeline. A test point pressure should be selected which is greater than or equal to the maximum calculated test point pressure, and the maximum hoop stress checked. For dry pipelines, the maximum hoop stress occurs at the lowest point on the pipeline. For wet pipeline sections, the maximum hoop stress occurs in the submerged section. Use the Result Plot option to plot the required test pressure versus elevation, or the hoop stress versus elevation for the selected test pressure. Hoop stress is calculated using Barlow's formula.

For the case where the local internal pressure is assumed to be equal to the maximum operating pressure at all points on the pipeline, use the user defined local pressure option, and set the internal pressure equal to the maximum operating pressure. This option is more onerous.

Note : A simplified check can be performed by calculating the maximum delta elevation from the maximum and minimum test pressure.

Reference : Australian Standard AS 2885.1 : Pipelines - Gas And Liquid Petroleum Part 1 : Design And Construction (2015)

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CALCULATOR MODULE : API RP 14E Platform Piping   ±
CALCULATOR MODULE : DNVGL RP O501 Erosion Rate   ±
CALCULATOR MODULE : DNVGL RP O501 Pipeline Erosion Rate   ±
CALCULATOR MODULE : DNVGL RP O501 Pipeline Bend Erosion Rate   ±
CALCULATOR MODULE : DNVGL RP O501 Pipeline Tee Erosion Rate   ±
CALCULATOR MODULE : DNVGL RP O501 Pipeline Reducer Erosion Rate   ±
CALCULATOR MODULE : DNVGL RP O501 Flexible Pipeline Erosion Rate   ±
CALCULATOR MODULE : DNVGL RP O501 Pipeline Fluid Velocity   ±

Calculate DNVGL RP O501 pipeline fluid velocity for single phase gas, single phase liquid, two phase gas liquid, or three phase black oil (gas, oil and water).

Gas oil ratio (GOR) is the ratio of gas moles over oil volume. Gas moles are commonly measured as gas volume at standard conditions (eg SCF or SCM). Water cut is measured relative to the total liquid volume (gas volume is ignored).

Liquid density can be calculated from degrees Baume, degrees Twaddell, or degrees API. For liquids lighter than or equal to water the density can be defined as degrees API, or degrees Baume (Be-). For liquids heavier than water the density can be defined by degrees Baume (Be+), or degrees Twaddell.

Gas density can be calculated from gas specific gravity, or gas molar mass. Gas molar mass is approximately equal to the molar mass of dry air times the gas specific gravity at standard conditions (for most gases the compressibility factor Z is approximately equal to 1 at standard conditions). The molar mass of dry air is taken as 28.964 kg/kg-mole. For gas mixtures, gas specific gravity is easier to measure than the molar mass.

Reference : DNVGL-RP-O501 Managing Sand Production And Erosion : formerly DNV-RP-O501 (Download from the DNVGL website)

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CALCULATOR MODULE : DNVGL RP O501 Pipeline And Sand Property   ±
CALCULATOR MODULE : DNVGL RP F115 Pipeline Pre Commissioning   ±
CALCULATOR MODULE : DNVGL RP F115 Pipeline Test Pressure   ±

Calculate DNVGL RP-F115 pipeline test pressure from design pressure and elevation.

The system test pressure is calculated from the local incidental pressure. The required system test pressure and mill test pressure should be calculated for all points on the pipeline or pipeline section. Use the Result Plot option to plot the test pressure and hoop stress from minimum to maximum elevation.

Reference : DNVGL-RP-F115 Pre-commissioning of Submarine Pipelines (Download from the DNVGL website)

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CALCULATOR MODULE : DNVGL RP F115 Pipeline Pressure Response   ±
CALCULATOR MODULE : DNVGL RP F115 Pipeline Leak Rate   ±
CALCULATOR MODULE : DNVGL RP F115 Pipeline Chemical Dose Rate   ±
CALCULATOR MODULE : DNVGL RP F115 Pipeline Temperature Correction   ±
CALCULATOR MODULE : DNVGL RP F115 Pipeline Tidal Correction   ±
CALCULATOR MODULE : DNVGL RP F115 Pipeline Local Pressure   ±

Calculate DNVGL RP-F115 pipeline local stationary internal and external pressure from elevation.

The external pressure is calculated from the water depth. The internal fluid density is assumed constant. Elevation is measured relative to any arbitrary datum (+ve above the datum -ve below the datum). Use the Result Plot option to plot pressure versus elevation.

Reference : DNVGL-RP-F115 Pre-commissioning of Submarine Pipelines (Download from the DNVGL website)

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CALCULATOR MODULE : Morison's Equation Subsea Pipeline Stability   ±

Calculate stability of on bottom structures using Morison's equation (Airy Stokes and Cnoidal waves).

For horizontal stability the horizontal wave and current loads must be less than the restraining friction force. For vertical stability the specific gravity should be greater than or equal to 1.1. Wave vertical velocity and acceleration are ignored. For some structures, depending on geometry, tipping should also be considered. Tipping does not generally occur on pipelines.

Refer also to : DNV-RP-F109 On-Bottom Stability Design Of Submarine Pipelines.

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CALCULATOR MODULE : Subsea Pipeline Submerged Weight   ±

Calculate subsea pipeline submerged weight and specific gravity.

The specific gravity is the ratio of pipe mass over the mass of the displaced fluid. Objects heavier than water have a specific gravity greater than one.

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CALCULATOR MODULE : Subsea Pipeline Seabed Embedment   ±

Calculate subsea pipeline seabed embedment or penetration depth due to self weight for a pipeline resting on sand or clay.

Penetration depth can normally be calculated for hydrotest during precommissioning (water filled). The penetration depth for rock is assumed to be zero.

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CALCULATOR MODULE : Subsea Pipeline Lay Radius   ±

Calculate subsea pipeline minimum lay radius from soil friction and lay tension.

The lay radius is limited by the lateral friction resistance at the pipeline laydown point.

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CALCULATOR MODULE : Subsea Pipeline Lay Catenary   ±

Calculate subsea pipeline lay catenary from water depth and lay tension.

The lay catenary is calculated by assuming that the pipeline has zero stiffness. This assumption is a reasonable approximation for initial estimates of lay tension.

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CALCULATOR MODULE : DNVGL RP F109 Submarine Pipeline Stability   ±

Calculate DNVGL-RP-F109 pipeline lateral and vertical stability.

Static or absolute stability can be calculated for clay seabed, sandy seabed (D50 ≤ 50 mm), or rocky seabed (D50 > 50 mm). The single oscillation velocity corresponds to the maximum wave velocity in the return period. Maximum current velocity data should be used.

Dynamic stability can be calculated on clay and sandy seabeds for Lstable (pipe displacement ≤ 0.5 OOD), L10 (pipe displacement ≤ 0.5 OOD), or user defined pipe displacement. Significant current velocity data should be used.

Seabed wave velocity is calculated from the JONSWAP surface spectrum with an Airy wave transfer function. The calculation should only be used for elevations at or near the seabed. The Airy wave transform may not be valid in shallow water.

Reference : DNVGL-RP-F109 : On-Bottom Stability Design Of Submarine Pipelines (Download from the DNVGL website)

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CALCULATOR MODULE : DNVGL RP F109 Shields Number   ±

Calculate DNVGL RP-F109 Shields number and critical velocity.

Shields number is the ratio of shear force to weight force and is used to estimate the onset of seabed movement for non cohesive soils. The critical velocity corresponds to to the onset of seabed movement.

Reference : DNVGL-RP-F109 : On-Bottom Stability Design Of Submarine Pipelines (Download from the DNVGL website)

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CALCULATOR MODULE : DNVGL RP F109 Initial Seabed Penetration   ±

Calculate DNVGL RP-F109 initial pipeline penetration due to weight on sand and clay soils.

Penetration should be calculated for the maximum pipe weight, normally the water filled weight during pre commissioning. Pipe penetration or embedment is assumed to be zero on rocky seabeds.

Reference : DNVGL-RP-F109 : On-Bottom Stability Design Of Submarine Pipelines (Download from the DNVGL website)

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CALCULATOR MODULE : DNVGL RP F109 Piping And Self Burial   ±

Calculate DNVGL RP-F109 piping and pipeline self burial in non cohesive soils.

Piping occurs with mobile, non cohesive sandy seabeds due to the flow around and underneath the pipe. Self burial is self limiting as the flow reduces with burial depth. The equilibrium burial depth is calculated. The Shields number can be used to check the onset of seabed instability. Self burial is a gradual process which occurs over a period of time. Self burial should be calculated using a sea state significantly smaller than the maximum design sea state.

Reference : DNVGL-RP-F109 : On-Bottom Stability Design Of Submarine Pipelines (Download from the DNVGL website)

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CALCULATOR MODULE : DNVGL RP F109 Curved Pipeline Laying   ±

Calculate DNVGL RP-F109 curved pipeline laying on clay and sandy seabeds.

The lay tension force is calculated to balance the lateral tension force and the passive resistance due to pipe embedment and lateral friction. Pipe embedment is assumed to be zero on rocky seabeds. The pipeline will normally be empty during laying.

Reference : DNVGL-RP-F109 : On-Bottom Stability Design Of Submarine Pipelines (Download from the DNVGL website)

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CALCULATOR MODULE : DNVGL RP F109 Wave Spreading And Directionality   ±

Calculate DNVGL RP-F109 wave spreading and directionality from relative heading and spreading factor.

The wave spreading factor accounts for the "choppiness" or multi directional properties of wave groups. Locally generated waves are generally more multi directional and should have small spreading factors. Long range swells tend to be more uni directional, and can be used with large spreading factors.

Reference : DNVGL-RP-F109 : On-Bottom Stability Design Of Submarine Pipelines (Download from the DNVGL website)

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CALCULATOR MODULE : DNVGL RP F109 Wave Seabed Velocity   ±

Calculate DNVGL RP-F109 wave seabed velocity from the JONSWAP surface spectrum.

An Airy wave transform is used to calculate the significant seabed velocity, and zero upcrossing wave period. The calculation is not valid in shallow water, or at elevations greater than half the water depth.

Reference : DNVGL-RP-F109 : On-Bottom Stability Design Of Submarine Pipelines (Download from the DNVGL website)

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CALCULATOR MODULE : DNVGL RP F109 Wave Probability And Return Period   ±

Calculate DNVGL RP-F109 wave and current amplitude from return period data.

Current velocity, wave height, and wave period can be calculated from return period data using either the Weibull, Gumbel or Frechet probability distributions. Enter data as comma or tab separated sets (eg R, Vc), with each set on a new row. Data can also be copied and pasted from a spreadsheet, or from a text document.

Reference : DNVGL-RP-F109 : On-Bottom Stability Design Of Submarine Pipelines (Download from the DNVGL website)

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CALCULATOR MODULE : DNVGL RP F109 Check Value   ±
DATA MODULE : ASME ANSI API Design Factor ( Open In Popup Workbook )   ±
DATA MODULE : DNVGL Design Factor ( Open In Popup Workbook )   ±
DATA MODULE : Soil Properties : Density Uplift Coefficient Shear Strength And Friction Factor ( Open In Popup Workbook )   ±

Soil properties, soil density, uplift coefficient, shear strength and friction factors.

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