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CALCULATOR MODULE : Pipe Beam Natural Vibration Frequency   ±

Calculate the damped and undamped pipe natural vibration frequency (simply supported, fixed, and cantilever).

For lateral vibration, the buckling load can be calculated using either the Euler equation (suitable for long beams), or the Johnson equation (suitable for short beams). The buckling load is dependent on the end type, and is used for mode 1 vibration only. Added mass should be included for submerged or wet beams. The added mass coefficient can be calculated in accordance with DNVGL RP F105. The submerged natural frequency is calculated for still water conditions, with no vortex shedding. For beams on a soft foundation such as soil, use the effective length factor to allow for movement at the beam ends. For defined beam ends such as structures, the effective length factor should be set to one. The axial load is calculated from temperature and pressure.

For longitudinal and torsional vibration, the natural frequency is independent of the cross section, and the general beam calculators can be used.

The mode factor k is dependent on the mode number, and the beam end type. The k factors have been taken from the Shock and Vibration handbook. The damping factor should be set to zero for undamped vibration or set greater than zero and less than or equal to one for damped vibration. For multi layer pipes the bending stiffness can be calculated with the concrete stiffness factor (CSF). The CSF accounts for the additional stiffness provided by the external concrete coating. The concrete stiffness factor is calculated in accordance with DNVGL RP F105. Enter the wall thickness for all layers. Only enter the elastic modulus for layers which affect the pipe stiffness.

Use the Result Table and Result Plot options to display tables and plots. Refer to the figures and 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 : Beam Cross Section   ±

Calculate beam cross section properties for circular pipes: cross section area, moment of inertia, polar moment of inertia, mass moment of inertia, section modulus, EI, EA, EAα, unit mass, total mass, unit weight and specific gravity.

Unit mass can be calculated with or without added mass. 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. For multi layer pipes the bending stifness can be calculated with the concrete stiffness factor (CSF). The CSF accounts for the additional stiffness provided by the external concrete coating. Use the Result Table option to display the cross section properties versus wall thickness. Refer to the help pages for more details.

Reference : Roark's Formulas For Stress And Strain, Warren C Young, McGraw Hill

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CALCULATOR MODULE : Beam Cross Section Parallel Axis Theorem   ±

Calculate beam moment of inertia using the parallel axis theorem.

The moment of inertia about an offset can be calculated by

`Ix = Il + Y AX^2 `
`Iy = Im + X AX^2 ::Hxy = Hlm + X Y AX^2 `

where :

Ix = moment of inertia about X axis
Iy = moment of inertia about Y axis
Il = moment of inertia about L axis
Im = moment of inertia about M axis
Hxy = product of inertia about offset
Hlm = product of inertia about the centroid
X = offset length from Y axis to centroid
Y = offset length from X axis to centroid
AX = cross section area

X and Y are perpendicular axes passing through the offset. L and M are perpendicular axes passing through the centroid and parallel to X and Y. The X and Y axes pass through the offset point.

For principal axes the product of inertia equals zero. Axes which are an axis of symmetry are principal axes. If the moment of inertia for a principal axis is equal to the moment of inertia of any other axis, all moments of inertia through that point are equal.

For rotated axes, the rotation is calculated relative to either the X axis or the L axis (anti clockwise is positive). Use the Result Plot option to plot the rotated moments of inertia and product of inertia versus the rotation angle.

Reference : Roark's Formulas For Stress And Strain, Warren C Young, McGraw Hill

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CALCULATOR MODULE : Line Pipe Cross Section   ±

Calculate pipe internal and external diameter, cross section area and EI from pipe schedule diameter and wall thickness.

Use the Result Table option to display the results for the selected pipe diameter. For multi layer pipes (line pipe with outside layers and or inside layers), the results for each layer are displayed in the output view at the bottom of the page. Change the number of layers on the setup page.

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CALCULATOR MODULE : Line Pipe EA And EI   ±
CALCULATOR MODULE : Plastic Pipe Cross Section   ±

Calculate plastic pipe diameter, wall thickness, tolerances, dimension ratio, unit mass (mass per length), and total mass from pipe schedule diameter and wall thickness or dimension ratio.

Use the Result Table option to display the results for the selected pipe diameter. The dimension ratio is based on the Renard R10 series. The standard dimension ratio SDR equals R10 + 1 and is calculated from the outside diameter divided by the pressure design wall thickness. The standard internal dimension ratio SIDR equals R10 - 1 and is calculated from the inside diameter divided by the pressure design wall thickness.

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CALCULATOR MODULE : Line Pipe Section Modulus   ±

Calculate pipeline EI and section modulus.

The section modulus is equal to the moment of inertia divided by the length from the centroid to the outer fibre (the outside radius).

`Zs = I / Y `

where :

Zs = Section Modulus
I = Moment Of Inertia Or Second Area Moment
Y = Length To Outer Fiber

The section modulus can be used to calculate the maximum bending stress from the bending moment

`SB = (BM) / (Zs) `

where :

SB = Bending Stress
BM = Bending Moment

For a pipe the the outer fiber length Y = the pipe radius. For combined stress calculations, the pipe mid wall radius can be used as the outer fiber length. This is based on the non linear stress distribution through the pipe wall. A mid wall approximation from DNVGL is also included.

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CALCULATOR MODULE : Line Pipe Concrete Stiffness Factor   ±

Calculate pipe concrete stiffness factor and effective EI from the concrete beam EI ratio.

The concrete stiffness factor is used to account for the effect of the concrete layer on the pipe EI. The concrete stiffness factor is calculated from the ratio of concrete EI over pipe EI in accordance with DNVGL RP F105. The effective EI can be calculated for asphalt coating, PE/PP coating, user defined coating factor Kc, user defined concrete stiffness factor CSF, or from the sum of the internal and external EI.

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

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CALCULATOR MODULE : Line Pipe Diameter Wall Thickness And Mass Schedule   ±
CALCULATOR MODULE : ASME B31.3 Process Piping Wall Thickness   ±

Calculate ASME B31.3 process piping wall thickness from temperature for low pressure steel pipe (Table A-1), high pressure steel pipe (Table K-1), and plastic piping.

Allowable stress for steel pipe is calculated from Table A-1 and Table K-1 US values (US units govern). Change units on the setup page. Stress values can be extrapolated for temperatures above the data range (care is required when using extrapolated values). The wall thickness calculations are valid for internal overpressure only. For combined internal and external pressure use the pressure difference in the calculations.

Use the Data Plot option to plot the allowable stress versus temperature for the selected material. Use the Data Table option to display the data table in the popup window (Table A-1, or Table K-1). Use the Result Table option to display a table of wall thickness and allowable pressure versus material type (for the calculate wall thickness option the allowable pressure equals the design pressure. for the specified wall thickness option the wall thickness equals the specified wall thickness). Refer to the help pages for notes on the data tables. Change units on the setup page. Use the workbook ASME B31.3 data tables to look up allowable stress data.

Note : The choice of high pressure versus low pressure service is at the discretion of the owner (section FK300). The ASME B16.5 Class 2500 pressure temperature rating for the material group is often used as a criteria.

Reference : ANSI/ASME B31.3 : Process Piping (2018)

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CALCULATOR MODULE : ASME B31.3 Process Piping Hoop Stress   ±

Calculate ASME B31.3 process piping hoop stress for low pressure steel pipe (Table A-1), high pressure steel pipe (Table K-1), and plastic piping.

The hoop stress can be calculated for either the minimum wall thickness (nominal wall thickness minus fabrication allowance), or the pressure design wall thickness (minimum wall thickness minus the corrosion allowance). For operation the hoop stress should be ≤ the design stress. For pressure tests, the hoop stress should be ≤ 100% of yield stress for hydrotest, or ≤ 90% of yield stress for pneumatic tests. For combined internal and external pressure use the pressure difference in the calculations. Use the workbook ASME B31.3 data tables to look up allowable stress data.

Note : The choice of high pressure versus low pressure service is at the discretion of the owner (section FK300). The ASME B16.5 Class 2500 pressure temperature rating for the material group is often used as a criteria.

Reference : ANSI/ASME B31.3 : Process Piping (2018)

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CALCULATOR MODULE : ASME B31.3 Process Piping Hydrotest Pressure   ±

Calculate ASME B31.3 process piping hydrotest and pneumatic leak test pressure and hoop stress check. The test pressure should be 1.5 times the design pressure for hydrotest, or 1.1 times the design pressure for pneumatic test. An allowance should be made for the pipe design temperature.

Hoop stress can be calculated for either the minimum wall thickness (nominal wall thickness minus fabrication allowance), or the pressure design wall thickness (minimum wall thickness minus the corrosion allowance). Minimum wall thickness is recommended for new piping, or piping in as new condition. The pressure design wall thickness is recommended for corroded piping. The hoop stress should be ≤ 100% of yield for hydrotest, or ≤ 90% of yield for pneumatic tests. The test pressure should be ≤ 1.5 x the pressure rating for pressure rated components.

For piping systems with combined internal and external pressure during operation, the test pressure should be calculated from the internal pressure only. The hoop stress should be calculated from the pressure difference during testing. Use the workbook ASME B31.3 data tables to look up allowable stress data.

Note : The choice of high pressure versus low pressure service is at the discretion of the owner (section FK300). The ASME B16.5 Class 2500 pressure temperature rating for the material group is often used as a criteria.

Reference : ANSI/ASME B31.3 : Process Piping (2018)

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CALCULATOR MODULE : ASME B31.3 Process Piping Branch Reinforcement   ±

Calculate ASME B31.3 process piping required branch reinforcement for welded and extruded branches.

The calculations are valid for right angle welded branches, angled welded branches ≥ 45 degrees, and right anngle extruded branches. Extruded branches must be used for high pressure piping. Use the workbook ASME B31.3 data tables to look up allowable stress data.

Reference : ANSI/ASME B31.3 : Process Piping (2018)

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CALCULATOR MODULE : ASME B31.3 Process Piping Design Factor   ±

Calculate ASME B31.3 process piping design factors (Y factor and W factor).

The Y factor is calculated from diameter for thick wall pipe (D/t < 6), or from temperature for thin wall pipe. The weld factor (W) is only relevant for design temperatures in the creep range. For design temperatures below the creep onset temperature W = 1. The weld factor does not apply for seamless pipe (W = 1).

Reference : ANSI/ASME B31.3 : Process Piping (2018)

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CALCULATOR MODULE : ASME B31.3 Process Piping Blank Flange   ±
CALCULATOR MODULE : ASME B31.3 Process Piping Bend   ±

Calculate ASME B31.3 process piping minimum thickness for formed bends, and allowable pressure for miter bends.

Minimum thickness of formed bends is calculated for the inside radius, the oputside radius, and the centerline radius. Bend thinning on the outside radius is estimated using the method from ASME B31.1. The estimated minimum bend thickness after thinning should be ≥ the required minimum bend thickness on the outside radius (extrados). Use the goal seek option to calculate the required straight pipe nominal wall thickness (before bending), for the minimum thickness on the outside radius (after bending).

The allowable pressure for miter bends is calculated from the nominal wall thickness. Use the goal seek option to calculate the required miter bend nominal wall thickness for the design pressure. Use the workbook ASME B31.3 data tables to look up allowable stress data.

Reference : ANSI/ASME B31.3 : Process Piping (2018)

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CALCULATOR MODULE : ASME B31.3 Process Piping Minimum Temperature For Impact Testing   ±

Calculate ASME B31.3 process piping minimum temperature for impact testing from wall thickness and material type.

For carbon steel materials with a minimum temperature letter designation, the minimum temperature for testing can be calculated according to table 323.2.2A (curves A, B, C and D).

If the maximum stress is less than the design stress, the impact testing temperature can be reduced according to figure 323.2.2B using the stress ratio. The stress ratio is the maximum of hoop stress over design stress, combined stress over design stress, or operating pressure over pressure rating for pressure rated components. The reduction in impact testing temperature from stress ratio is valid for minimum temperatures listed in table A-1, and for minimum temnperatures calculated from a letter designation (curves A, B, C or D). Use the workbook ASME B31.3 data tables to look up minimum temperature and letter designation data.

Reference : ANSI/ASME B31.3 : Process Piping (2018)

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CALCULATOR MODULE : ASME B31.3 Process Piping Design Pressure   ±

Calculate ASME B31.3 process piping design pressure for low pressure steel pipe (Table A-1), high pressure steel pipe (Table K-1), and plastic piping.

The design pressure is calculated from the pipe diameter, wall thickness, wall thickness tolerance and allowable stress (Table A-1 and Table K-1 US values : US units govern). The hoop stress is equal to the design stress at the design pressure. Change units on the setup page. Stress values can be extrapolated for temperatures above the data range (care is required when using extrapolated values). For combined internal and external pressure, the design pressure equals the pressure difference.

Use the Result Table option to display a table of design pressure versus wall thickness or design pressure versus material type. Use the Data Plot option to plot the design stress versus temperature for the selected material. Use the Data Table option to display the data table in the popup window (Table A-1, or Table K-1). Refer to the help pages for notes on the data tables (click the resources button on the data bar). Use the workbook ASME B31.3 data tables to look up allowable stress data.

Note : The choice of high pressure versus low pressure service is at the discretion of the owner (section FK300). The ASME B16.5 Class 2500 pressure temperature rating for the material group is often used as a criteria.

Reference : ANSI/ASME B31.3 : Process Piping (2018)

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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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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 Ripple Defect   ±
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 B31.8 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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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 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 B31G Pipe Corrosion Defect   ±

Calculate ASME B31G piping level 0 corrosion defect assessment for blunt defects (corrosion defects or other defects).

The level 0 assessment is useful as a screening check. The allowable defect length is calculated from the maximum defect depth. The calculation is taken from ASME B31G 1999 (original ASME B31G). The level 0 check is suitable for blunt defects of all types, including corrosion, mechanical damage and grinding repairs etc. For crack type defects the NG-18 crack defect calculators are recommended. The RSTRENG method (effective area method) can also be used for blunt type defects. The temperature derating calculation is from ASME B31.8. Material specific test data should be used if it is available.

Defects failing the level 0 check should be checked with a level 1 or level 2 assessment (see module links below). Use the level 1 assessment for simple defects from defect length and depth using either the original ASME B31G equation, or the modified ASME B31G equation. Use the level 2 assessment for complex defects from the defect river bottom profile.

Reference : ANSI/ASME B31G Manual For Determining The Remaining Strength Of Corroded Pipelines (2012)

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CALCULATOR MODULE : ASME B31G Level 1 Defect Assessment   ±

Calculate ASME B31G level 1 corrosion defect assessment for blunt type defects.

The level 1 assessment calculates the allowable pressure from the maximum defect depth and defect length, using either the original ASME B31G method (1999), or the modified ASME B31G method. Pressure derating is required if the allowable pressure is less than the maximum operating pressure.

The flow stress can be calculated as either 1.1 x SMYS, SMYS + 69 MPa, or 1/2 (SMYS + SMTS). For pipelines operating at high temperature, the SMYS and SMTS should be derated.

For submerged pipelines, or to calculate the allowable pressure at a reference elevation, use the level 1 calculator including elevation. The allowable local pressure is calculated including external pressure (use the external pressure = 0 for dry pipelines). The allowable reference pressure is calculated from the local allowable pressure, and the relative elevation.

ASME B31G is suitable for blunt defects of all types, including corrosion, mechanical damage and grinding repairs etc. For crack type defects the NG-18 crack defect calculators are recommended. The effective area method can also be used for blunt defects.

Reference : ANSI/ASME B31G Manual For Determining The Remaining Strength Of Corroded Pipelines (2012)

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CALCULATOR MODULE : ASME B31G Level 2 Defect Assessment   ±

Calculate ASME B31G level 2 corrosion defect assessment for blunt type defects.

The level 2 assessment calculates the allowable pressure from the defect "river bottom" profile using the effective area method (also known as the RSTRENG method). Pressure derating is required if the allowable pressure is less than the maximum operating pressure.

The flow stress can be calculated as either 1.1 x SMYS, SMYS + 69 MPa, or 1/2 (SMYS + SMTS). For pipelines operating at high temperature, the SMYS and SMTS should be derated.

For submerged pipelines, or to calculate the allowable pressure at a reference elevation, use the level 1 and level 2 calculators including elevation. The allowable local pressure is calculated including external pressure (use the external pressure = 0 for dry pipelines). The allowable reference pressure is calculated from the local allowable pressure, and the relative elevation.

ASME B31G is suitable for blunt defects of all types, including corrosion, mechanical damage and grinding repairs etc. For crack type defects the NG-18 crack defect calculators are recommended. The effective area method can also be used for blunt defects.

Reference : ANSI/ASME B31G Manual For Determining The Remaining Strength Of Corroded Pipelines (2012)

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CALCULATOR MODULE : ASME B31G Flow Stress   ±

Calculate ASME B31G flow stress from SMYS and SMTS.

Flow stress can be calculated by three methods

  • Sf = 1.1 x SMYS (Plain Carbon Steel T < 120 C and Sf < SMTS)
  • Sf = SMYS + 69 MPA (SMYS ≤ 483 MPa, T < 120 C and Sf < SMTS)
  • Sf = (SYT + SUT) / 2 (SMYS ≤ 551 MPa)

SYT and SUT are the temperature derated yield stress and tensile stress for temperatures above 120 C. The derating factors are valid up to 232 C (450 F). Material specific test data should be used if it is available.

Reference : ANSI/ASME B31G Manual For Determining The Remaining Strength Of Corroded Pipelines (2012)

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CALCULATOR MODULE : ASME B31.1 Power Piping Wall Thickness   ±

Calculate ASME B31.1 power piping wall thickness from the design temperature.

Wall thickness can be calculated from either the outside diameter (constant OD), or the inside diameter (constant ID).

The allowable stress (SE) is calculated from tables A-1 to A-9. For temperatures above the data range, select either constant value, constant slope, or zero value (engineering judgement is required). The weld factor W is relevant for temperatures in the creep range. For temperatures below the creep onset temperature W = 1. The ASME Y factor can either be calculated, or user defined. For thick wall pipe (D/tm < 6) Y is calculated from the diameter. For thin wall pipe Y is calculated from the temperature. For combined internal and external pressure use the pressure difference in the calculations.

Use the data plot option to plot the allowable stress versus temperature for the selected material. Use the Data Table option to display the data table in the popup window. Use the Result Table option to display a table of wall thickness and allowable pressure versus material type (for the calculate wall thickness option the allowable pressure equals the design pressure. for the specified wall thickness option the wall thickness is constant). The calculations use SI standard units. Change input and output units on the setup page. Refer to the help pages for notes on the data tables (click the resources button on the data bar). Use the workbook ASME B31.1 data tables to look up allowable stress data.

Reference : ANSI/ASME B31.1 : Power Piping (2014)

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CALCULATOR MODULE : ASME B31.1 Power Piping Hoop Stress   ±

Calculate ASME B31.1 power piping hoop stress for metal and plastic piping.

Hoop stress can be calculated for either the minimum wall thickness (nominal wall thickness minus fabrication allowance), or the pressure design wall thickness (minimum wall thickness minus the corrosion allowance). The minimum wall thickness can be used for new pipe, or pipe in good condition. The pressure design wall thickness should be used for corroded pipe. The pipe diameter can be defined from either the outside diameter, or the inside diameter. For combined internal and external pressure use the pressure difference in the calculations. Use the workbook ASME B31.1 data tables to look up allowable stress data.

Reference : ANSI/ASME B31.1 : Power Piping (2014)

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CALCULATOR MODULE : ASME B31.1 Power Piping Hydrotest Pressure   ±

Calculate ASME B31.1 power piping hydrotest pressure and pneumatic leak test pressure for steel pipe and plastic piping.

The test pressure should be ≥ 1.5 times the design pressure for hydrotest, and ≥ 1.2 times the design pressure for pneumatic tests. The hoop stress during testing should be ≤ 90% of the yield stress. Hoop stress can be calculated for either the minimum wall thickness (nominal wall thickness minus fabrication allowance), or the pressure design wall thickness (minimum wall thickness minus the corrosion allowance).

For piping systems with combined internal and external pressure the test pressure should be calculated from the internal pressure. The hoop stress is calculated from the pressure difference during testing. Use the workbook ASME B31.1 data tables to look up allowable stress data.

Reference : ANSI/ASME B31.1 : Power Piping (2014)

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CALCULATOR MODULE : ASME B31.1 Power Piping Branch Reinforcement   ±

Calculate ASME B31.1 power piping branch reinforcement for welded and extruded branches. Refer to the figures for details (click the resources button on the data bar)

For welded branches the branch angle must be ≥ 45 degrees. The pad reinforcement area also includes any welds or saddles which are inside the reinforcement zone. The extruded branch calculation is valid for right angle branches only. Use the workbook ASME B31.1 data tables to look up allowable stress data.

Reference : ANSI/ASME B31.1 : Power Piping (2014)

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CALCULATOR MODULE : ASME B31.1 Power Piping Design Factor   ±

Calculate ASME B31.1 power piping design factors (Weld factor W, Y factor and thinning allowance B).

The Y factor is calculated from diameter for thick wall pipe (D/t < 6), or from temperature for thin wall pipe. The weld factor (W) is only relevant for design temperatures in the creep range. For design temperatures below the creep onset temperature W = 1. The weld factor does not apply for seamless pipe (W = 1). The thinning allowance (B) is an approximate estimate of the thinning on the outside radius due to bending (ASME B31.3 table 102.4.5). A power law curve has been fitted to the data values in the table. Use the workbook ASME B31.1 data tables to look up allowable stress data.

Reference : ANSI/ASME B31.1 : Power Piping (2014)

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CALCULATOR MODULE : ASME B31.1 Power Piping Blank Flange   ±
CALCULATOR MODULE : ASME B31.1 Power Piping Bend   ±
CALCULATOR MODULE : ASME B31.1 Power Piping Design Pressure   ±

Calculate ASME B31.1 power piping design pressure from the design temperature.

The design stress (SE) is calculated from tables A-1 to A-9. For temperatures above the data range, select either constant value, constant slope, or zero value (engineering judgement is required). The weld factor W is relevant for temperatures in the creep range. For temperatures below the creep onset temperature W = 1. The ASME Y factor can either be calculated, or user defined. For thick wall pipe (D/tm < 6) Y is calculated from the diameter. For thin wall pipe Y is calculated from the temperature. For combined internal and external pressure use the pressure difference in the calculations.

Use the table data option for a table of allowable pressure versus wall thickness for the selected pipe schedule and diameter. Use the data plot option to plot the allowable stress versus temperature for the selected material. Use the Data Table option to display the data table in the popup window. Use the Result Table option to display a table of allowable pressure versus material type, or allowable pressure versus wall thickness. The calculations use SI standard units. Change input and output units on the setup page. Refer to the help pages for notes on the data tables (click the resources button on the data bar). Use the workbook ASME B31.1 data tables to look up allowable stress data.

Reference : ANSI/ASME B31.1 : Power Piping (2014)

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CALCULATOR MODULE : ASME B31.5 Refrigeration Piping Wall Thickness   ±

Calculate ASME B31.5 refrigeration piping wall thickness from internal pressure and design temperature .

Allowable stress is calculated from temperature using Table 502.3.1 (US values). Change units on the setup page. Stress values can be extrapolated for temperatures above the data range (care is required when using extrapolated values). The wall thickness calculations are valid for internal overpressure only. For combined internal and external pressure use the pressure difference in the calculations.

Use the data plot option to plot the allowable stress versus temperature for the selected material. Use the Data Table option to display the data table in the popup window. Use the Result Table option to display a table of wall thickness and allowable pressure versus material type (for the calculate wall thickness option the allowable pressure equals the design pressure. For the specified wall thickness option the wall thickness is constant). Use the workbook ASME B31.5 data tables to look up allowable stress data.

Reference : ANSI/ASME B31.5 : Refrigeration Piping And Heat Transfer Components (2013)

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CALCULATOR MODULE : ASME B31.5 Refrigeration Piping Hoop Stress   ±

Calculate ASME B31.5 refrigeration piping hoop stress from internal pressure. Use the allowable stress calculators to calculate the allowable stress from the design temperature.

The hoop stress can be calculated for either the minimum wall thickness (nominal wall thickness minus fabrication allowance), or the pressure design wall thickness (minimum wall thickness minus the corrosion allowance). For operation the hoop stress should be ≤ the design stress. For pressure tests, the hoop stress should be ≤ 100% of yield stress for hydrotest, or ≤ 90% of yield strss for pneumatic tests. For combined internal and external pressure use the pressure difference in the calculations. Use the workbook ASME B31.5 data tables to look up allowable stress data.

Reference : ANSI/ASME B31.5 : Refrigeration Piping And Heat Transfer Components (2013)

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CALCULATOR MODULE : ASME B31.5 Refrigeration Piping Hydrotest Pressure   ±

Calculate ASME B31.5 refrigeration piping hydrotest and pneumatic leak test pressure and hoop stress check. Use the allowable stress calculators to calculate the yield stress from the design temperature.

The test pressure should be 1.5 times the design pressure for hydrotest, or 1.1 times the design pressure for pneumatic test. Hydrotest should be used for secondary cooling piping only. Hydrotest should not be used for refrigeration piping.

Hoop stress can be calculated for either the minimum wall thickness (nominal wall thickness minus fabrication allowance), or the pressure design wall thickness (minimum wall thickness minus the corrosion allowance). Minimum wall thickness is recommended for new piping, or piping in as new condition. The pressure design wall thickness is recommended for corroded piping. The hoop stress should be ≤ 90% of yield for hydrotest or pneumatic tests.

For piping systems with combined internal and external pressure during operation, the test pressure should be calculated from the internal pressure only. The hoop stress should be calculated separately from the pressure difference during testing (use the hoop stress calculator). Use the workbook ASME B31.5 data tables to look up allowable stress data.

Reference : ANSI/ASME B31.5 : Refrigeration Piping And Heat Transfer Components (2013)

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CALCULATOR MODULE : ASME B31.5 Refrigeration Piping Minimum Temperature For Impact Testing   ±

Calculate ASME B31.5 refrigeration piping minimum temperature for impact testing from wall thickness and material type.

For carbon steel materials with a minimum temperature letter designation, the minimum temperature for testing can be calculated according to table 523.2.2 (curves A, B and C).

If the maximum stress is less than the design stress, the impact testing temperature can be reduced according to figure 523.2.2 using the stress ratio (the ratio of design tensile streess over allowable stress). Use the hoop stress calculator to calculate the hoop tensile stress. Use the flexibility calculators to calculate longitudinal tensile stress. Use the workbook ASME B31.5 data tables to look up minimum temperature and letter designation data.

Reference : ANSI/ASME B31.5 : Refrigeration Piping And Heat Transfer Components (2013)

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CALCULATOR MODULE : ASME B31.5 Refrigeration Piping Branch Reinforcement   ±

Calculate ASME B31.5 refrigeration piping required branch reinforcement for welded and extruded branches.

The calculations are valid for right angle welded branches, angled welded branches ≥ 45 degrees, and right anngle extruded branches.

Use the pipe wall thickness calculators to calculate design stress, minimum thickness and Y factor for the header pipe and branch pipe (use the user defined wall thickness option). Use the allowable stress calculators to calculate the design stress for the reinforcement pad. Use the workbook ASME B31.5 data tables to look up allowable stress data.

Reference : ANSI/ASME B31.5 : Refrigeration Piping And Heat Transfer Components (2013)

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Related Modules :

CALCULATOR MODULE : ASME B31.5 Refrigeration Piping Design Factor   ±
CALCULATOR MODULE : ASME B31.5 Refrigeration Piping Blank Flange And Closure   ±
CALCULATOR MODULE : ASME B31.5 Refrigeration Piping Design Pressure   ±

Calculate ASME B31.5 refrigeration piping maximum allowable design pressure from wall thickness and design temperature .

Allowable stress is calculated from temperature using Table 502.3.1 (US values). Change units on the setup page. Stress values can be extrapolated for temperatures above the data range (care is required when using extrapolated values). For combined internal and external pressure the allowable pressure is equal to the maximum allowable pressure difference.

Use the data plot option to plot the allowable stress versus temperature for the selected material. Use the Data Table option to display the relevant data table. Use the Result Table option to display a table of allowable pressure versus wall thickness for the selected pipe schedule.

Reference : ANSI/ASME B31.5 : Refrigeration Piping And Heat Transfer Components (2013)

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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 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 : Hot Pipeline Mass And Weight   ±

Calculate high temperature 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.

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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 Collapse Pressure   ±
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 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 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 Carbon Equivalent   ±

Calculate API 5L line pipe carbon equivalent from material composition. Carbon equivalent is an indicator of material weldability, and fracture toughness.

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 : API 5L Line Pipe Mass Tolerance   ±

Calculate API 5L line pipe unit mass (mass per length) and total mass from diameter, wall thickness and density.

Pipe mass can be calculated with API 5l tolerances, or as mass schedule with no tolerances. Tolerances can be calculated from API 5L, or specified as either a mass allowance or a mass fraction. To calculate mass per joint, enter the joint length as the pipe length. For construction quantities, enter the total pipe length as the pipe length. The API 5L negative tolerance is reduced if the total mass is greater than 18 tonne.

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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Related Modules :

CALCULATOR MODULE : ASME B31.1 Power Piping Flexibility And Stress Factor   ±
CALCULATOR MODULE : ASME B31.3 Process Piping Flexibility And Stress Factor   ±
CALCULATOR MODULE : ASME B31.4 Liquid Pipeline Flexibility And Stress Factor   ±
CALCULATOR MODULE : ASME B31.5 Refrigeration Piping Flexibility And Stress Factor   ±
CALCULATOR MODULE : ASME B31.8 Gas Pipeline Flexibility And Stress Factor   ±
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 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 : AS 2885.1 Pipeline Allowable Stress   ±

Calculate AS 2885.1 pipeline yield stress and allowable stress.

Select the appropriate stress table (API, ASM, DNV etc), material, and design factor. 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). The pressure design thickness equals the nominal wall thickness minus the corrosion allowance. The fabrication allowance is only required for pipes where the fabrication tolerance exceeds the relevant specification (for example some grades of 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 Bend Thickness   ±

Calculate AS 2885.1 pipeline bend minimum fabrication thickness.

Bend thickness checks are not required for cold field bends from straight pipe (ripples should be considered). For bends formed by other means such as induction bending, the fabricated thickness should be checked on both the inside of the bend (intrados), and the outside of the bend (extrados).

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 Branch Reinforcement   ±

Calculate AS 2885.1 pipeline welded branch reinforcement using the replacement area method.

Branch reinforcement can be provided by pipe excess thickness, and by welded pad reinforcement. The reinforcement must be inside the reinforcement zone. Pad reinforcement can include additional equivalent width to account for welds, provided that the equivalent width is inside the reinforcement zone. The header, branch and reinforcement material should have similar properties. The reinforcement areas are factored if the branch or pad reinforcement allowable stress is less than the header allowable stress.

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 Design Pressure   ±

Calculate AS 2885.1 pipeline maximum allowable design pressure from pressure design wall thickness and allowable stress.

The maximum allowable design pressure is calculated so that the hoop stress equals the allowable stress. Use the Result Table option to table the allowable pressure versus wall thickness for the selected pipe diameter schedule.

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 Collapse Pressure   ±
CALCULATOR MODULE : AS 2885.1 Pipeline Fracture Toughness   ±

Calculate AS 2885.1 pipeline critical defect length and fracture toughness.

The critical defect length is calculated from the flow stress and the maximum hoop stress using the Folias factor Mt. The initiation crack length is assumed to be equal to 0.8 - 0.9 of the critical defect length. The required initiation fracture toughness can then be calculated from the initiation defect length. The required CVN is then calculated from the fracture toughness.

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 Maximum Erosional Velocity   ±

Calculate API RP 14E maximum allowable erosional velocity for platform piping systems.

The fluid density can be calculated for single phase gas, single phase liquid, two phase gas liquid, or three phase black oil (gas oil and water). The erosional velocity is calculated from the fluid density and the C Factor. Equation 2.14 in API RP 14E uses FPS units. The API RP 14E calculators have been factored to use SI units.

For fluids with no entrained solids a maximum C value of 100 for continuous service, or 125 for intermittent service can be used. For fluids treated with corrosion inhibitor, or for corrosion resistant materials a maximum C value of 150 to 200 may be used for continuous service, and upto 250 for intermittent service. For fluids with solids, the C value should be significantly reduced.

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 the volume ratio of water in liquid (oil and water).

Reference : API 14E Recommended Practice For Design and Installation of Offshore Production Platform Piping Systems

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Related Modules :

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 And Sand Property   ±
CALCULATOR MODULE : API 520 Gas Pressure Relief Valve   ±

Calculate API 520 gas pressure relief valve (PRV) and rupture disk size.

The flow through the relief valve nozzle is assumed to be sonic (M = 1), adiabatic, and isentropic. If the back pressure is greater than the critical (sonic) pressure the flow is subsonic (M < 1).

Friction losses are accounted for using the discharge coefficient Kd. For initial sizing of PRV's the effective nozzle diameter should be used with the discharge coefficient Kd = 0.975. The actual nozzle diameter and the rated coefficient of discharge should be used to verify that the selected PRV is suitable for the required flow rate. The PRV effective diameter is taken from API 526 (letter designation D to T). Changes in phase are not accounted for.

The calculation can also be used for rupture disks. The rupture disk diameter should be substituted for the nozzle diameter, with a discharge coefficient Kd = 0.62. Rupture disks can also be analysed as part of a relief vent system using the flow resistance method.

Note : The ideal gas calculators use the ideal gas compressible flow equations. The API 520 gas and steam calculations use an approximation of the ideal gas compressible flow equations. Use the ideal gas calculators for a comparison with the API 520 calculators.

Reference : API 520 Sizing, Selection And Installation Of Pressure Relieving Devices (2014)

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Related Modules :

CALCULATOR MODULE : API 520 Steam Pressure Relief Valve   ±

Calculate API 520 steam pressure relief valve (PRV) and rupture disk size.

The flow through the relief valve nozzle is analysed using the Napier equation. For temperatures above 1200 F (922 K), the gas PRV calculation should be used. If the back pressure is greater than the critical (sonic) pressure the flow is sub sonic (M < 1).

Friction losses are accounted for using the discharge coefficient Kd. For initial sizing of PRV's the effective nozzle diameter should be used with the discharge coefficient Kd = 0.975. The actual nozzle diameter and rated coefficient of discharge should be used to verify that the selected PRV is suitable for the required flow rate. The PRV effective diameter is taken from API 526 (letter designation D to T). Changes in phase are not accounted for.

The calculation can also be used for rupture disks. The rupture disk diameter should be substituted for the nozzle diameter, with a discharge coefficient Kd = 0.62. Rupture disks can also be analysed as part of a relief vent system using the flow resistance method.

Note : The ideal gas calculators use the ideal gas compressible flow equations. The API 520 gas and steam calculations use an approximation of the ideal gas compressible flow equations. Use the ideal gas calculators for a comparison with the API 520 calculators.

Reference : API 520 Sizing, Selection And Installation Of Pressure Relieving Devices (2014)

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Related Modules :

CALCULATOR MODULE : API 520 Liquid Pressure Relief Valve   ±

Calculate API 520 liquid pressure relief valve (PRV) and rupture disk size (certified and non certifed devices).

The flow through the relief valve nozzle is analysed using the Bernoulli equation. Friction losses are accounted for using the discharge coefficient Kd. For initial sizing of PRV's the effective nozzle diameter should be used with the discharge coefficient Kd = 0.65 for certified PRV's and Kd = 0.62 for non certified PRV's. The actual nozzle diameter and rated coefficient of discharge should be used to verify that the selected PRV is suitable for the required flow rate. The PRV effective diameter is taken from API 526 (letter designation D to T). Changes in phase are not accounted for.

The PRV calculation can also be used for rupture disks. The rupture disk diameter should be substituted for the nozzle diameter, with a discharge coefficient Kd = 0.62. Rupture disks can also be analysed as part of a relief vent system using the flow resistance method.

Reference : API 520 Sizing, Selection And Installation Of Pressure Relieving Devices (2014)

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Related Modules :

CALCULATOR MODULE : API 520 Correction Factor   ±
CALCULATOR MODULE : API 520 Pressure Relief Vent   ±

Calculate API 520 flow rate through a constant diameter pressure relief vent.

The vent entry is assumed to be a pressure vessel or piping at stagnation pressure (valid when the pipe or vessel diameter is much greater than the vent diameter). The calculated vent exit pressure is flowing pressure (stagnation pressure minus dynamic pressure).

Vent pressure losses are calculated from the vent pressure loss factor (fld = fL/D + K). Minor losses should include the vent entry, valves and bends etc. The vent exit should not be included. The discharge coefficient can be used to factor the flow rate, depending on the design requirements.

For rupture disks, the flow resistance factor of the rupture Kr should be included in the minor losses (the resistance factor should be factored for the vent diameter). A discharge coefficient of 0.9 or less should be used for rupture disks. Alternatively, the PRV calculators can be used for rupture disk calculations.

Note : The ideal gas calculators use the ideal gas compressible flow equations. The API 520 gas and steam calculations use an approximation of the ideal gas compressible flow equations. Use the ideal gas calculators for a comparison with the API 520 calculators.

Reference : API 520 Sizing, Selection And Installation Of Pressure Relieving Devices (2014)

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Related Modules :

CALCULATOR MODULE : API 520 Back Pressure   ±

Calculate API 520 back pressure from mass flow rate through a constant diameter vent.

The calculated vent entry and exit pressures are flowing pressure (stagnation pressure minus dynamic pressure). Minor losses should include bends and valves etc. The vent entry and exit should not be included in the minor losses. The discharge coefficient can be used to factor the mass flow rate, depending on design requirements.

Where multiple pressure relieving devices share a common vent, the back pressure should be calculated for the total mass flow rate.

For relief vents with sections of increasing diameter, the back pressure should be calculated for each constant diameter section, going backwards from exit. The (flowing) exit pressure for each section equals the (flowing) inlet pressure for the previous section.

For pressure relief valves or rupture disks, the (flowing) inlet pressure for the vent is used as the (flowing) back pressure for the pressure relief device. This is valid provided that the vent diameter is greater than the diamter of the PRV nozzle or rupture disk.

Note : The ideal gas calculators use the ideal gas compressible flow equations. The API 520 gas and steam calculations use an approximation of the ideal gas compressible flow equations. Use the ideal gas calculators for a comparison with the API 520 calculators.

Reference : API 520 Sizing, Selection And Installation Of Pressure Relieving Devices (2014)

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Related Modules :

CALCULATOR MODULE : DNVGL RP C203 Pipeline Fatigue Stress   ±
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 Check Value   ±
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