Pipeng Toolbox : Flow Rate Modules Login
Short Cuts
GO
Main ±
Beams ±
References ±
Fluid Flow ±
Fluid Properties ±
Maths ±
Materials ±
Pipelines ±
Soils ±
Subsea ±
Data ±
Units ±
Help ±
Demo

Fluid Flow Rate Modules

Links : ±
CALCULATOR MODULE : ASME B31.3 Process Piping Fluid Velocity And Flow Rate   ±

Calculate ASME B31.3 process piping 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 B31.3 : Process Piping (2018)

Change Module :

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)

Change Module :

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)

Change Module :

CALCULATOR MODULE : ASME B31.1 Power Piping Steam Mass And Flow Rate   ±

Calculate ASME B31.1 power piping steam mass, velocity and flow rate from the steam table (IAPWS R7-97 Steam Table).

Steam mass and volume can be calculated from steam temperature and pressure, and either steam mass, steam volume, or piping length. Steam flow rate and velocity can be calculated from steam temperature and pressure, and either steam mass flow rate, steam volume flow rate, or steam velocity.

Steam properties can be calculated for water and steam, saturated water, saturated steam, saturated water and steam, metastable water, and metastable steam. The calculations for water and steam are valid between 273.15 K and 1073.15 K (0 to 100 MPa), and between 1073.15 K and 2273.15 K (0 to 50 MPa).

The saturated water and steam calculations are valid between 273.15 K and 647.096 K.

The metastable calculation is valid between 273.15 K and 647.096 K, and for pressure from the saturated vapour line to the 5% equilibium moisture line (user defined).

Note : There is an anomaly in the steam calculation for region 3 between the saturated vapour line, the regions 2/3 boundary, and the critical pressure. Refer to the region 3 anomaly help page for more details (click the utility button on the data bar).

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

Change Module :

CALCULATOR MODULE : ASME B31.5 Refrigeration Piping Fluid Velocity And Flow Rate   ±

Calculate ASME B31.5 refrigeration piping fluid velocity and flow rate for two phase gas and liquid.

The two phase gas liquid calculator can be used for single phase gas, single phase liquid, or two phase gas and liquid. 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 B31.5 : Refrigeration Piping And Heat Transfer Components (2013)

Change Module :

Related Modules :

CALCULATOR MODULE : Pipeline Fluid Velocity And Flowrate   ±

Calculate pipeline fluid velocity, density and flowrate for two phase gas liquid, three phase gas oil and water (black oil), single phase gas, and single phase liquid.

Two phase gas liquid density is calculated from the gas oil ratio (GOR). Three phase black oil density is calculated from the gas oil ratio (GOR), and water cut (WC). Single phase gas density is calculated from temperature, pressure, specific gravity (relative to air), and compressibility factor. Single phase liquid density can be calcuated from specific gravity, degrees Baume (Be+), degrees Baume (Be-), degrees API, or degrees Twaddell.

Change Module :

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)

Change Module :

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)

Change Module :

CALCULATOR MODULE : AS 2885.1 Pipeline Fluid Velocity And Flow Rate   ±

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

Change Module :

CALCULATOR MODULE : Piping Fitting Minor Loss Factor   ±

Calculate pipe fitting minor loss factors.

Minor loss factors can be defined as:

  • Av (SI) flow coefficient - the flow in cubic meters per second fluid density 1 kilogram per cubic meter which gives a pressure drop of 1 Pa
  • Cv-uk (UK) flow coefficient - the flow in UK gallons per minute of water at 60 degrees F which gives a pressure drop of 1 psi
  • Cv-us (US) flow coefficient - the flow in US gallons per minute of water at 60 degrees F which gives a pressure drop of 1 psi
  • Cv-met (Metric) flow coefficient - the flow in liters per minute of water at 16 degrees C which gives a pressure drop of 1 bar
  • Kv (EU) flow coefficient - the flow in cubic meters per hour of water at 16 degrees C which gives a pressure drop of 1 bar
  • Cv* the dimensionless US flow factor = Cv-us / din^2 (din is the inside diameter in inches)
  • K factor - the ratio of pressure loss over the dynamic pressure
  • Cd or discharge coefficient - the ratio of the actual flow rate of the fluid through the fitting over the frictionless flow rate.

The K factor and discharge coefficient are dimensionless and can be used with any consistent set of units. The dimensionless flow coefficient has inconsistent units, and is unit specific. The flow coefficient Av, Cv-us, Cv-uk, Cv-met and Kv have dimensions length squared, and can not be used interchangeably between different systems of units.

Note : The friction factor K, discharge coefficient Cd, dimensionless flow coefficient Cv*, and flow coefficients Av, Cv-uk, Cv-us, Cv-met and Kv are used in different situations. The discharge coefficient is usually used for discharge through an orifice, but can also be used in other situations (for example pressure relief valves). The flow coefficients Av, Cv-uk, Cv-us, Cv-met and Kv, and the dimensionless flow coefficient Cv* are usually used for valves, but can also be used for other fittings. Engineering judgement is required to determine the correct minor loss factor to use.

Change Module :

Related Modules :

CALCULATOR MODULE : Piping Fitting Pressure Loss   ±

Calculate outlet pressure and pressure loss through piping and fittings.

The pressure loss is calculated from the Moody diagram using the Darcy-Weisbach friction factor. The Darcy friction factor can be calculated using either the Hagen-Poiseuille laminar flow equation, the original Colebrook White turbulent flow equation, or the modified Colebrook White equation. Changes in elevation are ignored.

For liquid piping with fittings the outlet pressure is calculated by:

`Po = P - 8 (fL/D+ΣK) ρ (Q^2) / (pi^2D^4) `
`ΔP = P - Po `

where :

ΔP = pressure loss
P =inlet pressure
Po = outlet pressure
Po = outlet pressure
ρ = fluid density
Q= fluid volume flowrate
f = Darcy friction factor
L = pipe length
D = pipe inside diameter
Σ K = total fitting K factor

For gas piping with fittings the outlet pressure is calculated by:

`Po = √(P^2 - 16m^2(fd.L / D + ΣK) (mma.SG.ZRoT)/(pi^2D^4) ) `

where :

m = gas mole flowrate
mma = air molar mass
SG = gas specific gravity
Z = gas compressibility factor
Ro = universal gas constant
T = gas temperature

For liquid fittings the outlet pressure is calculated by:

`Po = P - 8 K ρ (Q^2) / (pi^2D^4) `

where :

K = fitting K factor

For gas fittings the outlet pressure is calculated by:

`Po = √(P^2 - m^2K (16mma.SG.ZRoT)/(pi^2D^4) ) `

Change Module :

Related Modules :

CALCULATOR MODULE : Bernoulli's Equation Fluid Flowrate And Velocity   ±
CALCULATOR MODULE : Bernoulli's Equation Flow Meter   ±

Calculate fluid flowrate from flowmeter pressure measurements using the Bernoulli equation.

The flowrate through a flow meter can be calculated from the difference in static pressure using the Bernoulli equation. The discharge coefficient accounts for friction losses through the flow meter. Bernoulli flow meters are normally installed horizontal so that changes in elevation can be ignored.

Change Module :

Related Modules :

CALCULATOR MODULE : Liquid Pipeline Pressure Loss From The Darcy Weisbach Equation   ±

Calculate single phase liquid pipeline pressure loss using the Darcy Weisbach equation.

`Po = P - (fd L / (ID) + K) 1/2 ρ V^2 + ρ g (zi - zo) `

where :

Po = outlet pressure
P = inlet pressure
fd = Darcy friction factor
L = piping length
ID = piping inside diameter
K = total friction loss factor for fittings
ρ = fluid density
V = fluid velocity
g = gravity constant
zi = inlet elevation
zo = outlet elevation

The Darcy friction factor can be calculated for

  • Hagen-Poiseuille laminar flow equation
  • original Colebrook White equation
  • modified Colebrook White equation
  • Prandtl Nikuradse smooth pipe equation
  • Blasius smooth pipe equation
  • Colebrook smooth pipe equation
  • Miller smooth pipe equation
  • Konakov smooth pipe equation
  • Von Karman rough pipe equation

For low Reynolds numbers Re < 2000, the fluid flow is laminar and the Darcy friction factor should be calculated using the Hagen-Poiseuille laminar flow equation. For high Reynolds numbers Re > 4000, the fluid flow is turbulent and the Darcy friction factor should be calculated using one of the turbulent flow equations. In the transition region 2000 < Re < 4000, the flow is unstable and the friction loss cannot be reliably calculated. The minor loss K factor is used to account for pipeline fittings such as bends, tees, valves etc..

The calculators use the Darcy-Weisbach pressure loss equation. The Fanning friction factor is used with the Fanning pressure loss equation. The transmission factors are commonly used for gas flow. The results for the Darcy and Fanning equations are identical provided that the correct friction factor is used.

Change Module :

Related Modules :

CALCULATOR MODULE : Liquid Pipeline Chemical Dose Rate   ±

Calculate single phase liquid pipeline, liquid chemical dose volume fraction, mass fraction, volume ratio, mass ratio, and average fluid density.

`Xv = (Vd) / (Vf) `
`Mv = (Md) / (Mf) `
`Rv = 1 : (Xl) / (Xd) = 1 : (1/(Xv) - 1) `
`Rm = 1 : (Ml) / (Md) = 1 : (1/(Xm) - 1) `
`Vf = Vd + Vl `
`Mf = Md + Ml `
`ρf = Xv. ρd + (1-Xv) ρl `

where :

Xv = dose volume fraction
Mv = dose mass fraction
Rv = dose volume ratio (1 : liquid volume / dose volume rounded)
Rm = dose mass ratio (1 : liquid mass / dose mass rounded)
Vf = total fluid volume
Vd = dose volume
Vl = liquid volume (before dosing)
Mf = total fluid mass
Md = dose mass
Ml = liquid mass (before dosing)
ρf = average fluid density (dosed)
ρd = dose chemical density
ρl = liquid density (before dosing)

The average fluid density includes the dosing chemical (combined undosed liquid and dose chemical). The volume of mixing is assumed to be equal to the sum of the individual volumes. The dose amount can be calculated from either the liquid volume (before dosing), or the total fluid volume. he dose rate can be calculated from either the liquid flowrate (before dosing), or the total fluid flowrate.

Change Module :

Related Modules :

CALCULATOR MODULE : Water Open Channel Or Culvert Flow Rate From The Manning Equation   ±

Calculate flowrate in circular or rectangular water channels using the Manning equation.

`Q = A (rh^2)/3 s^(1/2) / n `
`rh = A/P `

where :

Q = flow rate
A = cross section area
P = wetted perimeter
rh = hydraulic radius
s = channel slope
n = Manning friction factor

The channel is assumed to be either open, or partly full and at ambient pressure. The head loss equals the change in elevation. Channel roughness is accounted for using the Manning friction factor. The hydraulic radius is the ratio of channel cross section area over the wetted perimeter. Valves, tees and other pipe fittings should be included by adding a minor loss equivalent length to the pipeline length.

Change Module :

Related Modules :

CALCULATOR MODULE : Liquid Pipeline Fluid Velocity And Flow Rate   ±
CALCULATOR MODULE : Gas Pipeline Pressure Loss From The Darcy Weisbach Equation   ±

Calculate single phase gas pipeline pressure loss using the Darcy Weisbach equation.

`Po = √(P^2 - m^2(fd.L / D + K) ls (16mma.SG.ZRoT)/(pi^2D^4) ) / (es) `
`ss = (z2 - z2) SG.mma.g / (Ro T Z) `
`es = e^(ss) `
`ls = (es^2 - 1) / (ss) `

where :

Po = outlet pressure
P = inlet pressure
fd = Darcy friction factor
L = piping length
D = piping inside diameter
K = total friction loss factor for fittings
m = gas mole flowrategas
mma = air molar mass
SG = gas specific gravity
Z = gas compressibility factor
Ro = universal gas constant
T = gas temperature
g = gravity constant
zi = inlet elevation
zo = outlet elevation
ss = elevation exponent
es = elevation pressure factor
ls = elevation length factor

For low Reynolds numbers Re < 2000, the fluid flow is laminar and the Darcy friction factor should be calculated using the Hagen-Poiseuille laminar flow equation. For high Reynolds numbers Re > 4000, the fluid flow is turbulent and the Darcy friction factor should be calculated using one of the turbulent flow equations. In the transition region 2000 < Re < 4000, the flow is unstable and the friction loss cannot be reliably calculated. The minor loss K factor is used to account for pipeline fittings such as bends, tees, valves etc..

The calculators use the Darcy-Weisbach pressure loss equation with the Darcy friction factor. The Fanning transmission factor combined with the Fanning equation is commonly used for gas flow. The results for the Darcy and Fanning equations are identical provided that the correct friction factor is used.

The gas specific gravity is the ratio of gas density over the density of dry air at base temperature and pressure. The compressibility factor is assumed to equal 1 at the base conditions. The gas specific gravity is proportional to the gas molar mass.

Change Module :

Related Modules :

CALCULATOR MODULE : Gas Pipeline Chemical Dose Rate   ±

Calculate single phase gas pipeline, liquid chemical dose volume fraction, mass fraction, dose volume over gas mole ratio, dose mass over gas mole ratio, and average fluid density.

`Xv = (Vd) / (Vf) `
`Mv = (Md) / (Mf) `
`Rv = (Vg.Xv) / (1 - Xv) `
`Rm = Rv.ρd `
`Vf = Vd + Vg `
`Mf = Md + Mg `
`ρf = Xv.ρd + (1-Xv) ρg `
`Vg = (m Z Ro T) / P `

where :

Xv = dose volume fraction
Mv = dose mass fraction
Rv = dose volume ratio (dose volume:liquid volume)
Rm = dose mass ratio (dose mass:liquid mass)
Vf = total fluid volume
Vd = dose volume
Vg = gas volume (before dosing)
Mf = total fluid mass
Md = dose mass
Mg = gas mass (before dosing)
Vg = gas volume
m = gas moles
P = gas pressure
T = gas temperature
ρf = average fluid density (dosed)
ρd = dose chemical density
ρg= gas density (before dosing)

The average fluid density includes the dosing chemical (combined undosed liquid and dose chemical). The dose chemical is assumed to remain in the liquid phase. The dose quantity can be calculated from either the gas quantity (before dosing), or the total fluid quantity (after dosing). The dose rate can be calculated from either the gas flowrate (before dosing), or the total fluid flowrate:

Change Module :

Related Modules :

CALCULATOR MODULE : Gas Pipeline Fluid Velocity And Flow Rate   ±
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

Change Module :

Related Modules :

CALCULATOR MODULE : Pipeline Flow Rate   ±
CALCULATOR MODULE : Compressible Flow   ±

Calculate compressible flow ratios and gas properties for isentropic and isothermal flow (critical over stagnation ratios, flowing over stagnation ratios, and flowing over critical flow ratios).

For isentropic flow, critical flow occurs at M = 1. For isothermal flow, critical flow occurs at M = 1 / √k, where k is the specific heat ratio (Cp/Cv). For isothermal flow the isothermal temperature is assumed equal to the stagnation temperature. Phase changes are ignored.

For flow through a throat, the flow upstream from the throat is sub critical (M ≤ Mc). The flow downstream is super critical (M > Mc). The area ratio is inversely proportional to the mass flux ratio. At stagnation conditions, the area ratio is infinite.

Use the Result Plot option to plot flow ratios versus Mach number, or nozzle area ratio and diameter ratio versus Mach number.

Reference : Fluid Mechanics, Frank M White, McGraw Hill

Change Module :

Related Modules :

CALCULATOR MODULE : Compressible Flow Pressure Relief Valve   ±

Calculate compressible flow pressure relief valve capacity for isentropic, isothermal, and adiabatic conditions.

For pressure relief valves with no header, the mass flow rate can be calculated for isentropic or isothermal flow. The pressure relief valve is assumed to exit directly to ambient pressure. If the ambient pressure is less than the critical pressure the flow is critical (Mc = 1 for isentropic flow and Mc = √(1/γ) for isothermal flow). If the ambient pressure is greater than the critical nozzle pressure, the flow is sub critical (M < Mc). For isothermal flow the stagnation temperature should be close to or equal to the ambient temperature (for example a gas transmission pipeline). Phase changes are ignored.

For a combined pressure relief valve and pressure relief header, the mass flow rate can be calculated for

  • Isentropic nozzle and adiabatic header
  • Isentropic nozzle and isothermal header
  • Isothermal nozzle and isothermal header

The pressure relief valve is assumed to exit directly into the header. If the header inlet pressure is less than or equal to the nozzle critical pressure the nozzle flow is critical (Mc = 1 for isentropic flow and Mc = √(1/γ) for isothermal flow), and the mass flow rate is restricted by the nozzle. The header inlet pressure is calculated so that the header mass flow rate equals the nozzle mass flow rate. If the header inlet pressure is greater than the critical nozzle pressure, the nozzle flow is sub critical (M < Mc), and the mass flow rate is restricted by the header. The mass flow rate is calculated so that the header inlet pressure is equal to the nozzle pressure. The mass flow rate through the nozzle is always equal to the mass flow rate through the header.

For a pressure relief header, the mass flow rate can be calculated for adiabatic or isothermal flow. If the header is attached directly to the outlet of a pressure relief valve (PRV), the header inlet pressure should be set equal to the PRV nozzle outlet pressure. The header should be sized so that the calculated header mass flowrate is greater than or equal to the PRV mass flowrate. For headers with more than one PRV, the header mass flowrate is divided by the number of PRV's. If the header is oversized, the header inlet pressure will reduce so that the actual header mass flowrate is equal to the nozzle mass flowrate (there is a pressure drop between the PRV outlet and the header inlet).

Note : If the PRV is attached to a small diameter header which feeds into a larger diameter header (possibly with multiple PRVs), the large diameter header should be sized first. The inlet pressure for the large diameter header is used as the ambient pressure for the smaller diameter header (and PRV).

Header pressure losses are calculated from the pressure loss factor (fld = fL/D + K). The Darcy friction factor f is calculated for fully turbulent flow using the rough pipe equation. The header is assumed to be constant diameter. Minor losses can be included by the minor loss K factor, and should include valves and bends etc. The header entry and exit losses should not be included (the fluid dynamic pressure loss is included in the calculation). The discharge coefficient can also be used for minor losses, and as a safety factor. If the ambient pressure is less than the critical header pressure the header exit flow is critical (Mc = 1 for isentropic flow and Mc = √(1/γ) for isothermal flow). If the ambient pressure is greater than the critical header pressure, the header exit flow is sub critical (M < Mc). The header entry flow is assumed to be sub critical for all flow conditions.

The effective PRV valve nozzle orifice diameter and cross section area can be calculated from API letter designation (API 526 type D to T). API effective orifice sizing is used to compensate for the friction pressure losses in the relief valve. The combination of valve and nozzle orifice must be tested with the operating fluid at the design conditions, and certified as having a flow rate greater than or equal to the calculated flow rate for the equivalent size. The API 526 orifice sizing assumes isentropic flow. For certified API 526 valves, the isentropic nozzle calculation option should be used.

Note : The pressure relief header calculation is not suitable for pressure relief vents. Headers are assumed to be part of a PRV system. Vents are constant diameter piping attached to a pipeline or pressure vessel.

Use the Result Plot option to plot pressure, mach number and mass flow rate.

Reference : Fluid Mechanics, Frank M White, McGraw Hill

Change Module :

Related Modules :

CALCULATOR MODULE : Compressible Flow Pressure Relief Vent   ±

Calculate compressible flow pressure relief vent flow rate and pressure drop for either adiabatic or isothermal flow.

The vent is modelled as a frictionless entry, combined with a frictional constant diameter duct. For adiabatic flow the vent entry is assumed to be isentropic. For isothermal flow, the vent entry is assumed to be isothermal. The vent entry is assumed to be subsonic at all conditions. The pipeline is assumed to be at stagnation conditions (M = 0). At high pressure the vent exit flow is critical flow (Mc = 1 for adiabatic low and `Mc = 1 / (√γ)` for isothermal flow : γ = the gas specific heat ratio). At lower pressures the vent exit flow is sub critical (M < Mc).

Vent flow rate is calculated from the vent pressure loss factor (fld).

`fld = fd L/D + K `

where :

fld = vent pressure loss factor
fd = Darcy friction factor
L = vent length
D = vent inside diameter
K = minor loss K factor

The Darcy friction factor is calculated assuming fully turbulent flow. Minor losses should include the vent entry, and valves, bends etc.. The vent exit should not be included (the fluid dynamic pressure is included in the calculation). The discharge coefficient can be used as a safety factor.

Note : The vent calculation is not suitable for pressure relief headers which are part of a pressure relief valve (PRV) system.

Use the Result Plot option to plot inlet and exit pressure versus stagnation pressure, inlet and exit mach number versus stagnation pressure, or mass flow rate versus stagnation pressure and flow type.

Reference : Fluid Mechanics, Frank M White, McGraw Hill

Change Module :

Related Modules :

CALCULATOR MODULE : Compressible Flow Nozzle Flow Rate   ±

Calculate compressible flow mass flow rate and mole flow rate through a nozzle for isentropic and isothermal flow.

At high pressure the nozzle flow is critical (the critical exit pressure is ≥ the ambient pressure). The critical Mach number Mc = 1 for adiabatic low and Mc = 1 / √γ for isothermal flow (γ = the gas specific heat ratio). At lower pressures the nozzle flow is sub critical (M < Mc) (the critical exit pressure is < the ambient pressure). For isothermal flow the stagnation temperature should be close to or equal to the ambient temperature (eg gas transmission pipeline). The discharge coefficient can be used to account for friction losses, and as a design factor.

Reference : Fluid Mechanics, Frank M White, McGraw Hill

Change Module :

Related Modules :

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 Choke Gallery Erosion Rate   ±
CALCULATOR MODULE : DNVGL RP O501 Erosion Probe Sand Rate   ±
CALCULATOR MODULE : DNVGL RP F115 Pipeline Leak Rate   ±
CALCULATOR MODULE : DNVGL RP F115 Pipeline Chemical Dose Rate   ±
CALCULATOR MODULE : Pump Delta Pressure Versus Flowrate Curve   ±

Calculate pump curve (pressure versus flowrate) for viscous and non viscous flow. Viscous flow is recommended if the kinematic viscosity is greater than 20 cSt.

The pump curve is calculated using a three term quadratic curve (ΔP = ΔPo - A Q - B Q^2) calculated from the shut-in delta pressure (zero flow), the maximum flowrate, and the best efficiency point (BEP).

Note : The delta stagnation pressure is required for the calculation. Some pump curves show delta static pressure (the pressure equals zero at maximum flow) instead of delta stagnation pressure (the pressure equals the dynamic pressure at maximum flow). Use the pump pressure and head conversion calculator to convert delta static pressure to delta stagnation pressure.

The pump flowrate, delta pressure, inside diameter and efficiency can be scaled for a geometrically similar pump using the affinity or similarity laws. For geometric similarity the pump inside diameter should be proportional to the impeller diameter. In practice the pump inside diameter is usually limited to pipe sizes (eg 10 inch, 12 inch etc). The impeller diameter is also normally limited to fixed sizes. It is often more practical to select an available pump inside diameter and impeller diameter, and vary the pump speed. Pump efficiency scaling is based on an empirical formula. Pump efficiency scaling should be combined with flowrate scaling. Pump efficiency varies with flowrate. Pump performance is normally measured using water (density is assumed to be 1000 kg/m^3).

PLEASE NOTE : The pump calculators are currently being updated. Apologies for any inconvenience.

Change Module :

CALCULATOR MODULE : Pump Hydraulic And Input Power   ±

Calculate pump hydraulic power and input power or motive power from flowrate and delta pressure.

`Wh = Q ΔP `
`Wi = (Wh) / E `

where :

Wh = hydraulic power
Wi = input power or motive power
Q = volume flowrate
ΔP = delta stagnation pressure
E = efficiency factor

The pump efficiency accounts for energy losses in the pump such as friction etc. The input power is the motive power required to drive the pump (the size of motor). To calculate the energy required (eg electrical energy) the efficiency factor should equal the pump efficiency times the motor efficiency.

`E = Ep.Ee `

where :

Ep = pump efficiency factor
Ee = electric motor efficiency factor

Pump efficiency varies with flowrate. The flowrate with maximum efficiency is referred to as the best efficiency point (BEP).

PLEASE NOTE : The pump calculators are currently being updated. Apologies for any inconvenience.

Change Module :

CALCULATOR MODULE : Pump Flowrate Pressure And Power Coefficient   ±

Calculate pump flow coefficient (Cq), pressure coefficient (Cp), power coefficient (Cw) and pump specific speed from flowrate, delta pressure, pump speed and impeller diameter. The pump coefficients are calculated at the best efficiency point (BEP).

`Cq = Q / (n d^3) `
`Cp = (ΔP) / (ρ n^2 d^2) = (gΔH) / (n^2 d^2) `
`Cw = Cq. Cp = (Q ΔP) / (ρ n^3 d^5) `
`Ns = (Cq^(1/2)) / (Cp^(3/4)) = nQ^(1/2) (ΔP^(3/4)) / ρ `

where :

Cq = flowrate coefficient at BEP
Cp = pressure coefficient at BEP
Cw = power coefficient at BEP
Ns = pump specific speed at BEP
n = pump rotational speed at BEP
d = impeller diameter at BEP
Q = flow rate at BEP
ΔP = delta pressure at BEP
ΔH = delta head at BEP
ρ = fluid density
g = gravity constant

PLEASE NOTE : The pump calculators are currently being updated. Apologies for any inconvenience.

Change Module :

CALCULATOR MODULE : Liquid Kinematic And Dynamic Viscosity   ±

Calculate dynamic viscosity and kinematic viscosity for single phase liquids.

Kinematic viscosity is equal to the dynamic viscosity divided by the density of the fluid. The specific gravity (SG) equals the fluid density divided by the density of water (1000 kg/m^3). 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.

Change Module :

Related Modules :

CALCULATOR MODULE : Two Phase Gas Liquid Viscosity   ±

Calculate dynamic and kinematic viscosity for two phase gas liquids (gas and oil or gas and liquid).

Kinematic viscosity is equal to the dynamic viscosity divided by the density of the fluid. The viscosity of two phase fluids and mixtures can be calculated from the dynamic viscosity and the volume fraction. The gas oil ratio is the ratio of gas moles to oil volume. It is often measured as gas standard volume (scf or scm) per oil volume (barrels, gallons, cubic feet or cubic meters).

Change Module :

Related Modules :

CALCULATOR MODULE : Three Phase Gas Oil Water (Black Oil) Viscosity   ±

Calculate dynamic and kinematic viscosity for three phase black oil (gas oil and water).

Kinematic viscosity is equal to the dynamic viscosity divided by the density of the fluid. The viscosity of two phase fluids and mixtures can be calculated from the dynamic viscosity and the volume fraction.

The gas oil ratio is the ratio of gas moles to oil volume. The gas mass fraction is the ratio of gas mass to total fluid mass. The gas volume fraction is the ratio of gas volume to total fluid volume. Water cut is the ratio of water volume over total liquid volume (equals the water volume fraction in the liquid). Gas volume is dependent on fluid temperature and pressure. Gas oil ratio is often measured as gas standard volume (scf or scm) per oil volume (barrels, gallons, cubic feet or cubic meters).

Change Module :

Related Modules :

CALCULATOR MODULE : Gas Kinematic And Dynamic Viscosity   ±

Calculate dynamic viscosity and kinematic viscosity for single phase gas.

Kinematic viscosity is equal to the dynamic viscosity divided by the density of the fluid. Gas specific gravity (SG) equals the gas molar mass divided by the molar mass of air (28.964 kg/kg-mol).

Change Module :

Related Modules :

CALCULATOR MODULE : Two Phase Fluid Gas Oil Ratio GOR   ±
CALCULATOR MODULE : Two Phase Liquid Water Cut Ratio   ±
CALCULATOR MODULE : Two Phase Gas Liquid Density   ±

Calculate fluid density for two phase fluid (oil and gas, or gas and water).

The gas oil ratio is the ratio of gas moles to oil volume. The gas mass fraction is the ratio of gas mass to total fluid mass. The gas volume fraction is the ratio of gas volume to total fluid volume. Gas volume is dependent on fluid temperature and pressure. Gas oil ratio is often measured as gas standard volume (scf or scm) per oil volume (barrels, gallons, cubic feet or cubic meters).

Change Module :

Related Modules :

CALCULATOR MODULE : Three Phase Gas Oil Water (Black Oil) Density   ±

Calculate fluid density for three phase black oil (oil, water and gas).

The gas oil ratio is the ratio of gas moles to oil volume. The gas mass fraction is the ratio of gas mass to total fluid mass. The gas volume fraction is the ratio of gas volume to total fluid volume. Water cut is the ratio of water volume over total liquid volume (equals the water volume fraction in the liquid). Gas volume is dependent on fluid temperature and pressure. Gas oil ratio is often measured as gas standard volume (scf or scm) per oil volume (barrels, gallons, cubic feet or cubic meters).

Change Module :

Related Modules :

CALCULATOR MODULE : Single Phase Liquid Specific Gravity   ±

Calculate liquid specific gravity for single phase liquid.

Liquid specific gravity is calculated relative to the density of water (1000 kg/m^3). Liquid density can also be defined as degrees API (liquids lighter than water), degrees Baume (liquids lighter than water or liquids heavier than water), or degrees Twaddell (liquids heavier than water).

Change Module :

Related Modules :

CALCULATOR MODULE : Fluid Dosing Rate And Density   ±
CALCULATOR MODULE : Single Phase Gas Density   ±
CALCULATOR MODULE : Two Phase Gas Liquid Heat Capacity   ±

Calculate two phase gas liquid heat capacity.

Fluid heat capacity can be calculated for single phase phase liqui. single phase gas, or combined liquid and gas. Gas oil ratio (GOR) is the ratio of gas moles over liquid volume. Gas moles are commonly measured by standard cubic feet (scf), and stand cubic meters (scm). Gas oil ratio is often measured as gas standard volume (scf or scm) per oil volume (barrels, gallons, cubic feet or cubic meters).

Change Module :

Related Modules :

CALCULATOR MODULE : Three Phase Gas Oil Water (Black Oil) Heat Capacity   ±

Calculate three phase gas oil water (black oil) heat capacity.

Black oil is a three phase mixture of oil, water and gas. Water cut is measured relative to the total liquid volume (gas volume is ignored). Gas oil ratio (GOR) is measured relative to the oil volume at standard conditions (water volume is ignored). Gas oil ratio (GOR) is the ratio of gas moles over liquid volume. Gas moles are commonly measured by standard cubic feet (scf), and stand cubic meters (scm). Gas oil ratio is often measured as gas standard volume (scf or scm) per oil volume (barrels, gallons, cubic feet or cubic meters).

Change Module :

Related Modules :

CALCULATOR MODULE : IAPWS R7-97 Steam Volume And Mass Flow Rate   ±

Calculate IAPWS R7-97 steam table properties, and steam power from temperature, pressure and mass flow rate.

Steam table properties can be calculated for water and steam, saturated water, saturated steam, saturated water and steam, metastable water, and metastable steam. The enthalpy rate and internal energy rate (or power) are calculated from the mass flow rate.

Note : There is an anomaly in the steam calculation for region 3 between the saturated vapour line, the region 2/3 boundary, and the critical pressure. Refer to the region 3 anomaly help page for more details (click the utility button on the data bar). IAPWS R7-97 is intended for industrial use, and is a simplified version of IAPWS R6-95 for scientific use. IAPWS R7-97 was developed as an improvement of the IFC-67 model.

Reference : IAPWS R7-97 Industrial Formulation for thermodynamic Properties of Water and Steam

Change Module :

CALCULATOR MODULE : IAPWS R7-97 Fresh Water Density At Atmospheric Pressure   ±

Calculate IAPWS R7-97 fresh water density from temperature at atmospheric pressure.

The calculation is valid between the melting point (273.15 K), and the boiling point (373.15 K).

Note : There is an anomaly in the steam calculation for region 3 between the saturated vapour line, the region 2/3 boundary, and the critical pressure. Refer to the region 3 anomaly help page for more details (click the utility button on the data bar). IAPWS R7-97 is intended for industrial use, and is a simplified version of IAPWS R6-95 for scientific use. IAPWS R7-97 was developed as an improvement of the IFC-67 model.

Reference : IAPWS R7-97 Industrial Formulation for thermodynamic Properties of Water and Steam

Change Module :

CALCULATOR MODULE : TEOS-10 Seawater Density   ±

Calculate TEOS-10 seawater density from temperature, pressure and practical salinity.

The hydrostatic pressure used in TEOS-10 can be calculated from water depth or relative elevation. The water density is assumed constant. Changes in water density with water depth, salinity and temperature are ignored. Elevation is measured relative to an arbitrary datum (+ve up -ve down). Mean sea level (MSL) is often used as a datum.

Reference : TEOS-10 Thermodynamic Equation Of Seawater (2010)

Change Module :

Related Modules :

CALCULATOR MODULE : TEOS-10 Seawater Dynamic And Kinematic Viscosity   ±

Calculate TEOS-10 seawater dynamic and kinematic viscosity from temperature, pressure, and practical salinity.

Seawater viscosity is calculated from fresh water viscosity using the equation from Sharqawy (2010). The fresh water viscosity is calculated from temperature and density using the IAPWS R12-08 industrial equations. Practical salinity = parts per thousand of dissolved solids (mainly salt). The absolute salinity is taken as 35.16504 / 35 times the practical salinity (absolute salinity equals reference salinity). The absolute salinity anomaly δSA is ignored.

Reference : TEOS-10 Thermodynamic Equation Of Seawater (2010)

Change Module :

Related Modules :

CALCULATOR MODULE : IAPWS R12-08 Fresh Water Dynamic And Kinematic Viscosity   ±

Calculate the dynamic viscosity and kinematic viscosity of water and steam using the IAPWS R12-08 industrial equation (u2 = 1).

The viscosity can be either calculated directly from temperature and density, or from temperature and pressure using IAPWS R7-97 to calculate the density.

Note : There is an anomaly in the calculated density and viscosity close to the critical point. Refer to the help pages for more details (click the utility button on the data bar).

References :

IAPWS R12-08 Industrial Formulation 2008 for the Viscosity of Ordinary Water Substance
IAPWS R7-97 Industrial Formulation for thermodynamic Properties of Water and Steam

    Related Modules :

    pipeng.com 2025 (630 μs : 19 ms : 0.983 MB) Pengu CMS ©