Functions

API2SG

Converts a API gravity to oil specific gravity (water=1.0)

BasicFieldProfile

Typical field production profile. Units of volume [L3] and time [T] must be consistent.

Bg

Gas formation volume factor, [rcf/scf]

BoSat

Oil formation volume factor, P > Pb, [bbl/STB]

BoUSatAlMarhoun

Al-Marhoun correlation for oil formation volume factor, P <= Pb, [bbl/STB]

BoUSatGlaso

Glaso correlation for oil formation volume factor, P <= Pb, [bbl/STB]

BoUSatStanding

Standing correlation for oil formation volume factor, P <= Pb, [bbl/STB]

BoUSatVasquezBeggs

Vasquez and Beggs correlation for oil formation volume factor, P <= Pb, [bbl/STB]

BwMcCain

McCain correlation for water formation volume factor, [bbl/STB]

CfNewmanL

Newman correlation for rock pore volume compressibility in limestones, [1/psi]

CfNewmanS

Newman correlation for rock pore volume compressibility in sandstones, [1/psi]

Cg

Gas compressibility, [1/psi]

CubicSplineDifferentiate

A natural cubic spline with continuous second derivative in the interior and zero second derivative at the end points. Differentiate at point t.

CubicSplineIntegrate

A natural cubic spline with continuous second derivative in the interior and zero second derivative at the end points. Integrate up to point t.

CubicSplineIntegrateT1T2

A natural cubic spline with continuous second derivative in the interior and zero second derivative at the end points. Integrate from point t1 up to point t2.

CubicSplineInterpolate

A natural cubic spline with continuous second derivative in the interior and zero second derivative at the end points. Interpolate at point t.

CwSatOsif

Osif correlation for water compressibility, P >= Pb, [1/psi]

CwUSatMcCain

McCain correlation for water compressibility, P <= Pb, [1/psi]

DrainageAreaHorWell1

The horizontal well drainage area is represented by two half circles of radius b at each end and a rectangle, of dimensions L(2b), in the center. (Joshi Method 1), [acres]

ExponentialDeclineCumulative

Arps exponential production decline curve: cumulative production vs time. Units of volume [L3] and time [T] must be consistent.

ExponentialDeclineRate

Arps exponential production decline curve: rate vs time. Units of volume [L3] and time [T] must be consistent.

FlowRateSSVogel

FlowRateSSVogel – Vogel inflow performance for Steady state flow, [STB/d]

GasFlowRatePSS

GasFlowRatePSS – Gas well flow rate for pseudosteady state condition using Darcy flow approximation, [mscf/d]

GasFlowRatePSSNonDarcy

Gas well stabilized flow rate for pseudosteady state condition, with Non-Darcy flow equation, [mscf/d]

HarmonicDeclineCumulative

Arps harmonic production decline curve: cumulative production vs time. Units of volume [L3] and time [T] must be consistent.

HarmonicDeclineRate

Arps harmonic production decline curve: rate vs time. Units of volume [L3] and time [T] must be consistent.

HyperbolicDeclineCumulative

Arps hyperbolic production decline curve: cumulative production vs time. Units of volume [L3] and time [T] must be consistent.

HyperbolicDeclineRate

Arps hyperbolic production decline curve: rate vs time. Units of volume [L3] and time [T] must be consistent.

IFTgoAbdulMajeed

Interfacial (surface) tension for live oil by Abdul-Majeed correlation, [dymes/cm]

IFTgoBakerSwerdloff

Interfacial (surface) tension for live oil by Baker and Swerdloff correlation, [dymes/cm]

InletPressureBeggsBrill

Inlet pipe pressure for multiphase pipe flow by Beggs and Brill correlation, [psia]. It can be applied for any wellbore inclination and flow direction.

InletPressureGray

Inlet pressure for multiphase pipe flow by Gray correlation, [psia] It is commonly used for gas wells that are also producing liquid.

InletPressureHarBrown

Inlet pressure for multiphase pipe flow by Hagedorn and Brown correlation, [psia]. It was developed for vertical, upward flow and is recommended only for near-vertical wellbores.

KrcgIKGasCond

Ibrahim-Koederitz correlation for predicting relative permeability of condensate with respect to gas.

KrgIKGasCond

Ibrahim-Koederitz correlation for predicting gas relative permeability in gas-condensate system.

KrgIKGasOilCarb

Ibrahim-Koederitz correlation for predicting gas relative permeability in gas-oil system in carbonate.

KrgIKGasOilSand

Ibrahim-Koederitz correlation for predicting gas relative permeability in gas-oil system in sandstone.

KrgwIKGasWater

Ibrahim-Koederitz correlation for predicting relative permeability of gas with respect to water.

KrogIKGasOilCarb

Ibrahim-Koederitz correlation for predicting oil relative to gas permeability in carbonate.

KrogIKGasOilSand

Ibrahim-Koederitz correlation for predicting oil relative to gas permeability in sandstone.

KrowCorey

KrowCorey – Corey-type oil relative permeability, [dimensionless]

KrowHonarpourCarbInterWet

Honarpour correlation for predicting oil relative permeability in intermediately wet limestone and dolomite.

KrowHonarpourSandInterWet

Honarpour correlation for predicting oil relative permeability in intermediately wet sandstone and conglomerate.

KrowIKCarbInterWet

Ibrahim-Koederitz correlation for predicting oil relative permeability in intermediate-wet carbonate.

KrowIKCarbOilWet

Ibrahim-Koederitz correlation for predicting oil relative permeability in oil-wet carbonate.

KrowIKCarbStrongWaterWet

Ibrahim-Koederitz correlation for predicting oil relative permeability in strongly water-wet carbonate.

KrowIKCarbWaterWet

Ibrahim-Koederitz correlation for predicting oil relative permeability in water-wet carbonate.

KrowIKSandInterWet

Ibrahim-Koederitz correlation for predicting oil relative permeability in intermediate-wet sandstone.

KrowIKSandOilWet

Ibrahim-Koederitz correlation for predicting oil relative permeability in oil-wet sandstone.

KrowIKSandStrongWaterWet

Ibrahim-Koederitz correlation for predicting oil relative permeability in strongly water-wet sandstone.

KrowIKSandWaterWet

Ibrahim-Koederitz correlation for predicting oil relative permeability in water-wet sandstone.

KrowLET

LET-type oil relative permeability, [dimensionless]

KrwCorey

Corey-type water relative permeability, [dimensionless]

KrwHonarpourCarbInterWet

Honarpour correlation for predicting water relative permeability in intermediately wet limestone and dolomite.

KrwHonarpourSandInterWet

Honarpour correlation for predicting water relative permeability in intermediately wet sandstone and conglomerate.

KrwHonarpourSandWaterWet

Honarpour correlation for predicting water relative permeability in water wet sandstone and conglomerate.

KrwIKCarbInterWet

Ibrahim-Koederitz correlation for predicting water relative permeability in intermediate-wet carbonate.

KrwIKCarbOilWet

Ibrahim-Koederitz correlation for predicting water relative permeability in oil-wet carbonate.

KrwIKCarbStrongWaterWet

Ibrahim-Koederitz correlation for predicting water relative permeability in strongly water-wet carbonate.

KrwIKCarbWaterWet

Ibrahim-Koederitz correlation for predicting water relative permeability in water-wet carbonate.

KrwIKGasWater

Ibrahim-Koederitz correlation for predicting water relative permeability in gas-water system.

KrwIKSandInterWet

KrwIKSandInterWet – Ibrahim-Koederitz correlation for predicting water relative permeability in intermediate-wet sandstone.

KrwIKSandOilWet

Ibrahim-Koederitz correlation for predicting water relative permeability in oil-wet sandstone.

KrwIKSandStrongWaterWet

Ibrahim-Koederitz correlation for predicting water relative permeability in strongly water-wet sandstone.

KrwIKSandWaterWet

Ibrahim-Koederitz correlation for predicting water relative permeability in water-wet sandstone.

KrwLET

LET-type water relative permeability, [dimensionless]

OutletPressureBeggsBrill

Outlet pipe pressure for multiphase pipe flow by Beggs and Brill correlation, [psia]. It can be applied for any wellbore inclination and flow direction.

OutletPressureGray

Outlet pressure for multiphase pipe flow by Gray correlation, [psia] It is commonly used for gas wells that are also producing liquid.

OutletPressureHarBrown

Outlet pressure for multiphase pipe flow by Hagedorn and Brown correlation, [psia]. It was developed for vertical, upward flow and is recommended only for near-vertical wellbores.

PboAlMarhoun

Al-Marhoun correlation for oil bubble point pressure, [psia]

PboDoklaOsman

Dokla and Osman correlation for oil bubble point pressure, [psia]

PboGlaso

Glaso correlation for oil bubble point pressure, [psia]

PboStanding

Standing correlation for oil bubble point pressure, [psia]

PboVasquezBeggs

Vasquez and Beggs correlation for oil bubble point pressure, [psia]

PdLSSIHR

The expression of dimensionless line source solution pressure of infinite homogeneous reservoir.

PdwVWIHR

Dimensionless wellbore pressure drop for vertical well in infinite homogenous reservoir.

PdwVWIHRLCPB

Dimensionless wellbore pressure drop for vertical well in infinite homogenous reservoir with linear constant pressure boundary.

PdwVWIHRLSFB

Dimensionless wellbore pressure drop for vertical well in infinite homogenous reservoir with linear sealing fault boundary.

PdwVWIHRPCPB

Dimensionless wellbore pressure drop for vertical well in infinite homogenous reservoir with perpendicular constant pressures boundary.

PdwVWIHRPMB

Dimensionless wellbore pressure drop for vertical well in infinite homogenous reservoir with perpendicular mixed boundaries (boundary 1 – fault, boundary 2 – constant pressure).

PdwVWIHRPSFB

Dimensionless wellbore pressure drop for vertical well in infinite homogenous reservoir with perpendicular sealing faults boundary.

PpcStanding

Standing correlation for preudo-critical pressure of hydrocarbon gas, [psia]

PpcSutton

Sutton correlation for preudo-critical pressure of hydrocarbon gas, [psia]

PressureGradientBeggsBrill

Pressure gradient for multiphase pipe flow by Beggs and Brill correlation, [psi/ft] It can be applied for any wellbore inclination and flow direction.

PressureGradientGray

Pressure gradient for multiphase pipe flow by Gray correlation, [psi/ft] It is commonly used for gas wells that are also producing liquid.

PressureGradientHarBrown

Pressure gradient for multiphase pipe flow by Hagedorn and Brown correlation with Griffith modification , [psi/ft]. It was developed for vertical, upward flow and is recommended only for near-vertical wellbores.

ProdIndexHorWellBO

Pseudosteady state productivity index for horizontal well, [STB/(d.psi)] The Babu Odeh method for a box-shaped , anisotropic reservoir, with a well placed parallel to X(box length)-direction.

ProdIndexHorWellBO2

Pseudosteady state productivity index for horizontal well, [STB/(d.psi)] The Babu Odeh method for a box-shaped , anisotropic reservoir, with a well centrally placed parallel to X(box length)-direction.

ProdIndexHorWellBorisov

Horizontal well productivity index under steady state flow. Borisov method for well in an isotropic reservoir, [STB/(d.psi)]

ProdIndexHorWellGRJ

Horizontal well productivity index under steady state flow. The Giger-Reiss-Jourdan method for well in an anisotropic reservoir, [STB/(d.psi)]

ProdIndexHorWellJoshi

Horizontal well productivity index under steady state flow. The Joshi method for well in an anisotropic reservoir, [STB/(d.psi)]

ProdIndexHorWellRD

Horizontal well productivity index under steady state flow. The Renard-Dupuy method for well in an anisotropic reservoir, [STB/(d.psi)]

ProdIndexPSS

Pseudosteady state productivity index for vertical well, [STB/(d.psi)]

ProdIndexSS

Steady state productivity index for vertical well, [STB/(d.psi)]

ProdIndexTF

Transient state productivity index for vertical well, [STB/(d.psi)]

ptaCd

Dimensionless wellbore storage coefficient

ptaPd

Dimensionless pressure as defined for constant-rate production

ptaRwd

ptaRwd – Dimensionless radius

PwVWIHR

Wellbore pressure drop for vertical well in infinite homogenous reservoir, [psi]

PwVWIHRLCPB

Wellbore pressure drop for vertical well in infinite homogenous reservoir with linear constant pressure boundary, [psi]

PwVWIHRLSFB

Wellbore pressure drop for vertical well in infinite homogenous reservoir with linear sealing fault boundary, [psi]

PwVWIHRPCPB

Wellbore pressure drop for vertical well in infinite homogenous reservoir with perpendicular constant pressures boundary, [psi]

PwVWIHRPMB

Wellbore pressure drop for vertical well in infinite homogenous reservoir with perpendicular mixed boundaries (boundary 1 – fault, boundary 2 – constant pressure), [psi]

PwVWIHRPSFB

Wellbore pressure drop for vertical well in infinite homogenous reservoir with perpendicular sealing faults boundary, [psi]

ReynoldsNumberGas

Reynolds number for single phase pipe flow of gas (compressible fluid), [dimensionless]

ReynoldsNumberLiquid

Reynolds number for single phase pipe flow of incompressible, Newtonian fluid, [dimensionless]

RsoUSatGlaso

Glaso correlation for solution gas-oil ratio, P <= Pb, [scf/STB]

RsoUSatStanding

Standing correlation for solution gas-oil ratio, P <= Pb, [scf/STB]

RswMcCain

RswMcCain – McCain correlation for solution gas-water ratio for reservoir water, [scf/STB]

RswpMcCain

McCain correlation for solution gas-water ratio for pure water, [scf/STB]

SG2API

Converts a oil specific gravity to API gravity

TimeToPSS

Time to pseudosteady state for regular shape drainage area, [h]

TpcStanding

Standing correlation for preudo-critical temperature of hydrocarbon gas, [degR]

TpcSutton

Sutton correlation for preudo-critical temperature of hydrocarbon gas, [degR]

UgLGE

Lee, Gonzales and Eakin correlation for gas viscosity, [cP]

UodEgbogah

Egbogah correlation for dead oil viscosity, [cP]

UoUSatBeggsRobinson

UoUSatBeggsRobinson – Beggs and Robinson correlation for oil viscosity with solution gas, P < = Pb, [cP]

Uw1McCain

McCain correlation for water viscosity at atmospheric pressure and reservoir temperature, [cP]

UwMcCain

UwMcCain – McCain correlation for water viscosity, [cP]

ZfactorBrillBeggs

Brill and Beggs correlation for gas compressibility factor (Z), [dimensionless]

ZfactorDAK

Gas compressibility factor (Z) based on Dranchuk and Abou-Kassem EoS, [dimensionless]