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

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

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

Gas formation volume factor, [rcf/scf]

Al-Marhoun (1988) correlation for oil formation volume factor, P <= Pb, [bbl/STB]

Dindoruk and Christman (2001) correlation for oil formation volume factor, P <= Pb, [bbl/STB]

Glaso (1980) correlation for oil formation volume factor, P <= Pb, [bbl/STB]

Petrosky (1990) correlation for oil formation volume factor, P <= Pb, [bbl/STB]

Standing (1947) correlation for oil formation volume factor, P <= Pb, [bbl/STB]

Vasquez and Beggs (1980) correlation for oil formation volume factor, P <= Pb, [bbl/STB]

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

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

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

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

Gas compressibility, [1/psi]

Field production profile based on drilling schedule and typical well profile.

Villena-Lanzi (1985) correlation for oil compressibility, P <= Pb, [1/psi]

Vasquez and Beggs (1980) correlation for oil compressibility, P > Pb, [1/psi]

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

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

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.

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

x value of intersection point between two cubic splines.

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

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

Derivative for data samples at point t with smoothing.

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]

The horizontal well drainage area is an ellipse. (Joshi Method 2), [acres]

Effective drainage radius, [ft]

Effective wellbore radius, [ft]

Equivalent skin factor for vertical well with hydraulic fracture.

The exponential integral function – Ei(x)

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

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

Pseudosteady state production flow rate, [STB/d]

Vogel inflow performance for pseudosteady state flow, [STB/d]

Steady state production flow rate, [STB/d]

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

Transient-state production flow rate, [STB/d]

Vogel inflow performance for transient-state flow, [STB/d]

Frictional pressure drop from Fanning equation; Single-phase flow of an incompressible, Newtonian fluid, [psi]

Gas density, [g/cc]

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

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

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

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

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

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

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

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

Inlet pipe pressure for single phase pipe flow of gas (compressible fluid), [psia]

Inlet pipe pressure for single phase pipe flow of incompressible, Newtonian fluid, [psia]

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

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

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.

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

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

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

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

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

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

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

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

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

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

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

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

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

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

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

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

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

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

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

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

LET-type oil relative permeability, [dimensionless]

Corey-type water relative permeability, [dimensionless]

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

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

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

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

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

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

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

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

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

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

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

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

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

LET-type water relative permeability, [dimensionless]

Linear Spline Interpolation Algorithm. Differentiate at point t.

Linear Spline Interpolation Algorithm. Integrate up to point t.

Linear Spline Interpolation Algorithm. Integrate from point t1 up to point t2.

Linear Spline Interpolation Algorithm. Interpolate at point t.

x value of intersection point between two linear splines.

ModifiedHyperbolicDeclineCumulative

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

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

Correlation for estimating non-Darcy coefficient, [d/mscf]

Outlet pipe pressure for single phase pipe flow of gas (compressible fluid), [psia]

Outlet pipe pressure for single phase pipe flow of incompressible, Newtonian fluid, [psia]

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

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

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.

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

Dindoruk and Christman correlation for oil bubble point pressure, [psia]

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

Glaso correlation for oil bubble point pressure, [psia]

Petrosky and Farshad correlation for oil bubble point pressure, [psia]

Standing correlation for oil bubble point pressure, [psia]

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

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

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

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

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

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

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

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

PotentialEnergyPressureDropLiquid

Potential energy pressure drop; Single-phase flow of an incompressible, Newtonian fluid, [psi]

PowerLawExponentialDeclineRate

Power Law Exponential (PLE) Decline Rate-Time Relation. Units of volume [L3] and time [T] must be consistent.

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

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

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

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

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.

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.

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.

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

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

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

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

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

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

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

Proximal (Nearest-neighbor) Interpolation Algorithm. Interpolate at point t.

Dimensionless wellbore storage coefficient

Dimensionless distance

Dimensionless pressure as defined for constant-rate production

ptaRwd – Dimensionless radius

Dimensionless time

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

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

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

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

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

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

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

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

Al-Marhoun (1988) correlation for solution gas-oil ratio, P <= Pb, [scf/STB]

Dindoruk and Christman (2001) correlation for solution gas-oil ratio, P <= Pb, [scf/STB]

Glaso correlation (1980) for solution gas-oil ratio, P <= Pb, [scf/STB]

Petrosky and Farshad (1993) correlation for solution gas-oil ratio, P <= Pb, [scf/STB]

Standing correlation (1981) for solution gas-oil ratio, P <= Pb, [scf/STB]

Vasquez and Beggs (1980) correlation for solution gas-oil ratio, P <= Pb, [scf/STB]

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

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

Converts a oil specific gravity to API gravity

Step Interpolation Algorithm. Interpolate at point t.

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

Time to stabilized flow in gas well, [h]

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

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

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

Converts a number from one measurement system to another.

Egbogah (1983) correlation for dead oil viscosity, [cP]

Beggs and Robinson (1975) correlation for oil viscosity with solution gas, P < = Pb, [cP]

Vasquez and Beggs (1980) correlation for oil viscosity, P > Pb, [cP]

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

UwMcCain – McCain correlation for water viscosity, [cP]

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

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

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