Petroleum Engineering Correlations and Equations in Excel

ExponentialDeclineRate

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

ExponentialDeclineCumulative

Arps exponential 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.

HarmonicDeclineCumulative

Arps harmonic 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.

HyperbolicDeclineCumulative

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

ModifiedHyperbolicDeclineRate

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

ModifiedHyperbolicDeclineCumulative

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

PowerLawExponentialDeclineRate

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

BasicFieldProfile

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

CombinedFieldProfile

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

PboAlMarhoun

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

PboDindorukChristman

Dindoruk and Christman 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]

PboPetroskyFarshad

Petrosky and Farshad 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]

BoSatAlMarhoun1988

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

BoSatDindorukChristman2001

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

BoSatGlaso1980

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

BoSatPetrosky1990

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

BoSatStanding1947

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

BoSatVasquezBeggs1980

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

BoUSat

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

RsoAlMarhoun1988

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

RsoDindorukChristman2001

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

RsoGlaso1980

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

RsoPetroskyFarshad1993

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

RsoStanding1981

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

RsoVasquezBeggs1980

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

UodEgbogah1983

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

UoSatBeggsRobinson1975

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

UoUSatVasquezBeggs1980

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

CoSatVillenaLanzi1985

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

CoUSatVasquezBeggs1980

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

ZfactorBrillBeggs

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

ZfactorDAK

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

PpcStanding

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

PpcSutton

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

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]

BwMcCain

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

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]

CwSatMcCain

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

CwUSatOsif

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

Uw1McCain

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

UwMcCain

McCain correlation for water viscosity, [cP]

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]

FrictionPressureDropLiquid

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

InletPipePressureLiquid

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

OutletPipePressureLiquid

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

PotentialEnergyPressureDropLiquid

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

ReynoldsNumberLiquid

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

InletPipePressureGas

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

OutletPipePressureGas

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

ReynoldsNumberGas

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

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.

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.

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.

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.

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.

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.

InletPressureGray

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

OutletPressureGray

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

PressureGradientGray

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

FlowRatePSS

Pseudosteady state production flow rate, [STB/d]

FlowRatePSSVogel

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

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.

ProdIndexPSS

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

TimeToPSS

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

FlowRateSS

Steady state production flow rate, [STB/d]

FlowRateSSVogel

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

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)]

ProdIndexSS

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

FlowRateTF

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

FlowRateTFVogel

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

ProdIndexTF

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

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]

NonDarcyCoefficient

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

TimeToPSSGas

Time to stabilized flow in gas well, [h]

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]

DrainageAreaHorWell2

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

DrainageRadius

Effective drainage radius, [ft]

EffectiveWellboreRadius

Effective wellbore radius, [ft]

EquivalentSkinFactor

Equivalent skin factor for vertical well with hydraulic fracture.

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]

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.

ptaCd

Dimensionless wellbore storage coefficient

ptaLd

Dimensionless distance

ptaPd

Dimensionless pressure as defined for constant-rate production

ptaRwd

Dimensionless radius

ptaTd

Dimensionless time

KrowCorey

Corey-type oil relative permeability, [dimensionless]

KrwCorey

Corey-type water relative permeability, [dimensionless]

KrowLET

LET-type oil relative permeability, [dimensionless]

KrwLET

LET-type water relative permeability, [dimensionless]

KrowHonarpourCarbInterWet

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

KrowHonarpourCarbWaterWet

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

KrowHonarpourSandInterWet

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

KrowHonarpourSandWaterWet

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

KrwHonarpourCarbInterWet

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

KrwHonarpourCarbWaterWet

Honarpour correlation for predicting water relative permeability in water 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.

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.

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.

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

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.

CfNewmanL

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

CfNewmanS

Newman correlation for rock pore volume compressibility in sandstones, [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.