Function Category Description
1 ModifiedHyperbolicDeclineRate Decline Modified hyperbolic production decline curve: rate vs time
2 ModifiedHyperbolicDeclineCumulative Decline Modified hyperbolic production decline curve: cumulative production vs time
3 BasicFieldProfile Decline Typical field production profile, usually used for annual forecast.
4 CombinedFieldProfile Decline Field production profile based on drilling shchedule and typical well profile.
5 HyperbolicDeclineRate Decline Arps hyperbolic production decline curve: rate vs time
6 ExponentialDeclineRate Decline Arps exponential production decline curve: rate vs time
7 HarmonicDeclineRate Decline Arps harmonic production decline curve: rate vs time
8 HyperbolicDeclineCumulative Decline Arps hyperbolic production decline curve: cumulative production vs time
9 ExponentialDeclineCumulative Decline Arps exponential production decline curve: cumulative production vs time
10 HarmonicDeclineCumulative Decline Arps harmonic production decline curve: cumulative production vs time
11 PowerLawExponentialDeclineRate Decline Power Law Exponential Decline Rate-Time Relation
12 PressureGradientBeggsBrill PipeFlow Pressure gradient for multiphase pipe flow by Beggs and Brill correlation, [psi/ft] It can be applied for any wellbore inclination and flow direction.
13 InletPressureBeggsBrill PipeFlow Inlet pipe pressure for multiphase pipe flow by Beggs and Brill correlation, [psia]. It can be applied for any wellbore inclination and flow direction.
14 OutletPressureBeggsBrill PipeFlow Outlet pipe pressure for multiphase pipe flow by Beggs and Brill correlation, [psia]. It can be applied for any wellbore inclination and flow direction.
15 PressureGradientGray PipeFlow Pressure gradient for multiphase pipe flow by Gray correlation, [psi/ft] It is commonly used for gas wells that are also producing liquid.
16 InletPressureGray PipeFlow Inlet pressure for multiphase pipe flow by Gray correlation, [psi/ft] It is commonly used for gas wells that are also producing liquid.
17 OutletPressureGray PipeFlow Outlet pressure for multiphase pipe flow by Gray correlation, [psi/ft] It is commonly used for gas wells that are also producing liquid.
18 PressureGradientHarBrown PipeFlow 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.
19 InletPressureHarBrown PipeFlow Inlet pressure for multiphase pipe flow by Hagedorn and Brown correlation, [psi/ft]. It was developed for vertical, upward flow and is recommended only for near-vertical wellbores.
20 OutletPressureHarBrown PipeFlow Outlet pressure for multiphase pipe flow by Hagedorn and Brown correlation, [psi/ft]. It was developed for vertical, upward flow and is recommended only for near-vertical wellbores.
21 ReynoldsNumberGas PipeFlow Reynolds number for single phase pipe flow of gas (compressible fluid), [dimensionless]
22 InletPipePressureGas PipeFlow Inlet pipe pressure for single phase pipe flow of gas (compressible fluid), [psia]
23 OutletPipePressureGas PipeFlow Outlet pipe pressure for single phase pipe flow of gas (compressible fluid), [psia]
24 FrictionPressureDropLiquid PipeFlow Frictional pressure drop from Fanning equation; Single-phase flow of an incompressible, Newtonian fluid, [psi]
25 PotentialEnergyPressureDropLiquid PipeFlow Potential energy pressure drop; Single-phase flow of an incompressible, Newtonian fluid, [psi]
26 InletPipePressureLiquid PipeFlow Inlet pipe pressure for single phase pipe flow of incompressible, Newtonian fluid, [psia]
27 OutletPipePressureLiquid PipeFlow Outlet pipe pressure for single phase pipe flow of incompressible, Newtonian fluid, [psia]
28 ReynoldsNumberLiquid PipeFlow Reynolds number for single phase pipe flow of incompressible, Newtonian fluid, [dimensionless]
29 PdLSSIHR PTA The expression of dimensionless line source solution pressure of infinite homogeneous reservoir.
30 PdwVWIHR PTA Dimensionless wellbore pressure drop for vertical well in infinite homogenous reservoir.
31 PdwVWIHRLSFB PTA Dimensionless wellbore pressure drop for vertical well in infinite homogenous reservoir with linear sealing fault boundary.
32 PdwVWIHRLCPB PTA Dimensionless wellbore pressure drop for vertical well in infinite homogenous reservoir with linear constant pressure boundary.
33 PdwVWIHRPSFB PTA Dimensionless wellbore pressure drop for vertical well in infinite homogenous reservoir with perpendicular sealing faults boundary.
34 PdwVWIHRPCPB PTA Dimensionless wellbore pressure drop for vertical well in infinite homogenous reservoir with perpendicular constant pressures boundary.
35 PdwVWIHRPMB PTA Dimensionless wellbore pressure drop for vertical well in infinite homogenous reservoir with perpendicular mixed boundaries (boundary 1 - fault, boundary 2 - constant pressure).
36 PwVWIHR PTA Wellbore pressure drop for vertical well in infinite homogenous reservoir, [psi]
37 PwVWIHRLSFB PTA Wellbore pressure drop for vertical well in infinite homogenous reservoir with linear sealing fault boundary, [psi]
38 PwVWIHRLCPB PTA Wellbore pressure drop for vertical well in infinite homogenous reservoir with linear constant pressure boundary, [psi]
39 PwVWIHRPSFB PTA Wellbore pressure drop for vertical well in infinite homogenous reservoir with perpendicular sealing faults boundary, [psi]
40 PwVWIHRPCPB PTA Wellbore pressure drop for vertical well in infinite homogenous reservoir with perpendicular constant pressures boundary, [psi]
41 PwVWIHRPMB PTA Wellbore pressure drop for vertical well in infinite homogenous reservoir with perpendicular mixed boundaries (boundary 1 - fault, boundary 2 - constant pressure), [psi]
42 ptaPd PTA Dimensionless pressure as defined for constant-rate production
43 ptaTd PTA Dimensionless time
44 ptaRwd PTA Dimensionless radius
45 ptaLd PTA Dimensionless distance
46 ptaCd PTA Dimensionless wellbore storage coefficient
47 IFTgoBakerSwerdloff PVT Interfacial (surface) tension for live oil by Baker and Swerdloff correlation, [dymes/cm]
48 IFTgoAbdulMajeed PVT Interfacial (surface) tension for live oil by Abdul-Majeed correlation, [dymes/cm]
49 GasDensity PVT Gas density, [g/cc]
50 Cg PVT Gas compressibility, [1/psi]
51 Bg PVT Gas formation volume factor, [rcf/scf]
52 UgLGE PVT Lee, Gonzales and Eakin correlation for gas viscosity, [cP]
53 TpcSutton PVT Sutton correlation for preudo-critical temperature of hydrocarbon gas, [degR]
54 TpcStanding PVT Standing correlation for preudo-critical temperature of hydrocarbon gas, [degR]
55 PpcSutton PVT Sutton correlation for preudo-critical pressure of hydrocarbon gas, [psia]
56 PpcStanding PVT Standing correlation for preudo-critical pressure of hydrocarbon gas, [psia]
57 ZfactorBrillBeggs PVT Brill and Beggs correlation for gas compressibility factor (Z), [dimensionless]
58 ZfactorDAK PVT Gas compressibility factor (Z) based on Dranchuk and Abou-Kassem EoS, [dimensionless]
59 BoSat PVT Oil formation volume factor, P > Pb, [bbl/STB]
60 BoUSatStanding PVT Standing correlation for oil formation volume factor, P <= Pb, [bbl/STB]
61 BoUSatVasquezBeggs PVT Vasquez and Beggs correlation for oil formation volume factor, P <= Pb, [bbl/STB]
62 BoUSatGlaso PVT Glaso correlation for oil formation volume factor, P <= Pb, [bbl/STB]
63 BoUSatAlMarhoun PVT Al-Marhoun correlation for oil formation volume factor, P <= Pb, [bbl/STB]
64 BoUSatPetroskyFarshad PVT Petrosky and Farshad correlation for oil formation volume factor, P <= Pb, [bbl/STB]
65 BoUSatDindorukChristman PVT Dindoruk and Christman correlation for oil formation volume factor, P <= Pb, [bbl/STB]
66 CoSatVasquezBeggs PVT Vasquez and Beggs correlation for oil compressibility, P > Pb, [1/psi]
67 CoUSatVillenaLanzi PVT Villena-Lanzi correlation for oil compressibility, P <= Pb, [1/psi]
68 PboStanding PVT Standing correlation for oil bubble point pressure, [psia]
69 PboVasquezBeggs PVT Vasquez and Beggs correlation for oil bubble point pressure, [psia]
70 PboGlaso PVT Glaso correlation for oil bubble point pressure, [psia]
71 PboAlMarhoun PVT Al-Marhoun correlation for oil bubble point pressure, [psia]
72 PboPetroskyFarshad PVT Petrosky and Farshad correlation for oil bubble point pressure, [psia]
73 PboDoklaOsman PVT Dokla and Osman correlation for oil bubble point pressure, [psia]
74 PboDindorukChristman PVT Dindoruk and Christman correlation for oil bubble point pressure, [psia]
75 RsoUSatStanding PVT Standing correlation for solution gas-oil ratio, P <= Pb, [scf/STB]
76 RsoUSatVasquezBeggs PVT Vasquez and Beggs correlation for solution gas-oil ratio, P <= Pb, [scf/STB]
77 RsoUSatGlaso PVT Glaso correlation for solution gas-oil ratio, P <= Pb, [scf/STB]
78 RsoUSatAlMarhoun PVT Al-Marhoun correlation for solution gas-oil ratio, P <= Pb, [scf/STB]
79 RsoUSatPetroskyFarshad PVT Petrosky and Farshad correlation for solution gas-oil ratio, P <= Pb, [scf/STB]
80 RsoUSatDindorukChristman PVT Dindoruk and Christman correlation for solution gas-oil ratio, P <= Pb, [scf/STB]
81 UoSatVasquezBeggs PVT Vasquez and Beggs correlation for oil viscosity, P > Pb, [cP]
82 UodEgbogah PVT Egbogah correlation for dead oil viscosity, [cP]
83 UoUSatBeggsRobinson PVT Beggs and Robinson correlation for oil viscosity with solution gas, P < = Pb, [cP]
84 CfNewmanS PVT Newman correlation for rock pore volume compressibility in sandstones, [1/psi]
85 CfNewmanL PVT Newman correlation for rock pore volume compressibility in limestones, [1/psi]
86 BwMcCain PVT McCain correlation for water formation volume factor, [bbl/STB]
87 RswpMcCain PVT McCain correlation for solution gas-water ratio for pure water, [scf/STB]
88 RswMcCain PVT McCain correlation for solution gas-water ratio for reservoir water, [scf/STB]
89 CwSatOsif PVT Osif correlation for water compressibility, P >= Pb, [1/psi]
90 CwUSatMcCain PVT McCain correlation for water compressibility, P <= Pb, [1/psi]
91 Uw1McCain PVT McCain correlation for water viscosity at atmospheric pressure and reservoir temperature, [cP]
92 UwMcCain PVT McCain correlation for water viscosity, [cP]
93 KrgIKGasOilCarb SCAL Ibrahim-Koederitz correlation for predicting oil relative to gas permeability in carbonate.
94 KrgwIKGasWater SCAL Ibrahim-Koederitz correlation for predicting relative permeability of gas with respect to water.
95 KrwIKGasWater SCAL Ibrahim-Koederitz correlation for predicting water relative permeability in gas-water system.
96 KrowIKSandStrongWaterWet SCAL Ibrahim-Koederitz correlation for predicting oil relative permeability in strongly water-wet sandstone.
97 KrwIKSandStrongWaterWet SCAL Ibrahim-Koederitz correlation for predicting water relative permeability in strongly water-wet sandstone.
98 KrowIKCarbStrongWaterWet SCAL Ibrahim-Koederitz correlation for predicting oil relative permeability in strongly water-wet carbonate.
99 KrwIKCarbStrongWaterWet SCAL Ibrahim-Koederitz correlation for predicting water relative permeability in strongly water-wet carbonate.
100 KrowIKSandWaterWet SCAL Ibrahim-Koederitz correlation for predicting oil relative permeability in water-wet sandstone.
101 KrwIKSandWaterWet SCAL Ibrahim-Koederitz correlation for predicting water relative permeability in water-wet sandstone.
102 KrowIKCarbWaterWet SCAL Ibrahim-Koederitz correlation for predicting oil relative permeability in water-wet carbonate.
103 KrwIKCarbWaterWet SCAL Ibrahim-Koederitz correlation for predicting water relative permeability in water-wet carbonate.
104 KrowIKSandInterWet SCAL Ibrahim-Koederitz correlation for predicting oil relative permeability in intermediate-wet sandstone.
105 KrwIKSandInterWet SCAL Ibrahim-Koederitz correlation for predicting water relative permeability in intermediate-wet sandstone.
106 KrowIKCarbInterWet SCAL Ibrahim-Koederitz correlation for predicting oil relative permeability in intermediate-wet carbonate.
107 KrwIKCarbInterWet SCAL Ibrahim-Koederitz correlation for predicting water relative permeability in intermediate-wet carbonate.
108 KrowIKSandOilWet SCAL Ibrahim-Koederitz correlation for predicting oil relative permeability in oil-wet sandstone.
109 KrwIKSandOilWet SCAL Ibrahim-Koederitz correlation for predicting water relative permeability in oil-wet sandstone.
110 KrowIKCarbOilWet SCAL Ibrahim-Koederitz correlation for predicting oil relative permeability in oil-wet carbonate.
111 KrwIKCarbOilWet SCAL Ibrahim-Koederitz correlation for predicting water relative permeability in oil-wet carbonate.
112 KrowLET SCAL LET-type oil relative permeability, [dimensionless]
113 KrwLET SCAL LET-type water relative permeability, [dimensionless]
114 KrowCorey SCAL Corey-type oil relative permeability, [dimensionless]
115 KrwCorey SCAL Corey-type water relative permeability, [dimensionless]
116 KrwHonarpourSandWaterWet SCAL Honarpour correlation for predicting water relative permeability in water wet sandstone and conglomerate.
117 KrwHonarpourSandInterWet SCAL Honarpour correlation for predicting water relative permeability in intermediately wet sandstone and conglomerate.
118 KrowHonarpourSandAnyWet SCAL Honarpour correlation for predicting oil relative permeability in sandstone and conglomerate with any wettability.
119 KrwHonarpourCarbWaterWet SCAL Honarpour correlation for predicting water relative permeability in water wet limestone and dolomite.
120 KrwHonarpourCarbInterWet SCAL Honarpour correlation for predicting water relative permeability in intermediately wet limestone and dolomite.
121 KrowHonarpourCarbAnyWet SCAL Honarpour correlation for predicting oil relative permeability in limestone and dolomite with any wettability.
122 KrcgIKGasCond SCAL Ibrahim-Koederitz correlation for predicting relative permeability of condensate with respect to gas.
123 KrgIKGasCond SCAL Ibrahim-Koederitz correlation for predicting gas relative permeability in gas-condensate system.
124 KrogIKGasOilSand SCAL Ibrahim-Koederitz correlation for predicting oil relative to gas permeability in sandstone.
125 KrgIKGasOilSand SCAL Ibrahim-Koederitz correlation for predicting oil relative to gas permeability in sandstone.
126 KrogIKGasOilCarb SCAL Ibrahim-Koederitz correlation for predicting oil relative to gas permeability in carbonate.
127 CubicSplineInterpolate Utilities A natural cubic spline with continuous second derivative in the interior and zero second derivative at the end points. Interpolate at point t.
128 CubicSplineDifferentiate Utilities A natural cubic spline with continuous second derivative in the interior and zero second derivative at the end points. Differentiate at point t.
129 CubicSplineIntegrate Utilities A natural cubic spline with continuous second derivative in the interior and zero second derivative at the end points. Integrate up to point t.
130 CubicSplineIntegrateT1T2 Utilities 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.
131 CubicSplinesIntersection Utilities x value of intersection point between two cubic splines.
132 LinearSplineInterpolate Utilities Linear Spline Interpolation Algorithm. Interpolate at point t.
133 LinearSplineDifferentiate Utilities Linear Spline Interpolation Algorithm. Differentiate at point t.
134 LinearSplineIntegrate Utilities Linear Spline Interpolation Algorithm. Integrate up to point t.
135 LinearSplineIntegrateT1T2 Utilities Linear Spline Interpolation Algorithm. Integrate from point t1 up to point t2.
136 LinearSplinesIntersection Utilities x value of intersection point between two linear splines.
137 DataDifferentiate Utilities Derrivative of for data samples at point t with smoothing.
138 ExpIntegralEi Utilities The exponential integral function - Ei(x)
139 ProximalInterpolate Utilities Proximal (Nearest-neighbor) Interpolation Algorithm. Interpolate at point t.
140 StepInterpolate Utilities Step Interpolation Algorithm. Interpolate at point t.
141 UnitConverter Utilities Converts a number from one measurement system to another.
142 SG2API Utilities Converts a oil specific gravity to API gravity
143 API2SG Utilities Converts a API gravity to oil specific gravity (water=1.0)
144 GasFlowRatePSS WellFlow Gas well flow rate for pseudosteady state condition using Darcy flow approximation, [mscf/d]
145 GasFlowRatePSSNonDarcy WellFlow Gas well stabilized flow rate for pseudosteady state condition, with Non-Darcy flow equation, [mscf/d]
146 TimeToPSSGas WellFlow Time to stabilized flow in gas well, [h]
147 NonDarcyCoefficient WellFlow Correlation for estimating non-Darcy coefficient, [d/mscf]
148 DrainageRadius WellFlow Effective drainage radius, [ft]
149 DrainageAreaHorWell1 WellFlow 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]
150 DrainageAreaHorWell2 WellFlow The horizontal well drainage area is an ellipse. (Joshi Method 2), [acres]
151 EffectiveWellboreRadius WellFlow Effective wellbore radius, [ft]
152 EquivalentSkinFactor WellFlow Equivalent skin factor for vertical well with hydraulic fracture.
153 FlowRateTFVogel WellFlow Vogel inflow performance for transient-state flow, [STB/d]
154 FlowRateTF WellFlow Transient-state production flow rate, [STB/d]
155 ProdIndexTF WellFlow Transient state productivity index for vertical well, [STB/(d.psi)]
156 FlowRatePSSVogel WellFlow Vogel inflow performance for pseudosteady state flow, [STB/d]
157 FlowRatePSS WellFlow Pseudosteady state production flow rate, [STB/d]
158 TimeToPSS WellFlow Time to pseudosteady state for regular shape drainage area, [h]
159 ProdIndexPSS WellFlow Pseudosteady state productivity index for vertical well, [STB/(d.psi)]
160 FlowRateSSVogel WellFlow Vogel inflow performance for Steady state flow, [STB/d]
161 FlowRateSS WellFlow Steady state production flow rate, [STB/d]
162 ProdIndexSS WellFlow Steady state productivity index for vertical well, [STB/(d.psi)]
163 ProdIndexHorWellBorisov WellFlow Horizontal well productivity index under steady state flow. Borisov method for well in an isotropic reservoir, [STB/(d.psi)]
164 ProdIndexHorWellGRJ WellFlow Horizontal well productivity index under steady state flow. The Giger-Reiss-Jourdan method for well in an anisotropic reservoir, [STB/(d.psi)]
165 ProdIndexHorWellJoshi WellFlow Horizontal well productivity index under steady state flow. The Joshi method for well in an anisotropic reservoir, [STB/(d.psi)]
166 ProdIndexHorWellRD WellFlow Horizontal well productivity index under steady state flow. The Renard-Dupuy method for well in an anisotropic reservoir, [STB/(d.psi)]
167 ProdIndexHorWellBO WellFlow 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.
168 ProdIndexHorWellBO2 WellFlow 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.