Function Category Description
1 HyperbolicDeclineRate Decline Arps hyperbolic production decline curve: rate vs time. Units of volume [L3] and time [T] must be consistent.
2 ExponentialDeclineRate Decline Arps exponential production decline curve: rate vs time. Units of volume [L3] and time [T] must be consistent.
3 HarmonicDeclineRate Decline Arps harmonic production decline curve: rate vs time. Units of volume [L3] and time [T] must be consistent.
4 HyperbolicDeclineCumulative Decline Arps hyperbolic production decline curve: cumulative production vs time. Units of volume [L3] and time [T] must be consistent.
5 ExponentialDeclineCumulative Decline Arps exponential production decline curve: cumulative production vs time. Units of volume [L3] and time [T] must be consistent.
6 HarmonicDeclineCumulative Decline Arps harmonic production decline curve: cumulative production vs time. Units of volume [L3] and time [T] must be consistent.
7 BasicFieldProfile Decline Typical field production profile. Units of volume [L3] and time [T] must be consistent.
8 CombinedFieldProfile Decline Field production profile based on drilling schedule and typical well profile.
9 ModifiedHyperbolicDeclineRate Decline Modified hyperbolic production decline curve: rate vs time. Units of volume [L3] and time [T] must be consistent.
10 ModifiedHyperbolicDeclineCumulative Decline Modified hyperbolic production decline curve: cumulative production vs time. Units of volume [L3] and time [T] must be consistent.
11 PowerLawExponentialDeclineRate Decline Power Law Exponential (PLE) Decline Rate-Time Relation. Units of volume [L3] and time [T] must be consistent.
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, [psia] It is commonly used for gas wells that are also producing liquid.
17 OutletPressureGray PipeFlow Outlet pressure for multiphase pipe flow by Gray correlation, [psia] 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, [psia]. 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, [psia]. 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 ReynoldsNumberLiquid PipeFlow Reynolds number for single phase pipe flow of incompressible, Newtonian fluid, [dimensionless]
25 FrictionPressureDropLiquid PipeFlow Frictional pressure drop from Fanning equation; Single-phase flow of an incompressible, Newtonian fluid, [psi]
26 PotentialEnergyPressureDropLiquid PipeFlow Potential energy pressure drop; Single-phase flow of an incompressible, Newtonian fluid, [psi]
27 InletPipePressureLiquid PipeFlow Inlet pipe pressure for single phase pipe flow of incompressible, Newtonian fluid, [psia]
28 OutletPipePressureLiquid PipeFlow Outlet pipe pressure for single phase pipe flow of incompressible, Newtonian fluid, [psia]
29 ptaPd PTA Dimensionless pressure as defined for constant-rate production
30 ptaTd PTA Dimensionless time
31 ptaRwd PTA Dimensionless radius
32 ptaLd PTA Dimensionless distance
33 ptaCd PTA Dimensionless wellbore storage coefficient
34 PdLSSIHR PTA The expression of dimensionless line source solution pressure of infinite homogeneous reservoir.
35 PdwVWIHR PTA Dimensionless wellbore pressure drop for vertical well in infinite homogenous reservoir.
36 PdwVWIHRLSFB PTA Dimensionless wellbore pressure drop for vertical well in infinite homogenous reservoir with linear sealing fault boundary.
37 PdwVWIHRLCPB PTA Dimensionless wellbore pressure drop for vertical well in infinite homogenous reservoir with linear constant pressure boundary.
38 PdwVWIHRPSFB PTA Dimensionless wellbore pressure drop for vertical well in infinite homogenous reservoir with perpendicular sealing faults boundary.
39 PdwVWIHRPCPB PTA Dimensionless wellbore pressure drop for vertical well in infinite homogenous reservoir with perpendicular constant pressures boundary.
40 PdwVWIHRPMB PTA Dimensionless wellbore pressure drop for vertical well in infinite homogenous reservoir with perpendicular mixed boundaries (boundary 1 - fault, boundary 2 - constant pressure).
41 PwVWIHR PTA Wellbore pressure drop for vertical well in infinite homogenous reservoir, [psi]
42 PwVWIHRLSFB PTA Wellbore pressure drop for vertical well in infinite homogenous reservoir with linear sealing fault boundary, [psi]
43 PwVWIHRLCPB PTA Wellbore pressure drop for vertical well in infinite homogenous reservoir with linear constant pressure boundary, [psi]
44 PwVWIHRPSFB PTA Wellbore pressure drop for vertical well in infinite homogenous reservoir with perpendicular sealing faults boundary, [psi]
45 PwVWIHRPCPB PTA Wellbore pressure drop for vertical well in infinite homogenous reservoir with perpendicular constant pressures boundary, [psi]
46 PwVWIHRPMB PTA Wellbore pressure drop for vertical well in infinite homogenous reservoir with perpendicular mixed boundaries (boundary 1 - fault, boundary 2 - constant pressure), [psi]
47 BwMcCain PVT McCain correlation for water formation volume factor, [bbl/STB]
48 RswpMcCain PVT McCain correlation for solution gas-water ratio for pure water, [scf/STB]
49 RswMcCain PVT McCain correlation for solution gas-water ratio for reservoir water, [scf/STB]
50 CwSatOsif PVT Osif correlation for water compressibility, P >= Pb, [1/psi]
51 CwUSatMcCain PVT McCain correlation for water compressibility, P <= Pb, [1/psi]
52 Uw1McCain PVT McCain correlation for water viscosity at atmospheric pressure and reservoir temperature, [cP]
53 UwMcCain PVT McCain correlation for water viscosity, [cP]
54 GasDensity PVT Gas density, [g/cc]
55 Cg PVT Gas compressibility, [1/psi]
56 Bg PVT Gas formation volume factor, [rcf/scf]
57 PpcSutton PVT Sutton correlation for preudo-critical pressure of hydrocarbon gas, [psia]
58 PpcStanding PVT Standing correlation for preudo-critical pressure of hydrocarbon gas, [psia]
59 TpcSutton PVT Sutton correlation for preudo-critical temperature of hydrocarbon gas, [degR]
60 TpcStanding PVT Standing correlation for preudo-critical temperature of hydrocarbon gas, [degR]
61 UgLGE PVT Lee, Gonzales and Eakin correlation for gas viscosity, [cP]
62 ZfactorBrillBeggs PVT Brill and Beggs correlation for gas compressibility factor (Z), [dimensionless]
63 ZfactorDAK PVT Gas compressibility factor (Z) based on Dranchuk and Abou-Kassem EoS, [dimensionless]
64 IFTgoBakerSwerdloff PVT Interfacial (surface) tension for live oil by Baker and Swerdloff correlation, [dymes/cm]
65 IFTgoAbdulMajeed PVT Interfacial (surface) tension for live oil by Abdul-Majeed correlation, [dymes/cm]
66 BoSat PVT Oil formation volume factor, P > Pb, [bbl/STB]
67 BoUSatStanding PVT Standing correlation for oil formation volume factor, P <= Pb, [bbl/STB]
68 BoUSatVasquezBeggs PVT Vasquez and Beggs correlation for oil formation volume factor, P <= Pb, [bbl/STB]
69 BoUSatGlaso PVT Glaso correlation for oil formation volume factor, P <= Pb, [bbl/STB]
70 BoUSatAlMarhoun PVT Al-Marhoun correlation for oil formation volume factor, P <= Pb, [bbl/STB]
71 BoUSatPetroskyFarshad PVT Petrosky and Farshad correlation for oil formation volume factor, P <= Pb, [bbl/STB]
72 BoUSatDindorukChristman PVT Dindoruk and Christman correlation for oil formation volume factor, P <= Pb, [bbl/STB]
73 CoSatVasquezBeggs PVT Vasquez and Beggs correlation for oil compressibility, P > Pb, [1/psi]
74 CoUSatVillenaLanzi PVT Villena-Lanzi correlation for oil compressibility, P <= Pb, [1/psi]
75 PboStanding PVT Standing correlation for oil bubble point pressure, [psia]
76 PboVasquezBeggs PVT Vasquez and Beggs correlation for oil bubble point pressure, [psia]
77 PboGlaso PVT Glaso correlation for oil bubble point pressure, [psia]
78 PboAlMarhoun PVT Al-Marhoun correlation for oil bubble point pressure, [psia]
79 PboPetroskyFarshad PVT Petrosky and Farshad correlation for oil bubble point pressure, [psia]
80 PboDoklaOsman PVT Dokla and Osman correlation for oil bubble point pressure, [psia]
81 PboDindorukChristman PVT Dindoruk and Christman correlation for oil bubble point pressure, [psia]
82 RsoUSatStanding PVT Standing correlation for solution gas-oil ratio, P <= Pb, [scf/STB]
83 RsoUSatVasquezBeggs PVT Vasquez and Beggs correlation for solution gas-oil ratio, P <= Pb, [scf/STB]
84 RsoUSatGlaso PVT Glaso correlation for solution gas-oil ratio, P <= Pb, [scf/STB]
85 RsoUSatAlMarhoun PVT Al-Marhoun correlation for solution gas-oil ratio, P <= Pb, [scf/STB]
86 RsoUSatPetroskyFarshad PVT Petrosky and Farshad correlation for solution gas-oil ratio, P <= Pb, [scf/STB]
87 RsoUSatDindorukChristman PVT Dindoruk and Christman correlation for solution gas-oil ratio, P <= Pb, [scf/STB]
88 UoSatVasquezBeggs PVT Vasquez and Beggs correlation for oil viscosity, P > Pb, [cP]
89 UodEgbogah PVT Egbogah correlation for dead oil viscosity, [cP]
90 UoUSatBeggsRobinson PVT Beggs and Robinson correlation for oil viscosity with solution gas, P < = Pb, [cP]
91 CfNewmanS PVT Newman correlation for rock pore volume compressibility in sandstones, [1/psi]
92 CfNewmanL PVT Newman correlation for rock pore volume compressibility in limestones, [1/psi]
93 KrowCorey SCAL Corey-type oil relative permeability, [dimensionless]
94 KrwCorey SCAL Corey-type water relative permeability, [dimensionless]
95 KrowHonarpourSandWaterWet SCAL Honarpour correlation for predicting oil relative permeability in water wet sandstone and conglomerate.
96 KrwHonarpourSandWaterWet SCAL Honarpour correlation for predicting water relative permeability in water wet sandstone and conglomerate.
97 KrowHonarpourSandInterWet SCAL Honarpour correlation for predicting oil relative permeability in intermediately wet sandstone and conglomerate.
98 KrwHonarpourSandInterWet SCAL Honarpour correlation for predicting water relative permeability in intermediately wet sandstone and conglomerate.
99 KrwHonarpourCarbWaterWet SCAL Honarpour correlation for predicting water relative permeability in water wet limestone and dolomite.
100 KrowHonarpourCarbWaterWet SCAL Honarpour correlation for predicting oil relative permeability in water wet limestone and dolomite.
101 KrwHonarpourCarbInterWet SCAL Honarpour correlation for predicting water relative permeability in intermediately wet limestone and dolomite.
102 KrowHonarpourCarbInterWet SCAL Honarpour correlation for predicting oil relative permeability in intermediately wet limestone and dolomite.
103 KrcgIKGasCond SCAL Ibrahim-Koederitz correlation for predicting relative permeability of condensate with respect to gas.
104 KrgIKGasCond SCAL Ibrahim-Koederitz correlation for predicting gas relative permeability in gas-condensate system.
105 KrogIKGasOilSand SCAL Ibrahim-Koederitz correlation for predicting oil relative to gas permeability in sandstone.
106 KrgIKGasOilSand SCAL Ibrahim-Koederitz correlation for predicting gas relative permeability in gas-oil system in sandstone.
107 KrogIKGasOilCarb SCAL Ibrahim-Koederitz correlation for predicting oil relative to gas permeability in carbonate.
108 KrgIKGasOilCarb SCAL Ibrahim-Koederitz correlation for predicting gas relative permeability in gas-oil system in carbonate.
109 KrgwIKGasWater SCAL Ibrahim-Koederitz correlation for predicting relative permeability of gas with respect to water.
110 KrwIKGasWater SCAL Ibrahim-Koederitz correlation for predicting water relative permeability in gas-water system.
111 KrowIKSandStrongWaterWet SCAL Ibrahim-Koederitz correlation for predicting oil relative permeability in strongly water-wet sandstone.
112 KrwIKSandStrongWaterWet SCAL Ibrahim-Koederitz correlation for predicting water relative permeability in strongly water-wet sandstone.
113 KrowIKCarbStrongWaterWet SCAL Ibrahim-Koederitz correlation for predicting oil relative permeability in strongly water-wet carbonate.
114 KrwIKCarbStrongWaterWet SCAL Ibrahim-Koederitz correlation for predicting water relative permeability in strongly water-wet carbonate.
115 KrowIKSandWaterWet SCAL Ibrahim-Koederitz correlation for predicting oil relative permeability in water-wet sandstone.
116 KrwIKSandWaterWet SCAL Ibrahim-Koederitz correlation for predicting water relative permeability in water-wet sandstone.
117 KrowIKCarbWaterWet SCAL Ibrahim-Koederitz correlation for predicting oil relative permeability in water-wet carbonate.
118 KrwIKCarbWaterWet SCAL Ibrahim-Koederitz correlation for predicting water relative permeability in water-wet carbonate.
119 KrowIKSandInterWet SCAL Ibrahim-Koederitz correlation for predicting oil relative permeability in intermediate-wet sandstone.
120 KrwIKSandInterWet SCAL Ibrahim-Koederitz correlation for predicting water relative permeability in intermediate-wet sandstone.
121 KrowIKCarbInterWet SCAL Ibrahim-Koederitz correlation for predicting oil relative permeability in intermediate-wet carbonate.
122 KrwIKCarbInterWet SCAL Ibrahim-Koederitz correlation for predicting water relative permeability in intermediate-wet carbonate.
123 KrowIKSandOilWet SCAL Ibrahim-Koederitz correlation for predicting oil relative permeability in oil-wet sandstone.
124 KrwIKSandOilWet SCAL Ibrahim-Koederitz correlation for predicting water relative permeability in oil-wet sandstone.
125 KrowIKCarbOilWet SCAL Ibrahim-Koederitz correlation for predicting oil relative permeability in oil-wet carbonate.
126 KrwIKCarbOilWet SCAL Ibrahim-Koederitz correlation for predicting water relative permeability in oil-wet carbonate.
127 KrowLET SCAL LET-type oil relative permeability, [dimensionless]
128 KrwLET SCAL LET-type water relative permeability, [dimensionless]
129 UnitConverter Utilities Converts a number from one measurement system to another.
130 SG2API Utilities Converts a oil specific gravity to API gravity
131 API2SG Utilities Converts a API gravity to oil specific gravity (water=1.0)
132 DataDifferentiate Utilities Derrivative of for data samples at point t with smoothing.
133 ExpIntegralEi Utilities The exponential integral function - Ei(x)
134 ProximalInterpolate Utilities Proximal (Nearest-neighbor) Interpolation Algorithm. Interpolate at point t.
135 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.
136 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.
137 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.
138 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.
139 CubicSplinesIntersection Utilities x value of intersection point between two cubic splines.
140 LinearSplineInterpolate Utilities Linear Spline Interpolation Algorithm. Interpolate at point t.
141 LinearSplineDifferentiate Utilities Linear Spline Interpolation Algorithm. Differentiate at point t.
142 LinearSplineIntegrate Utilities Linear Spline Interpolation Algorithm. Integrate up to point t.
143 LinearSplineIntegrateT1T2 Utilities Linear Spline Interpolation Algorithm. Integrate from point t1 up to point t2.
144 LinearSplinesIntersection Utilities x value of intersection point between two linear splines.
145 StepInterpolate Utilities Step Interpolation Algorithm. Interpolate at point t.
146 GasFlowRatePSS WellFlow Gas well flow rate for pseudosteady state condition using Darcy flow approximation, [mscf/d]
147 GasFlowRatePSSNonDarcy WellFlow Gas well stabilized flow rate for pseudosteady state condition, with Non-Darcy flow equation, [mscf/d]
148 TimeToPSSGas WellFlow Time to stabilized flow in gas well, [h]
149 NonDarcyCoefficient WellFlow Correlation for estimating non-Darcy coefficient, [d/mscf]
150 ProdIndexHorWellBorisov WellFlow Horizontal well productivity index under steady state flow. Borisov method for well in an isotropic reservoir, [STB/(d.psi)]
151 ProdIndexHorWellGRJ WellFlow Horizontal well productivity index under steady state flow. The Giger-Reiss-Jourdan method for well in an anisotropic reservoir, [STB/(d.psi)]
152 ProdIndexHorWellJoshi WellFlow Horizontal well productivity index under steady state flow. The Joshi method for well in an anisotropic reservoir, [STB/(d.psi)]
153 ProdIndexHorWellRD WellFlow Horizontal well productivity index under steady state flow. The Renard-Dupuy method for well in an anisotropic reservoir, [STB/(d.psi)]
154 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.
155 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.
156 DrainageRadius WellFlow Effective drainage radius, [ft]
157 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]
158 DrainageAreaHorWell2 WellFlow The horizontal well drainage area is an ellipse. (Joshi Method 2), [acres]
159 EffectiveWellboreRadius WellFlow Effective wellbore radius, [ft]
160 EquivalentSkinFactor WellFlow Equivalent skin factor for vertical well with hydraulic fracture.
161 FlowRatePSSVogel WellFlow Vogel inflow performance for pseudosteady state flow, [STB/d]
162 FlowRatePSS WellFlow Pseudosteady state production flow rate, [STB/d]
163 TimeToPSS WellFlow Time to pseudosteady state for regular shape drainage area, [h]
164 ProdIndexPSS WellFlow Pseudosteady state productivity index for vertical well, [STB/(d.psi)]
165 FlowRateSSVogel WellFlow Vogel inflow performance for Steady state flow, [STB/d]
166 FlowRateSS WellFlow Steady state production flow rate, [STB/d]
167 ProdIndexSS WellFlow Steady state productivity index for vertical well, [STB/(d.psi)]
168 FlowRateTFVogel WellFlow Vogel inflow performance for transient-state flow, [STB/d]
169 FlowRateTF WellFlow Transient-state production flow rate, [STB/d]
170 ProdIndexTF WellFlow Transient state productivity index for vertical well, [STB/(d.psi)]