168 functions are available in Petroleum Office Excel Addin

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. |