Well Performance Functions
Inflow performance and multiphase tubing flow — the two sides of the nodal analysis point.
68 functions
PO.IPR.VW.SS.Rate
Calculates steady state production flow rate, [bbl/D].
PO.IPR.VW.SS.Rate.ByVogel
Calculates Vogel inflow performance for steady state flow, [bbl/D].
PO.IPR.VW.SS.PI
Calculates steady state productivity index for vertical well, [bbl/(D.psi)].
PO.IPR.VW.PSS.Rate
Calculates pseudosteady state production flow rate, [bbl/D].
PO.IPR.VW.PSS.Rate.ByVogel
Calculates Vogel inflow performance for pseudosteady state flow, [bbl/D].
PO.IPR.VW.PSS.Rate.ByFetkovich
Calculates Fetkovich backpressure IPR flow rate for oil, [STB/d]. Fetkovich (1973) correlation.
PO.IPR.VW.PSS.AOF.ByFetkovich
Calculates Fetkovich maximum flow rate (AOF) at Pwf = 0, [STB/d]. Fetkovich (1973) correlation.
PO.IPR.VW.PSS.Rate.ByKlins
Calculates Klins-Clark modified Vogel IPR flow rate for oil, [STB/d]. Klins & Clark (1993) correlation.
PO.IPR.VW.Klins.d
Calculates Klins-Clark pressure-dependent exponent d, [dimensionless]. Klins & Clark (1993) correlation.
PO.IPR.VW.PSS.Time
Calculates time to reach pseudosteady state for oil well with regular-shaped drainage area, [h].
PO.IPR.VW.PSS.PI
Calculates pseudosteady state productivity index for vertical well, [bbl/(D.psi)].
PO.IPR.VW.TF.Rate
Calculates transient-state production flow rate, [bbl/D].
PO.IPR.VW.TF.Rate.ByVogel
Calculates Vogel inflow performance for transient-state flow, [bbl/D].
PO.IPR.VW.TF.PI
Calculates transient state productivity index for vertical well, [bbl/(D.psi)].
PO.IPR.HW.SS.PI.ByBorisov
Calculates steady state productivity index for horizontal well using Borisov method (isotropic reservoir), [STB/(d.psi)].
PO.IPR.HW.SS.PI.ByGRJ
Calculates steady state productivity index for horizontal well using Giger-Reiss-Jourdan method (anisotropic reservoir), [STB/(d.psi)].
PO.IPR.HW.SS.PI.ByJoshi
Calculates steady state productivity index for horizontal well using Joshi method (anisotropic reservoir), [STB/(d.psi)].
PO.IPR.HW.SS.PI.ByRenardDupuy
Calculates steady state productivity index for horizontal well using Renard-Dupuy method (anisotropic reservoir), [STB/(d.psi)].
PO.IPR.HW.SS.PI.ByEconomides
Calculates steady state productivity index for horizontal well using Economides-Brand-Frick model (anisotropic reservoir, rectangular drainage), [STB/(d.psi)]. Economides et al. (1994) correlation.
PO.IPR.HW.SS.PI.ByEconomides.Centered
Calculates steady state productivity index for horizontal well using Economides model for centered well (Zw = h/2), [STB/(d.psi)]. Economides et al. (1994) correlation.
PO.IPR.HW.PSS.PI.ByBabuOdeh
Calculates pseudosteady state productivity index for horizontal well using Babu-Odeh method for a box-shaped, anisotropic reservoir, with a well placed parallel to X(box length)-direction, [STB/(d.psi)].
PO.IPR.HW.PSS.PI.ByBabuOdeh.Centered
Calculates pseudosteady state productivity index for horizontal well using Babu-Odeh method for a box-shaped, anisotropic reservoir, with a well centrally placed parallel to X(box length)-direction, [STB/(d.psi)].
PO.IPR.GW.PSS.Time
Calculates time to reach pseudosteady state (stabilized flow boundary) in gas well, [h].
PO.IPR.GW.PSS.Rate
Calculates gas well flow rate for pseudosteady state condition using Darcy flow approximation, [mscf/D].
PO.IPR.GW.PSS.Rate.NonDarcy
Calculates gas well stabilized flow rate for pseudosteady state condition with Non-Darcy flow equation, [mscf/D].
PO.IPR.GW.D
Calculates Non-Darcy flow coefficient (D) for gas well turbulence effects, [D/mscf]. Used as input to GW.PSS.Rate.NonDarcy.
PO.IPR.Re
Calculates effective drainage radius, [ft].
PO.IPR.HW.DrainArea.Rect
Calculates horizontal well drainage area using two half-circles at ends plus rectangle (Joshi), [acres].
PO.IPR.HW.DrainArea.Ellipse
Calculates horizontal well drainage area using ellipse geometry (Joshi), [acres].
PO.IPR.Rwa
Calculates effective wellbore radius, [ft].
PO.VFP.Liq.Pout
Calculates outlet pipe pressure for single phase pipe flow of incompressible, Newtonian fluid, [psi].
PO.VFP.Liq.Pin
Calculates inlet pipe pressure for single phase pipe flow of incompressible, Newtonian fluid, [psi].
PO.VFP.Liq.Re
Calculates Reynolds number for single phase pipe flow of incompressible, Newtonian fluid, [dimensionless].
PO.VFP.Liq.dPfrc
Calculates frictional pressure drop from Fanning equation for single-phase flow of an incompressible, Newtonian fluid, [psi].
PO.VFP.Liq.dPgrv
Calculates potential energy pressure drop for single-phase flow of an incompressible, Newtonian fluid, [psi].
PO.VFP.Gas.Pout
Calculates outlet pipe pressure for single phase pipe flow of gas (compressible fluid), [psi].
PO.VFP.Gas.Pin
Calculates inlet pipe pressure for single phase pipe flow of gas (compressible fluid), [psi].
PO.VFP.Gas.Re
Calculates Reynolds number for single phase pipe flow of gas (compressible fluid), [dimensionless].
PO.VFP.Gray.dPdL
Calculates pressure gradient for multiphase pipe flow using Gray (1974) correlation, [psi/ft]. Commonly used for gas wells that are also producing liquid.
PO.VFP.Gray.Pout
Calculates outlet pipe pressure using Gray (1974), [psi]. For gas wells producing liquid. Gas properties (ρg, μg, Bg) use DAK (Z-factor) and LGE (viscosity).
PO.VFP.Gray.Pin
Calculates inlet pipe pressure using Gray (1974), [psi]. For gas wells producing liquid. Gas properties (ρg, μg, Bg) use DAK (Z-factor) and LGE (viscosity).
PO.VFP.BeggsBrill.dPdL
Calculates pressure gradient for multiphase pipe flow using Beggs and Brill (1973) correlation, [psi/ft]. Can be applied for any wellbore inclination and flow direction.
PO.VFP.BeggsBrill.Pout
Calculates outlet pipe pressure using Beggs and Brill (1973), [psi]. For any wellbore inclination. Gas properties (ρg, μg, Bg) use DAK (Z-factor) and LGE (viscosity).
PO.VFP.BeggsBrill.Pin
Calculates inlet pipe pressure using Beggs and Brill (1973), [psi]. For any wellbore inclination. Gas properties (ρg, μg, Bg) use DAK (Z-factor) and LGE (viscosity).
PO.VFP.Orkiszewski.dPdL
Calculates pressure gradient using Orkiszewski (1967) correlation, [psi/ft]. Vertical wells, widely used industry standard.
PO.VFP.Orkiszewski.Pout
Calculates outlet pipe pressure using Orkiszewski (1967), [psi]. Vertical wells. Gas properties (ρg, μg, Bg) use DAK (Z-factor) and LGE (viscosity).
PO.VFP.Orkiszewski.Pin
Calculates inlet pipe pressure using Orkiszewski (1967), [psi]. Vertical wells. Gas properties (ρg, μg, Bg) use DAK (Z-factor) and LGE (viscosity).
PO.VFP.HagedornBrown.dPdL
Calculates pressure gradient for multiphase pipe flow using Hagedorn and Brown (1965) correlation with Griffith modification, [psi/ft]. Developed for vertical, upward flow and recommended only for near-vertical wellbores.
PO.VFP.HagedornBrown.Pout
Calculates outlet pipe pressure using Hagedorn and Brown (1965), [psi]. For vertical/near-vertical wells. Gas properties (ρg, μg, Bg) use DAK (Z-factor) and LGE (viscosity).
PO.VFP.HagedornBrown.Pin
Calculates inlet pipe pressure using Hagedorn and Brown (1965), [psi]. For vertical/near-vertical wells. Gas properties (ρg, μg, Bg) use DAK (Z-factor) and LGE (viscosity).
PO.VFP.DunsRos.dPdL
Calculates pressure gradient using Duns and Ros (1963) correlation, [psi/ft]. For vertical gas wells with liquid, high GOR wells.
PO.VFP.DunsRos.Pout
Calculates outlet pipe pressure using Duns and Ros (1963), [psi]. Vertical gas wells. Gas properties (ρg, μg, Bg) use DAK (Z-factor) and LGE (viscosity).
PO.VFP.DunsRos.Pin
Calculates inlet pipe pressure using Duns and Ros (1963), [psi]. Vertical gas wells. Gas properties (ρg, μg, Bg) use DAK (Z-factor) and LGE (viscosity).
PO.VFP.PoettmannCarpenter.dPdL
Calculates pressure gradient using Poettmann-Carpenter (1952), [psi/ft]. Historical no-slip method for high-rate dispersed bubble flow.
PO.VFP.PoettmannCarpenter.Pout
Calculates outlet pipe pressure using Poettmann-Carpenter (1952), [psi]. No-slip method. Gas properties (ρg, μg, Bg) use DAK (Z-factor) and LGE (viscosity).
PO.VFP.PoettmannCarpenter.Pin
Calculates inlet pipe pressure using Poettmann-Carpenter (1952), [psi]. No-slip method. Gas properties (ρg, μg, Bg) use DAK (Z-factor) and LGE (viscosity).
PO.VFP.Ansari.dPdL
Calculates pressure gradient using Ansari et al. (1994) mechanistic model, [psi/ft]. TUFFP industry standard for vertical upward flow.
PO.VFP.Ansari.Pout
Calculates outlet pipe pressure using Ansari et al. (1994), [psi]. Vertical wells. Gas properties (ρg, μg, Bg) use DAK (Z-factor) and LGE (viscosity).
PO.VFP.Ansari.Pin
Calculates inlet pipe pressure using Ansari et al. (1994), [psi]. Vertical wells. Gas properties (ρg, μg, Bg) use DAK (Z-factor) and LGE (viscosity).
PO.VFP.HasanKabir.dPdL
Calculates pressure gradient using Hasan-Kabir (1988) mechanistic model, [psi/ft]. For deviated wells and annular geometry.
PO.VFP.HasanKabir.Pout
Calculates outlet pipe pressure using Hasan-Kabir (1988), [psi]. For deviated wells. Gas properties (ρg, μg, Bg) use DAK (Z-factor) and LGE (viscosity).
PO.VFP.HasanKabir.Pin
Calculates inlet pipe pressure using Hasan-Kabir (1988), [psi]. For deviated wells. Gas properties (ρg, μg, Bg) use DAK (Z-factor) and LGE (viscosity).
PO.VFP.MukherjeeBrill.dPdL
Calculates pressure gradient using Mukherjee-Brill (1985) correlation, [psi/ft]. For inclined wells, improvement over Beggs-Brill.
PO.VFP.MukherjeeBrill.Pout
Calculates outlet pipe pressure using Mukherjee-Brill (1985), [psi]. For inclined wells. Gas properties (ρg, μg, Bg) use DAK (Z-factor) and LGE (viscosity).
PO.VFP.MukherjeeBrill.Pin
Calculates inlet pipe pressure using Mukherjee-Brill (1985), [psi]. For inclined wells. Gas properties (ρg, μg, Bg) use DAK (Z-factor) and LGE (viscosity).
PO.VFP.Aziz.dPdL
Calculates pressure gradient using Aziz et al. (1972) drift-flux model, [psi/ft]. Vertical wells, basis for mechanistic models.
PO.VFP.Aziz.Pout
Calculates outlet pipe pressure using Aziz et al. (1972), [psi]. Vertical wells. Gas properties (ρg, μg, Bg) use DAK (Z-factor) and LGE (viscosity).
PO.VFP.Aziz.Pin
Calculates inlet pipe pressure using Aziz et al. (1972), [psi]. Vertical wells. Gas properties (ρg, μg, Bg) use DAK (Z-factor) and LGE (viscosity).