Use This Blueprint

Download Petroleum Office to insert this blueprint in Excel.

Blueprints
Vertical Flow Performance
Multiphase Correlation Comparison

Multiphase Correlation Comparison

Description

Compare pressure drop predictions from all ten industry-standard multiphase flow correlations. Understanding correlation differences helps engineers select the most appropriate method for specific well conditions.

Correlations:

Beggs & Brill (1973): General-purpose, any inclination, most widely used
Gray (1974): Best for gas wells with liquid loading
Hagedorn & Brown (1965): Near-vertical oil wells, industry standard
Ansari (1994): Mechanistic TUFFP model, vertical wells
Hasan-Kabir (1988): Mechanistic, deviated wells and annular geometry
Mukherjee-Brill (1985): Improvement over Beggs-Brill for inclined wells
Orkiszewski (1967): Composite vertical well correlation
Duns & Ros (1963): High GOR gas wells
Aziz (1972): Drift-flux model for vertical wells
Poettmann-Carpenter (1952): Historical no-slip method, high-rate dispersed flow

Spreadsheet Preview

55 rows x 3 columns

Required Functions

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.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.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.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.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.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.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.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.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).

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.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.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.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.Ansari.dPdL

Calculates pressure gradient using Ansari et al. (1994) mechanistic model, [psi/ft]. TUFFP industry standard for vertical upward flow.

PO.VFP.HasanKabir.dPdL

Calculates pressure gradient using Hasan-Kabir (1988) mechanistic model, [psi/ft]. For deviated wells and annular geometry.

PO.VFP.MukherjeeBrill.dPdL

Calculates pressure gradient using Mukherjee-Brill (1985) correlation, [psi/ft]. For inclined wells, improvement over Beggs-Brill.

PO.VFP.Orkiszewski.dPdL

Calculates pressure gradient using Orkiszewski (1967) correlation, [psi/ft]. Vertical wells, widely used industry standard.

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.Aziz.dPdL

Calculates pressure gradient using Aziz et al. (1972) drift-flux model, [psi/ft]. Vertical wells, basis for mechanistic models.

PO.VFP.PoettmannCarpenter.dPdL

Calculates pressure gradient using Poettmann-Carpenter (1952), [psi/ft]. Historical no-slip method for high-rate dispersed bubble flow.

How to use this blueprint

In Excel, go to the Petroleum Office ribbon tab and click Blueprint Manager
Search for Multiphase Correlation Comparison
Click on the blueprint to preview the spreadsheet template
Click Insert to place it into your worksheet. Modify the input values to match your data.

Related Theory

Vertical Multiphase Flow Correlations

Hagedorn-Brown and Gray correlations for predicting pressure gradients in vertical and near-vertical wells

Beggs and Brill Multiphase Flow Correlation

Comprehensive correlation for predicting pressure drop and liquid holdup in multiphase flow through pipes at any inclination angle

Pipe Flow Overview

Overview

Comprehensive guide to single-phase and multiphase pipe flow correlations for wellbore and pipeline calculations

Single-Phase Pipe Flow

Reynolds number, friction factor, and pressure drop calculations for single-phase liquid and gas flow in pipes

vlpbeggs-brillgrayhagedorn-brownansarihasan-kabirmukherjee-brillorkiszewskiduns-rosazizpoettmann-carpentercomparisonmultiphase

Need a custom calculation? Request a Blueprint