I. Introduction
Multiphase flow meters (MPFMs) that provide real-time measurement of the volumetric flow of each of these phases are crucial for optimal reservoir management. The design of a reliable and accurate MPFM for oil-gas fields still remains a challenging task because of the opacity of the multiphase flow, in addition to the harshness of the surrounding environment. This led researchers to suggest various complementary sensing techniques such as capacitance [1]–[3], conductance [3], [4], and ultrasonic [1], [5] sensors for the computation of the multiphase flow fractions, while the total flow rate is measured using either differential pressure sensors (e.g., Venturi or orifice flow meters) or Coriolis flowmeter [4]. Overall, these multiple-sensing devices have demonstrated accurate measurement for specific ranges of phase compositions and flow rates. However, they require a prior knowledge of some fluid parameters such as the densities of all single phases composing the fluid. -ray flow meters, such as Schlumbergers’s PhaseWatcher Vx spectra [6], were also successfully deployed in several oil fields. They primarily combine a Venturi meter to measure the total volumetric flow rate and a dual-energy gamma ray device to measure the concentrations of individual phases. The meter was reported to exhibit an acceptable 5%–10% relative error.