From empirical to micro-scale modeling of multiphase flow; bridging the gap of R&D

In the petroleum industry, multiphase flows are complex phenomena and can be found in a variety of situations. The three more common working fluids (oil, natural gas and water) can have four different two-phase flow permutations of the three types of fluids. Multiphase flow modeling/metering is a key factor for optimal flow design and realizing optimal recovery of hydrocarbons. Over the last few decades, scientists developed the math of pressure and flow rate relationship in multiphase flow. A number of empirical correlations and mechanistic models have been developed for predicting pressure drop and other fluid flow characteristics during multiphase flow in wellbores and flow lines. Similarly, the emerging sensing and measurement tools were adapted for application of multiphase flow in oil and gas fields. With all calculation being computer-assisted and after many years of development and experimental research, the computer based numerical analysis methods have been evolved to solve the large number of equations and correlation coefficients. With the vast application of high performance computing, computational time is not an issue anymore but accuracy. The challenges associated with multiphase flow modeling/metering include accuracy, size, application, and cost. The need for efficient and cost effective modeling/measurement systems in oil and gas fields have kept and will continue the need for active participation of R&D and better integration with sensing systems. This paper reviews the state of art of modeling of multiphase flow and the major headways that led the way for subsequent research in this regard, and potential ways to promote accuracy and reduce cost. These are potential research projects being evaluated / proposed in the research institute in King Fahd University of Petroleum & Minerals in collaboration with international service providers and national field operators.