Accurate prediction of pressure profiles in a flowing well can greatly improve the design of production facilities in petroleum engineering. This can in turn lead to improvement in the artificial lift system design. Rigorous theoretical models are often complex and inconvenient. They depend on many variables and require detailed information about the fluid composition. This paper describes a simplified approach which is suitable for quick calculations to predict pressure profiles in multiphase flowing wells. The empirical model assumes steady state flow and is developed using a database consisting of measured data from more than 100 wells. No attempt was made to determine holdup for the purposes of simplification and therefore, oil, water and gas were considered to be a single phase. The total energy loss term was assumed to be constant over the entire segment length under consideration and was varied for various segment lengths due to the insitu fluid properties and velocity. Nearly all pressure drop prediction from this approach are based on data with flowrates in the range of 90-3000 bpd and 2 and 2.5 inch nominal tubing. This paper is an extraction of work done in relation to the masters' thesis by Palisetti1 and review of previous work published by other authors in the field of multiphase flow.

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