ملخص
Abstract Marginal fields require production optimization and proper management due to uncertainties surrounding the size, reserves and operational strategies and costs. One of the ways of achieving optimal development is by using an efficient artificial lift method early or later in the field life, that will increase recovery and profitability. However, knowing the best artificial lift method to use for a situation could sometimes be challenging. In this study, a techno-economic comparison of Continuous Gas Lift (CGL) and Electrical Submersible Pumps (ESP) was carried out for a marginal oil field (E 103 field) to choose the optimal method. Well and reservoir models were built to generate production forecasts under natural flow, CGL and ESP. Economic models were formulated, incorporating cost for each artificial lift method, oil price to estimate cumulative revenue of oil sales for the three production methods at the wells abandonment date.