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AbstractThis paper addresses the combined effect of formation damage and non-Darcy flow in naturally fractured reservoirs using simplified analytical solutions and a two-dimensional numerical simulator. Pressure drawdown, buildup, and isochronal tests simulated in this work indicate that, despite high fracture permeability, skin damage may accentuate the non-Darcy flow effect and drastically influence pressuretransient characteristics of low-pressure, naturally fractured reservoirs. In high-pressure reservoirs, this effect is significant only at high rates. Non-Darcy flow does not usually mask the typical pressure-transient characteristics of dual-porosity and dual-permeability reservoirs, but the conventional interpretation of the early time data may lead to erroneous results. If the exponent, n, of the gas performance curve approaches 0.5 while the matrix permeability is low and flow rate is rather high, this indicates predominance of fracture flow. The practical motivations of this study and its extensions to other practical problems, such as condensate reservoirs where the condensate dropout in the wellbore region should increase non-Darcy flow, are also discussed.