Depressurization of a virgin or waterflooded oil reservoir results in the appearance of a solution gas saturation. Above a saturation threshold, this gas becomes mobile and can be produced. Knowledge of the critical gas saturation (Sgc) and the subsequent relative permeabilities (Kr) in the far field and the near-wellbore region has a tremendous impact on gas and oil production forecasts. The present paper provides a new methodology to obtain representative Kr and Sgc values for a depressurization process. Specific experiments are presented in which under-saturated oil was injected upstream at a fixed rate whereas downstream the pressure was controlled in order to reproduce a drawdown. Evolution of pressure was recorded and in-situ gas saturations measured by CT-scanner. Two initial conditions were considered, fully oil saturated and at irreducible water saturation. Influence of the drawdown scheme was also explored. Transient evolution of the gas saturation profile in the core is clearly shown. Kr are deduced from history matching. They are finally compared to the Kr derived from gas injection experiments. It is demonstrated that gas/oil Kr shape is strongly affected by the way the gas appears and is distributed in the porous medium. For solution gas drive, oil relative permeability is higher and gas relative permeability is smaller than for gas injection. Concerning critical gas saturation, the experiments show two types of gas mobility depending on the operational conditions: mobility threshold attained from connection of bubbles or from mobilization of a population of separate bubbles. For the first type, Sgc can be linked to the values obtained through static experiments at fixed depletion rate. INTRODUCTION Work on depressurization has been conducted for several decades, first to study the solution gas drive as a primary recovery mechanism [1,2,3]. Recently this subject has regained interest as a good opportunity to extend life of waterflooded reservoir in the North Sea (Brent field) [4,5]. The main goal of the last researches is to optimize hydrocarbon recovery in terms of remaining gas and additional produced oil [6,7,8]. Whatever the context, primary recovery or waterflooded reservoir, it is of great importance to determine representative values of Sgc and Kr in the near wellbore region and the far field to establish reliable production forecasts. Indeed, their impact is direct on the field development, the operations planning and the sizing of surface facilities.