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PORE VOLUME MODELLING OF PLUG SAMPLES OF SANDSTONE RESERVOIR ORIGIN USING MULTIPLE STEEL CAPILLARY MODEL
Abstract
Regarding any hydrocarbon reservoir, the most important question that needs to be answered is production capacity. During production, the achievable fluid rate depends both on the properties of the reservoir as well as the pressure difference (drawdown [1]) between well and reservoir. From the petrophysical point of view, many effects restrict fluid flow in the porous system (pore size distribution, wettability properties, saturations etc.) resulting in the obtainable fluid rate corresponding to the existing drawdown. In reservoir engineering permeability, introduced by Darcy, is the parameter that describes those restrictions which are present during fluid flow in porous media. Although this method is the one that is currently being implemented in the industry has a major flaw, as using the geometrical cross-sectional area of the studied volume rather than the effective one, where flow truly happens. The aim of this study is to present a new approach for flow restriction modelling rather than Darcy?s equation represents a volume matching the total pore volume, constructed from steel capillaries of equal diameter. The number and diameter of the capillaries were determined by an iteration process where the sum of the pressure drops across all capillaries equal to the value appearing at 100% water saturation and steady condition during effective permeability measurement. Thus representing a more reliable solution for reservoir and production modelling also solving the issue of restriction not being described as a single value. In this paper the working model will be presented in details, supported by data of measurements performed on sandstone plug samples.
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