Classical methods to determine permeability distribution in a gas reservoir are sometimes inadequate: for a gas field, only core measurements are available and scale problems always appear when applying these values to the whole reservoir. An inverse modeling procedure is proposed to determine automatically the permeability field for a dry-gas reservoir. This method consists in the minimization of the difference between a historical record of real pressures and pressures computed from discretized equations of monophasic gas flow in porous medium. A Lagrangian method combined with geostatistical information is used. Two applications are presented: a history matching of a gas field giving a permeability distribution then used for prediction and a transient draw-down test on a gas well which gives an estimate of the local permeability in the surrounding matrix.


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