Schlumberger Technology Corporation

Services Petroliers Schlumberger

Geoquest Systems B.v.

Keith Pinto

Olivier Marché

Sylvain Wlodarczyk

Akshat Gupta

Andrey Vladimirovich Kazak

Olivier Marche

A method for modelling saturation in a reservoir, comprising: obtaining capillary pressure data representing capillary pressure in the reservoir; obtaining permeability data representing permeability in the reservoir; determining a number of pore throats represented by the capillary pressure data; creating hyperbolic tangents based on the capillary pressure data equal in number to the number of pore throats; combining hyperbolic tangents to create a curve to fit the capillary pressure data and to define hyperbolic tangent parameters; combining at least one of the hyperbolic tangent parameters with the permeability data to define a saturation height function; modelling a saturation in the reservoir using the saturation height function; and displaying the saturation model based on the saturation height function. The determination of the number of pore throats may comprise creating an initial capillary pressure curve using a predetermined number of multiple linked hyperbolic tangents, determining a first derivative of the capillary pressure curve, and determining a number of local minima in the capillary pressure curve.

Oilfield reservoir saturation and permeability modeling

A system and method for correcting capillary pressure curves includes creating a capillary pressure curve using multiple linked hyperbolic tangents, determining a closure correction pressure cutoff of the capillary pressure curve, and correcting the capillary pressure curve. The correction may include normalizing the capillary pressure curve and extrapolating the capillary pressure curve.

Method and system for correcting a capillary pressure curve

A method, apparatus, and program product for determining a formation pressure for a reservoir. Measurement data for a pretest of a formation of the reservoir is received. The measurement data is analyzed to determine a last-read event and a corresponding last-read pressure. Derivative data for flow regime identification is determined based at least in part on the measurement data. The derivative data is analyzed to determine a pressure derivative response, and a formation pressure is determined based at least in part on the last-read event, the last-read pressure, and the pressure derivative response.

Formation pressure determination

A method can include receiving porosimetry data for a range of pressures that spans a transition zone defined at least in part by a high-pressure end of a first pressure zone and a low-pressure end of a second pressure zone; detecting at least one artifact in the transition zone; computing accuracy information for the high-pressure end of the first pressure zone and the low-pressure end of the second pressure zone; computing a pressure-volume adjustment based at least in part on the accuracy information; and outputting a pressure-volume relationship in the transition zone based at least in part on the pressure-volume adjustment.

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Houston, TX, United States of America

Keith Pinto