Dassault Systemes Simulia Corp.

Dassault Systemes Americas Corp.

Exa Corporation

Bernd Crouse

Rui Xu

Hudong Chen

Raoyang Zhang

David M Freed

Guangyuan Sun

Andrew Fager

Yong Li

Hiroshi Otomo

Nils Koliha

Xiaobo Nie

David M Feed

Rafael Salazar Tio

Ganapathi Raman Balasubramanian

Hongli Fan

Jingjing Yang

Ganapathi Balasubramanian

Ashraful Islam

Rafael Salazar-Tio

Zhuang Sun

Systems, methods, and computer program products can be used for determining the amount of oil removed by a miscible gas flood. One of the methods includes identifying locations of oil within a volume representing a reservoir rock sample. The method includes identifying locations of gas within the volume. The method also includes determining the amount of oil removed based on locations within the volume where oil is either coincident with the gas or is connected to the gas by a continuous oil path.

Determination of oil removed by gas via miscible displacement in reservoir rock

Disclosed are computer implemented techniques for conducting a simulation of physical properties of a porous medium. The features include receiving a micro-CT 3D image that captures a representative elemental volume of the porous medium, the porous medium defined as having mineral types and fluid types with individual grains and grain to grain contacts, labeling the micro-CT 3D image as individual voxels according to mineral and fluid types and labeling the mineral type voxels as belonging to separated and fixed individual grains. The features also include transforming the labeled voxels into an unstructured conformal mesh representation for all grains and applying the unstructured conformal mesh representation to a parametric cohesive contact engine, with the parametric cohesive contact engine executing a parametric cohesive contact model that has an adjustable parameter, a critical separation δconditioned according to consolidation level.

Prediction of mechanical properties of sedimentary rocks based on a grain to grain parametric cohesive contact model

Systems, methods, and computer program products can be used for visualizing the behavior of flow of two or more fluid phases, wherein a fluid phase behavior is represented in a visualization. One of the methods includes determining an occupation time, which is the amount of elapsed time from when a fluid phase first occupies a particular location until a second time. The method includes generating data for a visualization, with a location in the visualization corresponding to the particular location, and with the generated data for that location in the visualization indicating the occupation time.

Multi-phase flow visualizations based on fluid occupation time

Disclosed are computer implemented techniques for conducting a fluid simulation of a porous medium. These techniques involve retrieving a representation of a three dimensional porous medium, the representation including pore space corresponding to the porous medium, with the representation including at least one portion of under-resolved pore structure in the porous medium, defining a representative flow model that includes the under-resolved pore structure in the representation, and constructing by the computer system fluid force curves that correspond to fluid forces in the under-resolved pore structure in the representation.

Computer simulation of multi-phase and multi-component fluid flows including physics of under-resolved porous structures

Techniques including methods, apparatus and computer program products are disclosed. These techniques include computer instructions that are encoded on computer storage media for determining wettability. The techniques use a numerical aging computation process to provide a representation of a wettability alteration of a physical rock sample in the presence of at least two fluids is disclosed. The techniques include retrieving a representation of a physical rock sample, the representation including pore space and grain space data corresponding to the physical rock sample, calculating local curvature for each surface in the pore space, determining from the calculated local curvature whether water-film breakage will occur, and classifying the wettability of the physical rock based on the determination of water-film breakage.

Determining fluid flow characteristics of porous mediums

Techniques including methods, apparatus and computer program products are disclosed for determining an amount of hydrocarbon recoverable from porous reservoir rock by a miscible gas flood. The techniques include retrieve a representation of a physical porous reservoir rock sample (porous reservoir rock), the representation including pore space and grain space data corresponding to the porous reservoir rock, subsequent to an execution of a multiphase flow simulation to obtain predictions of flow behavior of oil in the presence of a waterflood of the porous reservoir rock, locate substantially immobile oil blobs or patches in the retrieved representation of the porous reservoir rock; and for N number of substantially immobile oil blobs or patches (blobs), evaluate changes in mobility of the blobs for two or more iterations an effort level for of a given EOR technique, with a first one of the two or more iterations expending a first level of effort and a second one of the two or more iterations expending a second, higher level of effort, to estimate an amount of change in mobilization of the blob between the first and the second iterations for the given EOR technique.

Determination of hydrocarbon mobilization potential for enhanced oil recovery

This description relates to computer simulation of physical processes, such as computer simulation of multi-species flow through porous media including the determination/estimation of relative permeabilities for the multi-species flow through the porous media.

Mass exchange model for relative permeability simulation

Methods, systems, and apparatus, including computer programs encoded on computer storage media, for fluid blob tracking. One of the methods includes identifying, by a computer system, a connected fluid phase region in a flow simulation. The method includes tracking, by the computer system, the connected fluid phase region over a first timeframe and a second timeframe. The method also includes determining, by the computer system, movement of the connected fluid phase region from the first timeframe to the second timeframe based on the tracking.

Growing community of inventors

Berkeley, CA, United States of America

Bernd Crouse