Halliburton Energy Services, Inc.

Ingrain, Inc.

Yaoming Mu

Jonas Toelke

Abraham S Grader

Radompon Sungkorn

Naum Derzhi

Anyela Morcote

Carl Sisk

Joel D Walls

Giuseppe De Prisco

Michael Suhrer

Avrami Grader

Marcus Ganz

Gustavo Carpio

Gabriela Alexandra Davalos

Sneha Bhakta

A method for determining porosity associated with organic matter (PAOM) in a well or formation is provided. A system for performing the method is also provided.

Method for determining porosity associated with organic matter in a well or formation

Methods and systems for conditioning expanded porosity, including a method that includes creating a disconnected pore structure by reducing the pore sizes of a rock sample's scanned image, identifying expanded pores within the rock sample and generating an expanded pore image from the expanded pores. The method further includes combining the expanded pore image with the scanned image to create an expansion mask, generating a grain conditioning volume based on at least one unexpanded region of the rock sample, combining the grain conditioning volume with the expansion mask to generate a fill volume image, combining the fill volume image with the scanned image to create an unexpanded volume image, and generating and presenting to a user a formation log using a model generated based upon the unexpanded volume image.

Conditioning of expanded porosity

An example method includes acquiring two-dimensional (2D) or three-dimensional (3D) digital images of a rock sample. The method also includes iteratively analyzing property measurements collected throughout the digital images using different subsample sizes to identify a property distribution convergence as a function of subsample size. The method also includes selecting a smallest subsample size associated with the property distribution convergence as a representative elementary area or volume for the rock sample.

Representative elementary volume determination via clustering-based statistics

An example method includes acquiring two-dimensional (2D) or three-dimensional (3D) digital images of a rock sample. The method also includes selecting a subsample within the digital images. The method also includes deriving a trend or petrophysical property for the subsample. The method also includes applying the trend or petrophysical property to a larger-scale portion of the digital images.

Digital rock physics-based trend determination and usage for upscaling

A method for determining fabric and upscaled properties of a geological sample, such as a rock sample. A system for the method also is provided.

Method for determining fabric and upscaled properties of geological sample

A method for computing or estimating fractional, multi-phase/multi-component flow through a porous medium employing a 3D digital representation of a porous medium and a computational fluid dynamics method to calculate flow rates, pressures, saturations, internal velocity vectors and other flow parameters is described. The method employs a unique method of introducing non-wetting and wetting fluids into the pores at the inlet face of the 3D digital representation of a porous medium and a novel process control application to achieve quasi-steady state flow at low inlet concentrations of non-wetting fluid. In addition, the method of the present invention reduces the time required to simulate to complete the fluid dynamic calculations. The resulting values of flow of non-wetting fluid, wetting fluid, saturation, and other parameters are used to generate plots of relative permeability imbibition and drainage curves. Computerized systems and programs for performing the method are also provided.

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Houston, TX, United States of America

Yaoming Mu