Abstract: A method for analyzing a rock sample includes segmenting a digital image volume corresponding to an image of the rock sample, to associate voxels in the digital image volume with a plurality of rock fabrics of the rock sample. The method also includes identifying a set of digital planes through the digital image volume. The set of digital planes intersects with each of the plurality of rock fabrics. The method further includes machining the rock sample to expose physical faces that correspond to the identified digital planes, performing scanning electron microscope (SEM) imaging of the physical faces to generate two-dimensional (2D) SEM images of the physical faces, and performing image processing on the SEM images to determine a material property associated with each of the rock fabrics.

Abstract: A method for analyzing a rock sample includes segmenting a digital image volume corresponding to an image of the rock sample, to associate voxels in the digital image volume with a plurality of rock fabrics of the rock sample. The method also includes identifying a set of digital planes through the digital image volume. The set of digital planes intersects with each of the plurality of rock fabrics. The method further includes machining the rock sample to expose physical faces that correspond to the identified digital planes, performing scanning electron microscope (SEM) imaging of the physical faces to generate two-dimensional (2D) SEM images of the physical faces, and performing image processing on the SEM images to determine a material property associated with each of the rock fabrics.

Abstract: Methods to identify and quantify the emulsion properties in oil and gas producing wells at downhole condition or pipelines using NMR and to provide potential treatment options. The longitudinal (T1), transverse (T2) relaxation times and diffusion coefficient of a fluid are changed by the presence of a second dispersed fluid phase in the form of bubbles or droplets. Properties may be determined by comparing the measured T1 and T2 spectra and diffusion coefficient at downhole conditions with the bulk responses of the constituent fluids.

Abstract: The present invention is directed to a method to use nuclear magnetic resonance (“NMR”) to determine the surface relaxivity in a reservoir. The surface relaxivity can be used to calculate the pore size distribution in a reservoir.

Abstract: The present invention is directed to methods to identify and quantify the emulsion properties in oil and gas producing wells at downhole condition or pipelines using NMR and to provide potential treatment options. The longitudinal (T1), transverse (T2) relaxation times and diffusion coefficient of a fluid are changed by the presence of a second dispersed fluid phase in the form of bubbles or droplets. Properties may be determined by comparing the measured T1 and T2 spectra and diffusion coefficient at downhole conditions with the bulk responses of the constituent fluids.

Abstract: The present invention is directed to a method to use nuclear magnetic resonance (“NMR”) to determine the surface relaxivity in a reservoir. The surface relaxivity can be used to calculate the pore size distribution in a reservoir.