Abstract: Saturation-height functions in oil and gas reservoirs are determined using methods that include quantifying the microporosity of the subterranean formation; determining the distribution of facies and microporosity as a function of depth; and calculating the saturation-height function for a given formation.

Abstract: Methods of generating structural models of highly deviated or horizontal wells may be generated from the measurement of true stratigraphic thickness in three dimensions (TST3D). In one aspect, methods may include generating a structural model from one or more deviation surveys of a horizontal well, one or more single channel log measurements, and a three-dimensional reference surface.

Abstract: The present disclosure introduces methods and apparatus for acquiring a borehole image corresponding to a sidewall surface of a borehole that penetrates a subterranean formation, wherein the subterranean formation comprises structural elements and a varying geophysical characteristic. The borehole image comprises structure corresponding to the structural elements, texture corresponding to the varying geophysical characteristic, and coverage gaps (605) in which the structure and texture are missing. Trends corresponding to the structure are extracted from the borehole image. Missing structure within the gaps (605) is reconstructed based on the extracted trends. Missing texture within the gaps is simulated based on the borehole image and the reconstructed structure. A fullbore image is constructed based on the borehole image, the reconstructed structure within the gaps, and the simulated texture within the gaps.

Abstract: Saturation-height functions in oil and gas reservoirs are determined using methods that include quantifying the microporosity of the subterranean formation; determining the distribution of facies and microporosity as a function of depth; and calculating the saturation-height function for a given formation.

Abstract: The present disclosure introduces methods and apparatus for acquiring a borehole image corresponding to a sidewall surface of a borehole that penetrates a subterranean formation, wherein the subterranean formation comprises structural elements and a varying geophysical characteristic. The borehole image comprises structure corresponding to the structural elements, texture corresponding to the varying geophysical characteristic, and coverage gaps (605) in which the structure and texture are missing. Trends corresponding to the structure are extracted from the borehole image. Missing structure within the gaps (605) is reconstructed based on the extracted trends. Missing texture within the gaps is simulated based on the borehole image and the reconstructed structure. A fullbore image is constructed based on the borehole image, the reconstructed structure within the gaps, and the simulated texture within the gaps.

Abstract: Methods of generating structural models of highly deviated or horizontal wells may be generated from the measurement of true stratigraphic thickness in three dimensions (TST3D). In one aspect, methods may include generating a structural model from one or more deviation surveys of a horizontal well, one or more single channel log measurements, and a three-dimensional reference surface.

Abstract: Rapidly pulsed injection fracture acidizing. A method comprises rapidly pulsed injection of a high reactivity fracture treatment fluid mode or substage alternated with one or more low reactivity treatment fluid modes or substages.

Abstract: This disclosed subject matter is generally related to methods for characterizing two-dimensional (2D) and three-dimensional (3D) samples to determine pore-body and pore-throat size distributions and capillary pressure curves in porous media using petrographic image analysis. Input includes high-resolution petrographic images and laboratory-derived porosity measurements. Output includes: (1) pore-body and pore-throat size distributions, and (2) simulated capillary pressure curves for both pore bodies and pore throats.

Abstract: This subject disclosure describes methods to build and/or enhance 3D digital models of porous media by combining high- and low-resolution data to capture large and small pores in single models. High-resolution data includes laser scanning fluorescence microscopy (LSFM), nano computed tomography (CT) scans, and focused ion beam-scanning electron microscopy (FIB-SEM). Low-resolution data includes conventional CT scans, micro computed tomography scans, and synchrotron computed tomography scans.

Abstract: This subject disclosure describes methods to build and/or enhance 3D digital models of porous media by combining high- and low-resolution data to capture large and small pores in single models. High-resolution data includes laser scanning fluorescence microscopy (LSFM), nano computed tomography (CT) scans, and focused ion beam-scanning electron microscopy (FIB-SEM). Low-resolution data includes conventional CT scans, micro computed tomography scans, and synchrotron computed tomography scans.

Abstract: This disclosed subject matter is generally related to methods for characterizing two-dimensional (2D) and three-dimensional (3D) samples to determine pore-body and pore-throat size distributions and capillary pressure curves in porous media using petrographic image analysis. Input includes high-resolution petrographic images and laboratory-derived porosity measurements. Output includes: (1) pore-body and pore-throat size distributions, and (2) simulated capillary pressure curves for both pore bodies and pore throats.

Abstract: The subject disclosure relates to methods for determining representative element areas and volumes in porous media. Representative element area (REA) is the smallest area that can be modeled to yield consistent results, within acceptable limits of variance of the modeled property. Porosity and permeability are examples of such properties. In 3D, the appropriate term is representative element volume (REV). REV is the smallest volume of a porous media that is representative of the measured parameter.

Abstract: A process for analyzing geological bedding plane data from a well, and plotting the cumulative dip angle and dip direction of the bedding planes with respect to depth. The cumulative dip angle may also be plotted with respect to sample numbers, which are a function of depth. The process further analyzes the cumulative dip data to produce a series of straight line approximations of various groupings of data. When these straight line approximations intercept, the interception often indicates a fault or unconformity at the location of the interception. The process further analyzes the cumulative dip plot by taking the first derivative of the plotted line. A stepwise shift in the derivative indicates an inflection point in the line, which often indicates a fault or unconformity. The process also plots the dip direction as the color or symbol of each point plotted and a color or symbol change often indicates a fault or unconformity.