Abstract: A method is provided for evaluating a geological formation which integrates well data and high resolution computed tomography of rock samples thereof. Relationships are determined for a formation between a formation property, such as an elastic property, and at least one of photoelectric effect index (PEF), effective atomic number (Zeff), and bulk density (RHOB), using well data, and tomographic imaging is used to determine at least one of the latter mentioned properties (PEF, Zeff, RHOB) at higher resolution, which can be used in the relationship to determine a corresponding formation property. This affords an opportunity to develop formation property data for more challenging formations to evaluate, such as thinly laminated formations or others. Computerized systems, computer program products on non-transitory computer usable storage media, and programs for performing the methods are also provided.

Abstract: A method is provided for evaluating a geological formation which integrates well data and high resolution computed tomography of rock samples thereof. Relationships are determined for a formation between a formation property, such as an elastic property, and at least one of photoelectric effect index (PEF), effective atomic number (Zeff), and bulk density (RHOB), using well data, and tomographic imaging is used to determine at least one of the latter mentioned properties (PEF, Zeff, RHOB) at higher resolution, which can be used in the relationship to determine a corresponding formation property. This affords an opportunity to develop formation property data for more challenging formations to evaluate, such as thinly laminated formations or others. Computerized systems, computer program products on non-transitory computer usable storage media, and programs for performing the methods are also provided.

Abstract: The present invention relates to a method and system for integrating logging tool data and digital rock physics to estimate rock formation properties. A rock sample from a logging tool such as a sidewall plug or large enough cutting can be extracted by the logging tool at approximately the same well bore location that the logging tool measures fluid properties. The rock samples thus obtained is scanned using a CT scanner, scanning electron microscope or other suitable scanning device. The resulting scanned rock image can be segmented and rock properties comprising porosity, absolute permeability, relative permeability, capillary pressure and other relevant rock properties are calculated. The resulting digital calculations are integrated with logging tool data and rock property estimates to improve the accuracy and timeliness of the logging tool data.

Abstract: A method for increasing the accuracy of a target property value derived from a rock sample is described in which the sample is scanned to obtain a three-dimensional tomographic digital image which can be processed to pore space and solid material phases through a segmentation process. A process is used which revises the segmented volume, e.g., by increasing pore space connectivity, in a manner affecting the target property value that would be derived. Another described method increases the accuracy with which a segmented volume represents a material sample having structure not adequately resolved in an original three-dimensional tomographic digital image. Further, a system for performing the processes, and a segmented digital volume which more accurately represents a sample of a porous media, are described.

Abstract: A method is provided for evaluating a geological formation which integrates well data and high resolution computed tomography of rock samples thereof. Relationships are determined for a formation between a formation property, such as an elastic property, and at least one of photoelectric effect index (PEF), effective atomic number (Zeff), and bulk density (RHOB), using well data, and tomographic imaging is used to determine at least one of the latter mentioned properties (PEF, Zeff, RHOB) at higher resolution, which can be used in the relationship to determine a corresponding formation property. This affords an opportunity to develop formation property data for more challenging formations to evaluate, such as thinly laminated formations or others. Computerized systems, computer program products on non-transitory computer usable storage media, and programs for performing the methods are also provided.

Abstract: A method for increasing the accuracy of a target property value derived from a rock sample is described in which the sample is scanned to obtain a three-dimensional tomographic digital image which can be processed to pore space and solid material phases through a segmentation process. A process is used which revises the segmented volume, e.g., by increasing pore space connectivity, in a manner affecting the target property value that would be derived. Another described method increases the accuracy with which a segmented volume represents a material sample having structure not adequately resolved in an original three-dimensional tomographic digital image. Further, a system for performing the processes, and a segmented digital volume which more accurately represents a sample of a porous media, are described.

Abstract: A method for increasing the accuracy of a target property value derived from a rock sample is described in which the sample is scanned to obtain a three-dimensional tomographic digital image which can be processed to pore space and solid material phases through a segmentation process. A process is used which revises the segmented volume, e.g., by increasing pore space connectivity, in a manner affecting the target property value that would be derived. Another described method increases the accuracy with which a segmented volume represents a material sample having structure not adequately resolved in an original three-dimensional tomographic digital image. Further, a system for performing the processes, and a segmented digital volume which more accurately represents a sample of a porous media, are described.

Abstract: A method is provided for efficiently characterizing rock traversed while drilling a borehole for hydrocarbon reservoir development. A rock sample can be obtained having a provenance of collection linked to a specific region of the borehole, which is scanned to obtain a 2D digital image that is segmented to pixels characterized as pore space and as mineral matrix and defining a boundary between them. A transform relationship, for example, a form of the Kozeny-Carman equation adapted for application to a 2D segmented image environment, can be applied to calculate the estimated value for a target rock property, which can be absolute permeability, relative permeability, formation factor, elasticity, bulk modulus, shear modulus, compressional velocity, shear velocity, electrical resistivity, or capillary pressure, and the estimated value is used to characterize the rock at that region of the borehole.

Abstract: A method of evaluating a reservoir includes a multi-energy X-ray CT scan of a sample, obtaining bulk density and photoelectric effect index effect for the sample, estimation of at least mineral property using data obtained from at least one of a core gamma scan, a spectral gamma ray scan, an X-ray fluorescence (XRF) analysis, or an X-ray diffraction (XRD) analysis of the sample, and determination of at least one sample property by combining the bulk density, photoelectric effect index, and the at least one mineral property (e.g., total clay content). Reservoir properties, such as one or more of formation brittleness, porosity, organic material content, and permeability, can be determined by the method without need of detailed lab physical measurements or destruction of the sample. A system for evaluating a reservoir also is provided.

Abstract: A method for increasing the accuracy of a target property value derived from a rock sample is described in which the sample is scanned to obtain a three-dimensional tomographic digital image which can be processed to pore space and solid material phases through a segmentation process. A process is used which revises the segmented volume, e.g., by increasing pore space connectivity, in a manner affecting the target property value that would be derived. Another described method increases the accuracy with which a segmented volume represents a material sample having structure not adequately resolved in an original three-dimensional tomographic digital image. Further, a system for performing the processes, and a segmented digital volume which more accurately represents a sample of a porous media, are described.

Abstract: A method is provided for efficiently characterizing rock traversed while drilling a borehole for hydrocarbon reservoir development. A rock sample can be obtained having a provenance of collection linked to a specific region of the borehole, which is scanned to obtain a 2D digital image that is segmented to pixels characterized as pore space and as mineral matrix and defining a boundary between them. A transform relationship, for example, a form of the Kozeny-Carman equation adapted for application to a 2D segmented image environment, can be applied to calculate the estimated value for a target rock property, which can be absolute permeability, relative permeability, formation factor, elasticity, bulk modulus, shear modulus, compressional velocity, shear velocity, electrical resistivity, or capillary pressure, and the estimated value is used to characterize the rock at that region of the borehole.

Abstract: A method of evaluating a reservoir includes a multi-energy X-ray CT scan of a sample, obtaining bulk density and photoelectric effect index effect for the sample, estimation of at least mineral property using data obtained from at least one of a core gamma scan, a spectral gamma ray scan, an X-ray fluorescence (XRF) analysis, or an X-ray diffraction (XRD) analysis of the sample, and determination of at least one sample property by combining the bulk density, photoelectric effect index, and the at least one mineral property (e.g., total clay content). Reservoir properties, such as one or more of formation brittleness, porosity, organic material content, and permeability, can be determined by the method without need of detailed lab physical measurements or destruction of the sample. A system for evaluating a reservoir also is provided.

Abstract: A method for determining in-situ relationships between physical properties of a porous medium from a sample thereof includes acquiring a three-dimensional image of the sample and segmenting the image into pixels representing pore space and pixels representing rock grain. A plurality of sub-volumes are selected from the segmented image, and a porosity is calculated for each of the sub-volumes. A digital simulation is conducted on each of the sub-volumes to obtain a selected physical property for the sub-volume. A relationship is determined between porosity and the selected physical property using relationship data comprising the calculated porosity and the simulated physical property for each of the sub-volumes. The method includes at least one of storing and displaying the relationship.

Abstract: A method for estimating a relationship between physical properties of a porous material from a sample thereof includes making a three dimensional tomographic image of the sample of the material. The image is segmented into pixels each representing pore space or rock grains. The image is divided into sub-volumes. A porosity is estimated for each sub-volume. At least one petrophysical parameter is modeled from the image of each sub-volume. A relationship between the porosity and the at least one modeled petrophysical parameter is determined by, e.g., a best-fit statistical method. The relationship and the modeled petrophysical parameter for each sub-volume are stored in a computer or displayed.

Abstract: A method for estimating at least one elastic-wave-related property of a porous material from a sample thereof includes making a three dimensional tomographic image of the sample of the material. The image is segmented into pixels each representing pore space or rock grain. Bulk modulus and shear modulus of the porous material are determined from the segmented image at a frequency corresponding to mobile fluid. Bulk modulus and shear modulus of the porous material are determined from the segmented image at a frequency corresponding to immobile fluid. The at least one elastic-wave-related property is determined from the mobile fluid and immobile fluid moduli. The method includes at least one of storing and displaying the at least one elastic-wave-related property so determined.

Abstract: A method for estimating permeability properties of a porous material from a sample thereof includes making a three dimensional tomographic image of the sample of the material. The image is segmented into pixels each representing pore space or rock grains. The image is divided into sub-volumes. A porosity is estimated for each sub-volume. The components of a permeability tensor are determined by conducting simulations. Principal permeability values and directions are then calculated. The permeability properties are stored in a computer or displayed.

Abstract: A method for estimating a petrophysical parameter from a rock sample includes making a three dimensional tomographic image of the sample of the material. The image is segmented into pixels each representing pore space or rock grain. Porosity of the sample is determined from the segmented image. An image of at least one fracture is introduced into the segmented image to generate a fractured image. The porosity of the fractured image is determined. At least one petrophysical parameter related to the pore-space geometry is estimated from the fractured image.

Abstract: A method for estimating permeability properties of a porous material from a sample thereof includes making a three dimensional tomographic image of the sample of the material. The image is segmented into pixels each representing pore space or rock grains. The image is divided into sub-volumes. A porosity is estimated for each sub-volume. The components of a permeability tensor are determined by conducting simulations. Principal permeability values and directions are then calculated. The permeability properties are stored in a computer or displayed.

Abstract: A method for determining in-situ relationships between physical properties of a porous medium from a sample thereof includes acquiring a three-dimensional image of the sample and segmenting the image into pixels representing pore space and pixels representing rock grain. A plurality of sub-volumes are selected from the segmented image, and a porosity is calculated for each of the sub-volumes. A digital simulation is conducted on each of the sub-volumes to obtain a selected physical property for the sub-volume. A relationship is determined between porosity and the selected physical property using relationship data comprising the calculated porosity and the simulated physical property for each of the sub-volumes. The method includes at least one of storing and displaying the relationship.

Abstract: A method for estimating a petrophysical parameter from a rock sample includes making a three dimensional tomographic image of the sample of the material. The image is segmented into pixels each representing pore space or rock grain. Porosity of the sample is determined from the segmented image. An image of at least one fracture is introduced into the segmented image to generate a fractured image. The porosity of the fractured image is determined. At least one petrophysical parameter related to the pore-space geometry is estimated from the fractured image.