Abstract: A method for determining the pore types of a core sample can include: determining a porosity of a core sample, wherein the core sample has a permeability of 10 mD or less; saturating the core sample with a NMR saturation fluid to achieve a saturated core sample; taking a NMR measurement of fluids in the saturated core sample; and deriving a volume for a pore type based on the porosity based on a correlation between the NMR measurement and a NMR signal to fluid volume calibration, wherein the pore type is selected from the group consisting of a nanopore, a micropore, a macropore, and any combination thereof.

Abstract: A method for determining the porosity of a core sample can include: saturating a core sample with a nuclear magnetic resonance (NMR) saturation fluid, wherein the core sample has a permeability of 100 milliDarcy (mD) or less, to achieve a saturated core sample; taking a NMR measurement of fluids in the saturated core sample; determining a porosity of the core sample based on a correlation between the NMR measurement and a NMR signal to fluid volume calibration.

Abstract: A method of analyzing a rock sample includes analyzing one or more large-area, low-resolution micrographs to identify areas requiring higher-resolution imaging, and selecting one or more analysis regions from the areas requiring higher-resolution imaging. Multi-spectral imaging is used on the one or more analysis regions to obtain one or more high-resolution, multi-spectral images, and one or more features of the rock sample are identified from the corresponding one or more high-resolution, multi-spectral images. The method further includes upscaling the one or more high-resolution, multi-spectral images and thereby geo-locating the features of the rock sample to key regions of the rock sample.

Abstract: A method for determining the porosity of a core sample can include: submerging a core sample in a NMR saturation fluid, wherein the core sample has a permeability of 10 mD or less; exposing the fluid to a vacuum while the core sample is submerged the NMR saturation fluid for a sufficient period of time to saturate the core sample; removing the vacuum while maintaining the core sample submerged the NMR saturation fluid; taking a NMR measurement of fluids in the core sample; and determining a porosity of the core sample based on a correlation between the NMR measurement and a NMR signal to fluid volume calibration.

Abstract: A method for determining the fluid mobility of a core sample can include: determining a porosity of a core sample having a permeability of 10 mD or less; saturating the core sample with a NMR saturation fluid; taking a first NMR measurement of fluids in the core sample; diffusionally exchanging a hydrophobic fluid or a hydrophilic fluid in the core sample in a hydrophobic NMR exchange fluid or a hydrophilic NMR exchange fluid, respectively; taking a second NMR measurement of the fluid in the core sample after diffusional exchange; and deriving a property of the core sample based on the porosity, a NMR signal to fluid volume calibration, and a comparison between the first and the second NMR measurements, the property being selected from the group consisting of a mobile oil volume, an immobile hydrocarbon volume, a mobile water volume, an immobile water volume, and a combination thereof.

Abstract: A method for determining a core sample property selected from the group consisting of a recoverable oil volume, an irreducible hydrocarbon volume, a recoverable water volume, an irreducible water volume, and any combination thereof can include: determining a porosity of a core sample, wherein the core sample has a permeability of 100 milliDarcy (mD) or less; saturating the core sample with a NMR saturation fluid; taking a first nuclear magnetic resonance (NMR) measurement of fluids in the core sample; hydraulically exchanging a hydrophobic fluid or a hydrophilic fluid in the core sample in a hydrophilic NMR exchange fluid or a hydrophobic NMR exchange fluid, respectively; taking a second NMR measurement of the fluids in the core sample after hydraulic exchange; and deriving the property of the core sample based on the porosity, a NMR signal to fluid volume calibration, and a comparison between the first and second NMR measurements.

Abstract: A method determining a volume of a pore type of a core sample can include: determining a porosity of a core sample, wherein the core sample has a permeability of 100 milliDarcy (mD) or less; saturating the core sample with a nuclear magnetic resonance (NMR) saturation fluid to achieve a saturated core sample; taking a NMR measurement of fluids in the saturated core sample; and deriving a volume for a pore type based on the porosity based on a correlation between the NMR measurement and a NMR signal to fluid volume calibration, wherein the pore type is selected from the group consisting of a nanopore, a micropore, a macropore, and any combination thereof.

Abstract: A method and system are described for imaging core samples associated with a subsurface region. The imaging results may be used to create or update a subsurface model and using the subsurface model and/or imaging results in hydrocarbon operations. The imaging techniques may include NMR imaging and CT imaging. Further, the imaging techniques may also include exposing the core sample to the imaging gas.

Abstract: A method for determining a core sample property selected from the group consisting of a recoverable oil volume, an irreducible hydrocarbon volume, a recoverable water volume, an irreducible water volume, and any combination thereof can include: determining a porosity of a core sample, wherein the core sample has a permeability of 100 milliDarcy (mD) or less; saturating the core sample with a NMR saturation fluid; taking a first nuclear magnetic resonance (NMR) measurement of fluids in the core sample; hydraulically exchanging a hydrophobic fluid or a hydrophilic fluid in the core sample in a hydrophilic NMR exchange fluid or a hydrophobic NMR exchange fluid, respectively; taking a second NMR measurement of the fluids in the core sample after hydraulic exchange; and deriving the property of the core sample based on the porosity, a NMR signal to fluid volume calibration, and a comparison between the first and second NMR measurements.

Abstract: A method for determining the porosity of a core sample can include: saturating a core sample with a nuclear magnetic resonance (NMR) saturation fluid, wherein the core sample has a permeability of 100 milliDarcy (mD) or less, to achieve a saturated core sample; taking a NMR measurement of fluids in the saturated core sample; determining a porosity of the core sample based on a correlation between the NMR measurement and a NMR signal to fluid volume calibration.

Abstract: A method for determining the porosity of a core sample can include: submerging a core sample in a NMR saturation fluid, wherein the core sample has a permeability of 10 mD or less; exposing the fluid to a vacuum while the core sample is submerged the NMR saturation fluid for a sufficient period of time to saturate the core sample; removing the vacuum while maintaining the core sample submerged the NMR saturation fluid; taking a NMR measurement of fluids in the core sample; and determining a porosity of the core sample based on a correlation between the NMR measurement and a NMR signal to fluid volume calibration.

Abstract: A method for determining the fluid mobility of a core sample can include: determining a porosity of a core sample having a permeability of 10 mD or less; saturating the core sample with a NMR saturation fluid; taking a first NMR measurement of fluids in the core sample; diffusionally exchanging a hydrophobic fluid or a hydrophilic fluid in the core sample in a hydrophobic NMR exchange fluid or a hydrophilic NMR exchange fluid, respectively; taking a second NMR measurement of the fluid in the core sample after diffusional exchange; and deriving a property of the core sample based on the porosity, a NMR signal to fluid volume calibration, and a comparison between the first and the second NMR measurements, the property being selected from the group consisting of a mobile oil volume, an immobile hydrocarbon volume, a mobile water volume, an immobile water volume, and a combination thereof.

Abstract: A method determining a volume of a pore type of a core sample can include: determining a porosity of a core sample, wherein the core sample has a permeability of 100 milliDarcy (mD) or less; saturating the core sample with a nuclear magnetic resonance (NMR) saturation fluid to achieve a saturated core sample; taking a NMR measurement of fluids in the saturated core sample; and deriving a volume for a pore type based on the porosity based on a correlation between the NMR measurement and a NMR signal to fluid volume calibration, wherein the pore type is selected from the group consisting of a nanopore, a micropore, a macropore, and any combination thereof

Abstract: A method for determining the pore types of a core sample can include: determining a porosity of a core sample, wherein the core sample has a permeability of 10 mD or less; saturating the core sample with a NMR saturation fluid to achieve a saturated core sample; taking a NMR measurement of fluids in the saturated core sample; and deriving a volume for a pore type based on the porosity based on a correlation between the NMR measurement and a NMR signal to fluid volume calibration, wherein the pore type is selected from the group consisting of a nanopore, a micropore, a macropore, and any combination thereof

Abstract: A method and system are described for imaging core samples associated with a subsurface region. The imaging results may be used to create or update a subsurface model and using the subsurface model and/or imaging results in hydrocarbon operations. The imaging techniques may include NMR imaging and CT imaging. Further, the imaging techniques may also include exposing the core sample to the imaging gas.

Abstract: A method of analyzing a rock sample includes analyzing one or more large-area, low-resolution micrographs to identify areas requiring higher-resolution imaging, and selecting one or more analysis regions from the areas requiring higher-resolution imaging. Multi-spectral imaging is used on the one or more analysis regions to obtain one or more high-resolution, multi-spectral images, and one or more features of the rock sample are identified from the corresponding one or more high-resolution, multi-spectral images. The method further includes upscaling the one or more high-resolution, multi-spectral images and thereby geo-locating the features of the rock sample to key regions of the rock sample.

Abstract: A method and system are described for imaging core samples associated with a subsurface region. The imaging results may be used to create or update a subsurface model and using the subsurface model and/or imaging results in hydrocarbon operations. The imaging techniques may include NMR imaging and CT imaging. Further, the imaging techniques may also include exposing the core sample to the imaging gas.

Abstract: A method and system are described for imaging core samples associated with a subsurface region. The imaging results may be used to create or update a subsurface model and using the subsurface model and/or imaging results in hydrocarbon operations. The imaging techniques may include NMR imaging and CT imaging. Further, the imaging techniques may also include exposing the core sample to the imaging gas.

Abstract: A method, including: obtaining a grain size for amorphous silica associated with a basin and a grain size for quartz associated with the basin; obtaining kinetics of silica dissolution corresponding to the basin and quartz precipitation corresponding to the basin; determining, with a processor, a concentration of amorphous silica in water based on the grain size for amorphous silica, the grain size for quartz, and the kinetics of silica dissolution and quartz precipitation; comparing, with the processor, the concentration of amorphous silica in water to an amorphous silica saturation condition; and determining, with the processor, a presence of microquartz based on a result of the comparing.

Abstract: The present techniques are directed to a method for microprobe analyses of isotope ratios in inhomogeneous matrices. The method includes selecting matrix standards that have matrices that resemble a target matrix. A bulk isotope analysis is run on each of the matrix standards to determine a bulk isotope ratio value. A microprobe analysis is run on each of the matrix standards to determine a microprobe isotope ratio values for each of the plurality of matrix standards. Spurious values are eliminated from the microprobe isotope ratio values. The microprobe isotope ratio values are averaged for each of the matrix standards to create an average microprobe isotope ratio value associated with each of the matrix standards. The bulk isotope ratio value for each of matrix standards is plotted against the average microprobe isotope ratio value associated with each of the matrix standards to create a matrix corrected calibration curve.