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 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 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 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: The present invention generally relates to devices and methods for affecting the flow rate of fluid using pressure. The invention generally provides for controlled application of pressure to flowing fluids to control pressure and flow rates of those fluids, independent of location of the fluids relative to various devices. For example, in a series of devices, each connected to another via a conduit, pressure control units can be provided between devices to raise or lower pressure and/or flow rate of fluid flowing from one device to the next. In this way, a series of interconnected devices can be arranged such that inlet fluid pressure or flow rate of any individual device can be set independently of every other device.

Abstract: The present invention generally relates to the small-scale separation of a mixture of two or more components with different boiling points into enriched fractions. In some embodiments, a first and second fluid (e.g., a liquid and a gas, a liquid and a liquid, etc.) are passed through a channel. The first fluid may include at least two components, each with a unique boiling point. Upon contacting the first and second fluids within the channel, at least a portion of the most volatile of the components in the first fluid (i.e., the component with the lowest boiling point) may be transferred from the first fluid to the second fluid. In some instances, the transfer of the volatile component(s) from the first fluid to the second fluid may be expedited by heating, in some cases above the boiling point(s) of the component(s) to be transferred from the first fluid to the second fluid. Contact between the first and second fluids may be maintained, for example, via segmented flow, bubbling flow, etc.

Abstract: The present invention generally relates to devices and methods for affecting the flow rate of fluid using pressure. The invention generally provides for controlled application of pressure to flowing fluids to control pressure and flow rates of those fluids, independent of location of the fluids relative to various devices. For example, in a series of devices, each connected to another via a conduit, pressure control units can be provided between devices to raise or lower pressure and/or flow rate of fluid flowing from one device to the next. In this way, a series of interconnected devices can be arranged such that inlet fluid pressure or flow rate of any individual device can be set independently of every other device.

Abstract: The present invention generally relates to the small-scale separation of a mixture of two or more components with different boiling points into enriched fractions. In some embodiments, a first and second fluid (e.g., a liquid and a gas, a liquid and a liquid, etc.) are passed through a channel. The first fluid may comprise at least two components, each with a unique boiling point. Upon contacting the first and second fluids within the channel, at least a portion of the most volatile of the components in the first fluid (i.e., the component with the lowest boiling point) may be transferred from the first fluid to the second fluid. In some instances, the transfer of the volatile component(s) from the first fluid to the second fluid may be expedited by heating, in some cases above the boiling point(s) of the component(s) to be transferred from the first fluid to the second fluid. Contact between the first and second fluids may be maintained, for example, via segmented flow, bubbling flow, etc.

Abstract: One aspect of the invention relates to fluid-phase separators and devices containing them. Another aspect of the invention relates to the use of said fluid-phase separators and devices containing them for separating individual phases from gas-liquid and liquid-liquid two-phase mixtures for a range of flow regimes. The present invention also relates to methods of making said fluid-phase separators and devices containing them.