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: This disclosure relates to the adsorption and separation of fluid components, such as oxygen, in a feed stream, such as air, using zeolite ITQ-55 as the adsorbent. A process is disclosed for adsorbing oxygen from a feed stream containing oxygen, nitrogen and argon. The process comprises passing the feed stream through a bed of an adsorbent comprising zeolite ITQ-55 to adsorb oxygen from the feed stream, carrying out an equalization step to improve recovery, thereby producing a nitrogen product stream depleted in oxygen as well as a waste stream can be collected to have enriched oxygen. The kinetic selectivity and related mass transfer rates can be tuned by varying the mean crystal particle size of zeolite ITQ-55 within the range of from about 0.1 microns to about 40 microns, or by varying the adsorption temperature within the range from about -195° C. to about 30° C., or by varying the adsorption pressure within the range from about 1 bar (~14.7 psi) to about 30 bar (~435 psi), or combinations thereof.

Abstract: The present disclosure relates to a porous liquid or a porous liquid enzyme that includes a high surface area solid and a liquid film substantially covering the high surface area solid. The porous liquid or porous liquid enzyme may be contacted with a fluid that is immiscible with the liquid film such that a liquid-fluid interface is formed. The liquid film may facilitate mass transfer of a substance or substrate across the liquid-fluid interface. The present disclosure also provides methods of performing liquid-based extractions and enzymatic reactions utilizing the porous liquid or porous liquid enzyme of the present disclosure.

Abstract: Metal-organic frameworks (MOFs) are highly porous entities comprising a multidentate ligand coordinated to multiple metal atoms, typically as a coordination polymer. MOFs are usually produced in powder form. Extrusion of powder-form MOFs to produce shaped bodies has heretofore proven difficult due to loss of surface area and poor crush strength of MOF extrudates, in addition to phase transformations occurring during extrusion. The choice of mixing conditions and the mixing solvent when forming MOF extrudates can impact these factors. Extrudates comprising a MOF consolidated material may feature the MOF consolidated material having a BET surface area of about 50% or greater relative to that of a pre-crystallized MOF powder material used to form the extrudate. X-ray powder diffraction of the extrudate shows about 20% or less conversion of the MOF consolidated material into a phase differing from that of the pre-crystallized MOF powder material.

Abstract: A process for producing a bimetallic, terephthalate metal organic framework (MOF) having a flexible structure and comprising aluminum and iron cations, comprises contacting a water-soluble aluminum salt, a chelated iron compound and 1,4-benzenedicarboxylic acid or a salt thereof with a fluoride-free mixture of water and a polar organic solvent at a reaction temperature of less than 200° C. to produce a solid reaction product comprising the MOF.

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: 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 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 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 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 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: The present disclosure relates to a porous liquid or a porous liquid enzyme that includes a high surface area solid and a liquid film substantially covering the high surface area solid. The porous liquid or porous liquid enzyme may be contacted with a fluid that is immiscible with the liquid film such that a liquid-fluid interface is formed. The liquid film may facilitate mass transfer of a substance or substrate across the liquid-fluid interface. The present disclosure also provides methods of performing liquid-based extractions and enzymatic reactions utilizing the porous liquid or porous liquid enzyme of the present disclosure.

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.