Exxonmobil Research and Engineering Company

Exxonmobil Upstream Research Company

Exxonmobil Technology and Engineering Company

Other

Exxonmobile Research and Engineering Company

Pavel Kortunov

Harry William Deckman

Michael Siskin

Hubert E King

Lisa Saunders Baugh

Charanjit Singh Paur

David Charles Calabro

Antonio S Buono

Charanjit S Paur

Avelino Corma Canos

Sebastian Carmen Reyes

John Zengel

Zheng Ni

Yu Wang

Shreerang S Chhatre

Jose G Santiesteban, Legal Representative

Quanchang Li

Edward William Corcoran, Jr

Peter I Ravikovitch

Fernando Rey García

Susana Valencia Valencia

Miguel Palomino Roca

Hemantkumar R Sahoo

Fernando Rey Garcia

Jr Corcoran Edward W

Dennis G Peiffer

Benjamin A McCool

David C Calabro

John Henry Dunsmuir

Angel Cantin Sanz

Shawn Fullmer

Michael Sansone

Bo Gao

James G Kralik

Ye Xu

Lisa S Baugh

Mohsen Shahmirzadi Yeganeh

Hans Thomann

Preeti Kamakoti

P Scott Northrop

Matthew Scott Ide

Ning Ma

Zarath M Summers

Giovanni Pilloni

Qiuzi Li

Robert J Colby

Xiaozhou Zhang

Edward W Corcoran, Jr

Angel Cantín Sanz

Jr Edward W Corcoran

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 feed stream is exposed to the zeolite ITQ-55 at effective conditions for performing a rapid cycle of kinetic separation, in which oxygen exhibits greater kinetic selectivity than nitrogen and argon.

Air separation processes using zeolite ITQ-55

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.

Advanced NMR analysis of pore type and pore connectivity in core samples including diffusional fluid exchange methods

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.

Advanced NMR analysis of porosity and other properties in core samples using hydraulic fluid exchange

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.

Porous liquid and methods of making and using the same

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.

Methods for measuring the porosity of core samples using NMR analysis

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.

Methods using advanced NMR analysis for core samples

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.

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.

Advanced NMR analysis of pore type distribution in core samples using hydraulic fluid exchange

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.

Method and system for enhancing hydrocarbon operations

This invention refers to a microporous crystalline material of zeolitic nature that has, in its calcined state and in the absence of defects in its crystalline matrix manifested by the presence of silanols, the empirical formula(MXO):YOGeO:(1)SiO2

Separation and storage of fluids using ITQ-55

A method is described for separating COand/or HS from a mixed gas stream by contacting the gas stream with a non-aqueous, liquid absorbent medium of a primary and/or secondary aliphatic amine, preferably in a non-aqueous, polar, aprotic solvent under conditions sufficient for sorption of at least some of the CO. The solution containing the absorbed COcan then be treated to desorb the acid gas. The method is usually operated as a continuous cyclic sorption-desorption process, with the sorption being carried out in a sorption zone where a circulating stream of the liquid absorbent contacts the gas stream to form a CO-rich sorbed solution, which is then cycled to a regeneration zone for desorption of the CO(advantageously at &#x3c;100&#xb0; C.). Upon COrelease, the regenerated lean solution can be recycled to the sorption tower. CO:(primary+secondary amine) adsorption molar ratios&#x3e;0.5:1 (approaching 1:1) may be achieved.

Non-aqueous amine scrubbing for removal of carbon dioxide

Promoter amines are used to enhance COuptake by sterically hindered or tertiary amines. The promoter amines can be cyclic amines, including aromatic cyclic amines or bridged cyclic amines. The combination of a promoter amine plus a sterically hindered or tertiary amines allows for improved uptake kinetics while reducing or minimizing the amount of formation of carbamate salts. The promoted sterically hindered or tertiary amines can be used as part of a COcapture and release system that involves a phase transition from a solution of amine-COproducts to a slurry of amine-COprecipitate solids.

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This invention refers to a microporous crystalline material of zeolitic nature that has, in its calcined state and in the absence of defects in its crystalline matrix manifested by the presence of silanols, the empirical formula(MXO):YOGeO:(1&#x2212;)SiO2

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Flemington, NJ, United States of America

Pavel Kortunov