Abstract: A solution for injection to a formation containing hydrocarbons includes an ionic liquid and a brine having a salinity of at least 60,000 ppm total dissolved solids (TDS). The ionic liquid is configured to lower an interfacial tension between the solution and the hydrocarbons in the formation.

Abstract: A solution for injection to a formation containing hydrocarbons includes an ionic liquid and a brine having a salinity of at least 60,000 ppm total dissolved solids (TDS). The ionic liquid is configured to lower an interfacial tension between the solution and the hydrocarbons in the formation.

Abstract: Described is a method for enhanced carbon dioxide (CO2) sequestration in geological formations. The method includes dissolving CO2 in a low salinity fluid to form a CO2-brine solution. The low salinity fluid includes sodium (Na+) ions and sulfate (SO42?) ions. The CO2-brine solution is injected into a geological formation, and the CO2 reacts with the geological formation to produce solid carbonate minerals for CO2 sequestration.

Abstract: A method for enhancing productivity of a stratified subterranean wellbore includes introducing a mixture including water and a first set of nanoparticles reactive to high frequency acoustic waves having a size ranging from about 10 to 100 nm to a first target zone, located in a high permeability layer of the stratified subterranean wellbore. A first stimulation including acoustic waves having a frequency range of 1 kHz to 10 kHz is provided to the first set of nanoparticles to promote reacting. Then, a mixture including water and a second set of nanoparticles having a size ranging from about 1 to 10 nm is introduced to a second target zone, located in a medium permeability layer of the stratified subterranean wellbore. A second stimulation including acoustic waves having a frequency range of 100 Hz to 1 kHz is provided to the second set of nanoparticles to promote reacting.

Abstract: A method for manufacturing a micromodel with a mixed wettability surface representing a hydrocarbon reservoir is disclosed. The method includes coating a top surface of a hydrophilic substrate with photoresist, covering a top of the photoresist with a photomask, exposing the covered top of the photoresist to UV light that changes a chemical property of a region of the photoresist corresponding to a pattern of the photomask, removing the photomask, removing the region of the photoresist corresponding to the pattern of the photomask based on the chemical property of the region, depositing a hydrophobic thin-film on top of the hydrophilic substrate, and removing a remaining photoresist covered with the thin-film, such that the surface of the hydrophilic substrate is patterned with both a region covered with the hydrophobic thin-film and an uncovered region of the hydrophilic substrate, creating a mixed wettability surface on the hydrophilic substrate that represents the micromodel.

Abstract: A method includes 3d printing a polymer substrate having microfluidic channels and depositing calcite onto the polymer substrate then using atomic layer deposition to form a calcite microfluidic device. A device made from the method includes a 3d printed polymer substrate having microfluidic channels. The 3d printed polymer substrate has a calcite coating.

Abstract: A method for selectively optimizing water chemistry within a wellbore may include positioning a system tubing in the wellbore. The system tubing may include an electrochemical cell, a first chamber, and a second chamber. The method may also include injecting a fluid into the electrochemical cell and directing an electrical current into the electrochemical cell wherein the fluid separates by charge into a first fluid and a second fluid. The method may also include passing the first fluid into the first chamber and the second fluid into the second chamber. Also, the method may include rotating the system tubing, wherein the first fluid flows from the first chamber to the wellbore through a first radial conduit and the second fluid flows from the second chamber to the wellbore through a second radial conduit.

Abstract: A method for enhancing productivity of a stratified subterranean wellbore includes introducing a mixture including water and a first set of nanoparticles reactive to high frequency acoustic waves having a size ranging from about 10 to 100 nm to a first target zone, located in a high permeability layer of the stratified subterranean wellbore. A first stimulation including acoustic waves having a frequency range of 1 kHz to 10 kHz is provided to the first set of nanoparticles to promote reacting. Then, a mixture including water and a second set of nanoparticles having a size ranging from about 1 to 10 nm is introduced to a second target zone, located in a medium permeability layer of the stratified subterranean wellbore. A second stimulation including acoustic waves having a frequency range of 100 Hz to 1 kHz is provided to the second set of nanoparticles to promote reacting.

Abstract: A method includes flowing an inlet solution having an inlet salinity and an inlet ion concentration from an inlet to a membrane filtration system, dynamically adjusting the salinity or ion concentration of the inlet solution in situ as the inlet solution flows to an inlet of a microfluidic cell, and determining a wettability alteration in situ while dynamically adjusting the salinity or ion concentration of the inlet solution. A system includes a fluid inlet, a microfluidic cell fluidly coupled to the fluid inlet, the microfluidic cell having a surface representative of a reservoir rock, and a membrane filtration system coupled between the microfluidic cell and the fluid inlet.

Abstract: A pressure cell includes a metal pressure chamber, a heating stage, disposed in the interior of the metal pressure chamber, that heats the liquid sample, a chamber pump, connected to the interior of the metal pressure chamber, that pressurizes the interior of the metal pressure chamber, a salinity control system including a membrane coupled to the sample inlet, where the membrane is configured to reduce a salinity level of the liquid sample, and a controller that controls the chamber pump, the salinity control system, and the heating stage to control a pressure of the interior of the metal pressure chamber, a salinity level of the liquid sample, and a temperature of the liquid sample, respectively. The metal pressure chamber includes a liquid sample holder, a removable lid, a window in the removable lid, a sample inlet, and a sample outlet.

Abstract: A pressure cell includes a metal pressure chamber, a heating stage, disposed in the interior of the metal pressure chamber, that heats the liquid sample, a chamber pump, connected to the interior of the metal pressure chamber, that pressurizes the interior of the metal pressure chamber, a salinity control system including a membrane coupled to the sample inlet, where the membrane is configured to reduce a salinity level of the liquid sample, and a controller that controls the chamber pump, the salinity control system, and the heating stage to control a pressure of the interior of the metal pressure chamber, a salinity level of the liquid sample, and a temperature of the liquid sample, respectively. The metal pressure chamber includes a liquid sample holder, a removable lid, a window in the removable lid, a sample inlet, and a sample outlet.

Abstract: A method for selectively optimizing water chemistry within a wellbore may include positioning a system tubing in the wellbore. The system tubing may include an electrochemical cell, a first chamber, and a second chamber. The method may also include injecting a fluid into the electrochemical cell and directing an electrical current into the electrochemical cell wherein the fluid separates by charge into a first fluid and a second fluid. The method may also include passing the first fluid into the first chamber and the second fluid into the second chamber. Also, the method may include rotating the system tubing, wherein the first fluid flows from the first chamber to the wellbore though a first radial conduit and the second fluid flows from the second chamber to the wellbore through a second radial conduit.

Abstract: Method for enhancing oil recovery in a hydrocarbon-containing carbonate reservoir including: injecting a slug of an oil recovery solution into the carbonate reservoir such that the wettability of a rock surface of the hydrocarbon-containing reservoir is altered toward more water-wet; and injecting a slug of a displacing fluid into the hydrocarbon-containing carbonate reservoir formation after injecting the slug of the oil recovery solution. The oil recovery solution comprising: a manganese-bearing aqueous solution having manganese ions and one or more major ions. The aqueous saline solution having a concentration of manganese ions between 100 and 1,000 ppm TDS and a concentration of major ions that is equivalent to the concentration of major ions in seawater as it is found in nature. The one or more major ions can include: sodium ion, magnesium ion, calcium ion, chlorine ion, sulfate ion, bicarbonate ion, and combinations of the same.

Abstract: A system to measure a streaming potential of a core plug includes a measurement cell having a chamber to hold the core plug and an inlet fluid line connected to an inlet port of the measurement cell. A filtration device is arranged to control a salinity and ionic strength of a liquid medium received in the chamber through the inlet fluid line. The filtration device has membrane filters with different ion rejection rates and is controllable to selectively dispose each of the membrane filters in the inlet fluid line.

Abstract: A method includes flowing an inlet solution having an inlet salinity and an inlet ion concentration from an inlet to a membrane filtration system, dynamically adjusting the salinity or ion concentration of the inlet solution in situ as the inlet solution flows to an inlet of a microfluidic cell, and determining a wettability alteration in situ while dynamically adjusting the salinity or ion concentration of the inlet solution. A system includes a fluid inlet, a microfluidic cell fluidly coupled to the fluid inlet, the microfluidic cell having a surface representative of a reservoir rock, and a membrane filtration system coupled between the microfluidic cell and the fluid inlet.

Abstract: Method for enhancing oil recovery in a hydrocarbon-containing carbonate reservoir including: injecting a slug of an oil recovery solution into the carbonate reservoir such that the wettability of a rock surface of the hydrocarbon-containing reservoir is altered toward more water-wet; and injecting a slug of a displacing fluid into the hydrocarbon-containing carbonate reservoir formation after injecting the slug of the oil recovery solution. The oil recovery solution comprising: a manganese-bearing aqueous solution having manganese ions and one or more major ions. The aqueous saline solution having a concentration of manganese ions between 100 and 1,000 ppm TDS and a concentration of major ions that is equivalent to the concentration of major ions in seawater as it is found in nature. The one or more major ions can include: sodium ion, magnesium ion, calcium ion, chlorine ion, sulfate ion, bicarbonate ion, and combinations of the same.

Abstract: A system to measure a streaming potential of a core plug includes a measurement cell having a chamber to hold the core plug and an inlet fluid line connected to an inlet port of the measurement cell. A filtration device is arranged to control a salinity and ionic strength of a liquid medium received in the chamber through the inlet fluid line. The filtration device has membrane filters with different ion rejection rates and is controllable to selectively dispose each of the membrane filters in the inlet fluid line.

Abstract: Provided are oil recovery compositions and processes for enhancing oil recovery from a carbonate reservoir. A process for enhancing oil recovery includes injecting a first slug of an aqueous solution having a salinity in the range of about 5,000 ppm TDS to about 7,000 ppm TDS and sulfate ions in the range of about 500 ppm to about 5000 ppm. After injection of the first slug, the process includes injecting a second slug of an aqueous solution having a salinity in the range of about 5,000 ppm TDS to about 7,000 ppm TDS, calcium ion concentrations in the range of about 100 ppm to about 1000 ppm, and magnesium ions in the range of about 200 ppm to about 2000 ppm. A third slug of seawater or produce water may then be injected as chase water.

Abstract: Provided are oil recovery compositions and processes for enhancing oil recovery from a carbonate reservoir. A process for enhancing oil recovery includes injecting a first slug of an aqueous solution having a salinity in the range of about 5,000 ppm TDS to about 7,000 ppm TDS and sulfate ions in the range of about 500 ppm to about 5000 ppm. After injection of the first slug, the process includes injecting a second slug of an aqueous solution having a salinity in the range of about 5,000 ppm TDS to about 7,000 ppm TDS, calcium ion concentrations in the range of about 100 ppm to about 1000 ppm, and magnesium ions in the range of about 200 ppm to about 2000 ppm. A third slug of seawater or produce water may then be injected as chase water.