Abstract: A process for forming a particle carrier system includes supplying a particle carrier, the particle carrier having a surface and modifying the particle carrier surface to include a first ionic functional group. The process also includes chemically binding the first ionic functional group on the particle carrier surface to a first ionic molecule.

Abstract: A method includes forming an ionic liquid-based product, the ionic liquid-based product including an ionic liquid and mixing the ionic-liquid based product with a fluid. The method also includes injecting the fluid mixed with the ionic-liquid based product into a formation as part of an Improved Oil Recovery (IOR) application.

Abstract: A physical modeling method that includes providing a reservoir core plug, the reservoir core plug having a wellbore interface end, an outlet interface end, and a cylindrical face and saturating the reservoir core plug with hydrocarbon and brine to form a saturated core plug. The method also includes positioning the saturated core plug within a flooding apparatus and pumping the fracturing fluid through saturated core plug to displace a portion of the hydrocarbon to form a displaced hydrocarbon plug. In addition the method includes positioning the displaced hydrocarbon plug in an imbibition cell and conducting an imbibition test to form an imbibed core plug having brine and hydrocarbon. Further the method includes positioning the imbibed core plug in core-flooding apparatus and displacing a portion of the brine and hydrocarbon from the imbibed core plug.

Abstract: A process for forming a particle carrier system includes supplying a particle carrier, the particle carrier having a surface and modifying the particle carrier surface to include a first ionic functional group. The process also includes chemically binding the first ionic functional group on the particle carrier surface to a first ionic molecule.

Abstract: The method includes gathering field data of a formation, preparing samples of brine consistent with the composition of the formation brine and the injection brine, dead crude oil, and live crude oil, and characterizing the properties of crude oil samples. The method includes preparing samples of reservoir rock and characterizing the properties of the rock samples of the formation. The method includes measuring the contact angle of surfactant/formation brine/formation rock/formation crude oil samples at ambient and reservoir conditions and measuring the interfacial tension of the sample. The method includes characterizing the HLD properties of each surfactant. In addition, the method includes performing formulation targeting HLD=0 for a mixture of surfactants, performing laboratory evaluation of the HLD=0 formulation of the mixture of the surfactants to obtain values of oil recovery number, and testing the HLD=0 formulation of the mixture of the first and second selected surfactants in the formation.

Abstract: A method includes determining reservoir rock and fluid characteristics of a reservoir rock and, based on the reservoir rock and fluid characteristics of the reservoir rock, selecting a core. The method also includes selecting a first surfactant and selecting a second surfactant. In addition, the method includes performing a water block mitigation test using the selected core, the first surfactant and the second surfactant and performing a proppant phase trapping mitigation test using the selected core, the first surfactant and the second surfactant.

Abstract: A method includes forming an ionic liquid-based product, the ionic liquid-based product including an ionic liquid and mixing the ionic-liquid based product with a fluid. The method also includes injecting the fluid mixed with the ionic-liquid based product into a formation as part of an Improved Oil Recovery (IOR) application.

Abstract: A fluid injection process includes removing a core sample from a low permeability reservoir. The process also includes performing an imbibition test on a plurality of stage one surfactants, each stage one surfactant mixed with a first treatment fluid and using a portion of the core sample to obtain a wettability index or measurement of capillary pressure. The process includes selecting a stage one surfactant and performing an oil recovery test on a plurality of stage two surfactants, each stage two surfactant mixed with a second treatment fluid. The process includes selecting a stage two surfactant and injecting the selected stage one surfactant into a matrix of the low permeability reservoir. In addition, the method includes injecting the selected stage two surfactant into a fracture network of the low permeability reservoir.

Abstract: A crude oil displacement method includes partially filling a vessel with treatment fluid and positioning an oil-saturated sample within the treatment fluid. The method also includes adding a solvent system to the vessel above the treatment fluid. In addition, the method includes moving oil from the oil-saturated sample into the solvent system. The method also includes measuring one or more of R, G, B, L, a, b, L, C, H, H, S, B, reflectance, transmittance and wavelength of the displaced oil using a color device. In addition, the method includes determining the amount of displaced oil using the one or more of R, G, B, L, a, b, L, C, H, H, S, B, reflectance, transmittance and wavelength of the displaced oil.

Abstract: A physical modeling method that includes providing a reservoir core plug, the reservoir core plug having a wellbore interface end, an outlet interface end, and a cylindrical face and saturating the reservoir core plug with hydrocarbon and brine to form a saturated core plug. The method also includes positioning the saturated core plug within a flooding apparatus and pumping the fracturing fluid through saturated core plug to displace a portion of the hydrocarbon to form a displaced hydrocarbon plug. In addition the method includes positioning the displaced hydrocarbon plug in an imbibition cell and conducting an imbibition test to form an imbibed core plug having brine and hydrocarbon. Further the method includes positioning the imbibed core plug in core-flooding apparatus and displacing a portion of the brine and hydrocarbon from the imbibed core plug.

Abstract: A method includes determining reservoir rock and fluid characteristics of a reservoir rock and, based on the reservoir rock and fluid characteristics of the reservoir rock, selecting a core. The method also includes selecting a first surfactant and selecting a second surfactant. In addition, the method includes performing a water block mitigation test using the selected core, the first surfactant and the second surfactant and performing a proppant phase trapping mitigation test using the selected core, the first surfactant and the second surfactant.

Abstract: A fluid injection process includes removing a core sample from a low permeability reservoir. The process also includes performing an imbibition test on a plurality of stage one surfactants, each stage one surfactant mixed with a first treatment fluid, using a portion of the core sample to obtain a wettability index or measurement of capillary pressure for each stage one surfactant. In addition, the process includes selecting a stage one surfactant by determining which of the plurality of stage one surfactants has the highest wettability index or lowest capillary pressure and performing an oil recovery test on a plurality of stage two surfactants, each stage two surfactant mixed with a second treatment fluid. Further, the process includes selecting a stage two surfactant by determining which of the plurality of stage two surfactants has the highest oil recovery test result and injecting the selected stage one surfactant into a matrix of the low permeability reservoir.

Abstract: A fluid injection process includes removing a core sample from a low permeability reservoir. The process also includes performing an imbibition test on a plurality of stage one surfactants, each stage one surfactant mixed with a first treatment fluid, using a portion of the core sample to obtain a wettability index or measurement of capillary pressure for each stage one surfactant. In addition, the process includes selecting a stage one surfactant by determining which of the plurality of stage one surfactants has the highest wettability index or lowest capillary pressure and performing an oil recovery test on a plurality of stage two surfactants, each stage two surfactant mixed with a second treatment fluid. Further, the process includes selecting a stage two surfactant by determining which of the plurality of stage two surfactants has the highest oil recovery test result and injecting the selected stage one surfactant into a matrix of the low permeability reservoir.

Abstract: A fluid injection process includes removing a core sample from a low permeability reservoir. The process also includes performing an imbibition test on a plurality of stage one surfactants, each stage one surfactant mixed with a first treatment fluid, using a portion of the core sample to obtain a wettability index or measurement of capillary pressure for each stage one surfactant. In addition, the process includes selecting a stage one surfactant by determining which of the plurality of stage one surfactants has the highest wettability index or lowest capillary pressure and performing an oil recovery test on a plurality of stage two surfactants, each stage two surfactant mixed with a second treatment fluid. Further, the process includes selecting a stage two surfactant by determining which of the plurality of stage two surfactants has the highest oil recovery test result and injecting the selected stage one surfactant into a matrix of the low permeability reservoir.