Abstract: A fracturing fluid may comprise an aqueous based fluid and halloysite nanotubes, wherein the halloysite nanotubes comprise a cargo.

Abstract: Sand consolidation for a subterranean formation can be achieved by adding a curable resin to a drilling fluid. The curable resin can be a furan- or epoxy- or silane-based resin. The drilling fluid can form a filtercake on a wellbore wall. A filtercake-removal fluid can provide a dual function to remove the filtercake and cure the curable resin, which consolidates formation particles. A curing agent can also be included in the filtercake-removal fluid. Sand consolidation can also be achieved by adding the curable resin to the filtercake-removal fluid. The resin can penetrate into the formation as the filtercake is being removed and then cure.

Abstract: Methods of fracturing a subterranean formation containing a hydrocarbon include introducing a first fracturing fluid that includes natural gas into the formation at a rate and pressure sufficient to create a complex fracture in the formation; introducing a second fracturing fluid into the formation, wherein the second fracturing fluid comprises water, a gelling agent, a foaming agent, natural gas, and proppant particulates; and allowing the second fracturing fluid to transport a portion of the proppant particulates into the complex fracture.

Abstract: A fracturing fluid may comprise an aqueous based fluid and halloysite nanotubes, wherein the halloysite nanotubes comprise a cargo.

Abstract: A method of fracturing a subterranean formation may comprise: pumping a fracturing fluid into the subterranean formation, through a wellbore, at or above a fracture gradient of the subterranean formation, wherein the fracturing fluid comprises halloysite nanotubes.

Abstract: Fracturing fluids and acidizing fluids used in wellbore stimulation operations can include a metal silicate having a molar ratio of SiO2:M2O of 2:1 or above, wherein M is an alkali metal atom or an alkaline earth metal atom. The metal silicate can increase the viscosity of the stimulation fluids and slickwater stimulation fluids.

Abstract: Methods of fracturing a subterranean formation containing a hydrocarbon include introducing a first fracturing fluid that includes natural gas into the formation at a rate and pressure sufficient to create a complex fracture in the formation; introducing a second fracturing fluid into the formation, wherein the second fracturing fluid comprises water, a gelling agent, a foaming agent, natural gas, and proppant particulates; and allowing the second fracturing fluid to transport a portion of the proppant particulates into the complex fracture.

Abstract: Systems, methods, and compositions for creating microfractures within subterranean formations and delivering microproppant particles into microfractures within subterranean formations are provided. In some embodiments, the methods include: providing a treatment fluid that comprises an aqueous base fluid, a surfactant, and a plurality of microproppant particles having a mean particle diameter of about 100 microns or less; introducing the treatment fluid into a subterranean formation at or above a pressure sufficient to initiate the formation of at least one microfracture within the subterranean formation; and allowing at least a portion of the microproppant particles to enter the at least one microfracture within the subterranean formation.

Abstract: Various embodiments disclosed relate to proppant including a swellable coating thereon for treatment of subterranean formations. In various embodiments, the present invention provides a method of treating a subterranean formation. The method includes placing in the subterranean formation a proppant including a coating thereon. The coating is swellable with aqueous medium in response to a trigger including acidic pH, CO2, H2S, or a combination thereof.

Abstract: A method of fracturing a subterranean formation may comprise: pumping a fracturing fluid into the subterranean formation, through a wellbore, at or above a fracture gradient of the subterranean formation, wherein the fracturing fluid comprises halloysite nanotubes.

Abstract: Systems, methods, and compositions for creating microfractures within subterranean formations and delivering micro-proppant particles into microfractures within subterranean formations are provided. In some embodiments, the methods include: providing a treatment fluid that comprises an aqueous base fluid, a surfactant, and a plurality of microproppant particles having a mean particle diameter of about 100 microns or less; introducing the treatment fluid into a subterranean formation at or above a pressure sufficient to initiate the formation of at least one microfracture within the subterranean formation; and allowing at least a portion of the microproppant particles to enter the at least one microfracture within the subterranean formation.

Abstract: Various embodiments disclosed relate to proppant including a swellable coating thereon for treatment of subterranean formations. In various embodiments, the present invention provides a method of treating a subterranean formation. The method includes placing in the subterranean formation a proppant including a coating thereon. The coating is swellable with aqueous medium in response to a trigger including acidic pH, CO2, H2S, or a combination thereof.

Abstract: Methods and compositions are provided for removing a residue of resin from the surface of equipment. In one embodiment, the methods comprise: providing a cleaning solution comprising a pH-adjusting agent, a chemical solvent, and water, wherein the chemical solvent is selected from the group consisting of ?-lactam, ?-lactam, ?-lactam, ?-lactam, 2-pyrrolidone, N-methylpyrrolidone, 1,3-dimethyl-2-imidazolidinone (DMI), caprolactam, cyclohexanone, cyclopentanone, ?-butyrolactone, ?-butyrolactone, ?-decalactone, ?-valerolactone, ?-caprolactone, butylene carbonate, propylene carbonate, and ethylene carbonate, any combination thereof, and any derivative thereof; allowing the cleaning solution to contact a surface at least partially coated with a layer of resin; and allowing the cleaning solution to at least partially dissolve the resin.

Abstract: Methods and compositions are provided for removing a residue of resin from the surface of equipment. In one embodiment, the methods comprise: providing a cleaning solution comprising a pH-adjusting agent, a chemical solvent, and water, wherein the chemical solvent is selected from the group consisting of ?-lactam, ?-lactam, ?-lactam, ?-lactam, 2-pyrrolidone, N-methylpyrrolidone, 1,3-dimethyl-2-imidazolidinone (DMI), caprolactam, cyclohexanone, cyclopentanone, ?-butyrolactone, ?-butyrolactone, ?-decalactone, ?-valerolactone, ?-caprolactone, butylene carbonate, propylene carbonate, and ethylene carbonate, any combination thereof, and any derivative thereof; allowing the cleaning solution to contact a surface at least partially coated with a layer of resin; and allowing the cleaning solution to at least partially dissolve the resin.

Abstract: A subterranean zone surrounding a well bore is fractured with a fracturing fluid. Micro proppant of 200 mesh or smaller is pumped into far field fractures of the subterranean zone and props the far field fractures open.

Abstract: A subterranean zone surrounding a well bore is fractured with a fracturing fluid. Micro proppant of 200 mesh or smaller is pumped into far field fractures of the subterranean zone and props the far field fractures open.

Abstract: Improved methods for stabilizing unconsolidated subterranean formation particulates and reducing permeability of a subterranean formation to water. Some methods describe methods of stabilizing unconsolidated subterranean formation particulates and reducing the permeability of water comprising providing a portion of a subterranean formation that comprises unconsolidated formation particulates; introducing a fluid comprising a relative permeability modifier into at least a portion of the subterranean formation so as to at least partially reduce the permeability of that portion of the subterranean formation to water; and, introducing a fluid comprising a consolidating agent into at least a portion of the subterranean formation so as to at least partially consolidate the unconsolidated formation particulates.

Abstract: Methods of creating high porosity propped fractures in portions of subterranean formations, including method of forming a high porosity propped fracture in a subterranean formation comprising providing a slurry comprising a fracturing fluid and proppant particulates; introducing the slurry into a portion of a fracture within the subterranean formation; and, depositing the proppant particulates into the portion of the fracture within the subterranean formation so as to form a high porosity propped fracture.

Abstract: A method of treating a subterranean formation is provided, the method comprising the steps of: positioning a jetting tool in a wellbore penetrating the subterranean formation, wherein the jetting tool comprises at least one fluid jet forming nozzle; and delivering a curable composition through the jetting tool and to the formation, wherein the curable composition: cures to form a solid substance or a semi-solid, gel-like substance, and is a fluid having a sufficiently low viscosity to penetrate into the formation. The methods according to the invention are particularly suited for treating weakly consolidated or unconsolidated formations with a hardenable resin composition to help consolidate the formation.

Abstract: A new and distinct variety of strawberry plant named ‘DrisStrawOneHundredSix’, particularly selected for its yield potential, uniformity of fruit shape and size, stability of production, fruit flavor, and shelf life, is disclosed.