Abstract: A process for in situ thermal recovery of hydrocarbons from a reservoir is provided. The process includes: providing an oxygen-enriched mixture, fuel, feedwater and an additive including at least one of ammonia, urea and a volatile amine to a Direct-Contact Steam Generator (DCSG); operating the DCSG, including contacting the feedwater and the additive with hot combustion gas to obtain a steam-based mixture including steam, CO2 and the additive; injecting the steam-based mixture or a stream derived from the steam-based mixture into the reservoir to mobilize the hydrocarbons therein; and producing a produced fluid including the hydrocarbons.

Abstract: Disclosed are coated particles. The coated particles include substrate particles and a coating disposed over at least a portion of the substrate particles. The coating includes a condensation reaction product of a reaction mixture that includes a liquid isocyanate-functional component and an isocyanate-reactive composition. Also disclosed are methods for making such particles and methods for using such particles as proppants in hydraulic fracturing.

Abstract: A chemical packer composition having a polyurethane foam with nanoparticles or micron-sized particles for use as an annular chemical packer in openhole horizontal wells is provided. The chemical packer composition may be used in a horizontal well having a screen (for example, a gravel pack screen) and completed using an openhole completion. The chemical packer composition may include, for example, silica nanoparticles or sand micron-sized particles. The chemical packer composition may be placed in an annulus section defined by the wellbore and the screen that traverses one or more fluid producing zones. In some instances, a portion of the chemical packer composition may be selectively removed to open a fluid producing zone to the wellbore and form plugs blocking other fluid producing zones.

Abstract: Proppants coated with a cured reactive resin composition containing 92-99.5 wt. % of a reactive resin and 0.5 to 8 wt. % of a silicone resin containing at least 5 wt. % of alkoxy groups and at least 20 mol percent of T and/or Q units, in liquid form, exhibit high freedom from fines generation, and are free flowing.

Abstract: Cement slurries, cured cements, and methods of making cured cement and methods of using cement slurries are provided. The cement slurries have, among other attributes, increased yield point, reduced density, improved mechanical properties, increased resistance to H2S, and may be used, for instance, in the oil and gas drilling industry. The cement slurry comprises cement precursor material, Saudi Arabian volcanic ash, and an aqueous solution. The Saudi Arabian volcanic ash comprises SO3, CaO, SiO2, Al2O3, Fe2O3, MgO, and K2O and the cement slurry is free of any other SiO2 additive.

Abstract: Cement slurries, cured cements, and methods of making cured cement and methods of using cement slurries are provided. The cement slurries have, among other attributes, increased yield point, reduced density, improved mechanical properties, increased resistance to H2S, and may be used, for instance, in the oil and gas drilling industry. The cement slurry comprises cement precursor material, Saudi Arabian volcanic ash, and an aqueous solution. The Saudi Arabian volcanic ash comprises SO3, CaO, SiO2, Al2O3, Fe2O3, MgO, and K2O and the cement slurry is free of any other SiO2 additive.

Abstract: Hydrogel-coated proppants and methods for manufacture thereof. In preferred embodiments, the hydrogel coating is covalently attached and crosslinked to the proppant substrate in a core-shell structure. The enhanced proppant provides great flexibility in terms of functionalities that can be incorporated into the hydrogel coating. Also, the swelling behavior and mechanical properties of the hydrogel coating can be tailored as desired by varying the amounts of components in the composition such as monomer, crosslinker, polymer, silane comonomer, and initiator.

Abstract: An example method of forming a well includes identifying a lost circulation zone in a wellbore, where the lost circulation zone includes a fracture in a formation adjacent to the wellbore; arranging an inflatable in a vicinity of the lost circulation zone; forcing slurry into the inflatable to cause at least part of the inflatable containing the slurry to expand into the fracture; allowing the slurry to set for a period of time to produce a solid; and drilling through the solid in the inflatable in the wellbore, leaving the solid in the fracture.

Abstract: A wellbore tool includes a rotatable elongate pipe that includes a first elongate portion extending along a longitudinal axis of the elongate pipe. A first bending portion with a first end attaches to a downhole end of the first elongate portion. The first bending portion deviates from a longitudinal axis of the first elongate portion in a first direction. A second bending portion has a first end attached to a second end of the first bending portion. The second bending portion is positioned downhole of the first bending portion. The second bending portion deviates towards the longitudinal axis in a second direction different from the first direction. The first bending portion and the second bending are eccentric relative to the first elongate portion. The wellbore tool is rotated a set amount and stabbed in a downhole direction until the wellbore tool enters the parted casing.

Abstract: Methods of treating a subterranean formation penetrated by a wellbore include providing environmental water, admixing a viscosifying amount of a polymer and at least one divalent cation with the environmental water to form an admixture, and pumping the admixture through the wellbore at a rate and pressure sufficient to treat the subterranean formation. The viscosity of the admixture increases after the at least one divalent cation, the viscosifying amount of polymer and the environmental water are admixed. Such viscosity increase may be at least about 5% over at least a 10 minute period after the admixture is prepared. The divalent cation(s) may be selected from the group consisting of barium, calcium, copper(II), iron(II), magnesium, manganese(II), strontium, tin(II), zinc, and mixtures thereof. Further, the divalent cation(s) may be provided in the form of a salt with one or more anions selected from acetate, bicarbonate, nitrate, chloride, bromide, iodide, sulfate ion, and mixtures thereof.

Abstract: Certain embodiments are directed to magnetic rheological packer systems that seal an annulus in a downhole wellbore. In one embodiment, the seal is formed from a two-part epoxy and magnetorheological composition. The epoxy and magnetorheological compositions are allowed to be shaped by a magnetic field provided by one or more magnets exerting a magnetic field to place the packer seal.

Abstract: Various embodiments disclosed relate to compositions including acidic chelator or salt or ester thereof for treatment of subterranean formations including one or more fractures. In various embodiments, the present invention provides a method of treating a subterranean formation. The method includes placing in the subterranean formation a composition including an acidic chelator or a salt or ester thereof. The subterranean formation includes one or more fractures.

Abstract: Spacer fluid compositions comprising water, a clay, and a sulfur-containing polyether surfactant are disclosed, and such compositions often can further include a weighting additive, an antifoaming additive, and a co-solvent. These spacer fluid compositions can be used to treat metal casing and to remove drilling fluid residue for improved cement bonding in wellbore applications.

Abstract: Embodiments provide a method of encapsulating a solid cement additive. The method includes the step of applying a base film-forming monomer to the solid cement additive. The method includes the step of forming a coating layer surrounding the solid cement additive. The coating layer includes the base film-forming monomer. The method includes the step of applying an overlay film-forming monomer to the coating layer surrounding the solid cement additive. The method includes the step of reacting the base film-forming monomer and the overlay film-forming monomer to produce a polymer shell. The solid cement additive includes solid particles useful in cementing applications. The polymer shell includes a crosslinked polymer. The polymer shell surrounds the solid cement additive. The polymer shell has a permeability to water allowing controlled release of the solid cement additive.

Abstract: Cement slurries, cured cements, and methods of making cured cement and methods of using cement slurries are provided. The cement slurries have, among other attributes, increased yield point, reduced density, improved mechanical properties, increased resistance to H2S, and may be used, for instance, in the oil and gas drilling industry. The cement slurry comprises cement precursor material, Saudi Arabian volcanic ash, and an aqueous solution. The Saudi Arabian volcanic ash comprises SO3, CaO, SiO2, Al2O3, Fe2O3, MgO, and K2O and the cement slurry is free of any other SiO2 additive.

Abstract: A well completion assembly and method including apparatus for setting a compliant screen assembly and a liner within a wellbore in a single trip.

Abstract: A device is for perforation of a downhole formation. The device has an electronically induced acoustic shock wave generator; and an acoustic shock wave focusing member. The device is adapted to focus generated acoustic shock waves onto an area of a borehole in order to disintegrate the downhole formation within said area. The device is adapted to generate a plurality of consecutive focused acoustic shock waves in order to gradually excavate a perforation tunnel, or to improve an already existing perforation tunnel, extending from said borehole and into said formation.

Abstract: A method of fracturing a formation with a fracturing fluid in a wellbore extending into the formation includes pumping a spacer fluid through a spacer fluid channel into the wellbore and pumping a proppant slurry through a proppant slurry channel into the wellbore separately from the spacer fluid. The method further includes combining the spacer fluid and the proppant slurry within the wellbore to create the fracturing fluid with portions comprising varied proppant concentrations and pumping the fracturing fluid with the varied proppant concentrations into the formation.

Abstract: Provided here are various invert emulsion drilling fluid compositions. The invert emulsion fluid is a water in oil emulsion, which can include an invert emulsifier to stabilize the water in oil emulsion, a 16 to 18 carbon carboxylic acid, a 36 carbon fatty dimer diol, a polymeric filter control agent, and an inorganic mineral including one or more of lime, calcium chloride, and barite. The invert emulsion drilling fluids can be formulated to be substantially free of clay.

Abstract: Methods for servicing a hydrocarbon well using natural gas are provided. The method can include preparing a working fluid comprising about 5 vol % to about 100 vol % of natural gas. A quantity of the natural gas in the working fluid can be sufficient to form a heterogeneous phase well servicing mixture of a gaseous phase natural gas and a solid or liquid phase recovery target material under specified well intervention conditions. During the well servicing operation and under the specified well intervention conditions, the working fluid can be injected into the well and mixing the working fluid with the recovery target material in the well to form the heterogeneous phase well servicing mixture. The natural gas can be in a gas phase and can serve as a carrier fluid for the recovery target material. At least a portion of the heterogeneous phase well servicing mixture can be recovered at surface.