Abstract: Use of at least one compound of formula (I): (I) [P+(R1—Y—R2)4]zXz- is described for enhancing the injectivity of an injection well, wherein: Y is chosen from an oxygen atom or an NH group; R1 is a linear or branched alkyl radical having from 1 to 15 carbon atoms; R2 is chosen from a hydrogen atom or a linear or branched alkyl radical having from 1 to 14 carbon atoms; Xz- is a monovalent anion or a divalent anion, or a trivalent anion, or a tetravalent anion group; z is a number from 1 to 4. The compound of formula (I) is added to an aqueous medium to form an injection stream which is injected into a subterranean formation which comprises at least one polymer, via said injection well.

Abstract: A method of enhanced oil recovery that includes injecting a composition including an hyperbranched polyglycerol into an injection well in a subterranean oil-bearing reservoir, the hyperbranched polyglycerol being a primary alcohol that is a reaction product of a C2 to C25 carbon alcohol and a plurality of glycidols; and displacing oil in the subterranean oil-bearing reservoir using the composition.

Abstract: A method for producing heavy oil, the method including testing a plurality of samples either from a reservoir play or simulating a reservoir play in a temperature and pressure controlled gravity drainage experiment. Test injection fluids are injected into the samples at a reservoir temperature and pressure and Cumulative Oil Production (COP) or Recovery Factor (RF) or similar feature measured over time. An injection profile is obtained by selecting n injection fluids based on a best COP or RF at a given time Tn, wherein n is a number of fluid injection stages and switching to an n+1 injection fluid when a rate of change (ROC) in the COP or RF drops at least 25%-75%, but preferably 40-60% or 50%. The injection profile is then implemented in the reservoir to produce heavy oil. Optimized injection profiles for certain reservoirs are also provided.

Abstract: Methods of treating a subterranean formation including shale include preparing a treatment fluid by mixing an aqueous base fluid and a dry polyvinyl pyrrolidone (PVP) in flake or powder form having a molecular weight between about 500,000 and about 2,000,000 and introducing the treatment fluid in the subterranean formation.

Abstract: A method of treating a subterranean formation by contacting the formation with the following (a) ammonium bicarbonate; (b) and oxidizing agent selected from a perchlorate or a nitrite or combinations thereof; and (c) an acid (AA).

Abstract: Oil-soluble well treatment agents may be slowly released into a well or a subterranean formation by use of an aqueous fluid of (i) an oil-in-water dispersion having the oil-soluble well treatment agent as a dispersed phase and (ii) a second component having an oil-soluble or water-soluble primer coated onto a portion of its surface. The amount of the oil-soluble well treatment agent in the oil-in-water dispersion is from 20 to 50 weight percent and the average particle size of the oil-soluble well treatment agent in the dispersion may be from 0.005 to 2 micrometers. The oil-in-water dispersion may further contain a water-soluble well treatment agent.

Abstract: Cement slurries are prepared that comprise water, a hydraulic cement and particles of an oil-absorbent material. The particles are present in an amount sufficient to alter a property of a non-aqueous drilling fluid. The cement slurry is placed in a subterranean well, whereupon the slurry contacts residual drilling fluid on casing and formation surfaces. The oil-absorbent material in the cement slurry may reduce the mobility of the drilling fluid, thereby improving zonal isolation. The oil-absorbent material may be a polyolefin block copolymer.

Abstract: The present invention is concerned with an injection fluid comprising liquid or super-critical carbon dioxide (CO2) and alkoxylated alcohols and the use of such fluids in oil recovery processes. More specifically, the invention it relates to the reduction of the miscibility pressure during CO2 injection oil recovery processes by the use of alkox-ylated alcohols. Further, the invention relates to an oil recovery process injecting CO2 and alkoxylated alcohols.

Abstract: A method for enhancing geological storage by injecting nanoparticles to stabilize CO2 microbubbles, which belongs to the technical field of multiphase flow. The method first improves the physical properties of the fluid by pre-mixing CO2 and nanoparticles, and then the fluid is transported to the underground through high-pressure pipelines, and then CO2 microbubbles containing nanoparticles are generated through a dense perforated plate arranged by an injection well to improve the dissolution rate and sweep efficiency of the gas in the saline aquifer, so as to enhance the later mixing of the fluid. The combined injection can improve CO2 storage capacity and storage safety, and further reduce the risk of gas leakage in the reservoir.

Abstract: A downhole hydraulic frac tool for use in a hydraulic fracturing system, the frac tool comprising a dissolvable frac tool member that includes a water-dissolvable composition, the composition including: a water-soluble thermoplastic polymer; and water-soluble bulk metallic glass (BMG) particles, wherein: the BMG particles are embedded within a matrix of the water-soluble thermoplastic polymer, the BMG particles have a greater tensile strength than a tensile strength the water-soluble thermoplastic polymer, and the BMG particles have a higher fracture toughness than a fracture toughness the water-soluble thermoplastic polymer. A method of manufacturing a dissolvable downhole hydraulic frac tool member and, a hydraulic fracturing system associated with a wellbore in which dissolvable downhole hydraulic frac tools of the disclosure can be used, are also disclosed.

Abstract: A viscoelastic surfactant fluid composition comprising: a surfactant: a counterion: and a modified nanoparticle.

Abstract: An assembly includes a cement retainer, a unidirectional flow valve, and an upper stinger. The cement retainer is adapted to be mounted in the casing string. The cement retainer has a retainer aperture extending longitudinally therethrough from a retainer top end to a retainer bottom end. The unidirectional flow valve is configured to selectively control flow of fluid through the retainer aperture and is housed within the cement retainer. The upper stinger is configured to be removably retained within the retainer aperture. The upper stinger has an upper stinger aperture extending longitudinally therethrough from an upper stinger top end to an upper stinger bottom end. The upper stinger comprises an opening that provides a fluid flow path from an interior of the casing string to the upper stinger aperture when the upper stinger is removed from the cement retainer.

Abstract: Compositions and methods for chemical enhanced hydrocarbon recovery that utilize a nonionic surfactant that is a mixture of isomerized C9-11 ethoxylated alcohols.

Abstract: A sand consolidation composition includes a hydrocarbon mixture comprising asphaltene, bitumen, or tar, and a binding agent, where the binding agent is an amino silane, and where the composition has a viscosity ranging from 5 to 20 cP at 20 to 25° C. A method of sand consolidation includes introducing the sand consolidation composition in a wellbore, contacting sand downhole with the sand consolidation composition, maintaining the wellbore such that a viscosity of the sand consolidation composition and the sand increases from an initial viscosity of the sand consolidation composition, introducing a thermochemical reagent comprising sodium nitrite and ammonium chloride such that it intimately intermingles downhole with the sand consolidation composition and releases a gas, and after a period, forming a productive consolidated sand.

Abstract: A method of treating a subterranean formation by contacting the formation with the following: (a) ammonium compound; (b) an oxidizing agent selected from a perchlorate or a nitrite or combinations thereof; and (c) sulfamic acid.

Abstract: Methods for providing corrosion inhibition in conduits, containers, and wellbores penetrating subterranean formations are provided. In some embodiments, the methods include contacting a metal surface with a fluid that includes a corrosion inhibitor additive, in certain embodiments, the corrosion inhibitor additive includes an tonic liquid.

Abstract: Methods include pumping a fracturing pad fluid into a subterranean formation under conditions of sufficient rate and pressure to create at least one fracture in the subterranean formation, the fracturing pad fluid including a carrier fluid and a plurality of bridging particles, the bridging particles forming a bridge in a fracture tip of a far field region of the formation. Methods further include forming a first plurality of fibers in situ into the subterranean formation to form a low permeability plug with the bridging particles, and pumping a proppant fluid comprising a plurality of proppant particles.

Abstract: Non-aqueous drilling fluids may be removed from a wellbore or tubing nor casing within the wellbore by introducing into the well a biodegradable aqueous fluid comprising banana.

Abstract: Methods for treating a formation may include introducing components of a treatment solution into a wellbore such that the treatment solution contacts the formation to be treated, where the treatment solution may include urea, urease, a calcium ion source, one or more polysaccharides, a casein protein, a protease, an ionic compound, and a sugar, where the formation may have an amount of sand production before treatment and may be in fluid contact with the wellbore, and where an amount of sand production after treatment may be less than the amount of sand production before treatment. Consolidated sand structure compositions may include previously unconsolidated sand interlinked by inter-particle cementitious bonds comprising deposited calcium carbonate crystals, where the consolidated sand has a structural strength and the consolidated sand structure is porous to permit fluid flow through the composition.

Abstract: Methods and compositions for use in the inhibition of the formation of gas hydrate agglomerates are provided. In some embodiments, a method is provided that includes: providing an emulsion drilling fluid including: a continuous phase including a non-oleaginous fluid; an internal phase including an oleaginous fluid; and a thermodynamic hydrate inhibitor; and drilling at least a portion of a wellbore penetrating a subterranean formation.