Abstract: Dual cation hydrate inhibitor compositions and methods of using such compositions to, for example, inhibit the formation of gas hydrate agglomerates are provided. In some embodiments, such methods include introducing a hydrate inhibitor composition into a fluid, wherein the hydrate inhibitor composition includes at least one compound having the structural formula: wherein each of R1, R2, and R3 is independently a C1 to C6 hydrocarbon chain, wherein R4 is selected from the group consisting of hydrogen and any C1 to C50 hydrocarbon chain, wherein each of R5 and R6 is independently selected from the group consisting of hydrogen and a C1 to C50 hydrocarbon chain, wherein X? and Y? are counter anions, and wherein each of a and b is independently an integer from 1 to 10.

Abstract: The present invention relates to the use of a combination of block polymers and particular compositions in a fluid injected under pressure into an oil-bearing rock, where: the fluid comprises solid particles and/or is brought into contact with solid particles within the oil-bearing rock following the injection thereof, the combination comprises (i) a polymer comprising: —a first block that is adsorbed on at least a portion of the particles; and —a second block, having a composition different from that of the first, and having a weight-average molecular weight of greater than 10 000 g/mol, for example greater than 100 000 g/mol, and that is soluble in the fluid; (ii) particles suitable for providing a gas barrier effect, preferably a latex and/or silica particles.

Abstract: Systems, methods, and compositions that provide an energized natural gas (ENG) fracturing fluid including a complexing agent. A fracturing fluid may include: methane; water; a complexing agent; a surfactant; and wherein the fracturing fluid is an emulsion, the water is in a continuous phase of the emulsion, and methane is in a discrete phase of the emulsion.

Abstract: Aqueous well treatment fluids especially suited for use in far field diversion in low viscosity carrier fluids comprise water, a friction reducer, and a diverter. The diverter comprises dissolvable particulates and proppants. The dissolvable particulates have a specific gravity of from about 0.9 to about 1.6 and a particle size of about 50 mesh or less. The proppants have a specific gravity of from about 0.9 to about 1.4 and a particle size of from about 20 to about 100 mesh. The dissolvable particulates have a higher specific gravity and a smaller particle size than the proppant.

Abstract: Provided is a lost circulation material that may consist essentially of an alkaline nanosilica dispersion and a sodium bicarbonate activator. Further provided are methods that may control lost circulation in a lost circulation zone in a wellbore by introducing the lost circulation material such that it contacts the lost circulation zone and forms a gelled solid in the lost circulation zone.

Abstract: Methods and systems are directed to the uniform distribution of a fluid through an annulus between a pipe and a wellbore wall, primarily when there is a preferential flow in one side of the annulus relative to another side of the annulus. Generally, the methods and systems involve introducing a first agent into the annulus, wherein the first agent is configured to cause swelling of a cladding on the exterior of the section of the pipe. The swelling reduces flow in the annulus on the side of the pipe with preferential flow so as to reduce the preferential flow on that side of the pipe.

Abstract: A well bore cementing system may comprise a spacer fluid and a cement slurry. The spacer fluid may be positioned within a well bore, and the spacer fluid may comprise a first surfactant package comprising one or more surfactants. The cement slurry may be positioned within the well bore, and the cement slurry may comprise a second surfactant package comprising one or more surfactants.

Abstract: A system for slowly releasing an oil-soluble well treatment agent into a well or a subterranean formation includes a composite of the oil-soluble well treatment agent associated with a second component. The amount of the oil-soluble well treatment agent in the composite is from 20 to 35 weight percent and the average particle size of the oil-soluble well treatment agent in the composite is less than or equal to 1 micrometer. The composite may further contain a water-soluble well treatment agent.

Abstract: A vulcanized rubber and date tree based lost circulation material (LCM) is provided. The vulcanized rubber and date tree based LCM includes vulcanized rubber particles, date tree seed particles produced from date tree seeds, and date tree fibers produced from date tree waste. The LCM may include vulcanized rubber particles in the range of 20 pounds-per-barrel (ppb) to 40 ppb in the drilling fluid, date tree seed particles in the range of 50 ppb to 70 ppb in the drilling fluid, and date tree fibers in the range of 10 ppb to 40 ppb in a drilling fluid, including a first size of fibers in the range of 5 ppb to 20 ppb, and a second size of fibers in the range of 5 ppb to 20 ppb. Methods of lost circulation control and manufacture of the vulcanized rubber and date tree based LCM are also provided.

Abstract: Methods and compositions for using geopolymers to create storable cementitious slurries used for oil and gas well cementing are provided. The methods of the present disclosure include providing a set-delayed geopolymer cement composition including a geopolymer; activating the set-delayed geopolymer cement composition; introducing the set-delayed geopolymer cement composition into at least a portion of a subterranean formation; and allowing the set-delayed geopolymer cement composition to set in the subterranean formation.

Abstract: A plugging device, well system and method. In one example, a wrap, band or other type of binding is utilized to secure together multiple fibers, tubes, filaments, films, fabrics or lines of the plugging device. In another example, fibers, tubes, filaments, films, fabrics or lines are fused, adhered or bonded to an outer surface of a body of the plugging device. In other examples, a material of the plugging device may become more rigid or swell in a well. A plugging device may comprise a body loosely enclosed in a bag, wrapper or other enclosure.

Abstract: A process is provided for recovering hydrocarbons, such as heavy oils, from a subterranean reservoir. The process includes providing a subcritical or a supercritical aqueous fluid at a high temperature and high pressure to the underground hydrocarbon reservoir, injecting the aqueous fluid into the reservoir to heat the hydrocarbons in the reservoir, and recovering the heated hydrocarbons from the reservoir. In some cases, the supercritical fluid is also used to upgrade the hydrocarbons and/or facilitate the transportation of the hydrocarbons from the production field to another location, such as a refinery. Advantageously, isentropic expansion may be employed anywhere in the system for a more efficient and effective processes and systems.

Abstract: A method for improving oil recovery within a subterranean formation that includes forming a barrier within the formation to isolate at least a portion of a first region from a proximate second region. The barrier is formed by introducing a first solution including an ammonium containing compound and a second solution including a nitrite containing compound into the formation. The first solution, the second solution, or both, further include a foaming agent. The compounds react to generate nitrogen gas in the presence of the foaming agent to generate a foam within a first region. The foam provides the barrier. Water is introduced into the formation. The barrier diverts the water away from the first region and into the second region. The water operates to displace at least a portion of a hydrocarbon present in the second region and discharge the hydrocarbon from the formation.

Abstract: Ether amine additives are used in oil recovery such as steam-assisted gravity drainage and cyclic steam stimulation, as well as surface mining of bitumen. Methods of oil recovery using the ether amine additives are described. The ether amine additives are injected with steam into a subterranean oil reservoir such as oil tar sands to improve recovery of oils such as bitumen and/or heavy oil, or used to wash surface-mined rock to assist in oil extraction therefrom. The ether amine additives may be added to steam in steam-assisted oil recovery methods such as cyclic steam stimulation and steam-assisted gravity drainage. Condensates of the additives in steam exhibit very low advancing and receding contact angles and low interfacial tensions at low concentrations of the additives.

Abstract: A cement composition and set cement including cement and a sliding-ring polymer. A system and method of applying the cement composition.

Abstract: Lightweight micro-proppant suitable to prop open not only near-wellbore microfractures but also far-field microfractures. Some methods of fracturing and propping may comprise first introducing a pad fluid comprising a lightweight micro-proppant into a wellbore penetrating a subterranean formation at a rate and pressure sufficient to create or extend a fracture network in the subterranean formation, wherein the fracture network comprises microfractures. The lightweight micro-proppant comprises a thermoset nanocomposite having a specific gravity of about 0.9 to about 1.4 and having an average diameter of about 0.1 microns to about 50 microns. Then introducing a proppant slurry comprising a macro-proppant into the wellbore penetrating the subterranean formation after introducing the pad fluid forming a proppant pack in the fracture network wherein at least some of the lightweight micro-proppant is located in the microfractures.

Abstract: A downhole acoustic stimulation tool comprises: a sealed chamber containing a liquid; a pair of electrodes located in the chamber; at least one transducer arranged to generate an acoustic field between the electrodes thereby inducing cavitation in a volume of the liquid between the electrodes; and at least one capacitor configured to apply a pulse voltage across the electrodes when discharged, thereby causing the cavitating volume of liquid to form a plasma which collapses to form a shockwave. The at least one transducer constitutes a first energy source, and the at least one capacitor back and electrodes constitute a second energy source. Alternative forms and arrangements of the first and second energy sources are also disclosed.

Abstract: A method may include: heating a drilling waste comprising water, oil, and solid particulate; vaporizing at least a portion of the water and oil from the drilling waste to form a vaporized fluid, wherein the step of vaporization is performed at a pressure less than about 101.325 kPa; and condensing the at least a portion of the water and oil to form a recovered fluid emulsion.

Abstract: A system for use in performing a reverse cementing operation in a downhole well operation and creating a sectional separation within a well casing and a process completion indicator. The system comprising a well casing, and a magnetic element, and a plurality of magnetizable particles. The magnetic element is coupled with a radial, interior section of the well casing and the plurality of magnetizable particles couple with the magnetic element forming an impediment between a first and second section of the well casing. The impediment creates a detectable resistive force. The magnetizable particles and the at least one magnet form a contiguous and porous wall and the resistive force creates a pressure spike at a surface of the well in response to the interaction of a cement slurry pumped into an annulus of a wellbore and the wall.

Abstract: Treatment method for a rock formation against sand infiltration during production of fluid from this rock formation via a well drilled through said rock formation, comprising at least one step of injecting a geopolymer cement grout into said rock formation, in particular around the edges of said well and/or through said well.