Abstract: Systems and methods for improving injectivity of a hydrocarbon reservoir include: identifying a restriction of flow from an injection well into the hydrocarbon reservoir; transmitting a series of acoustic waves from an injection well into a formation that includes the hydrocarbon reservoir, wherein the series of acoustic waves are transmitted continuously for at least one day; transmitting a series of seismic waves from the injection well into the formation after the series of acoustic waves are transmitted into the hydrocarbon reservoir, wherein the series of seismic waves are transmitted continuously for at least one week; and injecting water into the injection well to cause hydrocarbon of the hydrocarbon reservoir to flow from the hydrocarbon reservoir to a production well after the series of acoustic waves are transmitted into the hydrocarbon reservoir.

Abstract: Rotating a casing during a cementing operation to ensure efficient displacement of cement slurry. More specifically, embodiments are directed towards a sub and rotating tool that are positioned above a first cement operation, wherein the rotating tool is positioned in a kickoff point or build section of a horizontal well.

Abstract: The present disclosure relates to a micromesh proppant for use in hydraulic fracturing of oil and gas wells. In one embodiment, a process for forming proppant particles includes providing a slurry comprising a ceramic raw material containing alumina, atomizing the slurry into droplets, coating seeds comprising alumina with the droplets to form green pellets, sintering the green pellets to form sintered pellets, and breaking the sintered pellets to form proppant particles comprising a sintered ceramic material and having a size of from about 150 mesh to about 500 mesh and a crush strength at 7,500 psi of from about 1% to about 20%. In one embodiment, a proppant particle includes a sintered ceramic material and having a size of from about 150 mesh to about 500 mesh and a crush strength at 7,500 psi of from about 1% to about 20%.

Abstract: According to embodiments disclosed herein, a method of monitoring a gel fluid composite may include directing the gel fluid composite into a wellbore extending into a subsurface where the wellbore has one or more downhole fractures so that the gel fluid composite enters the one or more downhole fractures, transforming the gel fluid composite from an aqueous phase to a gel phase, irradiating light onto the gel fluid composite so that the fluorescent compounds emit one or more photons, and detecting the one or more photons using a detection device. The gel fluid composite may include a nanosilica gel that includes silica nanoparticles and an activator, wherein the silica nanoparticles have a maximum cross-sectional dimension of from 3 nm to 100 nm, and one or more fluorescent compounds, wherein the one or more fluorescent compounds are dispersed in the nanosilica gel, bonded to the silica nanoparticles, or both.

Abstract: An electric drive pump system includes a power end and a detachable transmission assembly. The transmission assembly is mounted to the power end and is configured to provide rotational power to the power end through a plurality of electric motors. The plurality of electric motors use a gearbox to drive an output spline that engages the power end. A control module is used to regulate the performance characteristics of the plurality of electric motors. A temperature regulation assembly is configured to regulate the temperature of the transmission assembly and the power end.

Abstract: A method may include: providing a cleanout fluid comprising a single anionic surfactant, a single nonionic surfactant, and a solvent; preparing a cleanout pill by mixing the cleanout fluid with a brine; and displacing a fluid in a wellbore using the cleanout pill.

Abstract: A method includes providing an expandable metal slurry downhole in a wellbore. The expandable metal slurry includes granules of an expandable metal material suspended or dispersed in a fluid. Further, the method includes positioning the expandable metal slurry within the wellbore such that the granules of the expandable metal material in the expandable metal slurry are activatable to expand and form a seal within the wellbore.

Abstract: A performance evaluation device and a design method of a cement for well cementing in a penetrated hydrate layer are provided. The performance evaluation device includes an equivalent wellbore, an inner circulation system, an outer circulation system, a thermal insulation cover, a bracket, a temperature sensing system, and a cement mold. The device can simulate a true downhole situation, conduct an evaluation experiment on the heat insulation performance of a cementing cement, and conduct experiments at different temperatures with automatic temperature control. The design method is to use a low-hydration, early-strength, and heat-insulating cement slurry system during the well cementing in a penetrated hydrate layer, where the low-hydration and early-strength characteristics ensure the effective sealing of a hydrate layer during a cementing process, and the heat insulation characteristic results in low heat conductivity and thus can ensure the stability of a hydrate layer during a production operation.

Abstract: Activating a reaction of a sealant, such as cement, with a fiber optic cable, the reaction causing hardening of the sealant. The sealant may be used in wellbore cementing operations to cement a casing in a wellbore. The fiber optic cable may be deployed by attaching it to the outside of a casing during insertion into the wellbore. The activation of the sealant can be via thermal or optical initiation in order to causing a hydration reaction or polymerization.

Abstract: A process for producing a base oil composition particularly adapted for use in oil-base drilling mud compositions. The process includes contacting drilling waste containing an oil-base mud phase with a solvent to produce a mixture of liquids and solids, separating the two phases, partially evaporating the liquids phase to produce an oil base composition substantially lacking low molecular weight carbon chain compounds and also lacking significant concentrations of benzene, toluene, xylene, and/or ethyl benzene, and having increased closed-cup flashpoint when compared to the oil-base mud phase in the drilling waste. The resulting base oil has enhanced health and safety characteristics for workers interacting with and otherwise exposed to the oil base composition during transporting, conditioning or using such compositions. The base oil produced and drilling methods using the recovered and recycled mud are also described.

Abstract: Compositions and methods for the use in scale inhibitor squeeze treatments are provided. In some embodiments the present disclosure provides a method including introducing a pre-flush fluid into at least a portion of a subterranean formation, the pre-flush fluid including a choline chloride chemical additive; and introducing a treatment fluid including a scale inhibitor into the portion of the subterranean formation after at least a portion of the pre-flush fluid has been introduced into the portion of the subterranean formation.

Abstract: The present invention relates to a colloidal composition for stimulating the operation of high water-yield, natural gas, or petroleum-producing wells, which, when mixed with the water, forms a structured high viscosity barrier to exclude the water and to reduce the water/hydrocarbon volume proportion of the production, furthermore, at the time of use, in the proximity of the wells the residual oil sorbed on the surface of the hydrocarbon reservoir and/or the residual oil trapped in the pores of the hydrocarbon reservoir becomes compressible and recoverable. The colloidal composition comprises a vegetable oil reaction product based compound. Experiments with the new composition have demonstrated that it can be successfully used in a much wider range of parameters than before to form a barrier resulting in water displacement, as well as to mobilize and recover residual oil adhering to the well area.

Abstract: A method of servicing a wellbore penetrating a subterranean formation, the method including placing a wellbore servicing fluid into the wellbore proximate a permeable zone. The wellbore servicing fluid comprises a base fluid and from about 3 wt. % to about 25 wt. % by total weight of the wellbore servicing fluid of a particulate material. The particulate material comprises palm kernel shells.

Abstract: Surfactants for use in formulations and processes suitable for hydrocarbon recovery. These formulations, include formulations suitable for fracking, enhancing oil and or gas recovery, and the recovery and or production of bio-based oils.

Abstract: Various embodiments disclosed relate to surfactant compositions for treatment of subterranean formations and produced oil. In various embodiments, the present invention provides a method of treating a subterranean formation including placing in the subterranean formation a surfactant composition. The surfactant composition includes an alkanolamide surfactant and an alkoxylated alcohol surfactant. The surfactant composition also includes an ionic surfactant, a nonionic surfactant, or a combination thereof.

Abstract: Microemulsions comprising an alkyl propoxylated sulfate surfactant and related methods, including methods of use in the treatment of subterranean formations, such as oil and condensate wells, are provided. In some embodiments, the microemulsions and/or methods of use achieve ultra-low interfacial tensions (i.e. less than or equal to 0.01 mN/m) between a wide variety of crude oils and well treatment fluids at various reservoir conditions. In some embodiments, the microemulsion comprises water, an anionic alkyl propoxylated sulfate surfactant, a solvent (e.g., a terpene solvent), and a co-solvent. In some embodiments, the microemulsion further comprises a second and/or third surfactant (e.g., a nonionic and/or an anionic surfactant).

Abstract: Compositions and methods for use in fracturing treatments using friction reducing additives that include nanoparticles are provided. In some embodiments, the methods include: providing a treatment fluid that includes an aqueous base fluid and a friction reducing additive, the friction reducing additive including at least one polymer and a plurality of nanoparticles; and introducing the treatment fluid into a portion of a subterranean formation at or above a pressure sufficient to create or enhance at least one fracture in the subterranean formation.

Abstract: Expansive cement compositions for use in subterranean wellbores that include a monophase amorphous hydraulic binder material (MAHBM). The MAHBM may include a plurality of particles having a silica core and an amorphous coating substantially surrounding the silica core. The coating may comprise, for example, a plurality of amorphous ?-dicalcium silicate hydrate nanoparticles or microparticles. The MAHBM may be used as an expansion agent in a cement composition or used as an expansive cement by itself.

Abstract: A method and agent to induce accelerated creep deformation of shale rock formations in the annular gap between a shale formation and non-cemented sections of a casing string have been developed. A fluid containing alkali silicate or a modified alkali silicate is added to the annular space between the shale rock formation and the casing string. The alkali silicate promotes creep deformation of the shale rock, effectively closing the annulus surrounding the casing. It has been found lithium silicate provides the strongest shale-casing bond and is the presently preferred material for closing abandoned wells.

Abstract: A method may include introducing a resin treatment fluid into a wellbore, the resin treatment fluid including a resin, a hardening agent, and a neutron contrasting agent; and allowing the resin treatment fluid to set to form a hardened mass.