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: Provided, in one aspect, is a cementing apparatus. The cementing apparatus, in one embodiment comprising a housing; a fixed member coupled with the housing, the fixed member having at least one fixed member fluid opening therein; and a moving member positioned downhole of the fixed member and movable between a circulating position and a cemented position, the moving member having at least one moving member fluid opening therein, the at least one moving member fluid opening linearly offset from the at least one fixed member fluid opening.

Abstract: A precursor cement slurry includes a cement powder, water, and an additive. The additive includes a cement bond enhancer and a non-aqueous fluid additive. The non-aqueous fluid additive is an internal phase and the cement bond enhancer stabilizes the non-aqueous fluid additive in the form of a Pickering emulsion within the precursor cement slurry. The cement bond enhancer is comprised of the reaction product of graphene oxide with an anchoring functionality. A method of forming the precursor cement slurry and a method of cementing an annular space within a wellbore are also provided.

Abstract: A method to improve the efficiency of a gravity drainage CO2 gas injection process includes the steps of: (a) injecting a slug proximate to an underground reservoir, wherein the slug comprises a polymer component and an inorganic metal ion type crosslinking agent that are configured to form an in situ weak gel in the reservoir to block high permeability channels in a pay zone of the reservoir; and (b) continuously injecting CO2 gas at a top of the pay zone to form a gas cap at the top of the reservoir and to cause the gas cap to advance rapidly towards a producing well located below to provide a uniform sweep of the gas cap.

Abstract: A thermochemical soap stick, system, and method for unloading liquid from a well, the thermochemical soap stick having thermochemical reagents and to be provided into a wellbore in a subterranean formation, the thermochemical soap stick to dissolve in the liquid giving a thermochemical reaction to generate gas to foam the liquid, and displacing the liquid from the wellbore via pressure of the subterranean formation.

Abstract: Proppant embedment can sometimes be problematic during fracturing operations. A partially oxidized, amine-functionalized polysaccharide comprising a plurality of oxidatively opened monosaccharide units and bearing an amine moiety at one or more sites of oxidative opening may lessen the amount of proppant embedment that occurs. Fracturing methods may comprise providing a fracturing fluid comprising such a partially oxidized, amine-functionalized polysaccharide and a plurality of proppant particulates, introducing the fracturing fluid into a subterranean formation at a hydraulic pressure sufficient to create or extend one or more fractures therein, such that at least a portion of the plurality of proppant particulates become localized in the one or more fractures, and releasing the hydraulic pressure. Upon releasing the hydraulic pressure, embedment of the proppant particulates in a face of the one or more fractures is about 10% to about 40% of a grain size of the proppant particulates.

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: A method includes injecting an aqueous-based injection fluid into a wellbore at a first temperature, where the aqueous-based injection fluid includes phase-changing nanodroplets having a liquid core and a shell. The method also includes exposing the phase-changing nanodroplets to a second temperature in the wellbore that is greater than or equal to a boiling point of the liquid core to change a liquid in the liquid core to a vapor phase and expand the phase-changing nanodroplets, thus removing debris from the wellbore and surrounding area.

Abstract: An additive composition for improving one or more cold temperature properties in oil-based fluids is provided. One additive composition may include a first additive component selected from at least one alcohol ethoxylate, at least one amine ethoxylate, at least one ethylene oxide/propylene oxide copolymer, or a combination thereof, wherein the first additive component has an HLB ranging from about 4 to about 10. The additive composition may also include a second additive component selected from at least one alcohol, propylene glycol, at least one alcohol ethoxylate, or a combination thereof, wherein the second additive component has a total number of carbons from about 2 to about 30 carbons and a degree of ethoxylation is from zero to about 10.

Abstract: Coated proppants include a proppant particle, a surface copolymer layer surrounding the proppant particle, and a resin layer surrounding the surface copolymer layer. The surface copolymer layer includes a copolymer of at least two monomers chosen from styrene, methyl methacrylate, ethylene, propylene, butylene, imides, urethanes, sulfones, carbonates, and acrylamides, where the copolymer is crosslinked by divinyl benzene. The resin layer includes a cured resin.

Abstract: Method of carbon sequestration by capturing CO2 emissions and making a proppant from the captured carbon in either a carbon mineralization process or in a carbon nanomaterial manufacturing process, followed by treatments to ensure the quality control of the proppants so that they are suitable for use in hydraulic and other reservoir fracturing methods. Injection of the manufactured proppant in fracking thus sequesters the carbon from the original captured CO2 in the reservoir.

Abstract: The invention relates to a method of conducting a perf wash cement (“P/W/C”) abandonment job in an offshore oil or gas well annulus, in particular the washing or cementing operation using a rotating head with nozzles dispensing wash fluid or cement at pressure. A new design of bottom hole assembly is proposed in which the cementing tool has a relatively large diameter in order to optimize pressure whilst the wash tool has a relatively small diameter. The wash process, for a number of reasons, appears to be less sensitive to tool diameter and making the wash tool smaller reduces the overall risk of stuck pipe.

Abstract: A system includes an integrated liner hanger assembly that includes a liner hanger, a packer, and a cement retainer sub. The cement retainer sub includes a plurality of fluid passageways connecting a central bore of the liner hanger assembly to an annular volume downhole of the packer and uphole of the liner hanger. A running tool is configured to axially translate a sliding sleeve of the cement sub from a closed position to an open position in which flow if permitted through the passageways, and from the open position to a closed-and-locked position. In some embodiments, the system is configured such that running the assembly into the wellbore, actuating the liner hanger, actuating the packer assembly, translating the sliding sleeve from the closed and open position and from the open position to the closed-and-locked position, are completed in a single trip.

Abstract: A method of enhanced oil recovery comprising introducing into one or more injection wells located within a subterranean formation a treatment fluid comprising (i) an aminopolycarboxylic acid comprising a phosphonoalkyl moiety; and ii) a surfactant blend; and removing hydrocarbons from one or more production wells. A method of enhanced oil recovery comprising introducing into one or more injection wells located within a subterranean formation a treatment fluid comprising (i) an aminopolycarboxylic acid comprising a phosphonoalkyl moiety; and ii) a surfactant blend wherein the subterranean formation comprises non-source rock, naturally-fractured rock, low porosity rock, calcite rich reservoir rock or a combination thereof; and removing hydrocarbons from one or more production wells.

Abstract: A method of producing natural resources from a wellbore penetrating a subterranean formation with a Huff and Puff process comprising: (a) placing a recovery enhancing fluid system into the wellbore during an injection (Huff) period of time wherein placing the recovery enhancing fluid system comprises injecting under pressure; (b) ceasing injection of the recovery enhancing fluid system and allowing the composition to soak in the subterranean formation for a soak period of time; (c) producing fluids from the subterranean formation during a production (Puff) period of time; and (d) optionally repeating steps (a) to (c) for a plurality of Huff, soak, and Puff periods of time, respectively.

Abstract: Method of making and using a proppant from captured carbon in either a carbon mineralization process or in a carbon nanomaterial manufacturing process, followed by treatments to ensure the quality control of the proppants so that they are suitable for use in hydraulic and other reservoir fracturing methods.

Abstract: A method of stimulating petroleum production includes introducing a fracturing fluid into a petroleum formation, thereby creating at least one fracture to stimulate the petroleum production. The fracturing fluid is introduced into the petroleum formation at a pressure above the breakdown pressure of the formation. The fracturing fluid includes a plurality of proppants each including a proppant particle and a coating. The coating includes a hydrophobic coating, a cross-linked hydrogel, or both. From 1 to 50 wt. % of the plurality of proppants includes micro proppants having a particle size ranging from 0.5 to 150 ?m, and from 50 to 99 wt. % of the plurality of proppants includes macro proppants having a particle size of 100 mesh or greater.

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 cement wiper plug for deployment in casing with an inner radius has a central axis, a leading end, and a trailing end opposite the leading end. The wiper plug includes an elongate body. In addition, the wiper plug includes a first plurality of axially adjacent annular fins mounted to the body. Each fin extends radially outward from the body and each fin extends circumferentially about the body. The first plurality of fins includes a first fin and a second fin axially adjacent the first fin. The second fin is axially positioned between the first fin and the trailing end. The first fin and the second fin are configured to contact each other in the casing. The second fin is configured to bias the first fin radially outward and axially forward toward the leading end.

Abstract: A protective tubular is run downhole into a wellbore in a subterranean formation. A non-metallic tubular is disposed within the protective tubular. The non-metallic tubular includes an adapter. The adapter includes a spring-loaded latch, a ball seat, a shear pin, and a ball catcher. While intact, the shear pin holds a position of the non-metallic tubular relative to the protective tubular. A ball is used to shear the shear pin of the adapter, thereby allowing the non-metallic tubular to move relative to the protective tubular. Pressure is applied to the ball to move the non-metallic tubular relative to the protective tubular. The non-metallic tubular is coupled to the protective tubular using the spring-loaded latch of the adapter. Pressure is applied to the ball to shear the ball seat of the adapter. A fluid is flowed into the non-metallic tubular through an opening defined by the adapter.