Abstract: Methods and compositions for treating subterranean formations to mitigate lost circulation are provided. The methods of the present disclosure include forming a treatment fluid including one or more geopolymer lost circulation materials; introducing the treatment fluid into at least a portion of a subterranean formation that includes at least one loss zone; activating the geopolymer lost circulation materials to form a geopolymer that imparts a thixotropic property to the treatment fluid; and allowing the treatment fluid exhibiting the thixotropic property to at least partially reduce a rate of loss associated with the loss zone.

Abstract: An object of the present invention is to provide an environmentally friendly drilling fluid that has excellent cuttings transport capability and excellent hole cleaning capability. A drilling fluid according to the present disclosure is a drilling fluid containing water, biodegradable fibers, and a thickener. The thickener contains a biodegradable polysaccharide. The content of the biodegradable polysaccharide in the drilling fluid is greater than or equal to 0.01 g/L and less than or equal to 5 g/L.

Abstract: A scale inhibitor squeeze treatment is enhanced by injecting a pre-flush solution into a wellbore, where the pre-flush solution includes at least one organic carbonate solvent, such as a dialkyl carbonate and/or a cyclic carbonate. The use of an organic carbonate solvent can help prevent the pre-flush solution emulsion formation, help avoid water-blocking, and enhance scale inhibitor adsorption. The use of an organic carbonate solvent also permits the pre-flush solution to be free of water, in one non-limiting embodiment.

Abstract: A gel material for oil and gas conformance control operations is provided. The gel material includes a plurality of gel material components including polyacrylamide, triamine silica, and nanosilica which are added in suitable amounts to form the gel material under a gel formation condition. The present technology replaces and/or supplements conventional crosslinkers and provides enhanced polymeric gels, such as, for oil and gas field applications including wellbore strengthening, loss circulation materials, and water shut-off applications, at high temperatures. The present technology is compatible with fresh and high salinity water.

Abstract: A method includes conveying a straddle packer assembly into a wellbore that provides a water production zone and first and second oil production zones, the water production zone interposing the first and second oil production zones, deploying the straddle packer assembly and thereby isolating the water production zone from the first and second oil production zones, injecting an injection fluid into the water production zone from the straddle packer assembly, and preventing the influx of water from the water production zone into the wellbore with the injection fluid.

Abstract: A coating protects a dissolvable component of a downhole tool, so that the dissolvable component can be deployed to a desired downhole location, perform under high stress for fracturing operations, and be efficiently dissolved after the fracturing operations are completed. The present invention elevates known greases for this functionality usually performed by complex factory fabricated polymer and metal coatings. The coating includes an activation layer, a first grease layer, and a second grease layer. The first grease layer and the second grease layer have differential grease layer consistency ranges and thickness rages. The coating includes non-uniform layers of manually applied greases onsite to control degradation of the component substrate as effectively as factory coatings pre-fabricated on the components.

Abstract: A solid surfactant composition includes a water-wetting surfactant and a plant fiber carrying agent. A process includes forming a solid surfactant composition comprising a water-wetting surfactant and a plant fiber carrying agent and injecting the solid surfactant composition into a wellbore.

Abstract: Solidified nitrogen is placed at a downhole location within a wellbore formed in a subterranean formation. The solidified nitrogen is encapsulated by an emulsifying agent. The emulsifying agent is configured to dissolve in response to exposure to a downhole fluid. The solidified nitrogen encapsulated by the emulsifying agent is exposed to the downhole fluid at the downhole location within the wellbore, thereby dissolving the emulsifying agent and releasing the solidified nitrogen. The solidified nitrogen is allowed to sublimate into nitrogen gas within the wellbore, thereby reducing hydrostatic column in the wellbore. The downhole fluid is produced from the wellbore to a surface location.

Abstract: A treatment fluid composition includes a carrier fluid and a curable hybrid resin. The curable hybrid resin includes a first curable resin (A) including a reactive silyl group that reacts with water downhole, a second curable resin (B), and a curing agent for the second curable resin (B). A method of treating a subterranean formation includes injecting a treatment fluid including a curable hybrid resin into a target zone of the subterranean formation. The target zone may have unconsolidated or weakly consolidated sand. The method then includes maintaining the treatment fluid in the target zone for a period of time such that the curable hybrid resin cures and forming a consolidated formation in the target zone.

Abstract: Provided is a carbon dioxide fluidity control device comprising, a sample preparation tank, a high-pressure stirring unit, a reciprocating plunger pump and a booster pump, wherein the stirring unit comprises one or more high-pressure stirring tanks, each provided with an atomizing spray probe and a piston, wherein a discharge port of the sample preparation tank is connected to the atomizing spray probe via a plunger pump, which is connected to the piston to push the piston to reciprocate; the booster pump is connected to the high-pressure stirring tanks to provide supercritical carbon dioxide to the high-pressure stirring tank; and a discharge port of the high-pressure stirring tanks is connected to an oilfield well group. Provided is a carbon dioxide fluidity control method using the device, comprising mixing surfactants and nanoparticles with heated carbon dioxide, and injecting a microemulsion of supercritical carbon dioxide and nano-silicon dioxide into an oilfield well group.

Abstract: Compositions and methods using subterranean treatment fluids comprising water-soluble polymers are provided. In some embodiments, the methods include: adding an anionic or amphoteric water-soluble polymer to a treatment fluid comprising an aqueous base fluid; adding a dewatering agent to the treatment fluid, wherein the dewatering agent comprises an aqueous phase, a solvent, a co-solvent, and one or more surfactants selected from the group consisting of: ethoxylated alcohol, a polyamine polyether, a resin alkoxylated oligomer, and any combination thereof; and introducing the treatment fluid into a well bore penetrating at least a portion of the subterranean formation.

Abstract: A variety of methods and compositions are disclosed, including, in one embodiment, A friction reducer comprising: a continuous phase comprising a base oil and a secondary oil, wherein the secondary oil is different than the base oil; a discontinuous phase dispersed in the continuation phase, wherein the discontinuous phase comprises water and a water-soluble polymer; and an emulsifying surfactant.

Abstract: Wellbore drilling and completion systems implement a method of completing a wellbore. A laser head is mounted to a wellbore drilling assembly positioned within a wellbore formed in a subterranean zone. The laser head emits a first laser beam in a downhole direction within the wellbore to form the wellbore through the subterranean zone. Doing so causes portions of the subterranean zone to be released as drill cuttings into the wellbore. The laser head emits a second laser beam in a radial direction within the wellbore. The second laser beam is incident on a portion of the drill cuttings. The second laser beam causes the portion of the drill cuttings to consolidate and form a casing of the wellbore.

Abstract: Lost circulation material (LCM) compositions may include a resin; an emulsifier selected from the group consisting of ethoxylated phenol, sodium salt of modified tall oil fatty amide, carboxylic acid terminated fatty polyamide, modified amidoamine, tall oil fatty acid, oxidized tall oil fatty amidoamine, ether carboxylic acid, and combinations thereof; a crosslinker, a cementitious and/or weighting agent; a retarder; a dispersant; and a silicon-based defoamer. The LCM compositions may have a thickening time of from about 3 hours than about 6 hours by reaching a Bearden consistency of 100 Bc. Methods of eliminating or reducing lost circulation in a lost circulation zone from a well may include introducing these LCM compositions into the well.

Abstract: A slurry including a density-tunable heavy fracturing fluid and a method for completing a hydrocarbon well using such a slurry are provided herein. The slurry includes a proppant and the density-tunable heavy fracturing fluid, where the density-tunable heavy fracturing fluid includes a pseudo heavy fluid suspension, a concentrated aqueous solution of a soluble heavy compound, and/or a high-density organic solution. The density of the density-tunable heavy fracturing fluid is between 1.25 grams/milliliter (g/ml) and 3.4 g/ml. Moreover, the density of the density-tunable heavy fracturing fluid is selected based on the density of the proppant. According to the method provided herein, the slurry is used to provide for more effective placement of the proppant within the fractures than can be achieved using only a slurry including conventional fracturing fluid and the proppant.

Abstract: Techniques for treating a hydrocarbon reservoir include delivering a composition to the hydrocarbon reservoir. The composition includes at least one acid, and liquid or supercritical carbon dioxide (CO2). The method further includes exposing the delivered composition to water to activate the composition; and treating a rock formation of the hydrocarbon reservoir with the activated composition.

Abstract: The present disclosure relates to a fracturing propping agent and a preparation method thereof. The fracturing propping agent comprises the following raw materials: dry sludge, quartz sand, coal ash, bauxite and clay.

Abstract: A hydraulic fracturing method for recovering oil from a low-temperature subterranean oil formation is disclosed. Before, during, or after inducing hydraulic fracturing within the formation, a particulate, degradable polyester diverting agent is introduced into the formation in an amount effective to improve oil production from the formation. The diverting agent is allowed to degrade, and oil is recovered. The diverting agent has a melting point greater than the average temperature of the formation and is selected from: (i) ethylene glycol succinates; (ii) acid-terminated ethylene glycol succinates; (iii) acid-terminated polyglycolic acids; (iv) acid-terminated polylactic acids; (v) mixtures of any of (i) through (iv) with a half acid ester; and (vi) mixtures of polylactic acids or polyglycolic acids with a half acid ester.

Abstract: In accordance with one or more embodiments of the present disclosure, a host-guest lost circulation material (LCM) composition for sealing lost circulation zones in wellbores includes an aqueous solution; one or more linear polymer chains, the linear polymer chains comprising polyethylene glycols (PEG) with molecular weights greater than 2500 g/mol, polypropylene glycols (PPG), polydimethylsiloxanes (PDMS), or combinations thereof; and one or more cyclic molecules comprising alpha cyclodextrin, beta cyclodextrin, gamma cyclodextrin, or combinations thereof, and wherein the one or more cyclic molecules form a host-guest structure around the one or more linear polymer chains utilizing van der Waals forces.

Abstract: The present invention refers to a method for removing fouling in carbonate reservoirs and/or depleted reservoirs by adding carbon dioxide to industrial or desulphated water to produce carbonic acid, in producing well stimulation operations, to be used as a weak acid for removing fouling in remote operation aiming at keeping the productivity of producing wells and lessening the need for remote operations with stimulation vessel, and therefore reducing operating costs.