Abstract: The present disclosure relates to cementing fluids including a latex and a cement. In an exemplary embodiments, the latex includes a first polymer and a second polymer; the first polymer includes at least about 80 mol % polyvinyl acetate; the second polymer has a general structure in which x is an overall molar ratio of styrene, y is an overall molar ratio of butadiene, and z is an overall molar ratio of carboxylic acid; a sum of x, y, and z is represented as s; styrene (x) is about 20% to about 30% of s; butadiene (y) is about 70% to about 80% of s; and carboxylic acid (z) is 0% to about 2% of s.

Abstract: A composition of an invert emulsion oil-based drilling fluid is provided. The composition may include an oil phase and an aqueous phase. The oil phase may include an oleaginous fluid, an organophilic clay-based solid viscosifier, and a liquid viscosifier including a POSS. Further provided is a method of introducing the composition including the POSS into a wellbore. After introduction of the composition into the wellbore, the method includes maintaining wellbore conditions to provide a stable rheological property for a period up to about 96 hours in an HPHT section of a wellbore.

Abstract: The present disclosure relates to cement compositions including Portland cement and volcanic ash. An exemplary cement composition includes about 10 wt % to about 85 wt % of Portland cement, and about 10% by weight of cement (BWOC) to about 70% BWOC of volcanic ash.

Abstract: Described is a method for quantifying and tracking an amine-based shale inhibitor in a drilling fluid through UV-visible spectroscopy. A correlation is determined between varying concentrations of an amine-based shale inhibitor in a water-based drilling fluid sample and an ultraviolet (UV)-visible absorption intensity. A calibration plot is generated based on the correlations. Samples of a circulating drilling fluid having an unknown concentration of amine-based shale inhibitor are obtained. Using the calibration plot, the concentration of amine-based shale inhibitor in the samples of the circulating drilling fluid is estimated.

Abstract: The present disclosure relates to packer fluids including water and ethylene glycol, to methods for treating a wellbore with such packer fluids, and to wellbores including such packer fluids disposed in an annulus thereof.

Abstract: The present disclosure relates to packer fluids including a hydrocarbon and ethylene glycol, to methods for treating a wellbore with such packer fluids, and to wellbores including such packer fluids disposed in an annulus thereof.

Abstract: The present disclosure relates to slurries including an epoxy resin, a curing agent, silica sand, and silica flour, and to methods of sealing an annulus of a wellbore therewith.

Abstract: The present disclosure relates to cementing fluids including a latex and a cement. In an exemplary embodiments, the latex includes a first polymer and a second polymer; the first polymer includes at least about 80 mol % polyvinyl acetate; the second polymer has a general structure in which x is an overall molar ratio of styrene, y is an overall molar ratio of butadiene, and z is an overall molar ratio of carboxylic acid; a sum of x, y, and z is represented as s; styrene (x) is about 20% to about 30% of s; butadiene (y) is about 70% to about 80% of s; and carboxylic acid (z) is 0% to about 2% of s.

Abstract: A composition of an invert emulsion oil-based drilling fluid formulation includes an invert emulsion of an oil phase and an aqueous phase. The oil phase includes an oleaginous fluid and a liquid viscosifier that is a polyhedral oligomeric silsesquioxane (POSS). A method includes introducing an invert emulsion oil-based drilling fluid formulation including an oil phase, an aqueous phase, and a liquid viscosifier including POSS downhole through the wellbore and maintaining wellbore conditions such that the invert emulsion oil-based drilling fluid formulation provides a stable rheological property including one or more of viscosity, yield point, plastic viscosity, gel strength, and electrical stability for a period up to about 96 hours.

Abstract: A lost circulation material (LCM) composition comprising a spent drilling fluid and a chemical activator. The spent drilling fluid may comprise an aqueous solution, contaminants comprising heavy metals, salt, or both, and an alkaline nanosilica dispersion. The chemical activator may comprise a water soluble hydrolysable polyester. The spent drilling fluid may also have a pH and a gel pH, wherein the pH of the spent drilling fluid is greater than the gel pH.

Abstract: The disclosure relates to methods to prepare metal oxide nanoparticles (MONs) from the cathodes of lithium-ion batteries (LIBs), and related compositions and systems. The MONs can be used to improve the properties of drilling fluids, such as those used in underground drilling methods to produce oil and/or natural gas.

Abstract: Compositions may include a calcium lignosulfonate salt having a chemical structure (I), wherein a total number of syringyl groups is 2 to 10. The compositions may further include an alcohol, an aldehyde, and water. Cement slurries may include a lignosulfonate-based cement dispersant including a calcium lignosulfonate salt having a chemical structure (I), an alcohol, an aldehyde, and water, wherein a total number of syringyl groups in the chemical structure (I) is 2 to 10. The cement slurries may further include a cement and water. Methods may include introducing a cement slurry into a wellbore penetrating a subterranean formation, wherein the cement slurry comprises a lignosulfonate-based cement dispersant, a cement, and water, and allowing the cement slurry to set to a concrete in a downhole zone of interest.

Abstract: Described is a method for assessing quality of an amine-based shale inhibitor in drilling fluid. A relationship between a concentration of the amine-based shale inhibitor in a drilling fluid and turbidity is established by preparing drilling fluid solutions with varying concentrations of the amine-based shale inhibitor, allowing the drilling fluid solutions to form precipitates, and analyzing turbidity of the drilling fluid solutions. A sample of a drilling fluid with an unknown concentration of amine-based shale inhibitor is obtained. Using the established relationship, a concentration of the amine-based shale inhibitor in the sample of the drilling fluid is estimated.

Abstract: Methods for making and using an invert-emulsion drilling fluid, and the invert-emulsion drilling fluid are provided. An exemplary invert-emulsion drilling fluid includes a C-36 dimer diamine dihydrochloride salt (CDDH), an aqueous solvent, a non-aqueous solvent, an emulsifier, and calcium chloride.

Abstract: The present disclosure relates to cement compositions including Portland cement and volcanic ash. An exemplary cement composition includes about 10 wt % to about 85 wt % of Portland cement, and about 10% by weight of cement (BWOC) to about 70% BWOC of volcanic ash.

Abstract: A method of reducing water production in a wellbore may include introducing an alkaline nanosilica dispersion to the wellbore such that it contacts a water producing zone of the wellbore, introducing a sodium bicarbonate activator to the wellbore such that it contacts the alkaline nanosilica dispersion in the water producing zone, and forming a gelled solid from the water shutoff material in the water producing zone, thereby reducing water production in the wellbore.

Abstract: A loss circulation material (LCM) includes an alkaline nanosilica dispersion and a formate activator. The formate activator may be present in an amount in a range of 1 wt % to 40 wt % of the loss circulation material. A method of controlling loss circulation in a loss circulation zone (LCZ) in a wellbore includes introducing an alkaline nanosilica dispersion into the wellbore, introducing a formate activator solution into the wellbore, contacting the alkaline nanosilica dispersion with the formate activator, thereby forming a LCM composition, and forming a gelled solid from the LCM in the loss circulation zone. A method of controlling loss circulation in a LCZ in a wellbore includes introducing a LCM that includes an alkaline nanosilica dispersion and a formate activator into the wellbore such that they contact the LCZ, and forming a gelled solid from the LCM in the LCZ.

Abstract: A loss circulation material includes an acidic nanosilica dispersion and a formate activator, which may be present in an amount in a range of 1 wt % to 40 wt % of the loss circulation material. A method to control lost circulation in a lost circulation zone in a wellbore includes introducing an acidic nanosilica dispersion into the wellbore, introducing a formate activator into the wellbore, contacting the acidic nanosilica dispersion with the formate activator, thereby forming a loss circulation material composition, and forming a gelled solid from the loss circulation material in the lost circulation zone. A method of controlling lost circulation in a lost circulation zone in a wellbore includes introducing a loss circulation material comprising an acidic nanosilica dispersion and a formate activator into the wellbore, such that they contact the lost circulation zone, and forming a gelled solid from the loss circulation material in the lost circulation zone.

Abstract: A tool for use in a wellbore includes an annular body having an inner flow passage extending axially therethrough, at least one gripping member positioned around an outer perimeter of a retainer section of the annular body, and a gate member positioned in the inner flow passage. When the gate member is in a closed configuration, an upstream portion of the inner flow passage is sealed from a downstream portion of the inner flow passage by the gate member. When the gate member is in an open configuration, the upstream portion of the inner flow passage is fluidly connected to the downstream portion of the inner flow passage. At least one static mixing blade extends through the downstream portion of the inner flow passage to mix fluid when it flows through the open gate member.

Abstract: A method and system for controlling unwanted water production from a water-producing zone in a subterranean formation are provided. An exemplary method includes flowing an alkaline suspension of nanosilica particles into a wellbore such that it contacts the water-producing zone, and flowing a formate salt solution into the wellbore such that it contacts the alkaline suspension in the water-producing zone producing a composition. The wellbore is shut in a duration of time sufficient for the composition to form a gel that is impermeable to fluid flow.