Abstract: Producing proppants with nanoparticle proppant coatings includes reacting nanoparticles with at least one of an alkoxysilane solution or a halosilane solution to form functionalized nanoparticles and coating proppant particles with unfunctionalized organic resin, a strengthening agent, and the functionalized nanoparticles to produce the nanoparticle coated proppant. The functionalized nanoparticles include nanoparticles having at least one attached omniphobic moiety including at least a fluoroalkyl-containing group including 1H, 1H, 2H, 2H-perfluorooctylsilane. The strengthening agent comprises at least one of carbon nanotubes, silica, alumina, mica, nanoclay, graphene, boron nitride nanotubes, vanadium pentoxide, zinc oxide, calcium carbonate, or zirconium oxide.

Abstract: A wellbore fluid comprising a first aqueous base fluid and a plurality of silica nanoparticles suspended in the first aqueous base fluid. The nanoparticles are present in the fluid in an amount to have an effect of decreasing a crystallization temperature by at least 4 to 55° F. as compared to a second aqueous base fluid without the silica nanoparticles.

Abstract: In wellbore abandonment operations using recycled tire rubber, a quantity of shredded rubber obtained by shredding waste tires is mixed with a quantity of a wellbore fluid to form a wellbore abandonment fluid. A first plug of cement is flowed into a wellbore to be abandoned. After the first plug of cement has set, the wellbore abandonment fluid is flowed into the wellbore such that the wellbore abandonment fluid contacts and is uphole of the first plug of cement within the wellbore. After flowing the wellbore abandonment fluid into the wellbore, a second plug of cement is flowed into the wellbore such that the second plug of cement contacts and is uphole of the wellbore abandonment fluid.

Abstract: The present invention relates to a process for the preparation of a water-soluble copolymer comprising the step of reacting a monomer (a) of formula (I), wherein Q1, Q2, R1 to R7 and X have the meaning as indicated in the description and claims with at least one monoethylenically unsaturated, anionic monomer (b), preferably representing a monoethylenically unsaturated monomer comprising at least one carboxy, phosphonate or sulfonate group and salts thereof, preferably their ammonium salts or alkaline-earth metal salts or alkali metal salts; and at least one monoethylenically unsaturated, non-ionic monomer (c). The present invention further relates to a copolymer obtainable by said process and its use in enhanced oil recovery (EOR), a formulation comprising said copolymer and a method of oil production uses said formulation.

Abstract: The embodiments described herein generally relate to methods and chemical compositions for use with wellbore treatment processes. In one embodiment, a composition is provided comprising a cementitious material, a drilling fluid, or combinations thereof, and an additive composition comprising one or more components selected from the group of an aqueous insoluble lignin, a coke fine, a random tetracopolymer having the formula styrene-butadiene-acrylic-fumaric acid, a polyvinyl acetate, a surfactant composition, and combinations thereof.

Abstract: A method for controlling the permeability of an oil well includes the steps of preparing a polymerizable bicomponent system having at least a fluid with at least an olefinically unsaturated first polymerizable compound; optionally, at least one radical polymerization initiator IA, the initiator IA being activated thermally or in the presence of an accelerating compound and a fluid with a radical polymerization activator, the activator being selected from: a radical polymerization initiator IB for polymerizing the polymerizable compound, the initiator IB having an activation temperature equal to or lower than the temperature of the thief zone, an accelerator of the initiator IA, The method further includes injecting one of the fluids into the well annulus until the thief zone is reached, and injecting the remainder into the tubular element, until it comes into contact with the fluid injected through the annulus to form a blocking polymer at the thief zone.

Abstract: A treatment fluid and process for enhancing hydrocarbon production from a shale formation using a treatment fluid comprising a water soluble delayed release carbonate-dissolving agent and introducing the treatment fluid into the shale formation after or as part of a hydraulic fracturing process.

Abstract: A fluid control system includes a fluid control device configured to be connected to at least one of two casing elements in a well, for controlling a fluid flow between a bore of the fluid control device and a zone located outside the casing elements; and a tracer material located within an inner chamber of a body of the fluid control device, the tracer material being uniquely associated with the fluid control device. The fluid control device is configured to release, when activated, the tracer material out of the inner chamber.

Abstract: Disclosed is a temperature stabilized aqueous wettability composition and method of use for the recovery of petroleum from subterranean formulations. Said aqueous wettability composition comprises a polyethylene oxide nonionic surfactant, a disulfonated anionic surfactant, and one or more alcohol.

Abstract: The disclosure describes hydrocarbon flowline corrosion inhibitor overpressure protection. Such a protection system includes a fluid flow pathway fluidically coupled to a corrosion inhibitor injection pump that injections corrosion inhibitor into a hydrocarbon carrying flowline. When the injection pump pressure exceeds a threshold flow pressure, the corrosion inhibitor is flowed through a first branch of the fluid flow pathway to relieve the excess pressure. The first branch is fluidically isolated from a second branch. When a rupture disc in the first branch fails, then the corrosion inhibitor is diverted to flow through the second branch and the first branch is isolated from the corrosion inhibitor flow.

Abstract: The invention relates to an inverse polymer emulsion having the particular feature of auto-inverting without any need for the use of an inverting agent and containing a polymer of at least one water-soluble monomer and at least one LCST macromonomer. The invention also relates to the use of the inverse emulsion in the fields of the oil and gas industry, water treatment, slurry treatment, paper manufacturing, construction, mining, cosmetics, textiles, detergents or agriculture.

Abstract: A method and compounds for enhanced oil recovery (EOR) including flooding of a mixture of water and one or more of the compounds in a geological formation. The compounds have a fluoroalkyl group.

Abstract: A chemical gel system having a polymer and a silicon oxide Janus nanosheets crosslinker for treating thief zones in carbonate formations. The polymer and silicon oxide Janus nanosheets crosslinker may form a crosslinked polymer gel to reduce or prevent water production via thief zones during hydrocarbon production. The silicon oxide Janus nanosheets crosslinker includes a first side having negatively charged functional groups and a second side having amines. The negatively charged functional groups may include negatively charged oxygen groups and hydroxyl groups. Methods of reducing water production in a thief zone using the silicon oxide Janus nanosheets crosslinker and methods of manufacturing the silicon oxide Janus nanosheets crosslinker are also provided.

Abstract: Modified Drilling fluid compositions and methods for using drilling fluid compositions are provided with enhanced loss control properties where the modified drilling fluid may include a carrier fluid, one or more drilling fluid additives, and a loss control material blend. The loss control material blend may include a particle component of sized particulate comprising a plurality of a mixture of untreated date seed particles and a fibrous component comprising a mixture of hard date leaflet fibers and soft date tree fibers prepared from date tree waste materials. Methods to control lost circulation in a lost circulation zone in a wellbore may include introducing a modified drilling fluid into the wellbore such that the modified drilling fluid contacts the lost circulation zone.

Abstract: An apparatus may include an inlet and an enclosure includes a container that is coupled to the inlet. The container may receive water from the inlet. The apparatus may further include various check valves coupled to the container. The apparatus may further include a laser head coupled to the container. The laser head may receive a laser signal that converts the water inside the container into steam. The check valves may release the steam outside the enclosure.

Abstract: A system may include: a source of water fluidically coupled to a fracturing blender; water testing equipment disposed between the source of water and the fracturing blender wherein the water testing equipment is operable to measure at least one property of the source of water; a plurality of friction reducing polymers operable to be added to the fracturing blender; and a control system comprising: at least one processor; and a memory coupled to the processor to provide software that configures the processor to receive an input signal from the water testing equipment and select at least one of the plurality of friction reducing polymers.

Abstract: Polyacrylamide (PAM)-coated nanosand that may be a relative permeability modifier (RPM) and that is applied to treat a wellbore in a subterranean formation. The treatment may be for excess water production. The PAM-coated nanosand is PAM-hydrogel-coated nanosand. The PAM-coated nanosand os nanosand coated with PAM hydrogel. The PAM hydrogel includes crosslinked PAM in water. Application of the PAM-coated nanosand may reduce water production from the subterranean formation into the wellbore. The PAM hydrogel of the PAM-coated nanosand may expand in a water zone of the subterranean formation to restrict water flow into the wellbore. The PAM hydrogel of the PAM-coated nanosand may contract in an oil zone of the subterranean formation so not to significantly restrict crude oil flow into the wellbore.

Abstract: A method of controlling lost circulation includes introducing into a wellbore a lost circulation fluid comprising: an external oil phase, an internal aqueous phase, an emulsifier, a wetting agent, a magnesia sealant, and a; retarder; contacting the lost circulation fluid with a lost circulation zone; and forming a plug adjacent the lost circulation zone by reacting the magnesia sealant with water at a wellbore temperature, thereby reducing fluid loss into the lost circulation zone.

Abstract: The present disclosure relates to biocide compositions, formulations and methods for using formulations. In particular the present disclosure relates to biocide compositions and their use in effecting biocidal activity in subterranean oil and gas wells being drilled, completed, worked over or produced.

Abstract: A downhole tool for controlling the flow of a fluid in a wellbore includes a component that comprises: a cementitious material; an aggregate; and a ductility modifying agent comprising one or more of the following: an ionomer; a functionalized filler; the functionalized filler comprising one or more of the following: functionalized carbon; functionalized clay; functionalized silica; functionalized alumina; functionalized zirconia; functionalized titanium dioxide; functionalized silsesquioxane; functionalized halloysite; or functionalized boron nitride; a metallic fiber; or a polymeric fiber.