Various embodiments disclosed relate to compositions including a curable resin and organophilically-modified clay for subterranean oil well applications and methods of using the same. Various embodiments provide a method of treating a subterranean formation including placing in a subterranean formation a curable composition that includes at least one of a curable organic resin and a thermosetting polymer. The curable composition also includes an organophilically-modified clay.

A cement slurry composition, containing hydraulic cement, water, and from 1 to less than 4% of an organically modified nanoclay. A method for cementing a high pressure high temperature well by pumping the cement composition of claim 1 between a casing and a formation of a well bore to fill a gap between the casing and the formation, and allowing the cement to harden.

This invention relates to an adaptable Geopolymer cement composition for application in oil and gas wells having a wide range of downhole temperatures. The base Geopolymer cement composition has an acceptable rheology of below 200 cP and can be tailored by the inclusion of various chemicals to control properties such as thickening time over a wide range of temperatures and densities. The disclosed Geopolymer cement composition is pumpable, mixable and stable. The composition can also be adapted to have expandable and swellable properties.

This invention relates to an adaptable Geopolymer cement composition for application in oil and gas wells having a wide range of downhole temperatures. The base Geopolymer cement composition has an acceptable rheology of below 200 cP and can be tailored by the inclusion of various chemicals to control properties such as thickening time over a wide range of temperatures and densities. The disclosed Geopolymer cement composition is pumpable, mixable and stable. The composition can also be adapted to have expandable and swellable properties.

Drilling fluid compositions include invert emulsion fluids having an oleaginous phase, an aqueous phase, and an emulsifier composition that includes an ethoxylated alcohol compound and a polyaminated fatty acid compound. The ethoxylated alcohol compound has the formula R.sup.1—(OCH.sub.2CH.sub.2).sub.n—OH, where R.sup.1 is a hydrocarbyl group having from 8 to 22 carbon atoms and n is from 1 to 8. The ethoxylated alcohol compound has a Hydrophilic-Lipophilic Balance (HLB) of less than or equal to 6. The polyaminated fatty acid compound has the formula R.sup.2—CO—NH—CH.sub.2—CH.sub.2—N(COR.sup.2)—CH.sub.2—CH.sub.2—NH—CO—R.sup.3, where R.sup.2 is a hydrocarbyl group having from 1 to 20 carbon atoms and R.sup.3 is a hydrocarbyl group having from 1 to 10 carbon atoms or an alkylene carboxylate group having formula —R.sup.4—COOH, where R.sup.4 is a saturated or unsaturated hydrocarbylene having from 1 to 10 carbon atoms. Methods of drilling wells include operating a drill in a wellbore in the presence of drilling fluid compositions.

Drilling fluid compositions include invert emulsion fluids having an oleaginous phase, an aqueous phase, and an emulsifier composition that includes an ethoxylated alcohol compound and a polyaminated fatty acid compound. The ethoxylated alcohol compound has the formula R.sup.1—(OCH.sub.2CH.sub.2).sub.n—OH, where R.sup.1 is a hydrocarbyl group having from 8 to 22 carbon atoms and n is from 1 to 8. The ethoxylated alcohol compound has a Hydrophilic-Lipophilic Balance (HLB) of less than or equal to 6. The polyaminated fatty acid compound has the formula R.sup.2—CO—NH—CH.sub.2—CH.sub.2—N(COR.sup.2)—CH.sub.2—CH.sub.2—NH—CO—R.sup.3, where R.sup.2 is a hydrocarbyl group having from 1 to 20 carbon atoms and R.sup.3 is a hydrocarbyl group having from 1 to 10 carbon atoms or an alkylene carboxylate group having formula —R.sup.4—COOH, where R.sup.4 is a saturated or unsaturated hydrocarbylene having from 1 to 10 carbon atoms. Methods of drilling wells include operating a drill in a wellbore in the presence of drilling fluid compositions.

Various embodiments disclosed relate to a weighted composition for treatment of a subterranean formation. In various embodiments, the present invention provides a method of treating a subterranean formation. The method can include placing in a subterranean formation a weighted composition. The weighted composition can include a weighting agent and an inorganic coating material on the weighting agent. The inorganic coating material can be a crystalline inorganic coating material. The inorganic coating material can be an amorphous inorganic coating material.

Various embodiments disclosed relate to a weighted composition for treatment of a subterranean formation. In various embodiments, the present invention provides a method of treating a subterranean formation. The method can include placing in a subterranean formation a weighted composition. The weighted composition can include a weighting agent and an inorganic coating material on the weighting agent. The inorganic coating material can be a crystalline inorganic coating material. The inorganic coating material can be an amorphous inorganic coating material.

Precipitated particles may be formed under conditions that provide a particle morphology suitable for conveying a desired set of properties to a wellbore circulation fluid. Methods for using precipitated particles in a wellbore may comprise: selecting precipitation conditions for producing precipitated particles that are substantially non-spherical in shape, are about 1 micron or under in size, or any combination thereof; forming the precipitated particles from a reaction mixture under the precipitation conditions without using a polymeric dispersant; and introducing a wellbore circulation fluid comprising a plurality of the precipitated particles into a wellbore penetrating a subterranean formation. The precipitation conditions may include one or more of modulating various reaction conditions, applying an electric field to the reaction mixture, or including a carbohydrate-based material in the reaction mixture.

Precipitated particles may be formed under conditions that provide a particle morphology suitable for conveying a desired set of properties to a wellbore circulation fluid. Methods for using precipitated particles in a wellbore may comprise: selecting precipitation conditions for producing precipitated particles that are substantially non-spherical in shape, are about 1 micron or under in size, or any combination thereof; forming the precipitated particles from a reaction mixture under the precipitation conditions without using a polymeric dispersant; and introducing a wellbore circulation fluid comprising a plurality of the precipitated particles into a wellbore penetrating a subterranean formation. The precipitation conditions may include one or more of modulating various reaction conditions, applying an electric field to the reaction mixture, or including a carbohydrate-based material in the reaction mixture.