A method begins with the step of preparing a drag-reducing additive by mixing a dispersion polymer with a surfactant and a solvent. The method continues with the step of forming a drag-reducing composition by combining the drag-reducing additive with an aqueous treatment fluid. The method further involves the step of injecting the drag-reducing composition into a subterranean formation, a pipeline or a gathering line.

Methods of temporarily blocking zones of a subterranean formation for diversion, isolation, and fluid-loss control are provided. The method of diverting a fluid includes introducing a treatment fluid comprising a formate brine, xanthan gum, and a cross-linking agent into the formation; allowing the treatment fluid to set into a gel in perforations in a first zone of the formation to block the perforations in the first zone; introducing a stimulation fluid into the formation; and diverting the stimulation fluid away from the perforations in the first zone to perforations in a second zone of the formation.

Compositions and methods comprising certain microemulsions and certain clay control additives for enhancing clay swelling protection and persistency in treating swelling clay of a subterranean formation of oil and/or gas wells are generally provided. The combination of certain microemulsions and certain clay control additives exhibit synergistic effects by enhancing clay swelling protection and persistency in treating swelling clay. The well treatment composition may use up to four times less concentration of clay control additive compared to using the same clay control additive alone, while still providing the same, similar, or higher degree of clay swelling protection and enhanced persistency. The microemulsion and the clay control additive may be added to a carrier fluid to form the well treatment composition, which is injected into the subterranean formation to provide enhanced clay swelling protection and persistency of continuing to provide clay swelling protection for a longer period of time during flowback.

A method includes combining an aqueous fluid and an oleaginous fluid to prepare an invert emulsion comprising a polymerizable composition, degassing the invert emulsion under an extensional flow regime through an elongated passageway of an extender and thereby removing oxygen to produce a degassed invert emulsion. A flow rate of the invert emulsion and a diameter of the elongated passageway are sufficient to achieve a Reynolds number of 20,000 or greater. The method also includes transferring at least a portion of the degassed invert emulsion to the second extender at one or more time intervals and returning the portion of the degassed invert emulsion to the reactor, and isolating a polymer product from the degassed invert emulsion. A flow rate of the invert emulsion and a diameter of the elongated passageway are sufficient to achieve a Reynolds number of 20,000 or greater.

An aqueous-based well treatment fluid for and methods of controlling metal ions in a well, wherein the treatment fluid and methods use one or more polymer microgels, which comprise a plurality of polymer particles. Each polymer particle has a polymeric backbone bearing at least one moiety where such moiety is a chelating agent capable of boding with a metal ion.

Method for inhibiting the swelling and the dispersion of shales in the treatment of subterranean shale formations comprising the use of a cationic tamarind gum and fluids for the treatment of subterranean shale formations comprising a cationic tamarind gum.

A camera module comprising a polymer composition that includes a polymer matrix containing a liquid crystalline polymer and a mineral filler is provided. The liquid crystalline polymer contains repeating units derived from naphthenic hydroxycarboxylic and/or dicarboxylic acids in an amount of about 10 mol. % or more of the polymer. Further, the polymer composition exhibits a melt viscosity of from about 30 to about 400 Pa-s, as determined at a shear rate of 400 seconds.sup.1 and at a temperature 15 C. higher than the melting temperature of the composition in accordance with ISO Test No. 11443:2005.

Reaction products produced by mixing a maleated tall oil fatty acid and/or a maleated soy oil fatty acid/DETA component with an amine or amine bottom preparation are used as clay inhibitors in drilling fluids and in hydraulic fracturing fluids for drilling wells and for fracturing subterranean formations, and are also used as clay inhibitors in other treatment fluids for treating wells or subterranean formations.

Disclosed herein are the methods of using specific multiple charged cationic compounds, which are derived from polyamines through an aza-Michael addition with an ,-unsaturated carbonyl compound, in a clay treatment composition to reduces clay swelling, clay migration, and sludge formation in a subterranean formation in oil and gas operations. The disclosed methods or compositions are found to be more effective than those methods or compositions including commonly used for reducing clay swelling, clay migration, and sludge formation.

Reaction products produced by mixing a maleated tall oil fatty acid and/or a maleated soy oil fatty acid/DETA component with an amine or amine bottom preparation are used as clay inhibitors in drilling fluids and in hydraulic fracturing fluids for drilling wells and for fracturing subterranean formations, and are also used as clay inhibitors in other treatment fluids for treating wells or subterranean formations.