Abstract: A method of increasing a solubility of a manganese oxide includes contacting the manganese oxide with an acid component in the presence of a dissolution accelerator that includes at least one of hydrazine, a hydrazine derivative, or a hydrazide. Also disclosed is a drilling fluid containing a carrier; MnO2; and at least one of a viscosifier, a rheology modifier, a dispersant, a weighting agent, a defoamer, a fluid loss agent, bentonite, or a lubricant.

Abstract: A method of increasing a solubility of a manganese oxide includes contacting the manganese oxide with an acid component in the presence of a dissolution accelerator that includes at least one of hydrazine, a hydrazine derivative, or a hydrazide. Also disclosed is a drilling fluid containing a carrier; MnO2; and at least one of a viscosifier, a rheology modifier, a dispersant, a weighting agent, a defoamer, a fluid loss agent, bentonite, or a lubricant.

Abstract: At least one solid may be separated from a water-based fluid by flowing the water-based fluid through a filter media in combination with filtration equipment, such as a filter press. In a non-limiting embodiment, the filter media may be or include, but is not limited to, diatomaceous earth and at least one alkaline earth metal(s). The solid(s) may be or include a metal, such as but not limited to zinc, iron, manganese, mercury, nickel, cations thereof, and combinations thereof. In a non-limiting embodiment, the water-based fluid may be or include a production fluid, a drilling fluid, a drill-in fluid, a completions fluid, a fracturing fluid, a servicing fluid, a stimulation fluid, a treating fluid, and combinations thereof.

Abstract: An effective amount of a hydrazine complexing agent and/or a non-hydrazine complexing agent may be added to an oil-based fluid having at least one metal. The complexing agent may form an insoluble metal complex with the metal(s). The metal(s) may be or include, but are not limited to zinc metal, nickel metal, iron metal, cations thereof, and combinations thereof. The insoluble metal complex may be or include, but is not limited to a zinc complex, a nickel complex, an iron complex, and combinations thereof. The insoluble metal complex may be removed from the oil-based fluid where the metal may be separated from the insoluble metal complex.

Abstract: Zinc, nickel and iron can be recovered from spent brines and produced water using a method that includes admixing an aqueous fluid with hydrazine to form a hydrazine complex and then filtering or otherwise removing the hydrazine complex from the aqueous fluid. Once treated, the aqueous fluid can then be recycled or at be the subject to an easier disposal. The isolated metal hydrazine complex may be recycled or discarded.

Abstract: Brine-based well treatment compositions containing alkali nitrate exhibit greater thermal stability when used in deep wells than substantially similar brine-based well treatment compositions which do not contain an alkali nitrate. The brine is thickened with a water-soluble crosslinkable polymer and crosslinking agent. The enhanced thermal stability of the well treatment compositions allows use of the fluids at elevated temperatures, for instance as high as 400° F.

Abstract: Brine-based well treatment compositions containing alkali nitrate exhibit greater thermal stability when used in deep wells than substantially similar brine-based well treatment compositions which do not contain an alkali nitrate. The brine is thickened with a water-soluble crosslinkable polymer and crosslinking agent. The enhanced thermal stability of the well treatment compositions allows use of the fluids at elevated temperatures, for instance as high as 400° F.

Abstract: This invention relates to a wellbore treatment fluid and a method of enhancing wellbore treatment fluids to increase efficiency and productivity of wells. More specifically this invention provides methods for enhancing the thermal stability of wellbore treatment fluids such as drill-in, completion, work-over, packer, well treating, testing, spacer, or hole abandonment fluids. The methods include providing a wellbore treatment fluid that includes a polyol selected from glycerol, glycols and polyglycols as well as a polysaccharide viscosifier. The fluid prepared for use in this invention find particularly advantageous use as a completion fluid and as a fluid loss pill. However, the fluid can include a wide variety of additional agents to modify the physical and chemical properties of the wellbore treatment fluid.

Abstract: This invention relates to a wellbore treatment fluid and a method of enhancing wellbore treatment fluids to increase efficiency and productivity of wells. More specifically this invention provides methods for enhancing the thermal stability of wellbore treatment fluids such as drill-in, completion, work-over, packer, well treating, testing, spacer, or hole abandonment fluids. The methods include providing a wellbore treatment fluid that includes a polyol selected from glycerol, glycols and polyglycols as well as a polysaccharide viscosifier. The fluid prepared for use in this invention find particularly advantageous use as a completion fluid and as a fluid loss pill. However, the fluid can include a wide variety of additional agents to modify the physical and chemical properties of the wellbore treatment fluid.

Abstract: This invention relates to novel compositions and methods whereby a carboxylate based brine solution is used in drilling and/or well bore treating operations to inhibit corrosion of fluid handling equipment. In one embodiment of the invention the carboxylate based brine solution consists of a carboxylate salt dissolved in water. This brine solution is used to prepare halide-free drilling fluids. Use of halide-free drilling fluids inhibits corrosion stainless steel surfaces of fluid handling equipment. In an alternative embodiment of the present invention a mixed salt brine containing a carboxylate salt and a halide salt is provided for use in a drilling and/or well bore treating operations.

Abstract: Advantageous aqueous mixed salt systems viscosified with water-soluble or water-dispersable polymers which are superior to corresponding single salt systems of similar densities are provided. The mixed salt systems comprise water; a water-soluble or water-dispersable polymer capable of viscosifying an aqueous medium; one or more cations including a member selected from the group consisting of lithium, sodium, potassium, cesium, magnesium, calcium, zinc, or mixtures thereof; and one or more anions including a member selected from the group consisting of chloride, bromide, iodide, formate, nitrate, acetate, cyanate, thiocyanate, a zinc complex anion or mixtures thereof; there being present either at least two cations or at least two anions. Inventive viscosified mixed salt systems display--under such stressing factors as aging, heat, mechanical agitation, and shear--greater stability compared to the single salt systems of similar densities.

Abstract: The present invention provides compositions useful for viscosifying aqueous fluids, methods for making them and methods for using them. In one aspect of the invention, inventive compositions comprise a prehydrating alcohol having at least two hydroxyl groups and having a molecular weight of from about 60 to about 600; an inorganic salt; and a polymer. In a preferred aspect of the invention, the viscosifier composition additionally comprises a solvent having a molecular weight of from about 75 to about 1000. According to another aspect of the invention, inventive compositions comprise a prehydrating alcohol; an inorganic salt; and a polymer; and the composition is essentially free from water. Inventive compositions find advantageous use in viscosifying fluids utilized in subterranean drilling activities such as, for example, drilling, drill-in, completion, hydraulic fracturing, work-over, packer, well treating, testing, spacer, or hole abandonment fluids.