Abstract: A well treatment microemulsion for use in a subterranean formation is disclosed, the microemulsion comprises a solvent blend comprising a solvent and a co-solvent; a surfactant blend comprising a surfactant, wherein the surfactant blend is able to give formation intermediate wettability properties; an alcohol; and a carrier fluid; wherein the alcohol, the solvent and surfactant blends are combined with the carrier fluid to produce the well treatment microemulsion. By intermediate wettability it is meant that the water has an advancing contact angle on the surface between 62 and 133 degrees. The associate method of treating a subterranean formation of a well with the microemulsion and the associate method of modifying the wettability of the formation with the microemulsion are also disclosed.

Abstract: A subterranean formation stimulation method utilizes a treatment fluid comprising residual drilling fluid injected into the formation, and producing the stimulated formation. In one embodiment, a tight gas formation is fractured and the fracture has a higher conductivity than the formation.

Abstract: This invention relates to compositions and methods for treating subterranean formations, in particular, oilfield stimulation compositions and methods using water-in-water polymer emulsions to uniformly dissolve a rheologically active polymer, such as a thickener or friction reducer, in the treatment fluid. The emulsions have a low viscosity and are easily pumped for mixing into a treatment fluid, where upon dilution with an aqueous medium, the polymer is easily hydrated without forming fish-eyes. The partitioning agent in the water-in-water emulsion does not generally affect the rheology of the treatment fluid. The invention also relates to further processing of the emulsion by wet grinding, high shear mixing and/or heating to enhance the hydration rate in the preparation of the well treatment fluid.

Abstract: The invention discloses treatment and reuse of oilfield produced water. A method of inhibiting enzymes/bacteria in an aqueous medium for viscosification comprises contacting the aqueous medium with a denaturant and/or a bactericide and thereafter mixing a gelling agent in the aqueous medium. The viscosified fluid can be used as a well treating fluid for fracturing and other applications. A well treatment fluid comprises a metal denaturant and/or a bactericide and a gelling agent in an amount effective to viscosify the fluid. Also disclosed is oilfield produced water denatured with from 1 to 2000 ppm by weight of a zirconium compound.

Abstract: A method of treating a subterranean formation penetrated by a wellbore utilizes a treating fluid formed from an aqueous solution of a water-soluble polymer. The treating fluid further contains a crosslinking agent and an optional delayed release alkaline additive. The delayed release alkaline additive may be at least one of urea, a urea derivative, a solid alkaline earth metal carbonate, a solid alkaline earth metal oxide and combinations of these. The treating fluid further includes an acidic pH adjusting agent used in an amount to provide the treating fluid with a pH of less than about 5. The treating fluid is then introduced into the formation.

Abstract: A low molecular weight, high melting point, crystalline, oil soluble additive for use in wellbore fluids is provided that is preferably a ground crystalline material of melting point over 80° C., preferably over 100° C. which is readily soluble in produced hydrocarbons such as crude oil and lighter condensates, and which exhibits a molecular weight of less than 1000, and preferably less than 500, and more preferably less than 300. Its particle size can be adjusted to bridge efficiently across different pore size formations and control its solubility rate.

Abstract: The addition of fibrous mixtures in intimate mixtures with particulates for fracturing and gravel packing decreases or eliminates the undesirable flowback of proppant or formation fines while stabilizing the sand pack and lowering the demand for high polymer loadings in the placement fluids. Fibers are useful for forming a porous pack in the subterranean formation. In some cases, channels or fingers of void spaces with reduced concentrations of proppant may be introduced into the proppant pack.

Abstract: The addition of fibrous mixtures in intimate mixtures with particulates for fracturing and gravel packing decreases or eliminates the undesirable flowback of proppant or formation fines while stabilizing the sand pack and lowering the demand for high polymer loadings in the placement fluids. Fibers are useful for forming a porous pack in the subterranean formation. In some cases, channels or fingers of void spaces with reduced concentrations of proppant may be introduced into the proppant pack.

Abstract: The addition of fibrous materials in intimate mixture with particulates for fracturing and gravel packing decreases or eliminates the flowback of proppant and/or formation fines while stabilizing the sand pack and lowering the demand for high polymer loadings in the placement fluids. Preferred fibers include glass, aramide, nylon and other natural and synthetic organic and inorganic fibers and metal filaments.

Abstract: The addition of fibrous materials in intimate mixture with particulates for fracturing and gravel packing decreases or eliminates the flowback of proppant and/or formation fines while stabilizing the sand pack and lowering the demand for high polymer loadings in the placement fluids. Preferred fibers include glass, aramide, nylon and other natural and synthetic organic and inorganic fibers and metal filaments.

Abstract: This invention is directed to a polyurethane mixture. More particularly, there is provided a mixture polyurethanes comprising a first polyurethane with at least two end groups, where each end group comprises a terminal isocyanate and a polyether; a second polyurethane with at least two end groups, where each end group comprises a terminal isocyanate group and a non-functional group; and a third polyurethane with at least two end groups, where one end group comprises a terminal isocyanate and a polyether and one other end group comprises a terminal isocyanate and a non-functional group. A method for improving the sag resistance of an aqueous composition is also provided. This method permits the formulation of aqueous compositions which resist the tendency to sag. The polyurethane mixture of this invention is useful for thickening aqueous compositions such as paints, coatings, cosmetics, personal care items, hair shampoos and conditioners, cleaners, and the like.