Disclosed are methods for using a composition comprising HCl, urea, complex substituted keto-amine-hydrochloride, at least one alcohol selected from the group consisting of isopropyl alcohol and propargyl alcohol, an ethoxylate, and at least one ketone selected from the group consisting of methyl vinyl ketone, acetone, and acetophenone.

A method for reducing lost circulation in a subterranean formation. The method includes providing a treatment fluid comprising a base fluid and a lost circulation material comprising red mud. The treatment fluid is introduced into a wellbore within the subterranean formation such that at least a portion of the red mud bridges openings in the subterranean formation to reduce loss of fluid circulation into the subterranean formation.

A method for reducing lost circulation in a subterranean formation. The method includes providing a treatment fluid comprising a base fluid and a lost circulation material comprising red mud. The treatment fluid is introduced into a wellbore within the subterranean formation such that at least a portion of the red mud bridges openings in the subterranean formation to reduce loss of fluid circulation into the subterranean formation.

A method of treating a subterranean formation including suspending proppant particulates in a treatment fluid, wherein the proppant particles include a coating comprising a salt-tolerant, water-swellable polymer, and the treatment fluid includes at least one fluid consisting of fresh water, salt water, seawater, brine, an aqueous salt solution, and combinations thereof; and introducing the treatment fluid containing the settling retardant proppant particulates into the subterranean formation. A composite proppant particle includes a proppant substrate and a salt tolerant polymeric layer deposited on the proppant substrate.

A method of treating a subterranean formation including suspending proppant particulates in a treatment fluid, wherein the proppant particles include a coating comprising a salt-tolerant, water-swellable polymer, and the treatment fluid includes at least one fluid consisting of fresh water, salt water, seawater, brine, an aqueous salt solution, and combinations thereof; and introducing the treatment fluid containing the settling retardant proppant particulates into the subterranean formation. A composite proppant particle includes a proppant substrate and a salt tolerant polymeric layer deposited on the proppant substrate.

The invention provides concentrates for reducing the fluid loss on an oil base well drilling or servicing fluid, the concentrates comprising an oleagineous liquid and (1) a polymer which is solublized in the oleagineous liquid, or (2) a polymer which is solublized in the oleaginous liquid together with an organophilic polyphenolic material which is solublized and/or dispersed in the oleagineous liquid. The method of preparing the concentrate and the method of reducing the fluid loss of an oil base well drilling or servicing fluid utilizing the concentrates is also disclosed. The preferred oil soluble polymer is a styrene-butadiene rubber crumb. The preferred oleagineous liquid is an aromatic-free hydrogenated oil essentially containing only saturated hydrocarbons. The preferred polyphenolic material is a source of humic acid, such as mined lignite.

The invention is a fluid having a kinematic viscosity from 3 to 6 mm.sup.2/s, a flash point of higher than 120 C. and a pour point lower than 40 C., having a boiling point in the range of from 200 C. to 400 C. and a boiling range below 80 C., said fluid comprising more than 95% isoparaffins and less than 3% of naphthens by weight, a biocarbon content of at least 95% by weight, containing less than 100 ppm aromatics by weight. The invention is also a drilling fluid and the use of the fluid to improve the viscosity of the drilling fluid.

The invention is a fluid having a kinematic viscosity from 3 to 6 mm.sup.2/s, a flash point of higher than 120 C. and a pour point lower than 40 C., having a boiling point in the range of from 200 C. to 400 C. and a boiling range below 80 C., said fluid comprising more than 95% isoparaffins and less than 3% of naphthens by weight, a biocarbon content of at least 95% by weight, containing less than 100 ppm aromatics by weight. The invention is also a drilling fluid and the use of the fluid to improve the viscosity of the drilling fluid.

An acid spearhead formulation for mineral scale reduction that includes a sulfuric acid solution having an acidity that is substantially equivalent to a hydrochloric acid solution in an acid spearhead formulation, a sodium citrate compound, where an acid spearhead formulation for mineral scale reduction is formed, the acid spearhead formulation is disposed in a well bore to stabilize mineral scales, the acid spearhead formulation is disposed in the well bore to chelate solubilized calcium in a rock bed of the well bore, and the well bore includes a temporal thermodynamic subsurface barite cycling having a subsurface barite dissolution temporal phase, a subsurface barite transport to fractures temporal phase, a subsurface barite precipitation to fracture temporal phase and a subsurface barite dissolution to fracture space temporal phase, where the acid spearhead formulation for mineral scale reduction reacts with the well bore within the subsurface barite dissolution temporal phase.

An acid spearhead formulation for mineral scale reduction that includes a sulfuric acid solution having an acidity that is substantially equivalent to a hydrochloric acid solution in an acid spearhead formulation, a sodium citrate compound, where an acid spearhead formulation for mineral scale reduction is formed, the acid spearhead formulation is disposed in a well bore to stabilize mineral scales, the acid spearhead formulation is disposed in the well bore to chelate solubilized calcium in a rock bed of the well bore, and the well bore includes a temporal thermodynamic subsurface barite cycling having a subsurface barite dissolution temporal phase, a subsurface barite transport to fractures temporal phase, a subsurface barite precipitation to fracture temporal phase and a subsurface barite dissolution to fracture space temporal phase, where the acid spearhead formulation for mineral scale reduction reacts with the well bore within the subsurface barite dissolution temporal phase.