Abstract: A gelled organic-based fluid system and method of forming and using the system. The fluid system is prepared by gelling an organic solvent, a viscoelastic surfactant, and a nitrogen compound having a free electron pair such as urea in an amount effective to both increase viscosity and increase a rate of breaking the viscosity, relative to the gelled system without the nitrogen compound. In a further aspect, the method is used to treat a well penetrating a subterranean formation, for example, in a coiled tubing cleanout, or the like.

Abstract: The present disclosure relates to a combination of therapeutic agents for use in treating a patient a subject suffering from cancer. In addition, the present disclosure also relates to diagnostic assays useful in classification of patients for treatment with one or more therapeutic agents.

Abstract: A method of treating a medium for water fracturing is disclosed, the method comprises: introducing at least one biocide and at least one metabolic inhibitor in the medium, using the medium for water fracturing. In another aspect a method of controlling the post-fracture reservoir souring by the metabolic activities of sulfate reducing bacteria of a well is described: at least one biocide and at least one metabolic inhibitor are introduced in a medium made of water, the medium is used for fracturing the well, and the medium remains in the reservoir to kill and/or inhibit growth of sulfate reducing bacteria.

Abstract: A treatment fluid for treating a subterranean formation penetrated by a wellbore is formed from water, a polyacrylamide in an amount of less than about 0.5% by weight of the fluid for reducing friction of the fluid and a stabilized peroxide breaker. A method of treating a subterranean formation penetrated by a wellbore is carried out by forming treatment fluid comprising water, a polyacrylamide in an amount of less than about 0.5% by weight of the fluid for reducing friction of the fluid and a stabilized peroxide breaker. The treatment fluid is introduced into the formation through the wellbore at a pressure above the fracture pressure of the formation.

Abstract: A method of forming a gelled liquid hydrocarbon treatment fluid is disclosed. The method comprises combining a liquid hydrocarbon, a phosphoric acid ester and a pre-mixed solution comprising water, ferrous ion (Fe2+) and an amine; and forming the gelled liquid hydrocarbon treatment fluid. A method of treating a portion of a subterranean formation is also disclosed and comprises: providing a gelled liquid hydrocarbon treatment fluid, by combining a liquid hydrocarbon, a phosphoric acid ester and a pre-mixed solution comprising water, ferrous ion and an amine, and treating the portion of the subterranean formation with the gelled liquid hydrocarbon treatment fluid.

Abstract: Compositions and methods are given for delayed breaking of viscoelastic surfactant gels inside formation pores, particularly for use in hydraulic fracturing. Breaking inside formation pores is accomplished without mechanical intervention or use of a second fluid. Bromate oxidizing agents are used along with selected breaking activators for the bromate breaking compounds. Useful bromate breaking activators include acid-generating breaking activators, oxidizing sulfur containing breaking activators, and reducing agent breaking activators.

Abstract: A method and apparatus for treating a subterranean formation traversed by a wellbore including forming an emulsion comprising oil, acid, and particulate, wherein the forming the emulsion is prepared on the fly, and introducing the emulsion into a wellbore.

Abstract: A treatment fluid for treating a subterranean formation penetrated by a wellbore is formed from an aqueous medium, a diutan heteropolysaccharide having a tetrasaccharide repeating unit in the polymer backbone and a peroxide breaker. A method of treating a subterranean formation penetrated by a wellbore may be carried out by introducing the treatment fluid into the formation through the wellbore. Breaking aids or catalysts may also be used with the treatment fluid.

Abstract: A method for treating a wellbore or a subterranean formation penetrated by a wellbore includes preparing a gelled oil at the surface, introducing the gelled oil into the wellbore, recovering the gelled oil at the surface, adding a base to the gelled oil to reduce the viscosity, allowing entrained solids to settle out, adding an acid to increase the viscosity, and re-injecting the gelled oil.

Abstract: The current application discloses a method of treating a portion of a subterranean formation comprises providing a treatment fluid comprising a carrier fluid, a non-hydrolyzed polyacrylamide or a nonhydrolyzed non ionic copolymer of acrylamide, and a delaying agent; and treating the subterranean formation.

Abstract: A method of treating a portion of a subterranean formation comprises providing a treatment fluid comprising a carrier fluid, a viscosifying agent, a breaker, and a breaker aid wherein the breaker aid slowly releases a catalyst, wherein the viscosifying agent and the breaker in the carrier fluid have an initial viscosity and the catalyst and the breaker cooperate to decrease the viscosity of the treatment fluid below half of the initial viscosity after at least 30 minutes; and treating the subterranean formation.

Abstract: The invention discloses method of treating a subterranean formation of a well bore, the method comprising: providing a treatment fluid comprising: an aqueous base fluid; a viscosity enhancer; and a viscoelastic surfactant, wherein the enhancer is acid in the aqueous base fluid and co-operates with the viscoelastic surfactant to enhance viscosity compared to viscoelastic surfactant alone in the aqueous base fluid; and introducing the treatment fluid into the well bore.

Abstract: A method of removing a partial amount of water in a well, comprises deploying a differential filter downhole; and performing a downhole operation, wherein the differential filter comprises a swellable polymer that swells after contacting water such that permeability of the differential filter is reduced by removing said partial amount of water, the swellable polymer being non-soluble in the water and/or hydrocarbon and wherein the swellable polymer comprises at least one selected from the group consisting of polyacrylic acid, polyacrylate, polymethacrylic acid, poly maleic anhydride, polyacrylamide, polyvinyl alcohol, latex, polyamide, polyester, and a co-polymer thereof.

Abstract: Disclosed herein is a composition comprising from about 0.1 wt % to about 50 wt % of a plant based product comprising mucilage. Methods of making the composition, a well treatment fluid comprising the composition, and methods of using the composition are also disclosed.

Abstract: A method for treating a subterranean formation is made of steps of providing a composition comprising a carrier fluid, a polymer viscosifying agent, carbon dioxide and a formate salt or formic acid; injecting into a wellbore, the composition; contacting the composition with the subterranean formation, wherein the temperature is above 100 degrees Celsius at this contact; and allowing the composition to treat the subterranean formation.

Abstract: Methods and apparatus for using a fluid within a subterranean formation, including forming a fluid comprising an acrylamide copolymer and a formate salt, and introducing the fluid to the subterranean formation, wherein a temperature of the formation is about 149° C. or warmer. Also, methods and apparatus for a fluid for use within a subterranean formation, including an acrylamide copolymer comprising polyacrylamide, a formate salt comprising potassium, and a crosslinker comprising zirconium. Additionally, methods and apparatus for using a fluid within in a subterranean formation, including forming a fluid comprising an acrylamide copolymer and a formate salt, and introducing proppant into the fluid to form a mixture, introducing the mixture to the subterranean formation, wherein a temperature of the formation is about 149° C. or warmer.

Abstract: A method for treating a subterranean formation is made of steps of providing a composition comprising a carrier fluid, a polymer viscosifying agent, carbon dioxide and a formate salt or formic acid; injecting into a wellbore, the composition; contacting the composition with the subterranean formation, wherein the temperature is above 100 degrees Celsius at this contact; and allowing the composition to treat the subterranean formation.

Abstract: The invention provides a method made of steps of injecting into a wellbore, a composition comprising a solvent, a crosslinkable polymer, a crosslinking agent capable of crosslinking the polymer or forming a polymer, and a gelling accelerator selected from the group consisting of carbon dioxide, polylactic acid, encapsulated acid and latent acid; and allowing viscosity of the composition to increase and form a gel more quickly with the gelling accelerator than without.

Abstract: The invention provides a method made of steps of injecting into a wellbore, a composition comprising a solvent, a surfactant, a foaming gas, a foam enhancer, a crosslinkable polymer, and a crosslinking agent capable of crosslinking the polymer, wherein the foam enhancer increases the foam half-life of the gel composition compared to the gel composition without the foam enhancer; and allowing viscosity of the composition to increase and form a gel.

Abstract: Compositions and methods of treating a subterranean formation including forming a fluid comprising polyacrylamide and calcium carbonate and introducing the fluid to the formation, wherein the viscosity of the fluid is higher than if no calcium carbonate is present. Compositions and methods of treating a subterranean formation penetrated by a well bore including forming a fluid comprising polyacrylamide, calcium carbonate, and crosslinker, and introducing the fluid to the formation, wherein the fluid viscosity at 100 s-1 is increased from 300 cP to 600 cP at a temperature of 93 degC. Compositions and methods of treating a subterranean formation penetrated by a well bore including forming a fluid comprising polyacrylamide and barium carbonate and introducing the fluid to the formation, wherein the viscosity of the fluid is higher than if no barium carbonate is present.