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 includes performing a chemical process to create a chemical product and an amount of heat, and transferring the heat to a first fluid. The method further includes hydrating a polymer in the first fluid, and adding the chemical product from the chemical process to the first fluid to create a treatment fluid. The method further includes diluting the treatment fluid with respect to at least one constituent of the treatment fluid. The method includes treating a formation of interest in a wellbore with the treatment fluid. The method includes changing a formulation of the treatment fluid during the treating. The method also includes extending the treating beyond a design amount, or ending the treatment before the design amount and preserving some reagents of the chemical process.

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: 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.

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: Internal breakers are given that break fluids viscosified with non-polymeric viscosifiers such as viscoelastic surfactants, inside formation pores. The breakers are polyols, for example natural and synthetic sugars, monoalcohols, and mixtures of the two. The sugars may be ketones and aldehydes. The sugars are also breaker aides for oxidizing agents used as breakers. Methods of using the breakers and breaker aides in oilfield treatment fluids are given.

Abstract: A wellbore treatment fluid is formed from an aqueous medium, a gas component, a viscosifying agent, and a surfactant. The surfactant is represented by the chemical formula: [R—(OCH2CH2)m—Oq—YOn]pX wherein R is a linear alkyl, branched alkyl, alkyl cycloaliphatic, or alkyl aryl group; O is an oxygen atom; Y is either a sulfur or phosphorus atom; m is 1 or more; n is a integer ranging from 1 to 3; p is a integer ranging from 1 to 4; q is a integer ranging from 0 to 1; and X is a cation. The fluid may be used in treating a subterranean formation penetrating by a wellbore by introducing the fluid into the wellbore. The fluid may be used in fracturing a subterranean formation penetrated by a wellbore by introducing the fluid into the formation at a pressure equal to or greater than the fracture initiation pressure.

Abstract: A method of decreasing the viscosity of a gelled organic-based fluid is disclosed. The method comprises combining an organic solvent, a gelling agent, and a metal crosslinker; forming the gelled organic-based fluid; and adding a chelating agent forming a complex with the metal to decrease the viscosity of the gelled organic-based fluid. The chelating agent may be chosen within nitrilotriacetic acid (NTA), citric acid; ascorbic acid, hydroxyethylethylenediaminetriacetic acid (HEDTA) or its salts, ethylenediaminetetraacetic acid (EDTA) or its salts, diethylenetriaminepentaacetic acid (DTPA) or its salts, phosphinopolyacrylate, thioglycolates, or a combination thereof.

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 wellbore treatment fluid is formed from an aqueous medium, a gas component, a viscosifying agent, and a surfactant. The surfactant is represented by the chemical formula: [R—(OCH2CH2)m—Oq—YOn]pX wherein R is a linear alkyl, branched alkyl, alkyl cycloaliphatic, or alkyl aryl group; O is an oxygen atom; Y is either a sulfur or phosphorus atom; m is 1 or more; n is a integer ranging from 1 to 3; p is a integer ranging from 1 to 4; q is a integer ranging from 0 to 1; and X is a cation. The fluid may be used in treating a subterranean formation penetrating by a wellbore by introducing the fluid into the wellbore. The fluid may be used in fracturing a subterranean formation penetrated by a wellbore by introducing the fluid into the formation at a pressure equal to or greater than the fracture initiation pressure.

Abstract: Methods and apparatus for forming a fluid for use within in a subterranean formation including combining a partitioning agent and viscosifying polymer into a fluid, introducing the fluid into the subterranean formation, and recovering at least a portion of the fluid at a uppermost surface of the subterranean formation. Methods and apparatus of forming a fluid for use within in a subterranean formation including combining a partitioning agent and viscosifying polymer into a fluid, introducing the fluid into the subterranean formation at a temperature of about 45° C. or higher, and recovering at least a portion of the fluid at a uppermost surface of the subterranean formation at a temperature of about 45° C. or lower.

Abstract: Embodiments of this invention relate to a composition and a method for tailoring the rheology of a fluid for use in the oil field services industry including forming a fluid comprising a tetrakis(hydroxyalkyl) phosphonium salt and a polymer, and exposing the fluid to a temperature of about 20° C. to about 200° C., wherein a viscosity is observed that is at least about 5 percent different than if no salt were present. Embodiments of this invention also relate to a composition and a method for tailoring the rheology of a fluid for use in the oil field services industry including forming a fluid comprising a tetrakis(hydroxyalkyl) phosphonium salt and diutan and/or guar and/or guar derivatives and/or a combination thereof, and exposing the fluid to a temperature of about 20° C. to about 163° C., wherein a viscosity is observed that is at least about 5 percent lower than if no salt were present.

Abstract: A method for shortening the shear recovery time of cationic, nonionic, anionic, zwitterionic, and amphoteric viscoelastic surfactant fluid systems by adding an effective amount of an amphiphilic polymeric rheology enhancer. The rheology enhancer is a grafted polymer of polydimethylsiloxane, for example polydimethylsiloxanes grafted with ethylene/propylene glycol. The rheology enhancer also increases fluid viscosity and very low rheology enhancer concentration is needed.

Abstract: Apparatus and methods are described herein for detecting pilot signals. An access terminal determines whether each pilot signal in its active set can be tracked. If not, the access terminal adjusts the search window center associated with any untracked pilot to a position that allows tracking In some aspects, a known search window center of a tracked member of a same pilot group may be used.

Abstract: Embodiments of this invention relate to a composition and a method for tailoring the rheology of a fluid for use in the oil field services industry including forming a fluid comprising a tetrakis(hydroxyalkyl) phosphonium salt and a polymer, and exposing the fluid to a temperature of about 20° C. to about 200° C., wherein a viscosity is observed that is at least about 5 percent different than if no salt were present. Embodiments of this invention also relate to a composition and a method for tailoring the rheology of a fluid for use in the oil field services industry including forming a fluid comprising a tetrakis(hydroxyalkyl) phosphonium salt and diutan and/or guar and/or guar derivatives and/or a combination thereof, and exposing the fluid to a temperature of about 20° C. to about 163° C., wherein a viscosity is observed that is at least about 5 percent lower than if no salt were present.

Abstract: The invention provides a method of forming a gelled liquid hydrocarbon treatment fluid, comprising: 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: A method includes performing a chemical process to create a chemical product and an amount of heat, and transferring the heat to a first fluid. The method further includes hydrating a polymer in the first fluid, and adding the chemical product from the chemical process to the first fluid to create a treatment fluid. The method further includes diluting the treatment fluid with respect to at least one constituent of the treatment fluid. The method includes treating a formation of interest in a wellbore with the treatment fluid. The method includes changing a formulation of the treatment fluid during the treating. The method also includes extending the treating beyond a design amount, or ending the treatment before the design amount and preserving some reagents of the chemical process.

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. Oxidizing agents such as air, oxygen, persulfates, bromates, peroxides, and others are used. The break may be accelerated, for example with a free radical propagating species, or retarded, for example with an oxygen scavenger. In certain brines, for example bromide brines, certain zwitterionic viscoelastic fluid systems that can decarboxylate and that require an anion-containing co-surfactant undergo delayed degradation if oxygen is present, for example from fluid preparation or in a foam.

Abstract: The invention provides a well treatment composition comprising: a viscoelastic surfactant or a cementing composition and an environmentally friendly component made of cellulosic matrix with organic acid trapped within. A method is disclosed comprising introducing into a wellbore penetrating a subterranean formation an environmentally friendly component made of cellulosic matrix with organic acid trapped within.

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.