Abstract: Methods and systems for preparing slurries for treating subterranean formations are provided herein. The methods may include: combining proppant particulates and a base fluid at a well site to form a slurry; and extracting dust from a mixing tank at a well site in which the slurry is disposed. The systems may include: a first tank containing proppant particulates located at a wellsite; a second tank containing a base fluid located at a well site; at least one mixer operable to receive and mix at least a portion of the proppant particulates from the first tank and at least a portion of the base fluid from the second tank at the well site to form a slurry; at least one mixing tank operable to receive the slurry from the mixer; and at least one dust extractor operable to extract dust from the at least one mixing tank.

Abstract: Methods and systems for preparing slurries for treating subterranean formations are provided herein. The methods may include: combining proppant particulates and a base fluid at a well site to form a slurry; and extracting dust from a mixing tank at a well site in which the slurry is disposed. The systems may include: a first tank containing proppant particulates located at a wellsite; a second tank containing a base fluid located at a well site; at least one mixer operable to receive and mix at least a portion of the proppant particulates from the first tank and at least a portion of the base fluid from the second tank at the well site to form a slurry; at least one mixing tank operable to receive the slurry from the mixer; and at least one dust extractor operable to extract dust from the at least one mixing tank.

Abstract: Methods including preparing a treatment fluid comprising a bulk amount of anhydrous ammonia, wherein the anhydrous ammonia is present in an amount greater than about 10% by weight of a liquid portion of the treatment fluid, and wherein the anhydrous ammonia is in a phase selected from the group consisting of a liquid phase, a gaseous phase, supercritical phase, and any combination thereof; and introducing the treatment fluid into a subterranean formation.

Abstract: Methods comprising preparing a gelled fluid comprising a base fluid, a first gelling agent, and particulates; introducing the gelled fluid into a process stream, the process stream in fluid communication with a subterranean formation; introducing anhydrous ammonia into the gelled fluid at a downstream location in the process stream, thereby forming a particulate-containing treatment fluid; and introducing the particulate-containing treatment fluid into the subterranean formation from the process stream and through the wellhead.

Abstract: A aqueous solution that includes water, from 100,000 to 300,000 ppm of dissolved solids, from 0.5 to 3 gallons per thousand gallons of a water-in-oil emulsion, and an inverting surfactant. The water-in oil emulsion includes an oil phase and an aqueous phase where the oil phase is a continuous phase comprising an inert hydrophobic liquid and the aqueous phase is present as dispersed distinct particles in the oil phase. The aqueous phase contains water, a water soluble polymer, and surfactants. The water soluble polymer includes 30 to 50 weight percent of a non-ionic monomer, 5 to 15 weight percent of a sulfonic acid containing monomer, and 40 to 60 weight percent of a cationic monomer. The water soluble polymer makes up from 10 to 35 weight percent of the water-in-oil emulsion.

Abstract: This present application relates generally to fracture-treatment compositions and methods that provide for a proppant having a first angle of repose, a chemical additive coated on the proppant, wherein the coated proppant has a second angle of repose and the second angle of repose is no more than 10% greater than the first angle of repose.

Abstract: Fracturing methods include introducing a relatively high concentration of a surfactant in an initial portion of one or more fluids used in a fracturing treatment and then cutting or ramping back to a relatively low concentration of the surfactant in the remaining fluid used in the treatment. By using such a method, the volume of surfactant to provide superior treatment can be reduced significantly from the normal recommendations, leading to a high cost savings while still obtaining the desired effect upon cleanup.

Abstract: Methods comprising preparing a gelled fluid comprising a base fluid, a first gelling agent, and particulates; introducing the gelled fluid into a process stream, the process stream in fluid communication with a subterranean formation; introducing anhydrous ammonia into the gelled fluid at a downstream location in the process stream, thereby forming a particulate-containing treatment fluid; and introducing the particulate-containing treatment fluid into the subterranean formation from the process stream and through the wellhead.

Abstract: Methods including preparing a treatment fluid comprising a bulk amount of anhydrous ammonia, wherein the anhydrous ammonia is present in an amount greater than about 10% by weight of a liquid portion of the treatment fluid, and wherein the anhydrous ammonia is in a phase selected from the group consisting of a liquid phase, a gaseous phase, supercritical phase, and any combination thereof; and introducing the treatment fluid into a subterranean formation.

Abstract: Ampholyte polymeric compound that comprises at least one nonionic monomer, at least one sulfonic acid-containing monomer, and at least one cationic monomer may be useful in viscosifying treatment fluids for use in subterranean operations at a concentration of about 0.5 v/v % to about 30 v/v % of the treatment fluid. Such operations may involve introducing the treatment fluid into a wellbore penetrating a subterranean formation optionally at a pressure sufficient to create or extend at least one fracture in the subterranean formation.

Abstract: Ampholyte polymeric compounds that comprise at least one nonionic monomer, at least one sulfonic acid-containing monomer, and at least one cationic monomer may be useful as friction reducing agents in treatment fluids for use in subterranean operations at a concentration of about 0.001 v/v % to about 0.5 v/v % of the treatment fluid. Such operations may involve introducing the treatment fluid into a wellbore penetrating a subterranean formation optionally at a rate and/or a pressure sufficient to create or extend at least one fracture in the subterranean formation.

Abstract: Fracturing methods include introducing a relatively high concentration of a surfactant in an initial portion of one or more fluids used in a fracturing treatment and then cutting or ramping back to a relatively low concentration of the surfactant in the remaining fluid used in the treatment. By using such a method, the volume of surfactant to provide superior treatment can be reduced significantly from the normal recommendations, leading to a high cost savings while still obtaining the desired effect upon cleanup.

Abstract: A wellbore servicing foam comprising a reducible material and a wellbore servicing material, wherein the wellbore servicing material is uniformly dispersed throughout the foam, and wherein the foam has (i) equal to or greater than 5% reticulated structure and (ii) a specific surface area of from about 0.1 m2/g to about 1000 m2/g as determined by pycnometry. A highly expanded, wellbore servicing foam comprising a reducible material and a wellbore servicing material, wherein the wellbore servicing material is uniformly dispersed throughout the foam, wherein the foam has (i) a percentage expansion of from about 5% to about 6200% when compared to the same amount of the same reducible material in the absence of expansion, (ii) a specific surface area of from about 0.1 m2/g to about 1000 m2/g as determined by pycnometry, and (iii) equal to or greater than 5% reticulated structure.

Abstract: A aqueous solution that includes water, from 100,000 to 300,000 ppm of dissolved solids, from 0.5 to 3 gallons per thousand gallons of a water-in-oil emulsion, and an inverting surfactant. The water-in oil emulsion includes an oil phase and an aqueous phase where the oil phase is a continuous phase comprising an inert hydrophobic liquid and the aqueous phase is present as dispersed distinct particles in the oil phase. The aqueous phase contains water, a water soluble polymer, and surfactants. The water soluble polymer includes 30 to 50 weight percent of a non-ionic monomer, 5 to 15 weight percent of a sulfonic acid containing monomer, and 40 to 60 weight percent of a cationic monomer. The water soluble polymer makes up from 10 to 35 weight percent of the water-in-oil emulsion.

Abstract: Ampholyte polymeric compounds that comprise at least one nonionic monomer, at least one sulfonic acid-containing monomer, and at least one cationic monomer may be useful as friction reducing agents in treatment fluids for use in subterranean operations at a concentration of about 0.001 v/v % to about 0.5 v/v % of the treatment fluid. Such operations may involve introducing the treatment fluid into a wellbore penetrating a subterranean formation optionally at a rate and/or a pressure sufficient to create or extend at least one fracture in the subterranean formation.

Abstract: Ampholyte polymeric compound that comprises at least one nonionic monomer, at least one sulfonic acid-containing monomer, and at least one cationic monomer may be useful in viscosifying treatment fluids for use in subterranean operations at a concentration of about 0.5 v/v % to about 30 v/v % of the treatment fluid. Such operations may involve introducing the treatment fluid into a wellbore penetrating a subterranean formation optionally at a pressure sufficient to create or extend at least one fracture in the subterranean formation.

Abstract: A method comprising: providing at least one encaged treatment chemical that comprises a treatment chemical and a polymer carrier; placing the encaged treatment chemical into a portion of a subterranean formation; and allowing the treatment chemical to diffuse out of the encaged treatment chemical and into a portion of the subterranean formation or an area adjacent thereto.

Abstract: Of the many methods provided herein. one method comprises: providing at least a portion of a subterranean formation that comprises a shale; providing a plasticity modification fluid that comprises an aqueous fluid and an alkaline embrittlement modification agent; placing a pack completion assembly neighboring the portion of the subterranean formation; and embrittling at least a portion of the shale to form an embrittled shale portion.

Abstract: Of the many methods provided herein, one method comprises: providing at least one fracture in a subterranean formation that comprises tight gas, a shale, a clay, and/or a coal bed; providing a plasticity modification fluid that comprises an aqueous fluid and an alkaline embrittlement modification agent; placing the plasticity modification fluid into the fracture in the subterranean formation; and embrittling at least one fracture face of the fracture to form an embrittled fracture face.

Abstract: Of the many methods provided herein, one method comprises: providing at least one fracture in a subterranean formation that comprises tight gas, a shale, a clay, and/or a coal bed; providing a plasticity modification fluid that comprises an aqueous fluid and an alkaline embrittlement modification agent; placing the plasticity modification fluid into the fracture in the subterranean formation; and embrittling at least one fracture face of the fracture to form an embrittled fracture face.