Abstract: An isolation system contains an isolation packer and a setting tool. The isolation packer comprises an inner mandrel, an expandable sealing around the inner mandrel, the expandable sealing includes a center sealing element, the outer diameter of the center sealing element in a relaxed state is larger than the outer diameter in a stretched state. The isolation packer further comprises an actuator to stretch the expandable sealing. the setting tool comprises a motor, a set of gear reducer, and an adapter, the adapter comprises a plurality of detents having ability to couple with the actuator when the adapter rotate anticlockwise and to decouple from the connector when the adapter rotate clockwise. The adapter also comprises a plurality of holes to receive shear screws.

Abstract: The present invention provides a high-strength magnesium alloy which can react rapidly with a medium and production processes thereof. In one embodiment, the magnesium alloy comprises gadolinium, yttrium, aluminum, zinc, zirconium, rhenium, silicon, copper, iron, nickel, gallium, indium, beryllium, calcium and magnesium. In another embodiment, the magnesium alloy comprises gadolinium, yttrium, aluminum, zinc, zirconium, rhenium, silicon, copper, iron, nickel, lanthanum, cerium, manganese, gallium, indium, beryllium, calcium and magnesium.

Abstract: Methods of introducing into a subterranean formation a series of treatment fluids comprising one of micro-proppant particulates, micro-degradable particulates, branch-proppant particulates, branch-degradable particulates, main-proppant particulates, and main-degradable particulates and placing the particulates into portions of microfracture(s), branch fracture(s), and main fracture(s) to increase fracture complexity of a fracture network in the subterranean formation.

Abstract: A method of treating a treatment zone of a subterranean formation penetrated by a wellbore of a well, the method including the steps of: (A) forming a treatment fluid comprising: (i) an aqueous phase comprising water having at least 1,000 ppm total dissolved inorganic salts; (ii) a carboxymethyl hydroxyethyl cellulose, wherein: (a) the carboxymethyl hydroxyethyl cellulose has a carboxymethyl degree of substitution is in the range of about 0.3 to about 0.45 per glucopyranose unit in the polymer; and (b) the carboxymethyl hydroxyethyl cellulose has a hydroxyethyl molecular substitution is in the range of about 2.1 to about 2.8 per glucopyranose unit in the polymer; and (iii) a breaker for the carboxymethyl hydroxyethyl cellulose; and (B) introducing the treatment fluid into the treatment zone. In embodiments, the carboxymethyl hydroxyethyl cellulose may or may not be crosslinked.

Abstract: A method of servicing a wellbore in a subterranean formation comprising placing a wellbore servicing fluid comprising a resin-loaded expanded material into a wellbore wherein a resin is released from the resin-loaded expanded material in situ within the wellbore or subterranean formation. A wellbore treatment composition comprising a resin-loaded expanded material wherein the expanded material comprises polylactide and the resin material comprises a high-temperature epoxy-based resin.

Abstract: Embodiments including methods of treating a subterranean formation comprising providing a solvent-based treatment fluid comprising a liquid resin agent, wherein the liquid resin agent comprises the reaction product of a multifunctional electrophilic compound comprising at least two electrophilic reactive groups and at least one nucleophilic compound selected from the group consisting of a dimer acid; a dimer diamine; any derivative thereof; and any combination thereof, and wherein the multifunctional electrophilic compound comprises at least two electrophilic reactive groups; introducing the solvent-based treatment fluid into the subterranean formation; and curing the liquid resin agent.

Abstract: A wellbore servicing composition comprising a base fluid, the base fluid comprising a substantially aqueous fluid, a brine, an emulsion, an invert emulsion, an oleaginous fluid, or combinations thereof, a quantity of template assisted crystallization beads, and a wellbore servicing fluid component, the wellbore servicing fluid component comprising a quantity of proppant, a quantity of gravel, or combinations thereof. A wellbore servicing system comprising a flowpath, the flowpath comprising at least one component of wellbore servicing equipment, and a conduit extending from the at least one component of wellbore servicing equipment to a wellbore, and a wellbore servicing fluid disposed within the flowpath, wherein the wellbore servicing fluid comprises a plurality of template assisted crystallization beads.

Abstract: A method of servicing a wellbore in a subterranean formation comprising preparing a wellbore servicing fluid comprising a particulate material, an aqueous base fluid, an oleaginous fluid, and a macromolecular surfactant, and placing the wellbore servicing fluid in the wellbore and/or subterranean formation to consolidate and/or enhance conductivity of at least a portion of the wellbore and/or subterranean formation. A method of servicing a wellbore in a subterranean formation comprising preparing a wellbore servicing fluid comprising a particulate material, an aqueous base fluid, an oleaginous fluid, and a macromolecular surfactant, wherein the particulate material comprises sand, and the macromolecular surfactant comprises a hydrophobically modified polyethyleneimine, and placing the wellbore servicing fluid in the wellbore and/or subterranean formation to consolidate and/or enhance conductivity of at least a portion of the wellbore and/or subterranean formation.

Abstract: Methods of introducing into a subterranean formation a series of treatment fluids comprising one of micro-proppant particulates, micro-degradable particulates, branch-proppant particulates, branch-degradable particulates, main-proppant particulates, and main-degradable particulates and placing the particulates into portions of microfracture(s), branch fracture(s), and main fracture(s) to increase fracture complexity of a fracture network in the subterranean formation.

Abstract: Proppants for use in subterranean formations and methods for fracturing a subterranean formation penetrated by a wellbore are provided. The proppant material comprises a particulate body having a hydrophobic surface. The method involves introducing a plurality of the particulate bodies into an aqueous fluid to produce a fracturing fluid. Subsequently, the fracturing fluid is introduced into the wellbore at or above a pressure sufficient to create or enhance at least one fracture in the subterranean formation. The proppant material has an increased buoyance factor within the aqueous fluid than a similar proppant material without the hydrophobic surface.

Abstract: A method of use of single component resins to strengthen structural features in subterranean formations includes providing particulates, a carrier fluid, a curable resin and a latent curing agent. The curable resin is not cured by the latent curing agent at room temperature, standard pressure or neutral pH. The particulates are coated with the curable resin and the latent curing agent to create resin-coated particulates. A slurry of resin-coated particulates is created in the carrier fluid, and placed into a portion of a subterranean formation and allowing the latent curing agent to cure the curable resin to form cured, resin-coated particulates.

Abstract: Methods of treating a wellbore in a subterranean formation including providing an aqueous treatment fluid comprising a liquid resin agent, wherein the liquid resin agent comprises the reaction product of a multifunctional electrophilic compound and at least one nucleophilic compound selected from the group consisting of a dimer acid; a dimer amine; any derivative thereof; and any combination thereof, and wherein the multifunctional electrophilic compound comprises least two electrophilic reactive groups; introducing the aqueous treatment fluid into the wellbore in the subterranean formation; and, curing the liquid resin agent.

Abstract: A method of servicing a wellbore in a subterranean formation comprising preparing a wellbore servicing fluid comprising a resin material, a silane coupling agent, and an aqueous base fluid, placing the wellbore servicing fluid in the wellbore and/or subterranean formation, and allowing the wellbore servicing fluid to harden therein.

Abstract: Stabilizers that include hydrophobically modified amine-containing polymers may be utilized as compositions or in methods for controlling particulate migration in a subterranean formation. For example, a method may include providing a treatment fluid that comprises a base fluid and a hydrophobically modified amine-containing polymer (HMAP), the HMAP comprising a plurality of hydrophobic modifications on an amine-containing polymer; introducing the treatment fluid into a wellbore penetrating a subterranean formation, the subterranean formation comprising a plurality of particulates; and allowing the HMAP to coat at least some of the particulates.

Abstract: A method of treating a treatment zone of a subterranean formation penetrated by a wellbore of a well, the method including: (A) introducing into the treatment zone a first particulate, wherein: (i) the first particulate comprises a first degradable material; (ii) the first particulate comprises a first particulate size selected to bridge the pore throats of a first matrix permeability of the treatment zone; and (B) introducing into the treatment zone a second particulate, wherein: (i) the second particulate comprises a second degradable material; (ii) the second particulate comprises a second particulate having a second particulate size selected to bridge the pore throats of a second matrix permeability of the treatment zone; and (C) introducing into the treatment zone a liquid resin, wherein the liquid resin is introduced into the treatment zone.

Abstract: A method of treating a treatment zone of a subterranean formation penetrated by a wellbore of a well, the method including the steps of: (A) forming a treatment fluid comprising: (i) an aqueous phase comprising water having at least 1,000 ppm total dissolved inorganic salts; (ii) a carboxymethyl hydroxyethyl cellulose, wherein: (a) the carboxymethyl hydroxyethyl cellulose has a carboxymethyl degree of substitution is in the range of about 0.3 to about 0.45 per glucopyranose unit in the polymer; and (b) the carboxymethyl hydroxyethyl cellulose has a hydroxyethyl molecular substitution is in the range of about 2.1 to about 2.8 per glucopyranose unit in the polymer; and (iii) a breaker for the carboxymethyl hydroxyethyl cellulose; and (B) introducing the treatment fluid into the treatment zone. In embodiments, the carboxymethyl hydroxyethyl cellulose may or may not be crosslinked.

Abstract: A method of treating a subterranean formation using low-viscosity subterranean treatment fluids with proppants suspended in gel fragments, including providing a fracturing fluid comprising an aqueous base fluid, a proppant, and swellable micro-gel fragments, wherein the fracturing fluid has a low-viscosity in the range of about 0 to about 800 centipoise; allowing the micro-gel fragments to swell to form a matrix, wherein the proppant is suspended in the fracturing fluid; placing the fracturing fluid in a fracture within the subterranean formation; and allowing the matrix to at least partially degrade in the subterranean formation.

Abstract: A method of servicing a wellbore in a subterranean formation comprising preparing a wellbore servicing fluid comprising a particulate material, an aqueous base fluid, an oleaginous fluid, and a macromolecular surfactant, and placing the wellbore servicing fluid in the wellbore and/or subterranean formation to consolidate and/or enhance conductivity of at least a portion of the wellbore and/or subterranean formation. A method of servicing a wellbore in a subterranean formation comprising preparing a wellbore servicing fluid comprising a particulate material, an aqueous base fluid, an oleaginous fluid, and a macromolecular surfactant, wherein the particulate material comprises sand, and the macromolecular surfactant comprises a hydrophobically modified polyethyleneimine, and placing the wellbore servicing fluid in the wellbore and/or subterranean formation to consolidate and/or enhance conductivity of at least a portion of the wellbore and/or subterranean formation.

Abstract: The present invention relates to compositions including a particulate bridging agent and fibers, and methods of treating a subterranean formation with the same. In various embodiments, the present invention provides a method of treating a subterranean formation that includes obtaining or providing a composition including a particulate bridging agent and fibers. The method includes placing the composition in a subterranean formation. The method includes forming within the formation a bridging agent-fiber diverter. The bridging agent-fiber diverter is formed from the composition including the bridging agent and the fibers.

Abstract: Embodiments herein include a method comprising proving a treatment fluid comprising an activator and providing gas-forming particulates comprising coating particulates with a binding agent, wherein the binding agent holds a gas-generating chemical onto the particulates. The gas-forming particulates are suspended in the treatment fluid and the treatment fluid comprising the gas-forming particulates is introduced into a subterranean formation. The gas-generating chemical and the activator then react to generate gas-formed particulates.