Abstract: A method using a propping fluid comprising a first carrier fluid and a plurality of propping agents and a spacer fluid comprising a second carrier fluid and an expandable filler material. The method introduces the propping fluid into a fracture in a subterranean formation and introduces the spacer fluid into the fracture. Then the expandable filler material is exposed to an expanding agent that causes the expandable filler material to expand and press against the adjacent propping agents.

Abstract: Methods of fracturing a subterranean formation comprising introducing a fracturing fluid into the subterranean formation at a pressure sufficient to create or enhance at least one fracture therein. And providing proppant aggregates themselves comprising proppant particles coated with a binding fluid and having foamed particulates adhered thereto that are suspended in gelled treatment fluid and placed into at least a portion of the fracture so as to form a proppant pack therein.

Abstract: A fluid is provided including: (A) an aqueous phase; and (B) a dimer acid grafted polymer, wherein the dimer acid grafted polymer is at least sparingly soluble in water, wherein the polymer is dispersed, hydrated, or dissolved in the aqueous phase. The fluid can be used, for example, in a method of treating a well, including: (A) forming a fluid comprising a dimer acid grafted polymer, and (B) introducing the fluid into a treatment zone of a well.

Abstract: A fluid is provided including: (A) an aqueous phase; and (B) a dimer acid grafted polymer, wherein the dimer acid grafted polymer is at least sparingly soluble in water, wherein the polymer is dispersed, hydrated, or dissolved in the aqueous phase. The fluid can be used, for example, in a method of treating a well, including: (A) forming a fluid comprising a dimer acid grafted polymer, and (B) introducing the fluid into a treatment zone of a well.

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 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: 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: 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: Planarization methods and microelectronic structures formed therefrom are disclosed. The methods and structures use planarization materials comprising fluorinated compounds or acetoacetylated compounds. The materials are self-leveling and achieve planarization over topography without the use of etching, contact planarization, chemical mechanical polishing, or other conventional planarization techniques.

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: 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: New compositions and methods of using those compositions as protective layers during the production of semiconductor and MEMS devices are provided. The compositions comprise a cycloolefin copolymer dispersed or dissolved in a solvent system, and can be used to form layers that protect a substrate during acid etching and other processing and handling. The protective layer can be photosensitive or non-photosensitive, and can be used with or without a primer layer beneath the protective layer. Preferred primer layers comprise a basic polymer in a solvent system.

Abstract: Methods of treating a subterranean formation including providing a treatment fluid comprising an aqueous base fluid and a friction reducing clay; wherein the friction reducing synthetic clay is a phyllosilicate clay selected from the group consisting of a phyllosilicate smectite group clay; a phyllosilicate serpentine group clay; a phyllosilicate pyrophyllite-talc group clay; a phyllosilicate mica group clay; a phyllosilicate chlorite group clay; and any combinations thereof; and placing the treatment fluid into the subterranean formation.

Abstract: Methods of treating a wellbore in a subterranean formation comprising unconsolidated particulates including providing a treatment fluid comprising a furan-based resin and a stimuli-delayed acid generator; wherein the stimuli-delayed acid generator generates acid upon encountering a wellbore stimulus and wherein at least a portion of the stimuli-delayed acid generator is a liquid; introducing the treatment fluid into the wellbore in the subterranean formation; and stimulating the stimuli-delayed acid generator so as to generate acid and at least partially cure the furan-based resin; wherein the at least partial curing of the furan-based resin at least partially consolidates the unconsolidated particulates.

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.

Abstract: A method of servicing a wellbore in a subterranean formation comprising placing a first wellbore servicing fluid comprising a self-degrading diverter material into the wellbore wherein the self-degrading diverter materials comprises (i) a diverting material and (ii) a degradation accelerator; allowing the self-degrading diverter material to form a diverter plug at a first location in the wellbore or subterranean formation; diverting the flow of a second wellbore servicing fluid to a second location in the wellbore or subterranean formation; and removing the diverter plug, wherein the first and second wellbore servicing fluids may be the same or different.

Abstract: A method of servicing a wellbore in a subterranean formation comprising placing a first wellbore servicing fluid comprising an expanded diverting material into the wellbore allowing the expanded diverting material to form a diverter plug diverting the flow of a second wellbore servicing fluid to a different portion of the wellbore; and removing the diverter plug. A method of servicing a wellbore in a subterranean formation comprising placing a wellbore servicing fluid into the subterranean formation at a first location; plugging the first location with a expanded diverting material such that all or a portion of the wellbore servicing fluid is diverted to a second location in the subterranean formation; placing the wellbore servicing fluid into the subterranean formation at the second location; and allowing the expanded diverting material to degrade to provide a flowpath from the subterranean formation to the wellbore for recovery of resources from the subterranean formation.

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: A method of servicing a wellbore in a subterranean formation comprising placing a first wellbore servicing fluid comprising a self-degrading diverter material into the wellbore wherein the self-degrading diverter materials comprises (i) a diverting material and (ii) a degradation accelerator; allowing the self-degrading diverter material to form a diverter plug at a first location in the wellbore or subterranean formation; diverting the flow of a second wellbore servicing fluid to a second location in the wellbore or subterranean formation; and removing the diverter plug, wherein the first and second wellbore servicing fluids may be the same or different.

Abstract: A method of servicing a wellbore in a subterranean formation comprising: placing a wellbore servicing fluid comprising a proppant-associated foamed material into the subterranean formation via the wellbore wherein the proppant associated foamed material comprises (i) a proppant and (ii) a foamed material and wherein the proppant forms a proppant pack flow channel within the wellbore having a proppant pack flow channel space that is from about 10% to about 60% greater than the proppant pack flow channel space that would be created by the same amount of proppant in the absence of the foamed material. A wellbore servicing fluid comprising a proppant-loaded foamed material comprising a polylactide, a resin-coated sand, and a carrier fluid.