Abstract: Methods including introducing a high-viscosity treatment fluid into a subterranean formation through an opening and applying incrementally increased fracturing rate steps (IIFRSs) to create or enhance a dominate fracture, wherein between each IIFRS a downhole pressure slope over time will increase, decline, or stabilize at a HVTF measured pressure slope. Further evaluating the HVTF measured pressure slope prior to applying a subsequent IIFRS. Performing a particulate sequence transport operation with a first, second, and third low-viscosity treatment fluid (LVTF), wherein the LVTFs collectively create or enhance at least one near-wellbore secondary azimuth fracture and at least one far-field secondary azimuth fracture extending from the dominate fracture, and further propping the dominate fracture, near-wellbore, and far-field secondary azimuth fractures with the particulates.

Abstract: The present disclosure relates to oil and gas well proppant compositions and methods for enhancing the conductivity of a propped fracture formed during a hydraulic fracturing operation. The method introduces a micro-proppant slurry prepared with slickwater containing both a low-density and a conventional micro-proppant during injection of the pad fluid stages to prop the natural and induced microfractures open and then injecting a proppant slurry prepared with slickwater containing low-density proppant and conventional frac sand during proppant slurry stage to prop the dominant fractures or large branches, provide open flow paths to keep them connective with the wellbore.

Abstract: A method may comprise providing a concentrated proppant slurry comprising a slurry fluid and a proppant, preparing a fracturing fluid by combining components comprising the concentrated proppant slurry, a carrier fluid, and a dispersing agent, and introducing the fracturing fluid through a wellbore penetrating a subterranean formation at an injection rate and pressure that is at or above the fracture gradient of the subterranean formation.

Abstract: The present disclosure relates to oil and gas well proppant compositions and methods for enhancing the conductivity of a propped fracture formed during a hydraulic fracturing operation. The method introduces a micro-proppant slurry prepared with slickwater containing both a low-density and a conventional micro-proppant during injection of the pad fluid stages to prop the natural and induced microfractures open and then injecting a proppant slurry prepared with slickwater containing low-density proppant and conventional frac sand during proppant slurry stage to prop the dominant fractures or large branches, provide open flow paths to keep them connective with the wellbore.

Abstract: Compositions, systems, and methods for generating heat and/or gas, for example, to create and/or enhance microfractures in low-permeability formations are provided. In certain embodiments, the methods comprise: providing a treatment fluid that comprises a base fluid and a plurality of microbubbles, wherein the microbubbles each comprise at least an outer shell and a heat- and/or gas-generating chemical within the shell, and have a diameter of about 100 microns or less; and introducing the treatment fluid into at least a portion of a subterranean formation. In some embodiments, the microbubbles may enter one or more microfractures in the subterranean formation and release the heat- and/or gas-generating chemical therein.

Abstract: A method of fracturing a subterranean formation comprising: introducing a fracturing fluid into the subterranean formation to create or enhance a fracture comprising a bottom and top portion; introducing a first treatment fluid into the fracture, wherein after introduction of the first treatment fluid, at least a portion of the first treatment fluid remains in the bottom portion; and simultaneously introducing a second and third treatment fluid into the fracture after introduction of the first treatment fluid, wherein after introduction of the second and third treatment fluids, at least a portion of the second treatment fluid remains in the top portion, wherein after introduction of the first, second, and third treatment fluids, the bottom portion of the fracture has a first permeability and the top portion of the fracture has a second permeability that is greater than the first permeability. The first treatment fluid can create or enhance the fracture.

Abstract: A conductivity cell for simulating micro-proppant flowing through microstructures includes a core wafer holder defining a fluid inlet and a fluid outlet, with a core wafer chamber connecting the fluid inlet in fluid communication with the fluid outlet. A core wafer is installed within the core wafer chamber of the core wafer holder. A pressure piston is biased against the core wafer within the core wafer chamber. A pre-determined channel gap is defined on the core wafer for passage of the fluid through the cell.

Abstract: A method of treating in a subterranean formation including combining an aqueous base fluid, an oil based fluid, a hydrophobic proppant, and a non-hydrophobic proppant to form an immiscible fluid system; and introducing the immiscible fluid system into the subterranean formation. A method of treating includes combining an aqueous base fluid, an oil based fluid, a hydrophobic proppant, and a non-hydrophobic proppant to form an immiscible fluid system; introducing the immiscible fluid system into a fracture in the formation; allowing the immiscible fluid system to separate into at least two separate phases, wherein the oil based fluid and hydrophobic proppant to form proppant aggregates and the aqueous based fluid to act as a spacer fluid surrounding at least a portion of the proppant aggregates; and removing the spacer fluid from the fracture during flowback stage or well production to form proppant-free channels between proppant aggregates.

Abstract: A method of fracturing a subterranean formation is provided. In accordance with the method, a silicate component and a silica precipitation agent are each mixed with the fracturing fluid, and the fracturing fluid is allowed to precipitate silica and form micro-proppant particulates in situ in the microfracture.

Abstract: A variety of systems, methods and compositions are disclosed, including, in one method, a method may comprise pumping a solids containing fluid through a wellbore and into a previously fractured subterranean formation at an injection rate and pressure that is at or above a fracture gradient of the previously fractured subterranean formation, wherein the solids containing fluid comprises a curable resin coated proppant; lowering the injection rate of the solids containing fluid to allow a portion of the curable resin coated proppant to, at least partially, pack and fill one or more voids surrounding a casing disposed in the wellbore; and allowing the portion of the curable resin coated proppant disposed in the one or more voids to cure and form an in situ mechanical screen.

Abstract: A variety of systems, methods, and compositions that relates generally to well site operations and, more particularly, to the capture and recovery of exhaust gas from machinery located and operated at a well site are disclosed. Exhaust gas comprising carbon dioxide is captured, absorbed or reacted with amine sources, and separated for reuse or further processed for use in subterranean formation operations, such as hydraulic fracturing operations.

Abstract: Lightweight micro-proppant suitable to prop open not only near-wellbore microfractures but also far-field microfractures. Some methods of fracturing and propping may comprise first introducing a pad fluid comprising a lightweight micro-proppant into a wellbore penetrating a subterranean formation at a rate and pressure sufficient to create or extend a fracture network in the subterranean formation, wherein the fracture network comprises microfractures. The lightweight micro-proppant comprises a thermoset nanocomposite having a specific gravity of about 0.9 to about 1.4 and having an average diameter of about 0.1 microns to about 50 microns. Then introducing a proppant slurry comprising a macro-proppant into the wellbore penetrating the subterranean formation after introducing the pad fluid forming a proppant pack in the fracture network wherein at least some of the lightweight micro-proppant is located in the microfractures.

Abstract: The present disclosure relates to a method of treating a subterranean formation comprising creating at least one fracture in the subterranean formation, providing a fracturing fluid comprising proppant particulates and a geopolymer composition coated on the proppant particulates, wherein the geopolymer composition comprises an aluminosilicate source, a metal silicate source, and an activator, alternately injecting a spacer fluid and the fracturing fluid into the fracture such that a plurality of proppant aggregates are disposed in the fracture surrounded by the spacer fluid, wherein the proppant aggregates each comprise a portion of the proppant particulates coated with a volume of the geopolymer composition; and allowing the geopolymer composition to set in the formation such that the proppant aggregates gain consolidation strength.

Abstract: Methods of treating subterranean formations, and compositions, systems and methods for performing the methods. A method of treating a subterranean formation, including obtaining or providing a composition that includes an alkenoate ester. The composition also includes at least one of a dialkenyldihydrocarbylammonium halide and an N,Ndihydrocarbyl-substituted alkenamide. The method also includes placing the composition in a subterranean formation downhole. Methods of treating a subterranean formation using a composition including a polymer that is a reaction product of a mixture including an alkenoate ester and at least one of a dialkenyldihydrocarbylammonium halide and an N,N-dihydrocarbyl-substituted alkenamide.

Abstract: Methods for producing a coating on a fracture surface within a subterranean formation are provided. A pad fluid is injected or introduced into a wellbore to form a primary fracture in the subterranean formation and a coating fluid is injected or introduced into the primary fracture to form secondary fractures in the subterranean formation. The coating fluid is flowed into the secondary fractures to expose nucleation surfaces on the secondary fractures to the coating fluid and to produce a resin coating on the nucleation surfaces. Conductive flow paths are formed on and/or within the resin coating. Hydrocarbons can be retrieved from the subterranean formation via the conductive flow paths within the secondary fractures. A viscosity of the pad fluid is greater than a viscosity of the coating fluid and the coating fluid contains or includes a resin, a curing agent, a surfactant, and an organic solvent.

Abstract: Systems and methods for treating fracture faces and/or unconsolidated portions of a subterranean formation are provided. In some embodiments, the methods comprise: providing an aqueous alkali solution; introducing the aqueous alkali solution into at least a portion of a subterranean formation that comprises one or more fractures; contacting an aluminum component and a silicate component with the aqueous alkali solution to form a geopolymer on one or more fracture faces in the fractures; and placing a plurality of proppant particulates in the fractures.

Abstract: Provided are methods and systems for treating a subterranean formation. An example method comprises adding proppant particulates to a fluidized bed granulator; spraying a binding agent on the proppant particulates to at least partially coat the proppant particulates with the binding agent, wherein the coated proppant particulates form proto-aggregates; adding the proto-aggregates to a treatment fluid; and introducing the treatment fluid into a fracture within the subterranean formation.

Abstract: Methods for treating a zone of a subterranean formation penetrated by a wellbore comprising: (A) forming a treatment fluid comprising: (i) an aqueous continuous phase; (ii) a first chemical having: (a) a single epoxy group; and (b) at least one alkoxy group on a silicon atom, wherein the first chemical is water soluble or dissolves with hydrolysis in the aqueous continuous phase; (iii) a second chemical having an amine group, wherein the second chemical is water soluble or dissolves with hydrolysis in the aqueous continuous phase; and (B) introducing the treatment fluid through the wellbore into the zone of the subterranean formation.

Abstract: Systems and methods using electrically controlled propellant to operate equipment in subterranean formations are provided. In some embodiments, the methods comprise: providing a tool assembly that comprises a tool body and an electrically controlled propellant; and placing the tool assembly in at least a portion of a subterranean formation. Electrical current may be applied to at least a portion of the electrically controlled propellant to ignite the portion of the propellant to operate a portion of the tool assembly.

Abstract: Methods of diverting fluid flow, controlling fluid loss, and/or providing zonal isolation in subterranean formations are provided. In some embodiments, the methods comprise: providing a particulate material that comprises an electrically controlled propellant; placing the particulate material in at least a first portion of the subterranean formation; introducing a treatment fluid into the subterranean formation; and allowing the particulate material to at least partially divert the flow of the treatment fluid away from the first portion of the formation.