Abstract: Various embodiments disclosed relate to methods of acidizing subterranean formations and systems for performing the method. In various embodiments, the present invention provides a method of acidizing a subterranean formation including placing an acid-resisting treatment composition including a surface modification agent in a subterranean formation, such that part of the subterranean formation includes an at least partially acid-resistant coating including the acid-resisting treatment composition or a reaction product thereof. The method also includes placing an acidizing composition in the subterranean formation, wherein the acidizing composition at least one of etches and dissolves a part of the subterranean formation substantially free of the acid-resistant coating.

Abstract: Methods including introducing a first high-viscosity treatment fluid (HVTF) into a subterranean formation through an opening and applying incrementally increased fracturing rate steps (IIFRSs) to the first HVTF to create or enhance a dominate fracture, wherein between each IIFRS applied to the first HVTF a downhole pressure slope over time will increase, decline, or stabilize at a first HVTF measured pressure slope. Evaluating the first HVTF measured pressure slope prior to applying a subsequent IIFRS to the first HVTF. Introducing a first low-viscosity treatment fluid (LVTF) through the opening to create or enhance a secondary azimuth fracture extending from the dominate fracture, and introducing a low-viscosity diversion fluid pill (LVDF) pill through the opening to create a fluidic seal therein.

Abstract: Methods of preparing a viscosified treatment fluid comprising a base fluid, a gelling agent, and breaker coated particulates (“BCPs”). The BCPs comprise particulates at least partially coated with a first layer of a stabilization agent followed by a second layer of a breaker. The viscosified treatment fluid may be introduced into a subterranean formation, the breaker activated to reduce a viscosity thereof, and a particulate pack formed in the subterranean formation with the BCPs.

Abstract: A method for directing a proppant in a subterranean formation including providing a first wellbore and a second wellbore, wherein the first wellbore and the second wellbore are disposed about a target area of the subterranean formation; creating a pressure differential between the first wellbore and the second wellbore, such that the pressure of one of the first wellbore or the second wellbore is at a higher pressure and the other of the first wellbore or second wellbore is at a lower pressure; and initiating a fracturing pressure in the higher pressure wellbore by pumping a fracturing fluid in the wellbore, the fracturing pressure sufficient to create a fracture at a predetermined location; whereby the fracturing fluid is drawn from the fractured wellbore toward the lower pressurized wellbore as a result of the pressure differential.

Abstract: Provided are example methods and systems for treating a subterranean formation. An example method comprises alternately pumping a volume of proppant-laden fluid and a volume of spacer fluid into a wellbore penetrating a subterranean formation. The proppant-laden fluid comprises an aqueous fluid and proppant. The spacer fluid comprises an aqueous fluid. At least one of the proppant-laden fluid or the spacer fluid comprises a synthetic clay. The volume of proppant-laden fluid and the volume of spacer fluid may be pumped in any order. The method further comprises repeating the alternately pumping a volume of proppant-laden fluid and a volume of spacer fluid at least once.

Abstract: Method comprising introducing a proppant-free fluid into a wellbore penetrating a subterranean formation to create or enhance one or more fractures; providing binding agent-coated proppant comprising proppant coated with a binding agent; and introducing, in alternating order, a proppant-laden fluid and a spacer fluid into one or more of the fractures. The proppant-laden fluid comprises a base fluid and binding agent-coated proppant, and the spacer fluid comprises a base fluid and degradable ultra-low density particulates. And forming a proppant pack in the fracture, wherein the proppant pack comprises binding agent-coated proppant and degradable ultra-low density particulates; producing hydrocarbons through the proppant pack; wherein the hydrocarbons degrade the degradable ultra-low density particulates to leave behind particulate-free channels.

Abstract: The present disclosure 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. 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: Methods of increasing fracture complexity including introducing a solids-free high viscosity fracturing fluid into a subterranean formation at a pressure above the fracture gradient to create a dominate fracture, and thereafter introducing a low-viscosity pad fluid comprising micro-proppant and meso-proppant into the subterranean formation at a pressure above the fracture gradient to create a secondary branch fracture. The micro-proppant and meso-proppant are placed into the secondary branch fracture. A low-viscosity proppant slurry comprising macro-proppant and micro-proppant is introduced into the subterranean formation at a pressure above the fracture gradient, where the macro-proppant and micro-proppant are introduced into the dominate fracture. Fracture closure stress is applied and the meso-proppant transmits the closure stress to form tertiary branch fractures. The macro-proppant may also transmit the closure stress to form additional secondary branch fractures.

Abstract: Resin coatings are frequently formed in conjunction with performing a subterranean treatment operation. However, poor thermal conductivity and mechanical strength of resin coatings can be problematic in a downhole environment and eventually lead to their breakdown. Methods for enhancing a resin coating in a downhole environment can comprise: introducing a treatment fluid comprising a curable resin and a carbon nanomaterial into a wellbore penetrating a subterranean formation; forming a coating of the curable resin on a surface in the wellbore, the carbon nanomaterial being dispersed throughout the coating; and curing the curable resin to form a cured resin coating.

Abstract: A well treatment fluid is provided. The well treatment fluid comprises a base fluid, and a plurality of degradable metal alloy milling waste particulates. A method of treating a well using the well treatment fluid is also provided.

Abstract: The present invention relates to compositions for treatment of subterranean formations including a curable resin that is amine-curable and a curing agent having a structure including at least one primary amine and at least one secondary amine, and methods of using the same. In various embodiments, the present invention provides a method of treating a subterranean formation. The method can include obtaining or providing a composition including a curable resin that is amine-curable and a curing agent having a structure including at least one primary amine and at least one secondary amine. The method can include placing the composition in a subterranean formation downhole.

Abstract: Methods including introducing a first particulate-free treatment fluid (first PFTF) into a subterranean formation above the fracture gradient. Alternatingly introducing a first particulate-laden treatment fluid (first PLTF) and a second particulate-laden treatment fluid (second PLTF) into the subterranean formation, wherein the first PLTF comprises nano-particles and degradable particles and the second PLTF comprises proppant particulates, and wherein the alternating introduction causes the proppant particulates in the second PLTF to agglomerate into proppant aggregates being surrounded by the first PLTF. Placing the proppant aggregates into at least one fracture, removing the hydraulic pressure to close the at least one fracture, and degrading the degradable particulates to form at least one channel between adjacent proppant aggregates.

Abstract: Methods including providing an actual formation core sample; determining an internal anatomy of at least a portion of the actual formation core sample; determining a virtual 3D model of the external anatomy of the actual formation core sample in a computer readable format, wherein the virtual 3D model of the external anatomy of the actual formation core sample is represented by successive 2D cross-sectional layers; providing a 3D printer; transmitting the virtual 3D model of the external anatomy of the actual formation core sample to the 3D printer; and printing a facsimile core sample using the 3D printer, thereby replicating at least a portion of the external anatomy of the actual formation core sample.

Abstract: Methods for treating a zone of a subterranean formation penetrated by a wellbore comprising: (A) introducing an acidizing fluid into the zone of the subterranean formation; (B) forming a treatment fluid comprising: (i) 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 an aqueous phase; and (ii) a second chemical having an amine group, wherein the second chemical is water soluble or dissolves with hydrolysis in an aqueous phase; and (C) introducing the treatment fluid through the wellbore into the zone of the subterranean formation. In various embodiments, the treatment fluid has a viscosity of less than 5 cP measured at a shear rate of 511 sec?1.

Abstract: Application of biodegradable oils to additive particles to control dusting. A method of reducing an amount of dust produced during transfer of additive particles comprising: treating at least some of the additive particles with one or more biodegradable oils; storing the additive particles; and transferring the additive particles prior to and after storage, wherein biodegradable oil reduces the amount of dust produced during at least one of the transfers of the additive particles.

Abstract: Methods comprising: introducing a micro-proppant treatment fluid into a formation at a rate and pressure sufficient to create or enhance at least one fracture in a first treatment interval, wherein the micro-proppant treatment fluid comprises a first aqueous base fluid, micro-proppant particulates, and a first aqueous-based surface modification agent (“ASMA”); placing the micro-proppant particulates into the at least one fracture; introducing a surface modification treatment fluid into the subterranean formation, wherein the surface modification treatment fluid comprises a second aqueous base fluid and a second ASMA; coating at least a portion of a face of the at least one fracture with the second ASMA; introducing a macro-proppant treatment fluid into the subterranean formation, wherein the macro-proppant treatment fluid comprises a third base fluid and macro-proppant particulates; and placing the macro-proppant particulates into the at least one fracture.

Abstract: Methods including introducing a solids-free high-viscosity fracturing fluid (HVFF) into a subterranean formation to create or enhance at least one dominate fracture, introducing a low-viscosity pad fluid (LVPadF) into the subterranean formation above the fracture gradient pressure to create or enhance at least one first microfracture, wherein the LVPadF comprises micro-proppant, and placing at least a portion of the micro-proppant into the at least one first microfracture. Alternatingly introducing a first low-viscosity proppant fluid (LVPropF) and a high-viscosity crosslinked spacer fluid (HVCSF) into the subterranean formation, wherein the first LVPropF comprises proppant aggregates and the HVCSF comprises a gelling agent, a crosslinking agent, and a breaker, and placing at least a portion of the proppant aggregates into the dominate fracture, where the HVCSF separates clusters of proppant aggregates in the dominate fracture.

Abstract: Compositions, systems, and methods for delivering treatment chemicals, for example, to enhance conductivity in microfractures and/or low-permeability formations, are provided. In one embodiment, the methods comprise: providing a treatment fluid that comprises a base fluid and a plurality of microbubbles, wherein one or more of the microbubbles each comprise at least an outer shell and a treatment 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 treatment chemical therein.

Abstract: Some embodiments herein described relate to method comprising: providing a portion of a subterranean formation comprising unconsolidated particulates; introducing a polymerizable aqueous consolidation composition into the portion of the subterranean formation so as to contact the unconsolidated particulates with the polymerizable aqueous consolidation composition, thereby creating coated, unconsolidated particulates; introducing a substantially solids-free, aqueous flush fluid into the portion of the subterranean formation so as to remove the polymerizable aqueous consolidation composition from interstitial spaces between the coated, unconsolidated particulates; introducing a water-soluble polymerization initiator composition into the portion of the subterranean formation so as to contact the coated, unconsolidated particulates; and consolidating the coated, unconsolidated particulates in the portion of the subterranean formation.

Abstract: Methods including creating or extending a first main fracture with a pad fluid into a subterranean formation, wherein the pad fluid is a high-viscosity fluid; alternatingly introducing a micro-proppant fluid with the pad fluid, wherein the micro-proppant fluid is a low-viscosity fluid comprising micro-sized proppant particulates; creating or extending a first branch fracture extending from the first main fracture with the alternatingly introduced micro-proppant fluid, whereby at least a portion of the micro-sized proppant particulates enter into the first branch fracture and form at least a partial monolayer of micro-sized proppant particulates therein; and introducing a macro-proppant fluid through the first opening at a second flow rate, wherein the macro-proppant fluid is a low-viscosity fluid comprising macro-sized proppant particulates, and whereby at least a portion of the macro-sized proppant particulates enter into the first main fracture and form a proppant pack therein.