Abstract: Optimizing well planning scenarios. At least some of the illustrating embodiments include: receiving, by a computer system, a complex fracture model that estimates fractures in a subsurface target; applying the complex fracture model to a reservoir model that estimates geological features between the subsurface target and earth's surface; and determining an earth surface well site and a well path from the earth surface well site to the subsurface target based on the complex fracture model and the geological in formation, wherein the earth surface well site is offset from the subsurface target.

Abstract: A sand control screen assembly (170) is operably positionable within a wellbore (48). The sand control screen assembly (170) includes a base pipe (172) having at least one opening (176) and an internal flow path (174). A swellable material layer (182) is disposed exteriorly of the base pipe (172). A fluid collection subassembly (184) and a sensor (192) are disposed exteriorly of the swellable material layer (182). The fluid collection subassembly (184) is in fluid communication with the internal flow path (174). A filter medium (188) is disposed in a fluid path between the exterior of the sand control screen assembly (170) and the internal flow path (174). In response to contact with an activating fluid, radial expansion of the swellable material layer (182) causes at least a portion of the fluid collection subassembly (184) and the sensor (192) to be displaced toward a surface of the wellbore (48).

Abstract: Methods are provided that include a method comprising providing a consolidating agent emulsion composition comprising an aqueous fluid, an emulsifying agent, and a consolidating agent; and introducing the consolidating agent emulsion composition into at least a portion of a subterranean formation. In some embodiments, the consolidating agent emulsion composition may be introduced into at least a portion of a propped fracture that comprises proppant particulates and allowed to at least partially consolidate at least a portion of the propped fracture. In some embodiments, the consolidating agent emulsion composition comprises a resin composition. Additional methods are also provided.

Abstract: Methods of reducing the permeability of a subterranean formation to aqueous-based fluids using a water-soluble relative permeability modifier that comprises a reaction product of a hydrophilic compound and a hydrophilic polymer. In some methods the hydrophilic polymer may be selected from the group consisting of: a polyacrylamide, a polyvinylamine, a poly(vinylamine/vinyl alcohol), an alkyl acrylate polymer, and a combination thereof. In other methods the hydrophilic polymer may be selected from the group consisting of: a polyvinylamine; a poly(vinylamine/vinyl alcohol); a cellulose; a chitosan; a polyamide; a polyetheramine; a polyethyleneimine; a polyhydroxyetheramine; a polylysine; a polysulfone; a gum; a starch, and a combination thereof.

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.

Abstract: Methods comprising mixing particulates with a consolidating agent emulsion to form a slurry; creating a foamed slurry by adding a foaming agent and a gas to the slurry; placing the foamed slurry into a portion of a subterranean formation so as to create a particulate pack; and flushing the particulate pack with a postflush fluid. In some embodiments, the consolidating agent emulsion composition comprises a resin composition.

Abstract: A sand control screen assembly (70) is operably positionable within a wellbore (84). The sand control screen assembly (70) includes a base pipe (72) having at least one opening and an internal flow path (74). A swellable material layer (76) is disposed exteriorly of the base pipe (72). A fluid collection subassembly (78) is disposed exteriorly of the swellable material layer (76). A drainage layer (82) is disposed exteriorly of the fluid collection subassembly (78) and the swellable material layer (76). In response to contact with an activating fluid, radial expansion of the swellable material layer (76) causes at least a portion of the fluid collection subassembly (78) and the drainage layer (82) to be displaced toward a surface of the wellbore (84).

Abstract: Provided herein are methods for controlling the migration of particulates within a portion of a subterranean formation that comprise aqueous tackifying treatment fluids, curable resin compositions, and/or noncurable resin compositions.

Abstract: Of the methods provided herein, is a method comprising: providing a clean-up fluid comprising a peroxide-generating compound and an aqueous base fluid; placing the clean-up fluid in a subterranean formation; removing contaminants from at least a portion of the subterranean formation to form a cleaned portion of the formation; providing a consolidation agent; placing the consolidation agent on at least a portion of the cleaned portion of the formation; and allowing the consolidation agent to adhere to at least a plurality of unconsolidated particulates in the cleaned portion of the formation.

Abstract: Consolidation fluids comprising: an aqueous base fluid comprising a hardening agent; an emulsified resin having an aqueous external phase and an organic internal phase; a silane coupling agent; and a surfactant. The consolidation fluid itself may be emulsified and further comprise an emulsifying agent. The consolidation fluid may also be foamed in some cases.

Abstract: Method of treating a subterranean formation comprising providing a consolidation fluid, introducing the resin consolidation fluid into a subterranean formation comprising unconsolidated particulates; and, curing the resin to at least partially consolidate the unconsolidated particulates. The consolidation fluid comprises a resin in emulsified form with an aqueous external phase and an organic internal phase wherein the emulsified resin does not comprise a hardening agent and an aqueous base fluid that further comprises a hardening agent. The consolidation fluid may further comprise an emulsifying agent.

Abstract: Methods of reducing the permeability of a subterranean formation to aqueous-based fluids using a water-soluble relative permeability modifier that comprises a reaction product of a hydrophilic compound and a hydrophilic polymer. In some methods the hydrophilic polymer may be selected from the group consisting of: a polyacrylamide, a polyvinylamine, a poly(vinylamine/vinyl alcohol), an alkyl acrylate polymer, and a combination thereof. In other methods the hydrophilic polymer may be selected from the group consisting of: a polyvinylamine; a poly(vinylamine/vinyl alcohol); a cellulose; a chitosan; a polyamide; a polyetheramine; a polyethyleneimine; a polyhydroxyetheramine; a polylysine; a polysulfone; a gum; a starch, and a combination thereof.

Abstract: Methods including the steps of providing an injection well having unconsolidated particulates in one or more formation intervals along the wellbore that accept injection fluid; providing a consolidating treatment fluid comprising a base fluid and a consolidating agent; introducing the consolidating treatment fluid through the injection well, while the well is under injection, such that the consolidating treatment fluid enters into a portion of a formation interval along the wellbore that accepts injection fluid; and, allowing the consolidating fluid to consolidate formation particulates therein. The methods may be performed such that the percentage of consolidating agent varies over the course of the treatment or the rate of injection varies over the course of the treatment.

Abstract: Methods of controlling fluid loss in a subterranean formation comprising: providing a treatment fluid comprising an aqueous fluid and a fluid loss control additive comprising a water-soluble polymer having hydrophobic or hydrophilic modification; introducing the treatment fluid into an interval of a well bore, the well bore penetrating the subterranean formation; creating one or more perforations in the interval of the well bore, wherein the perforations extend from the well bore and into the subterranean formation; and allowing the treatment fluid to contact a portion of the subterranean formation through the one or more perforations. Methods of a reducing fluid loss from a perforated and/or gravel packed interval of a well bore using a fluid loss control additive comprising a water-soluble polymer having hydrophobic or hydrophilic modification.

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.

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: A well bore in a subterranean formation includes a signaling subsystem communicably coupled to injection tools installed in the well bore. Each injection tool controls a flow of fluid into an interval of the formation based on a state of the injection tool. Stresses in the subterranean formation are altered by creating fractures in the formation. Control signals are sent from the well bore surface through the signaling subsystem to the injection tools to modify the states of one or more of the injection tools. Fluid is injected into the stress-altered subterranean formation through the injection tools to create a fracture network in the subterranean formation. In some implementations, the state of each injection tool can be selectively and repeatedly manipulated based on signals transmitted from the well bore surface. In some implementations, stresses are modified and/or the fracture network is created along a substantial portion and/or the entire length of a horizontal well bore.