Abstract: A matrix stimulation tool includes a cylindrical tube; at least one piston disposed within the cylindrical tube and longitudinally moveable within the cylindrical tube; and at least one hollow tube coupled to the piston, the hollow tube including a distal end disposed within a hole disposed within a wall of the cylindrical tube. Movement of the piston within the cylindrical tube causes movement of the distal end of the at least one hollow tube through the hole.

Abstract: A matrix stimulation tool includes a cylindrical tube; at least one piston disposed within the cylindrical tube and longitudinally moveable within the cylindrical tube; and at least one hollow tube coupled to the piston, the hollow tube including a distal end disposed within a hole disposed within a wall of the cylindrical tube. Movement of the piston within the cylindrical tube causes movement of the distal end of the at least one hollow tube through the hole.

Abstract: A method for monitoring pitting corrosion of a production tubing in a hydrocarbon well under downhole conditions during a production process using a coupon segment, the method comprising the steps of placing the coupon segment in the hydrocarbon well at a placement depth, the coupon segment is exposed to produced fluids and comprises an outer layer, an inner layer, and a hollow middle layer comprises a tracer fluid operable to leak into the produced fluids when pitting corrosion penetrates the outer layer, operating the production process in the hydrocarbon well such that produced fluids flow through the production tubing to a surface of the hydrocarbon well and wherein the produced fluids contact the coupon segment such that pitting corrosion occurs on the coupon segment; obtaining a sample of the produced fluids at the surface of the hydrocarbon well; and measuring an amount of the tracer fluid in the sample.

Abstract: A hydraulic fracturing fluid for use in oilfield applications, where hydraulic fracturing fluid includes a spherical bead-forming liquid composition, the spherical bead-forming liquid composition comprising a micellar forming surfactant, a bead-forming compound, a non-solids bearing liquid solvent, a pH control agent, and a curing agent.

Abstract: A method for monitoring pitting corrosion of a production tubing in a hydrocarbon well under downhole conditions during a production process using a coupon segment, the method comprising the steps of placing the coupon segment in the hydrocarbon well at a placement depth, the coupon segment is exposed to produced fluids and comprises an outer layer, an inner layer, and a hollow middle layer comprises a tracer fluid operable to leak into the produced fluids when pitting corrosion penetrates the outer layer, operating the production process in the hydrocarbon well such that produced fluids flow through the production tubing to a surface of the hydrocarbon well and wherein the produced fluids contact the coupon segment such that pitting corrosion occurs on the coupon segment; obtaining a sample of the produced fluids at the surface of the hydrocarbon well; and measuring an amount of the tracer fluid in the sample.

Abstract: A polymerizable chemical system for consolidating particulates in a subterranean formation including a liquid resin, a curing agent, and a permeability enhancing additive. The chemical system is a homogenous composition that polymerizes to forms a solid upon heating at a temperature greater than 60° C. Consolidating particulates in a subterranean formation includes providing a polymerizable chemical system comprising a liquid resin, a curing agent, and a permeability enhancing additive to a subterranean formation, and polymerizing the polymerizable chemical system to consolidate particulates in the formation to yield a porous consolidated particulates pack.

Abstract: A polymerizable chemical system for consolidating particulates in a subterranean formation including a liquid resin, a curing agent, and a permeability enhancing additive. The chemical system is a homogenous composition that polymerizes to forms a solid upon heating at a temperature greater than 60° C. Consolidating particulates in a subterranean formation includes providing a polymerizable chemical system comprising a liquid resin, a curing agent, and a permeability enhancing additive to a subterranean formation, and polymerizing the polymerizable chemical system to consolidate particulates in the formation to yield a porous consolidated particulates pack.

Abstract: A main bore is drilled with an inclined section extending toward a hydrocarbon bearing earth formation. First and second laterals are drilled from the inclined section downward into the formation at a steeper angles than the inclined section. The first lateral is opened to the formation at a depth greater than a depth of an opening of the second lateral. After completion, well fluid flows through the openings in the first and second laterals into the inclined section of the main bore. In response to an increasing water content in the well fluid flowing up the main bore, the flow of well fluid from the first lateral is restricted.

Abstract: A hydraulic fracturing fluid for use in oilfield applications, where hydraulic fracturing fluid includes a spherical bead-forming liquid composition, the spherical bead-forming liquid composition comprising a micellar forming surfactant, a bead-forming compound, a non-solids bearing liquid solvent, a pH control agent, and a curing agent.

Abstract: A hydraulic fracturing fluid for use in oilfield applications, where hydraulic fracturing fluid includes a spherical bead-forming liquid composition, the spherical bead-forming liquid composition comprising a micellar forming surfactant, a bead-forming compound, a non-solids bearing liquid solvent, a pH control agent, and a curing agent.

Abstract: A system and method of wellbore operations that forms notches into a subterranean formation that circumscribes a wellbore prior to fracturing the formation. The notches extend past the hoop stress regime that surrounds the wellbore so that fractures formed by fracturing are oriented in a designated plane. In one example, a fluid jet is used to form the notches, and which is discharged from a nozzle that rotates about a downhole tool. The nozzle is set in a sleeve that is rotatable about the downhole tool, and pressurized fluid is delivered to a plenum disposed on an inner surface of the sleeve. The nozzle is oriented oblique to a radius of the sleeve, so that the fluid being discharged from the nozzle generates a force that rotates the sleeve.

Abstract: The present application relates to coated silica particles, compositions containing the coated silica particles, and methods for using these compositions in subterranean formations. The coated silica particle includes a cationic species non-covalently bound to an outer surface of the particle. The particle can include a nanoparticle.

Abstract: A main bore is drilled with an inclined section extending toward a hydrocarbon bearing earth formation. First and second laterals are drilled from the inclined section downward into the formation at a steeper angles than the inclined section. The first lateral is opened to the formation at a depth greater than a depth of an opening of the second lateral. After completion, well fluid flows through the openings in the first and second laterals into the inclined section of the main bore. In response to an increasing water content in the well fluid flowing up the main bore, the flow of well fluid from the first lateral is restricted.

Abstract: A jetting gun placed in a wellbore in a formation for penetrating the formation to create perforation tunnels comprising a pressure vessel, the pressure vessel comprising a propellant chamber and a nozzle, the pressure vessel configured to withstand a pressure of the wellbore, the nozzle embedded in the pressure vessel in a predetermined orientation, such that the propellant chamber is in fluid communication with the wellbore. The propellant chamber fully enclosed within the pressure vessel configured to hold a jetting fluid and an energetic material, wherein the energetic material is operable to generate pressure within the propellant chamber when activated such that the pressure projects the jetting fluid through the nozzle to create an impact fluid to penetrate the formation to create the perforation tunnels. The jetting gun also includes a detonating mechanism configured to activate the energetic material to generate the pressure within the propellant chamber.

Abstract: The present application relates to coated silica particles, compositions containing the coated silica particles, and methods for using these compositions in subterranean formations. The coated silica particle includes a cationic species non-covalently bound to an outer surface of the particle. The particle can include a nanoparticle.

Abstract: Materials and methods for protecting electric cables and connectors from corrosive atmospheres and chemicals, particularly in oil wells, are provided herein.

Abstract: Dissolving iron sulfide on the carbon steel tubing to yield chelated iron is achieved by treating the carbon steel tubing with a composition including an iron chelant and an additive. The additive includes at least one of an oxidizing agent and a base. A weight ratio of the iron chelant to the additive is in a weight range of 50:1 to 5:1.

Abstract: A polymerizable chemical system for consolidating particulates in a subterranean formation including a liquid resin, a curing agent, and a permeability enhancing additive. The chemical system is a homogenous composition that polymerizes to forms a solid upon heating at a temperature greater than 60° C. Consolidating particulates in a subterranean formation includes providing a polymerizable chemical system comprising a liquid resin, a curing agent, and a permeability enhancing additive to a subterranean formation, and polymerizing the polymerizable chemical system to consolidate particulates in the formation to yield a porous consolidated particulates pack.

Abstract: Treating carbon steel tubing includes contacting the carbon steel tubing with a first treatment solution including a salt; corroding the carbon steel tubing with the salt to yield a corroded surface on the carbon steel tubing; contacting the corroded surface on the carbon steel tubing with a second treatment solution comprising sulfide ions; and forming an iron sulfide layer on the corroded surface of the carbon steel tubing by chemically bonding the sulfide ions in the second treatment solution with iron in the carbon steel tubing. In some cases, the first treatment solution also includes sulfide ions, and the iron sulfide layer is formed by contacting the carbon steel tubing with the first treatment solution.

Abstract: A hydraulic fracturing fluid for use in oilfield applications, where hydraulic fracturing fluid includes a spherical bead-forming liquid composition, the spherical bead-forming liquid composition comprising a micellar forming surfactant, a bead-forming compound, a non-solids bearing liquid solvent, a pH control agent, and a curing agent.