Abstract: A bottom hole assembly includes a well logging tool including a plurality of sensors, a vibrator tool coupled to the well logging tool for inserting the well logging tool into a wellbore, and a spoolable composite tube coupled to the vibrator tool, the spoolable composite tube configured to carry power and data cables from the surface to the plurality of sensors in the well logging tool. The well logging tool may further include one or more cameras installed on a distal end of the tool to provide a live visual means to check a well condition. A method for monitoring a well condition includes inserting a bottom hole assembly into a wellbore, and receiving, in real-time, data pertaining to the monitored well condition on the surface.

Abstract: A system and method for isolating a zone in a wellbore having a sand screen including applying hydrogel into an annulus between the sand screen and the geological formation to form a hydrogel packer in the annulus.

Abstract: Lateral wellbores intersecting a main wellbore are located with calipers on a tool. Each caliper includes first and second segments pinned to one another. Ends of each first segment distal from the pinned connections pivotingly attach to the tool. Ends of each second segment distal from the pinned connections couple with shuttles that slide axially along the tool. Biasing means urge the shuttles toward the pivoting connections of the first elongated segments to urge the pinned connections radially outward. When downhole and away from a lateral wellbore, walls of the main wellbore prevent the calipers from projecting into a radial maximum extension. When adjacent a lateral wellbore, calipers facing the lateral wellbore are extendable to a maximum radial extension. Distances between the pinned connections and tool are estimated with sensors; and openings to lateral wellbores are detectable based on the estimated distances. A steering arm optionally steers the tool downhole.

Abstract: Methods for equalizing flow into a wellbore using consolidated material are described. An unconsolidated material and a consolidation fluid are flowed into a wellbore formed in a hydrocarbon-bearing subterranean zone, and a permeability of the subterranean zone to flow fluid through the subterranean zone into the wellbore is non-uniform across an axial length of the wellbore. The unconsolidated material and the consolidation fluid are contacted across at least an axial segment of an inner surface of the wellbore, and the unconsolidated material is bound with the consolidated fluid to form a pack, in which the pack has a permeability that is more uniform than the permeability of the subterranean zone. A flow of fluids from the axial segment of the subterranean zone into the wellbore is controlled through the pack.

Abstract: Methods for equalizing flow into a wellbore using consolidated material are described. An unconsolidated material and a consolidation fluid are flowed into a wellbore formed in a hydrocarbon-bearing subterranean zone, and a permeability of the subterranean zone to flow fluid through the subterranean zone into the wellbore is non-uniform across an axial length of the wellbore. The unconsolidated material and the consolidation fluid are contacted across at least an axial segment of an inner surface of the wellbore, and the unconsolidated material is bound with the consolidated fluid to form a pack, in which the pack has a permeability that is more uniform than the permeability of the subterranean zone. A flow of fluids from the axial segment of the subterranean zone into the wellbore is controlled through the pack.

Abstract: Methods for equalizing flow into a wellbore using consolidated material are described. An unconsolidated material and a consolidation fluid are flowed into a wellbore formed in a hydrocarbon-bearing subterranean zone, and a permeability of the subterranean zone to flow fluid through the subterranean zone into the wellbore is non-uniform across an axial length of the wellbore. The unconsolidated material and the consolidation fluid are contacted across at least an axial segment of an inner surface of the wellbore, and the unconsolidated material is bound with the consolidated fluid to form a pack, in which the pack has a permeability that is more uniform than the permeability of the subterranean zone. A flow of fluids from the axial segment of the subterranean zone into the wellbore is controlled through the pack.

Abstract: A well livening downhole tool for the in-situ production of nitrogen is provided. The well livening downhole tool may produce nitrogen in-situ in a well to lighten the fluid column and lift the well fluids. The well livening downhole tool may include sodium azide and other reactants to produce nitrogen and scavenge other reaction products to produce alkaline silicate and water. The well-livening downhole tool may include multiple modules each having nitrogen-producing reactants and ignition components such that each module may be activated independently to produce nitrogen at different depths. A process for lifting the well fluids using the well livening downhole tool is also provided.

Abstract: A method of increasing a stimulated reservoir volume in a hydrocarbon-bearing formation in fluid communication with a wellbore, the method including drilling a plurality of lateral extensions at varying depths in the formation extending from a vertical wellbore using underbalanced coiled tubing drilling; and injecting an exothermic reaction component into the plurality of lateral extensions to create a plurality of fractures extending outwardly from and between the plurality of lateral extensions to create a multilateral fracture network.

Abstract: Provided is a method and composition for the in-situ generation of synthetic sweet spots in tight-gas formations. The composition can include gas generating compounds, which upon activation, exothermically react to generate heat and gas. The method of using the composition includes injecting the composition into a tight-gas formation such that upon activation, the heat and gas are generated, resulting in the formation of fractures and microfractures within the formation.

Abstract: Provided is a method and composition for the in-situ generation of synthetic sweet spots in tight-gas formations. The composition can include gas generating compounds, which upon activation, exothermically react to generate heat and gas. The method of using the composition includes injecting the composition into a tight-gas formation such that upon activation, the heat and gas are generated, resulting in the formation of fractures and microfractures within the formation.

Abstract: A method of increasing a stimulated reservoir volume in a hydrocarbon-bearing formation in fluid communication with a wellbore, the method including drilling a plurality of lateral extensions at varying depths in the formation extending from a vertical wellbore using underbalanced coiled tubing drilling; and injecting an exothermic reaction component into the plurality of lateral extensions to create a plurality of fractures extending outwardly from and between the plurality of lateral extensions to create a multilateral fracture network.

Abstract: A method of increasing a stimulated reservoir volume in a hydrocarbon-bearing formation in fluid communication with a wellbore, the method including drilling a plurality of lateral extensions at varying depths in the formation extending from a vertical wellbore using underbalanced coiled tubing drilling; and injecting an exothermic reaction component into the plurality of lateral extensions to create a plurality of fractures extending outwardly from and between the plurality of lateral extensions to create a multilateral fracture network.

Abstract: Systems and methods of enhancing oil recovery with an electrochemical apparatus include introducing the electrochemical apparatus into an injection well bore. The electrochemical apparatus includes an anode, a cathode and an interior wall, the interior wall defining an interior that contains both the anode and the cathode. The electrochemical apparatus is operated such that injection water of the injection well bore is introduced into the interior of the electrochemical apparatus. Electrical power is introduced to the electrochemical apparatus such that a portion of the injection water is converted into a product gas, the product gas including hydrogen gas and oxygen gas. The electrochemical apparatus is operated such that the product gas forms product gas bubbles and the product gas bubbles travel into a formation, where the product gas bubbles react with a reservoir hydrocarbon of the formation to form a production fluid that is produced through a production well bore.

Abstract: Methods for equalizing flow into a wellbore using consolidated material are described. An unconsolidated material and a consolidation fluid are flowed into a wellbore formed in a hydrocarbon-bearing subterranean zone, and a permeability of the subterranean zone to flow fluid through the subterranean zone into the wellbore is non-uniform across an axial length of the wellbore. The unconsolidated material and the consolidation fluid are contacted across at least an axial segment of an inner surface of the wellbore, and the unconsolidated material is bound with the consolidated fluid to form a pack, in which the pack has a permeability that is more uniform than the permeability of the subterranean zone. A flow of fluids from the axial segment of the subterranean zone into the wellbore is controlled through the pack.

Abstract: A method of increasing a stimulated reservoir volume in a hydrocarbon-bearing formation in fluid communication with a wellbore, the method including drilling a plurality of lateral extensions at varying depths in the formation extending from a vertical wellbore using underbalanced coiled tubing drilling; and injecting an exothermic reaction component into the plurality of lateral extensions to create a plurality of fractures extending outwardly from and between the plurality of lateral extensions to create a multilateral fracture network.

Abstract: Plasma-pulsed hydraulic fracture system with carbonaceous slurry is described. The system includes a hydraulic fluid pumping unit and a plasma pulsing tool. The pumping unit can pump hydraulic fracturing fluid to a downhole location in a wellbore formed in a hydrocarbon reservoir. A hydraulic fracture is to be initiated at the downhole location. The pumping unit can pump the fracturing fluid at a hydraulic fluid pressure sufficient to initiate and propagate the hydraulic fracture from the downhole location into the hydrocarbon reservoir. The plasma pulsing tool is positioned at the downhole location. The tool can generate and transmit a plasma pulse to the downhole location. The plasma pulse can increase the hydraulic fluid pressure of the hydraulic fracturing fluid.

Abstract: A method of increasing a stimulated reservoir volume in a hydrocarbon-bearing formation in fluid communication with a wellbore, the method including drilling a plurality of lateral extensions at varying depths in the formation extending from a vertical wellbore using underbalanced coiled tubing drilling; and injecting an exothermic reaction component into the plurality of lateral extensions to create a plurality of fractures extending outwardly from and between the plurality of lateral extensions to create a multilateral fracture network.

Abstract: Lateral wellbores intersecting a main wellbore are located with calipers on a tool. Each caliper includes first and second segments pinned to one another. Ends of each first segment distal from the pinned connections pivotingly attach to the tool. Ends of each second segment distal from the pinned connections couple with shuttles that slide axially along the tool. Biasing means urge the shuttles toward the pivoting connections of the first elongated segments to urge the pinned connections radially outward. When downhole and away from a lateral wellbore, walls of the main wellbore prevent the calipers from projecting into a radial maximum extension. When adjacent a lateral wellbore, calipers facing the lateral wellbore are extendable to a maximum radial extension. Distances between the pinned connections and tool are estimated with sensors; and openings to lateral wellbores are detectable based on the estimated distances. A steering arm optionally steers the tool downhole.

Abstract: Embodiments of a method and apparatus for locating lateral wellbores extending from a main wellbore includes a caliper sensing tool having spring actuated calipers extending radially therefrom. Each of the calipers is connected to a sensor, such as a linear variable displacement sensor, that is used to calculate the radial extension distance of the respective caliper. When the tool is inserted through a wellbore and moves past a lateral wellbore opening, the calipers extend into the lateral wellbore opening. The extension, as well as contact with the surfaces of the lateral wellbore, are used to determine the wellbore depth location and azimuthal direction of the lateral wellbore. A deflectable steering arm is operable to be selectively steered into the lateral opening to facilitate access to the lateral wellbore for logging or intervention purposes.

Abstract: A vibrator tool for use in inserting a bottom hole assembly into a wellbore. The vibrator tool includes a substantially cylindrical body, a motor within the substantially cylindrical body, and a non-linear shaft attached to the motor so that the motor turns the non-linear shaft. The non-linear shaft extends outwardly from the motor within the substantially cylindrical body. The vibrator tool further includes a bearing attached to the shaft a predetermined distance from the motor so that the bearing rotates as the non-linear shaft turns. The bearing contacts portions of the inner surface of the cylindrical body as the non-linear shaft turns, thereby vibrating the substantially cylindrical body.