Abstract: Methods and systems for managing dielectric properties of a pulsed power drilling fluid are provided. In one embodiment, the methods include introducing a drilling fluid into a drilling pipe that extends into a portion of a wellbore; separating the drilling fluid into a solids rich portion and a solids lean portion in the drilling pipe at a location proximate to a pulsed power drill bit; allowing the solids lean portion of the drilling fluid to flow through the pulsed power drill bit; and drilling at least a portion of a wellbore. In some embodiments, the methods and systems include passing the drilling fluid through one or more hydrocyclones. In some embodiments, the methods and systems include passing the drilling fluid through one or more centrifuges.

Abstract: Provided is a downhole rotary slip ring joint, a well system, and a method for accessing a wellbore.

Abstract: The disclosed embodiments include multilateral completion systems and methods to deploy multilateral completion systems. A multilateral completion system includes a main bore completion having an inductive coupler, a lateral completion having an inductive coupler, and a second lateral completion also having an inductive coupler. The multilateral completion system also includes a junction having an inductive coupler, and a second junction having an inductive coupler.

Abstract: An artificial lift system utilizing a downhole impeller-style pump and a motor at the surface. The system includes a centralizer for use with the rod string or tubing. The centralizer centralizes a rotating rod at intermediate points within the tubing string. The centralizer includes a plurality of flexure springs and bearings. A rod string tensioner induces a tension load on the rod string.

Abstract: An acoustic telemetry tool can include string connectors at respective opposite ends of the acoustic telemetry tool, a tubular outer housing extending longitudinally between the connectors, an inner mandrel extending longitudinally between the connectors, an annular chamber formed radially between the outer housing and the inner mandrel, and an acoustic telemetry assembly positioned in the annular chamber. In one acoustic telemetry tool, the outer housing is configured to transmit mechanical loads between the connectors, but the inner mandrel is configured to not transmit mechanical loads between the connectors. In another acoustic telemetry tool, the outer housing and the inner mandrel are configured to transmit mechanical loads between the connectors. In another tool, there may be multiple sets of outer housings, inner mandrels and acoustic telemetry assemblies.

Abstract: A mechanical autonomous pipe cutting system for cutting a pipe in a wellbore includes a locking unit that prevents the system from moving within the pipe when engaged to an inner surface of the pipe, a punching unit that moves a plurality of punching elements radially relative to an axis of the system, and a cutting unit that is designed to sever the pipe. The locking unit, the punching unit, and the cutting unit are attached to a body of the mechanical autonomous pipe cutting system. The body includes a motor that rotates the cutting unit. The mechanical autonomous pipe cutting system further includes a sensor module that detects interactions between the pipe and walls of the wellbore and a control unit in electronic communication with the sensor module, the locking unit, and the punching unit.

Abstract: A system for connecting a perforating gun to at least one other component in a perforating tool string includes a perforating gun that includes a gun housing and a charge carrier received within the gun housing wherein the charge carrier includes a first electrical connector, a tool connected end-to-end with the perforating gun where the tool includes an outer sleeve and a second electrical connector, a solid signal puck arranged with the perforating gun and the tool where the puck forms a pressure resistant barrier between the gun and the tool and wherein the solid signal puck includes a first endface oriented and a second endface and an outer periphery between the endfaces, and wherein the largest outer diameter of the outer periphery is at least 40% of the length between the first endface and the second endface of the puck.

Abstract: A directional drilling assembly includes a downhole piston and an uphole piston. A downhole piston diameter of the downhole piston is smaller than an uphole piston diameter of the uphole piston diameter. This may allow the downhole piston and/or the uphole piston to be located closer to the bit, thereby improving the maximum DLS of the system.

Abstract: A wellbore positioning system includes a first wellbore casing element bearing a first magnetic pattern that encodes first information associated with the wellbore or a drone. The first wellbore casing element is configured for placement down-hole in the wellbore. The first wellbore casing element extends along a central axis and defines an axially oriented passage. Also, the system includes an untethered drone configured for relative movement in the passage of the first wellbore casing element. The drone is configured to detect the first magnetic pattern and determine a position of the drone within the wellbore based on the first information.

Abstract: Methods and apparatus for identifying downhole dynamics in a drilling system are provided. Acceleration-detecting sensors are mounted at multiple locations near to a drill bit, such as at a drill collar. The sensors may be spaced 90° apart along a circumference of the drill collar. The sensors detect acceleration measurements in a plane orthogonal to the drill string's axis of rotation, with respect to a first reference frame that moves with the drill string. The acceleration measurements are received by a processor and processed to determine rotational and revolution positions of the drill string within the wellbore with respect to a static reference frame. Whirl dynamics may, in particular, be determined based on the results in real time.

Abstract: A drilling rig may include a mast and a top drive system. The mast is aligned with a wellbore, the wellbore defining a wellbore centerline. The top drive system may include a top drive. The top drive is movable vertically relative to the mast. The top drive is movable horizontally between a position aligned with the wellbore centerline and a position out of alignment with the wellbore centerline.

Abstract: Systems and method for applying roadway marking materials into a groove(s) in a roadway surface and/or forming a recessed groove(s) in a roadway surface. The systems and methods incorporate a contour sensor that provides real-time information of the marking material and/or groove. Based on the contour information, a marking material applicator can be aligned with a recessed groove in a roadway surface to ensure the marking material is applied within the confines of the groove. Alternatively, such contour information may be acquired during groove formation to ensure depth, tilt and/or bottom surface smoothness of the groove is within predetermined limits.

Abstract: A method of removing wellbore water from a production wellbore includes determining a production flow rate. The method also includes determining a target production flow rate of the production fluid and comparing the production flow rate to a flow rate threshold associated with the target production flow rate. The method also includes determining, based on a result of comparing the production flow rate to the flow rate threshold, that the production flow rate satisfies the threshold. The method also includes activating a fluid moving device fluidly coupled to a wellbore string extending from a terranean surface to the water to inject, into the water, at least one of i) a surfactant, ii) a gas, or iii) a foaming agent, allowing the water and the production fluid to emulsify together and thereby allowing a mixture of water and production fluid to flow to the terranean surface of the wellbore.

Abstract: Dimensions of a tool moving in/out of a well may be measured during well operations. The measured dimensions of the tool may be used to analyze the well operations. Analysis of well operations may include identification of types of well operations being performed at the well, monitoring of the well operations, benchmarking of the well operations, identification of tools being used in the well operations, and/or other analysis of the well operations.

Abstract: Systems for forming or extending a tunnel or shaft within a working surface may include a ram accelerator assembly for accelerating a projectile into geologic material to weaken a region of the geologic material. A cutting tool may then be used to remove the weakened material. A collection assembly may be used to move debris away from the working surface while the projectile and cutting operations are performed to enable generally continuous use of the system. The number of projectiles that are accelerated and the rate at which projectiles are used may be controlled based on characteristics of the geologic material and the rate at which created debris may be removed.

Abstract: In an embodiment, a method of fabricating a polycrystalline diamond compact is disclosed. The method includes sintering a plurality of diamond particles in the presence of a metal-solvent catalyst to form a polycrystalline diamond body; leaching the polycrystalline diamond body to at least partially remove the metal-solvent catalyst therefrom, thereby forming an at least partially leached polycrystalline diamond body; and subjecting an assembly of the at least partially leached polycrystalline diamond body and a cemented carbide substrate to a high-pressure/high-temperature process at a pressure to infiltrate the at least partially leached polycrystalline diamond body with an infiltrant. The pressure of the high-pressure/high-temperature process is less than that employed in the act of sintering of the plurality of diamond particles.

Abstract: An apparatus for downhole connection of well components includes a first tubular component defining a through bore for receiving a second tubular component and a travel joint including an axially moveable inner sleeve and a coupling feature configured for coupling the second tubular component with the inner sleeve when received in the through bore of the first tubular component.

Abstract: A method for mining narrow vein deposit of ore, the narrow vein deposit having a hanging wall and a foot wall, the method comprising: drilling a pilot hole into the narrow vein deposit along a path substantially centrally between the hanging wall and the foot wall to a depth within the vein; following the pilot hole with a larger diameter drilling assembly to fragment the ore into drill cuttings; circulating the drill cuttings to a wellhead; and collecting the drill cuttings for processing to recover the ore therefrom.

Abstract: A gas lift system for lifting oil with a production tube positioned inside a well casing with manifolds in the production tube spaced apart from each other; the system including valve assemblies on the manifolds that each have an open position and a closed position, each of the valve assemblies including a biasing device that biases the valve towards the closed position, where pressurizing each valve assembly with a control fluid generates a force that acts against the biasing force of the biasing device to open the valve, and a means to selectively control the pressure of the control fluid in the control line, where each of the valve assemblies includes different biasing forces in each valve, with a topmost valve having a highest biasing force and each sequentially lower valve having a lower biasing force. A method for using the gas lift system is also included.

Abstract: A downhole tool for coupling an electrical connection in the wellbore comprising a locator sub and a receptacle sub. The locator sub can be conveyed into the wellbore with a workstring. The receptacle sub can be coupled to a lower completion with at least one downhole tool. Workstring manipulation can insert the locator sub into the receptacle sub to provide an electrical connection between a resilient connector on the locator sub and ring connector within the receptacle sub. A fluid source fluidically connected to the electrical connection can flush out trapped wellbore fluids via a fluid pathway. The electrical connection can electrically couple to a control system at surface to the at least one downhole tool.