Abstract: A wet-mate connector assembly can include a male portion having a male electrical contact with a valve metal alloy thereon. The wet-mate connector assembly can also include a female portion having a female electrical contact with the valve metal alloy thereon. The female portion can receive the male portion for defining a fluid flow path therein and can form an electrical connection with the male portion. The valve metal alloy can respond to an electrical charge and a downhole fluid by forming an insulation layer on at least one of the male electrical contact or the female electrical contact in a downhole of a well.

Abstract: Described herein are systems and techniques for improving an accuracy of determinations made using data sensed in a wellbore or in a laboratory. Nuclear magnetic resonance (NMR) sensing devices may be used to collect data in a wellbore or lab. NMR sensing devices include a magnet (e.g., a permanent magnet or electromagnet) that provides a magnetic field that aligns the spins of protons in substances near the NMR sensing device. The magnetic field strength provided by the magnet of the NMR sensing device affects the sensitivity of the NMR sensing device and affects frequencies that the NMR sensing device effectively uses when the NMR sensing device operates. Systems and techniques of the present disclosure may measure concentrations of lithium in brine deposits when identifying particular brine deposits that include sufficient lithium concentrations to justify extracting lithium from those particular brine deposits.

Abstract: Provided is a sealing/anchoring tool, a well system and a method for sealing/anchoring within a wellbore. The sealing/anchoring tool, in one aspect, includes a mandrel and a hydraulically deformable member positioned about the mandrel. The sealing/anchoring tool, in accordance with this aspect, further includes a sealing/anchoring element positioned about the hydraulically deformable member, the sealing/anchoring element including a circlet having an inside surface having an inside diameter (di), an outside surface having an outside diameter (do), a width (w), and a wall thickness (t), the circlet comprising an expandable metal configured to expand in response to hydrolysis to chemically deform the circlet from a radially reduced chemical state to a radially enlarged chemical state.

Abstract: A method includes obtaining, by a downhole tool, a first shape of sensor data representing one or more characteristics of a wellbore, comparing, by the downhole tool, the first shape with a set of pre-determined reference shapes stored in a downhole memory to select a pre-determined reference shape that can be imposed on the first shape, calculating one or more delta values between the first shape and the selected pre-determined reference shape, and transmitting, by the downhole tool, the pre-determined reference shape and the delta values to a processor at a surface of the wellbore.

Abstract: A lubricant composition containing a vegetable oil, a degreasing agent, and a non-ionic surfactant. The vegetable oil may be soybean oil, the degreasing agent may be ethyl lactate, and the non-ionic surfactant may comprise sorbitan esters, polyethoxylated sorbitan esters, or a combination thereof. Also provided is a wellbore servicing fluid containing a base fluid and the lubricant composition containing vegetable oil, degreasing agent, and non-ionic surfactant. Methods of introducing the lubricant composition and wellbore servicing fluids containing the lubricant composition into a subterranean zone (e.g., into a wellbore disposed in a subterranean formation) are also provided.

Abstract: Some implementations include an apparatus for washing a downhole tubular. The apparatus may include a head coupled to a rotatable shaft, the head including one or more jets configured to emit fluid to cause the head to rotate on the rotatable shaft and wash the downhole tubular. The apparatus may include one or more brakes coupled with the rotatable shaft and configured to control rotation of the head.

Abstract: Shunt closures with a compensating piston and methods of using the same. An example shunt closure includes a compensator piston disposed between an oil chamber and a piston chamber and configured to translate towards the piston chamber to allow for an increase in the volume of the oil chamber. The shunt closure also includes a piston coupling connected to the compensator piston; wherein a portion of the piston coupling is configured to translate into the piston chamber upon translation of the compensator piston. The shunt closure further includes the piston chamber configured to house a portion of the piston coupling and the oil chamber configured to house an oil. Thermal expansion of the oil applies pressure to the compensator piston. The shunt closure also includes a shunt isolation sleeve coupled to and adjacent to the piston chamber.

Abstract: A method for identifying a cement bond. The method may include disposing an acoustic logging tool into a tubing of a wellbore, wherein the wellbore further comprises casing cemented to a formation by a cement. The method may further include transmitting an acoustic signal into at least part of the tubing and at least part of the casing, measuring one or more signal waves from the at least part of the tubing and the at least part of the casing, and computing an array waveform from the one or more signal waves. Additionally, the method may include applying a beamforming algorithm to the array waveform to form a filtered signal, identifying eccentricity of the tubing within the casing using the filtered signal, and identifying a cement bond between the cement and the casing.

Abstract: A system can be used to connect downhole fiber optic wet mates. The system can include a first completion system and a second completion system. The first completion system can include a stinger sub-system that can include a first energy transfer line coupled to a first wet mate connector. The second completion system can include a deflector sub-system that can include a deflector positioned adjacent to a second wet mate connector that can be coupled with a second energy transfer line. The deflector can be positioned in the second completion system to deflect the stinger sub-system laterally outward to cause the second wet mate connector to couple with the first wet mate connector.

Abstract: A wiper dart can be used in an oil and gas operation. The wiper dart can have at least two different outer diameters. A first outer diameter can be less than a second outer diameter and used to wipe the insides of tool joints of a tubing string. The second outer diameter can be used to wipe the insides of pipe sections of the tubing string that have a larger inner diameter than the tool joints. The single, bi-diameter wiper cup can be used in lieu of two or more current, conical-shaped wiper cups to accomplish the same functionality. The wiper cup can be generally bell shaped and have a variety of first and second outer diameters.

Abstract: Provided is a clutch assembly, a SSSV, and a method for operating an SSSV. The clutch assembly, in one aspect, includes an output coupler housing, an input shaft, and an electromagnet coupled to the input shaft. In at least one aspect, the electromagnet is configured to magnetize the output coupler housing when the electromagnet is energized. The clutch assembly, in one aspect, further includes one or more grooves located in an inner surface of a central opening in the output coupler housing and one or more engagement members located in the outer surface of the input shaft.

Abstract: A method of conducting a pressure test on a piping and manifold system can include isolating a wellhead from fluid flow into a well to form a closed test system, operating at least one and less than all of the plurality of pumping units to pump fluid into and pressurize the closed test system to a first predetermined pressure, upon reaching the first predetermined pressure, halting pumping of fluid by the at least one of the plurality of pumping units, continuing pumping of fluid into the closed test system with at least one pressure test pump to pressurize the manifold and piping to a final predetermined pressure, and upon reaching the final predetermined pressure, halting pumping of the fluid by the at least one pressure test pump.

Abstract: In some implementations, a clamshell packer for use in a wellbore proximate to a subsurface formation comprises an expandable non-elastomeric material and is configured to annularly envelop a non-compliant portion of a tubular in the wellbore, the non-compliant portion between one or more expandable screens.

Abstract: A lower completion assembly includes a tubular comprising an interior passageway defined by an internal surface of the pipe and a port extending between external and internal surfaces of the tubular. The port is defined by a first surface that extends between the internal and external surfaces. The assembly also includes an inflow control device that is coupled to the external surface of the pipe and that comprises a fluid exit that is adjacent the port. The assembly has a first configuration and a second configuration. When in the first configuration a dissolvable plug extends across the fluid exit to fluidically isolate the fluid exit from the interior passageway and a gap is defined adjacent the first surface. When in the second configuration, the dissolvable plug does not extend across the fluid exit and the fluid exit is in fluid communication with the interior passageway.

Abstract: Regulating downhole fluid flow through a plurality of valves to treat wellbore sections while also allowing for production to continue. If it is determined that fluid flow through a valve of a plurality of valves is below a threshold, maintaining fluid flow through the below threshold valve may be maintained while restricting fluid flow through other valves of the plurality. This restriction fluidly isolates a section of a well from other sections of the well. Once isolated, a treatment substance may be injected through the below threshold valve into the isolated section of well. Afterwards, the closed valves may be reopened while restricting fluid flow through the treated section valve for a threshold period of time. the treated section valve may then be reopened after the threshold period of time.

Abstract: A drilling system, assembly, and method may help optimize drilling in a system that involves more than one rotary tool that engages the formation. A rotary tool may be a rotary cutting tool, such as a drill bit or reamer, or some other rotary tool (e.g. stabilizer or rotary steerable tool) that has the potential to drag on the wall of the hole being drilled and take energy away from cutting. In an example, a wellbore or portion thereof is formed by rotating a first rotary cutting tool having a first cutting structure in engagement with one portion of the formation together with a second rotary cutting tool having a second cutting structure in engagement with another portion of the formation. Forces are obtained above and below the second cutting structure. One or more drilling parameter or drill bit design parameter are adjusted in relation to a force differential between the forces above and below the second cutting structure.

Abstract: Provided is an expandable liner hanger assembly and a well system including the same. The expandable liner hanger assembly, in one aspect, includes a radially expandable tubular defining an interior passageway and an exterior surface. The expandable liner hanger assembly, in accordance with this aspect, further includes one or more continuous anchoring ridges extending radially outward from the radially expandable tubular, at least one of the one or more continuous anchoring ridges having a plurality of localized hardened sections placed circumferentially there around, the radially expandable tubular configured to move from an initial state wherein the one or more continuous anchoring ridges are not in contact with a wellbore tubular to an expanded state wherein the one or more continuous anchoring ridges are in gripping engagement with the wellbore tubular.

Abstract: A selective anchor assembly for a downhole completion comprising an anchor sub and a seal assembly with at least one seal unit. The anchor sub comprises at least one button slip within a corresponding piston port that is fluidically coupled to an inner passage of the anchor. The selective anchor is configured to slidingly and sealingly engage a polish bore of a downhole completion. The selective anchor is configured to anchor to a shroud coupled to the polish bore in response to pressure applied to the inner passage of the anchor sub.

Abstract: Systems and methods are provided for performing closed loop, fully autonomous directional drilling using a drilling and steering system. An example method can include receiving, by a surface controller, a well plan for performing directional drilling of a wellbore; determining, based on the well plan, a first drilling instruction for directing a drilling and steering system to drill the wellbore; sending the first drilling instruction to a downhole controller that is coupled to the drilling and steering system; receiving at least one sensor measurement from a downhole sensor that is associated with the drilling and steering system; determining, based on the well plan and the at least one sensor measurement, a second drilling instruction for directing the drilling and steering system to drill the wellbore; and sending the second drilling instruction to the downhole controller that is coupled to the drilling and steering system.

Abstract: Embodiments herein provide a method of actuating a downhole tool, comprising the steps of providing a conductor having a first end positioned at a surface location and a second end positioned at a first downhole location within a wellbore, receiving an electrical signal from the conductor at the first downhole location, transmitting an acoustic signal through the wellbore, starting at the first downhole location and arriving at the second downhole location, receiving the acoustic signal at the second downhole location, moving a spring-forced piston in response to the acoustic signal, and actuating the downhole tool from a first configuration to a second configuration by moving the piston.