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: 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: 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 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: 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: 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: 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: 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 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: Disclosed herein are embodiments of systems and methods of actuating a downhole tool, having the steps of providing a conductor having a first end positioned at a surface location and a second end positioned at a downhole location, cycling the wellbore through varying pressures of well fluids, moving a balance piston with the various pressures of well fluids to build pressure within a hydraulic boost assembly, transmitting an electrical signal through from above the wellbore, through the conductor, and arriving at the downhole location, receiving the signal at the downhole location, and utilizing the pressure within the hydraulic boost assembly to transition the downhole tool from a first configuration to a second configuration in response to the signal. In some embodiments, a hydraulic boost assembly may build pressure from a cycling of well fluid pressures for later use by the system.

Abstract: A method which may comprise disposing a bottom hole assembly (BHA) into a wellbore, wherein the BHA comprises a measurement assembly configured to record one or more measurements. The method may further comprise identifying one or more operating depths; forming a telemetry table based at least on one or more operating depths; acquiring a pseudo log by converting one or more measurements into telemetry values with the telemetry table and back to scientific values with the telemetry table; comparing the pseudo log to the one or more measurements to form a comparison; and publishing the telemetry table based at least in part on the comparison.

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.

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 include a protruding ring located circumferentially around the wiper cup at the first outer diameter. A plurality of buttons or splines can be spaced apart around the wiper cup at the second outer diameter.

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: A system for protecting a bond line may comprise a downhole tool and a rubber material bonded to the downhole tool to form the bond line. The downhole tool may further include a barrier configured to be applied to the rubber material and the ridged substrate to encapsulate the bond line. A method for protecting a bond line may comprise attaching at least a portion of a rubber to a downhole tool to form the bond line and applying a barrier to the rubber material and the downhole tool to encapsulate the bond line.

Abstract: Systems and methods are provided for using sequential residual symbolic regression for petrophysical modeling. An example method can include receiving training data for modeling one or more petrophysical parameters based on reservoir formation data; performing symbolic regression using the training data to obtain a first set of symbolic regression models; determining a first residual based on the training data and a first symbolic regression model from the first set of symbolic regression models; performing symbolic regression using the first residual to obtain a second set of symbolic regression models; and updating the first symbolic regression model based on a second symbolic regression model from the second set of symbolic regression models to yield a first revised symbolic regression model.

Abstract: A method comprising: disposing a tool into a borehole, wherein the tool comprises: one or more guard electrodes configured to transmit a current into at least a formation surrounding the borehole; and one or more monitor electrodes configured to obtain one or more measurements from at least the formation surrounding the borehole. The method may be further configured to perform a first and second inversion on the one or more measurements to form a first inversion set; forming a misfit of the first inversion and a misfit of the second inversion based at least on the first inversion set and second inversion set; determining a weighting inversion coefficient based at least on the misfit of the first inversion and the misfit of the second inversion; and combining the first invasion set, the second invasion set, and/or weighting inversion coefficient to form one or more inversion products.

Abstract: Some embodiments 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 a 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 a downhole tool from a first configuration to a second configuration by moving the spring-forced piston with force generator by a spring in combination with an atmospheric chamber.

Abstract: Described herein are systems and techniques for improving accuracies of determinations made using a nuclear magnetic resonance (NMR) sensing device when the NRM sensing device collects data in a wellbore. In certain instances, determinations made from NMR measurement data may not correspond to measurements made by other types of sensing equipment. For example, determinations of pore sizes made from evaluating sets of capillary pressure data may not correspond to determinations made from data sensed during an NMR test. Since the accuracy of determinations regarding wellbore petrophysical parameters made from data sensed by sensing equipment can affect the efficiency and profitability of a wellbore operation, and since NMR sensing devices are more deployable in a wellbore than other forms of test equipment, systems and techniques of the present disclosure are directed to improving the accuracy of petrophysical parameters determinations made from data sensed by NMR sensing devices.