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 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: 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 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: 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: 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: 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 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: 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 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: 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: 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.

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: 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 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 method for acidizing a subterranean formation may include: preparing a water-in-oil emulsion comprising a non-polar phase, a polar phase, an emulsifier an acid, and a drag reducing agent; pumping the water-in-oil emulsion into a wellbore penetrating a subterranean formation above a fracture gradient of the subterranean formation to create or extend at least one fracture in the subterranean formation.

Abstract: A method may include dividing a wellplan into one or more section using a section detection algorithm, receiving a depth measurement of a drill bit or a bottom hole assembly located in a wellbore, utilizing the section detection algorithm and the depth measurement to identify a section of the wellplan from the one or more sections of the wellplan, and identifying a target based at least in part on the identified section. The method may further include determining one or more steering commands based at least in part on the target and a control algorithm and steering the bottom hole assembly to the target using the one or more steering commands.

Abstract: A driveline assembly for use with a well-servicing pump system is disclosed. The driveline assembly comprises a stub shaft attachable to one of a pump or a motor, a flange shaft attachable to the other of the pump or the motor, and a coupling assembly comprising a drive-transfer cylinder and a spring-loaded locking sleeve. In a drivingly-engaged position, rotary drive motion of the motor is transferred to the pump. In an unlocked position, the locking sleeve allows the drive-transfer cylinder to move axially from the drivingly-engaged position where the drive-transfer cylinder connects and transfers rotary drive between the flange shaft and the stub shaft to the drivingly-disengaged position where the drive-transfer sleeve disconnects and allows relative rotation between the flange shaft and the stub shaft. In a locked position, the locking sleeve locks the drive-transfer cylinder in one of either the drivingly-engaged position or the drivingly-disengaged position.

Abstract: A system for regulating a pump down operation may include a controller, a motor drive, a parameter estimation unit and a controller design unit. In examples, the controller may be configured to identify a difference between a downhole tension set-point to an actual downhole tension. The motor drive may be configured to adjust a line speed set point of the motor drive based at least in part on the difference from the controller to create an actual line speed from the motor drive to follow the downhole tension set-point. The parameter estimation unit may be configured to produce a fluid drag coefficient, a friction coefficient, and a line speed delay constant. The controller design unit may be configured to send one or more control gains to the controller based at least in part on the fluid drag coefficient, the friction coefficient, and the line speed delay constant.