Abstract: Systems and methods for an automated directional drilling control system including a programmable logic computer (“PLC”) configured with one or more constraint and configured to calculate one or more metrics to automatically adjust drilling parameter setpoints to optimize performance. During performance of a first portion of a slide drill segment, the automated directional drilling control system is configured to maximize a rate of penetration (“ROP”) while maintaining a desired slide score. After one or more conditions are met during the first portion of the slide drill segment, a second portion of the slide drill segment is performed during which the automated directional drilling control system controls either a ROP setpoint parameter or a weight on bit (“WOB”) setpoint parameter while floating the setpoint of the non-controlling parameter at a value above its current average value. The selection of the controlling parameter can be toggled back and forth manually or automatically.

Abstract: A method of cooling wellbore fluids using hydromotor driven air cooler includes flowing wellbore fluid received from a wellhead of a wellbore through a hydromotor to generate torque and rotation. The wellbore fluid exiting the hydromotor is flowed through a heat exchanger network that includes multiple pipes arranged to exchange heat of the wellbore fluid with air flowed past an outer surface of the heat exchanger network. Using the torque and rotation generated by flowing the wellbore fluid through the hydromotor, an air blowing system is operated to generate air. The generated air is directed to flow past the outer surface of the heat exchanger network.

Abstract: A flow control device such as an inflow control valve is disclosed. The flow control device can include an override assembly for non-destructively decoupling an actuator from a flow control component of the flow control device. The flow control device may include an override assembly having a floating shifting member that is arranged within the flow control component, and is linearly displaceable relative to a device body of the flow control device and limitedly linearly displaceable relative to the flow control component. The floating shifting member is linearly displaceable by a shifting tool from a first position where the floating shifting member supports a coupled arrangement of the flow control component and the actuator assembly to a second position where the coupled arrangement of the flow control component and the actuator assembly is unsupported by the floating shifting member and the flow control component is decouplable from the actuator assembly.

Abstract: An apparatus for measuring orientation of a downhole perforating gun system includes a housing or platform for attachment to an interior of a perforating gun, a loading tube, or shape charges for a perforation wireline. The apparatus also includes at least one sensor configured to measure orientation information. The apparatus also includes a communications interface for communicating the measured orientation information to one or more electronic devices communicatively coupled to the apparatus. The apparatus also includes at least one controller configured to cause transmission, using the communications interface, of the orientation information, which corresponds to an orientation of at least one of the perforating gun, the loading tube, or the shape charges, to the one or more electronic devices and initiate a firing sequence of the perforating gun or the shape charges based on a signal received from at least one of the one or more electronic devices.

Abstract: Methods and systems for determining formation properties in subsurface operations include drilling into a formation with a disintegrating device disposed on a downhole string, monitoring dynamics information signals in the downhole string with a dynamics information sensor to obtain dynamics information data, applying a transfer function to the dynamics information data to obtain a dynamics information signature, and analyzing the dynamics information signature to determine a formation property of the formation drilled by the disintegrating device.

Abstract: Embodiments herein generally relate to a method and system for controlling a multi-stage wireline operation in a well, such as during a plug-and-perf operation. The method can comprise: applying a trained initial stage machine learning model to generate predictions for optimized wireline parameters, for a first stage of the wireline operation; operating a wireline control system, to complete the first stage, in accordance with the optimized wireline parameters; applying a trained later stages machine learning model to generate predictions for optimized wireline parameters for each subsequent stage of the wireline operation; and operating the wireline control system, to complete each subsequent stage, in accordance with the optimized wireline parameters generated for that stage by the trained later stages model.

Abstract: There is described a method of using one or more computer processors to control drilling of a wellbore. A current bit depth indicative of a depth of a drill bit being used to drill the wellbore is determined. A compression factor indicative of compression of a drill string to which is attached the drill bit is determined. Based on the current bit depth and the compression factor, the current bit depth is updated. The drilling of the wellbore is controlled based on the updated bit depth.

Abstract: Systems and methods for well flowback monitoring include connecting wells to a test separator and a commingle separator; solitarily coupling a first well to the test separator; measuring output values of the first well via the test separator; coupling the first well to the commingle separator; solitarily coupling a second well to the test separator; measuring output values of the second well with the test separator; taking measurements via the commingle separator of a subset of the wells including the first well and not including the second well; determining an interpolated value of the first well; and using the interpolated value against the measurements of the commingle separator to determine a percentage of a total relating to the first well; each well is rotated through the test separator, the associated output values used to determine associated interpolated values for use with measurements taken via the commingle separator.

Abstract: The invention provides well control system for a riser. The well control system comprises a riser assembly and at least one flow meter. The at least one flow meter is configured to be mounted on the riser.

Abstract: Provided is an automated drilling arrangement comprising a platform, a drill pipe loading assembly arranged on the platform and including a cradle for receiving a drill pipe section, and a handler assembly configured automatically to displace and orientate said drill pipe section from the cradle into an upright position for engagement with a drill string. Arrangement also includes a drilling mast arranged on the platform and comprising a rotary head drive displaceable along the mast to effect drilling, and a drill pipe manipulator configured automatically to receive, align and connect said section of drill pipe from the handler assembly with a drill string of the rotary head drive to facilitate automated drilling by the automated drilling arrangement.

Abstract: Provided are a forward and reverse circulation assembly for core drilling tools and a coring operation method using the same. The forward and reverse circulation assembly includes an outer tube body and an inner receiving body arranged inside it, defining a downward drilling fluid channel between the two, at least one longitudinal fluid acceleration groove is formed on an outer peripheral wall of the inner receiving body. During operation, the drilling fluid is rapidly accelerated as it flows through the acceleration groove, thereby forming a stable negative pressure zone downstream. The negative pressure zone is formed by a reverse circulation channel, which draws fluid and rock cores upwards from a rock core inlet, thereby creating a protective local reverse circulation. A mainstream drilling fluid that does not participate in a reverse circulation continues to flow downwards, thereby forming a forward circulation for chip removal and cooling.

Abstract: There is a downhole tool for use in a drill string including a friction-reducing vibration tool and a bypass control. The vibration tool includes a rotary driving device responsive to fluid flow in the drill string, a valve including a rotary component and a stationary component configured to rotate relative to each other to vary flow through the valve, the rotary component of the valve driven by the rotary driving device, and a bypass passage around or through one or more of the rotary driving device and the valve. The bypass control has a sensor for detecting a stimulus, a bypass actuator for controlling an amount of fluid flow through the bypass passage to activate or deactivate the vibration tool, and a processor in communication with the sensor to control the bypass actuator in response to signals from the sensor.

Abstract: Device (10) for guiding a user to mark a core sample (12) carried by a core tube (14), the device (10) including: a housing (20) mountable relative to the core sample (12) or the core tube (14) and having a marking guide (22) configured to be arranged adjacent the core sample (12) to guide marking; a communications module (26) operable to communicate with the downhole tool (16) to receive data; a user interface (28) operable to convey perceptible feedback to the user; and a processor (30) and associated memory (32). The processor (30) is configured to store data in the memory (32) and determine a marking position based on the data, and operate the user interface (28) to direct the user to cause relative rotation of the marking guide (22) and the core sample (12) so that the marking guide (22) is aligned with the marking position, allowing the user to use the marking guide (22) to mark the core sample (12) at the marking position.

Abstract: A system and method for stall recovery of mud motors may be implemented in a steering control system. The stall recovery system and method may involve automatic detection of a stall of a mud motor during drilling controlled by the steering control system, and may respond to the stall in a rapid and controlled manner to avoid or minimize damage to the mud motor, such as by immediately reducing mud pressure and stopping rotary drilling, if used, faster than a typical human operator could perform. The stall recovery system and method may further take actions to automatically restart drilling.

Abstract: A system for constructing geothermal fields includes a coiled tubing (CT) string, a power source, and an electrically activated bottomhole assembly (BHA) coupled to the CT string. The electrically activated BHA includes an electric motor and a drill bit. The system includes one or more processors and memory. The memory stores instructions that, when executed by the one or more processors, cause the system to deploy the CT string from a surface into a subsurface for drilling a geothermal borehole, and cause the system to, during the drilling, (i) transfer power from the power source to the electric motor via at least a first portion of the CT string and (ii) transfer electrical current from the electric motor to the electric power source via an electrical conductor that is different from the at least the first portion of the CT string.

Abstract: A remote hydraulic system for controlling a valve of a wellhead or frac manifold includes a remote hydraulic skid, control skid, and power supply skid. The remote hydraulic skid includes a hydraulic reservoir, a hydraulic pump, an accumulator, a hydraulic manifold operatively coupled to the accumulator, and a hydraulic valve operatively coupled to the hydraulic manifold. The hydraulic valve is operatively coupled to the valve of the wellhead or frac manifold by a hydraulic line. The control skid includes an interface and is operatively coupled to the remote hydraulic skid. The power supply skid is coupled to the remote hydraulic skid to provide the power necessary to drive the hydraulic pump on the remote hydraulic skid. The remote hydraulic skid is positioned within a hazardous zone around the wellhead, while the control skid and power supply skid are positioned outside of the hazardous zone.

Abstract: Aspects of the disclosed technology provide solutions for facilitating user visualization and control the path of a new wellbore in three-dimensions (3D). This may include displaying visualizations that show a current well path, a well plan, all nearby offset well paths, and well path projections in a manner that may use different projection methods. These visualizations may also include boundaries where a drilling tool should not go, such “No-Go-Zones” may be shown in a 3D spatial visualization. Visualizations may be displayed continuously along the well path, at survey stations, and at user-defined depth positions during a drilling process. Such visualizations may include projections that show an anticipated wellbore path, based on current settings of a drilling control system. Alerts may be triggered to warn users of various issues that may affect a new well being drilled. Systems, methods, and computer-readable media are provided.

Abstract: Threaded connection for exploration and production of a hydrocarbon well, said threaded connection including a pin including an outer pin surface provided with an external thread, a box including an inner box surface provided with an internal thread for mating with the external thread during rotational make-up of the threaded connection, and an anti-rotation device to allow relative rotation between the pin and the box in a make-up rotation direction and prevent relative rotation between the pin and the box in an opposite break-out rotation direction, wherein the pin and the box extend along a longitudinal axis, the anti-rotation device includes a releasable mounted first anti-rotation member which is arranged in a first radial recess provided in one of the outer pin surface and the inner box surface, and a second anti-rotation member provided at the other of the outer pin surface and the inner box surface.

Abstract: An apparatus, system, and method according to which one or more sensors are adapted to detect a presence or absence of fluid entering, or before entering, a lubricator, within the lubricator, exiting, or after exiting, the lubricator, or any combination thereof, while fluid flow is received into the lubricator, the lubricator being operably coupled to a wellhead used in oil and gas operations. Based on the one or more sensors detecting the presence or absence of fluid, additional fluid flow into the lubricator is impeded.

Abstract: A method including deploying a formation testing tool in a borehole, actuating first and second packers of the formation testing tool in the borehole, obtaining measurements in response to actuation of the first and second packers of the formation testing tool in the borehole, and analyzing the measurements to estimate at least a shear modulus (G) of a geological formation surrounding the borehole.