Abstract: A control line clamp includes a clamping element for retaining one or more control lines alongside a pipe; a first collar; and a second collar. The clamping element is arranged to be attached to the pipe by positioning the first and second collars around the pipe on opposing sides of the clamping element and moving the first and second collars relatively towards each other in an axial direction.

Abstract: The present invention relates to a wireline cased-hole standoff (WCSO) for installation on a wireline cable of a wellbore logging tool. In embodiments, WCSO may be capable of significantly reducing wireline cable drag in a cased-hole section of a well or wellbore as well as reduce logging tensions and improve force transmission from wellbore surface to logging tool cable head during wireline logging operations. In one embodiment, WCSO comprises two cable insert halves, two opposing WCSO body halves (an upper body and a lower body), and two outer shells (an upper low-friction shell and a lower low-friction shell). Such components may be fastened together onto the wireline cable using screws, bolts, dowel pins, spigots, or any combinations thereof.

Abstract: A variety of methods, systems, and apparatus are disclosed, including, in one embodiment a method of steering a drilling bit including: determining at least one control command to a drilling system, wherein the control command includes a combination of one or more nominal control commands output from a feedforward controller and one or more control command error values output from a feedback controller operating in an error space; and directing the drill bit of the drilling system in the wellbore based on at least the control command to extend the wellbore towards a planned depth-based wellbore trajectory.

Abstract: Systems and methods include a computer-implemented method for providing a photonic sensing system to perform an automated method to characterize displacement of equipment surfaces and monitor changes in real-time. A three-dimensional (3D) point cloud of one or more objects is generated by an analysis and presentation system using light information collected through structured light illumination by an array of structured-light sensors (SLSes) directed toward the one or more objects. Generating the point cloud includes defining points of the 3D point cloud that are relative to reference points on the one or more objects. Real-time contactless 3D surface measurements of the one or more objects are performed using the 3D point cloud. Changes in one or more parts of the one or more objects are determined by the an analysis and presentation system by analyzing the real-time contactless 3D surface measurements.

Abstract: A straddle packer for proppant-laden fracturing fluids has a slotted frac sub with a proppant filtration plug body that excludes proppant in the fracturing fluid from a central passage of the straddle packer downhole from the slotted frac hub. Pressure equalization sleeve filters exclude an entry of debris in a well bore through pressure equalization ports of the straddle packer.

Abstract: The modular managed pressured drilling system provides multiple skids with individual chokes and PRVs on the skids. These skids secure to one another to construct a modular MPD system that provides the proper equipment for the drilling operation. An inlet flow junction and an outlet flow junction are secured to each skid. The flow junctions provide multiple ports to provide different pathways for the drilling fluid through the flow junctions. The flow junctions may direct the fluid through a first choke, a second choke, a pressure relief valve, or a bypass.

Abstract: A downhole turbine may include a stator disposed in a turbine housing, a rotor disposed between the stator and the turbine housing and wherein the rotor includes an outer housing, a gap that separates the stator and the rotor, wherein the gap is oil filled, and one or more blades disposed on the outer housing between the turbine housing and the rotor. The downhole turbine may further include a compressible medium attached to the outer housing between the stator and the outer housing, wherein the compressible medium is separated from the stator by the gap, and one or more magnets attached to an inner surface of the compressible medium, wherein the one or more magnets are separated from the stator by the gap.

Abstract: Techniques described herein relate to a method for identifying downhole conditions during a drilling operation using a vibratory separator. The method includes calibrating a sensor system attached to the vibratory separator by periodically measuring the G-force acting on the vibratory separator functioning under steady-state operating parameters. The method also includes determining the relationship between the G-force acting on the vibratory separator and the flow rate and rate of penetration (ROP) for the drilling operation by measuring the G-force acting on the vibratory separator functioning under different non-steady-state operating parameters.

Abstract: A directional drill vice and associated methods are shown. A directional drill and associated methods are also shown. Examples of directional drill stem configurations include gripping jaws configured with a common jaw pivot. Examples of directional drill stem configurations also include a slot in a vice frame to allow lateral insertion of a drill stem segment.

Abstract: An annulus safety valve assembly for controlling gas flow in a wellbore annulus that includes a passage, a check valve in the passage, and an actuator that is selectively changed between first and second states. The actuator is bi-stable, and requires no energy to remain in either state. When the actuator is put into one of the states, the check valve configuration is changed from one way flow to two way flow. Reconfiguring the check valve into the two way flow configuration vents lift gas from inside the annulus that is below the check valve.

Abstract: A robotic apparatus (1) for performing drill floor operations comprises a support arrangement (2) and at least one manipulator arm (6). The at least one manipulator arm (6) is configured to carry an end effector (11) configured to manipulate one or more of tubing, tools and/or equipment on a drill floor (d) or pipe deck of an oil and gas rig in order to perform a given drill floor operation.

Abstract: A drill string connect tool comprises a housing having first and second sections. The first section has a first recess, and the second section has a second recess. The tool and the first and sections may be in a connected configuration or a disconnected configuration. The connect tool comprises at least one tension member placeable within, and suitable to transfer tensile forces between, the first and second sections when in the connected configuration. A retaining member can retain the tension member within the first and second recesses. The retaining member is selectively dissolvable by a dissolving fluid, while the remaining components of the tool can withstand the dissolving fluid. When exposed to a dissolving fluid, the retaining member dissolves, allowing the tension member to exit the first and second recesses, thereby actuating the tool to the disconnected configuration.

Abstract: Provided here are methods and system to detect an untethered device in a wellhead. The untethered device includes a housing, a transducer, and one or more sensors configured to measure data along the subterranean well. The transducer emits acoustic signals that are received by microphones on the surface of the wellhead. Based on these acoustic signals, the location of the untethered device is determined and appropriate valves may be opened or closed by an operator.

Abstract: A first characteristic of a first discharge of electrodes of a pulse power drilling assembly in a borehole of a subterranean formation is determined. The first characteristic is based on a measurement of the first discharge. A second characteristic of a second discharge of the electrodes is determined. The second discharge occurs after the first discharge, and the second characteristic is based on a measurement of the second discharge. A difference between the first characteristic and the second characteristic is determined. A boundary layer of the subterranean formation is determined based on the difference.

Abstract: For a side pocket mandrel that has a primary flow bore and an offset side pocket, a method for installing a guide sleeve begins with the step of compressing the guide sleeve to reduce an outer diameter of the guide sleeve. The method continues with the step of inserting the guide sleeve into a section of the primary flow bore that has a first inner diameter (D1). The method continues with the steps of allowing the guide sleeve to radially expand such that the outer diameter of the guide sleeve matches the first diameter, pushing the guide sleeve further into the primary flow bore to a guide sleeve section that has a second inner diameter (D2) that is larger than the first inner diameter (D1), and allowing the guide sleeve to radially expand to capture the guide sleeve within the guide sleeve section of the primary flow bore.

Abstract: Aspects of the present disclosure relate to apparatus and methods for regulating flow from a geological formation, and associated components thereof. In one implementation, an apparatus for regulating a multi-phase fluid stream flowing from a subterranean geological formation includes a conduit. The conduit includes an outer wall, a primary flow path for a fluid stream, and a first restriction having a throat portion. A first return path includes a return channel, and the return channel is fluidly connected to the primary flow path through a return inlet and a return outlet. The apparatus includes a gas siphon port formed in the outer wall of the conduit, and a gas siphon path extending from the conduit. The gas siphon path is fluidly connected to the gas siphon port.

Abstract: A well system may include a tubing string positioned downhole in a wellbore defining an annulus between the tubing string and a wellbore. An annular safety valve may be positioned at the surface of the wellbore for controlling a passage of gas through the annular safety valve into the annulus. The annular safety valve may include an inductive coupler that is coupled to a power source at the surface via a power line for powering the annular safety valve.

Abstract: The disclosure relates to a method of evaluating characteristics of an earth formation, comprising deploying a packer assembly in a borehole penetrating an earth formation, the packer assembly comprising an instrumented inflatable packer element including fiber optic sensors; inflating the instrumented inflatable packer elements; detecting, using the fiber optic sensors, events occurring in the earth formation; and transmitting data corresponding to the detected events to a surface processing system. The disclosure also relates to a packer element and a instrumented packer assembly system. The disclosure may enable to derive formation characteristic in several configurations such as a stress test or a hydraulic fracturing configuration.

Abstract: A hydraulic fracturing system has a pump driven by an electrically powered motor. The pump pressurizes fluid which is piped into a wellbore to fracture a subterranean formation. The pump and motor are mounted on a trailer that is hitched to a tractor. A platform assembly is mounted onto the trailer, and which is selectively moveable between deployed and stowed configurations. The platform assembly includes a platform, a lateral rail assembly mounted to the platform, and gates on the forward and aft ends of the platform. The rail assembly and gates define a safety barrier to prevent operations personnel from falling off the platform. In the stowed configuration the platform assembly is anchored in place over wheels on the trailer. In the deployed configuration, the platform assembly provides work surface so that operations personnel can readily access the pump on the trailer.

Abstract: A clamp assembly device for connecting a rotating control device bearing assembly to a main body of a rotating control device. The device includes clamp members configured to retain the bearing assembly in place on the main body, a clamp actuator for driving clamping and unclamping of the clamp members and a lock pin controlled by a lock pin actuator. The lock pin actuator is configured to lock and unlock the clamp assembly device by moving the pin between locked and unlocked positions along an axis substantially parallel with the axis of rotation of the bearing assembly.