Abstract: A pressure pulse system includes a stator, a rotor rotatably positioned in the stator, and a valve assembly configured to induce a pressure pulse in response to rotation of the rotor within the stator, wherein the valve assembly includes a first valve plate coupled to one of the stator and the rotor and including a flow passage, and a second valve plate coupled to the other of the stator or the rotor to which the first valve plate is not coupled and comprising a first flow passage and a second flow passage that is spaced from the first flow passage, wherein the valve assembly provides a first flowpath and a second flowpath between the flow passage of the first valve plate and the second flow passage of the second valve plate.

Abstract: Systems and methods for landing a tubing hanger in a wellhead and then orienting a tree (or spool, or flowline connection body) relative to the tubing hanger while landing the tree on the wellhead are provided. This alignment is accomplished without the use of either a tubing spool or a BOP stack with an orientation pin. The tubing hanger alignment devices may be used to orientate the tree as the tree is landed so that the couplings and stabs between the tree and the tubing hanger line up with each other just at the moment of landing.

Abstract: Systems and methods for coupling subsea tubular members together are provided. An apparatus may be used to properly orient and/or provide communication between a first subsea tubular member that is being landed on a second subsea tubular member. An apparatus for coupling subsea tubular members may include an alignment sub and a corresponding alignment member. The alignment sub includes: a generally cylindrical body having one or more fluid, electric, or fiber optic lines extending therethrough, one or more couplings coupled to at least one end of the alignment sub, and an orientation profile disposed on a surface of the alignment sub. The alignment member has a profile designed to interface with the orientation profile of the alignment sub. One of the alignment sub and the alignment member remains stationary while the other rotates relative to the stationary structure.

Abstract: A horizontal directional drilling machine includes a drill string rotational drive unit having an output member configured to connect with and selectively drive rotation of a drill string, the rotational drive unit including a hydraulic motor. A hydraulic circuit has a configuration that puts the motor in a drive mode to apply torque and a second configuration that puts the motor in a freewheel mode disabled from applying torque. The hydraulic circuit includes a first fluid flow path for connecting the hydraulic motor through a first rotary ball valve to one of an inlet side and an outlet side of a drive pump, and a second fluid flow path for selectively connecting the hydraulic motor through a second rotary ball valve to the other side of the drive pump. In the first configuration, there is no pressure drop across the first and second rotary ball valves.

Abstract: A rotor bearing system configured to operatively couple a progressing cavity machine to an external device can comprise a housing including an inner surface defining a first bore extending through the housing along a central axis, a first bearing arranged on the inner surface, and a shaft member including an outer surface extending between a proximal portion and a distal portion of the shaft member and a second bearing arranged on the outer surface, the second bearing the second bearing configured to contact the first bearing to limit eccentric motion of the driveshaft of the external device and the rotor head of the progressing cavity machine relative to a stator of the progressing cavity machine during rotation of the rotor head, the shaft member, and the driveshaft.

Abstract: The hydraulic rotary-percussive hammer drill includes a fluid injection portion including a fluid feed-in inlet and an annular inner groove fluidly connected to the fluid feed-in inlet; a shank including a fluid injection conduit fluidly connected to the annular inner groove; front and rear main sealing gaskets disposed on either side of the annular inner groove and configured to cooperate with a first shank portion of the shank; a rear backup sealing gasket located at the rear of the rear main sealing gasket and configured to cooperate with a second shank portion of the shank; a leakage passage defined between the shank and the fluid injection portion; pressure drop generation means configured to generate pressure drops in the leakage passage when a leakage flow flows in the leakage passage.

Abstract: A tool, system and associated methodorient core samples extracted during borehole drilling intended to be coupled to a core barrel and/or to the cable of a head assembly, which at least include electronic processing means provided with at least one processing unit and orthogonally coupled triaxial accelerometers communicated with the processing unit, configured to record data on the movement and/or instantaneous vibration of the tool, which further includes orthogonally coupled micromechanical gyroscopes, configured to rotate relative to an axis of rotation of the tool and transmit the orientation data to the processing unit, wherein the processing unit is configured to, from the data of the set of triaxial accelerometers and the set of micromechanical gyroscopes, calculate the orientation of the core sample with respect to true north and the trajectory of the drilled borehole.

Abstract: An integrated data recorder may be positioned within a slot in a tool. The integrated data recorder includes a sensor package that includes one or more drilling dynamics sensors, a processor in data communication with the one or more drilling dynamics sensors, a memory module in data communication with the one or more drilling dynamics sensors, a wireless communications module in data communication with the processor, and an electrical energy source in electrical communication with the memory module, the one or more drilling dynamics sensors, and the processor.

Abstract: Systems and methods for predicting drill bit wearing state using drilling parameters and formation properties are disclosed. The methods include, for each of a plurality of past bit runs, obtaining a measured rock property value and a measured drilling variable value for the past bit run, and obtaining a measured dull grade for a drill bit used for the past bit run. The methods also include determining parameters of a functional relationship between the measured dull grade, the bit run time, the measured rock property value, and the measured drilling variable value, and predicting a predicted dull grade for a future bit run using a new drill bit. The methods further include replacing the new drill bit with a replacement drill bit at a time based, at least in part, on the predicted dull grade.

Abstract: A method may comprise forming a data matrix, extracting chromatographs of a mud filtrate and a formation fluid, extracting concentration profiles of the mud filtrate and the formation fluid, and decomposing a data set on an information handling machine using a bilinear model. A system may comprise a downhole fluid sampling tool and an information handling tool. The downhole fluid sampling tool may comprise one or more multi-chamber sections, one or more fluid module sections, one or more gas chromatographers, wherein the one or more gas chromatographers are disposed in the one or more fluid module sections, and an information handling system.

Abstract: Some systems and methods for determining depths of subterranean formation layer tops while drilling through the subterranean formation include a drill bit, a drill rig, a microphone, a depth sensor, and a processor. While drilling the through the subterranean formation, the processor receives a measured sound from the microphone and a measured drill bit depth from the depth sensor, normalizes the measured sound across all measured drill bit depths, determines frequency information of the normalized sound for each depth of the plurality of depths, determines frequency spectrums of the normalized sound for one or more depths of the plurality of depths, transforms the frequency spectrums into a depth spectrum, and determines the depths of subterranean formation layer tops based on the depth spectrum.

Abstract: An indexing mechanism includes a piston. An indexing sleeve encases a portion of the piston. The indexing mechanism is longitudinally fixed to the piston, and is rotatable relative to the piston. The indexing sleeve includes an indexing track. An indexing ring surrounds less than an entirety of the indexing sleeve. The indexing ring is rotatable relative to the piston. The indexing ring includes an indexing pin that extends into the indexing track.

Abstract: An untethered device includes a housing, a magnetic actuator that is coupled to the housing, and a buoyancy device. The buoyancy device includes an attachment plate that is securable to the magnetic actuator, a degradable ballast weight that is coupled to the attachment plate, and a buoyancy-enhancing feature that is positioned adjacent to the attachment plate.

Abstract: A coiled tubing injector for running coiled tubing into and out of a well in a hydrocarbon-bearing formation, includes a coiled tubing injector head including a base and a gripping mechanism configured to grip the coiled tubing running through the base and to advance and retract the coiled tubing, and a control system. The control system includes a coiled tubing indicator disposed between the gripping mechanism and a blowout preventer coupled to a head of the well, to indicate a change from presence of the coiled tubing to absence of the coiled tubing. The control system also includes a gripping mechanism control coupled to the coiled tubing indicator and operable to stop movement of gripping mechanism, thus discontinuing movement of the coiled tubing in response to the coiled tubing indicator indicating the change from the presence of the coiled tubing to the absence of the coiled tubing.

Abstract: A driving system for a core drilling rig has a driving motor. The driving motor has an outer rotor and an inner stator, and mutually-matched convex ribs are provided on the inner wall of the outer rotor and the outer wall of the inner stator. The outer rotor and the inner stator are in clearance fit. A clearance between the outer rotor and the inner stator is a driving liquid channel. The length of the outer rotor is less than that of the inner stator. The outer rotor is provided between the front and rear ends of the inner stator. The outer rotor is connected to an outer cylinder. The rear end of the inner stator is connected to a coupling.

Abstract: A drilling control system may access a drilling plan for a borehole comprising one or more of planned path for the borehole, drill string information, mud properties, drill bit properties, formation properties, and drill rig properties. The system may receive a plurality of operating parameters from a rig for the borehole including one or more of an observed toolface, a spindle setting, a rate of penetration, a differential pressure, and a weight-on-bit. The system may receive one or more propagation functions for the borehole determined by a model of the drill string. The system may determine one or more spindle changes or block speed changes based at least in part on the propagation functions and the plurality of operating parameters. The system may generate one or more predicted drill properties from a simulator using the one or more spindle changes or the one or more block speed changes.

Abstract: The present invention pertains novel coiled tubing units and methods of stabbing. The coiled tubing unit has a tubing reel; a tubing guide operably connected to the tubing reel; and an injector operably connected to the tubing guide. The injector is configured to move toward or away from the tubing reel. This advantageously allows for more convenient, effective, and/or potentially safer stabbing methods to be employed.

Abstract: An anchoring device for a horizontal directional rig is provided. The anchoring device uses vibrations from a motor to drive an anchor into the ground in a more efficient manner than traditional stake down systems. The vibrating motor is mounted to a stake down carriage. The oscillations from the motor allow the steel anchor to penetrate the ground with a small axial load and therein allows greater surface and holding force.

Abstract: The present disclosure includes a plug for cementing a wellbore. The plug may include a cylinder. The cylinder may include at least one body including a non-conductive material with conductive filaments dispersed within the non-conductive material. The present disclosure also includes float equipment for cementing a wellbore. The float equipment may include a casing segment including an inner surface, drillable material affixed to the inner surface of the casing segment, and a check valve attached to the drillable material. The drillable material may include a non-conductive material and conductive filaments dispersed within the non-conductive material.

Abstract: An apparatus comprises a sub-section of a pulse power drilling assembly including a transformer encircling a center flow tube through which a drilling mud is to flow for drilling a borehole into a subsurface formation based on periodic pulses of electrical discharges from the pulse power drilling assembly. The transformer comprises at least one primary winding that encircles the center flow tube; a core that encircles the at least one primary winding, wherein the core comprises an electrically non-conductive material; and at least one secondary winding that encircles the core.