Abstract: A leak detection and collection system includes a cap configured to couple to a wellbore component. The system also includes an alert system removably coupled to the cap and a packer coupled to the cap. The packer extends into a bore of the wellbore component and the packer is actuated to seal against the wellbore component and to block flow through the bore. The system further includes a release mechanism coupled to the alert system, a first flow path, an accumulator, and a second flow path. The release mechanism is activated at a first pressure above a first threshold to release the alert system and the second flow path directs flow to the accumulator at a second pressure above a second threshold.

Abstract: A vibratory grouting rod with drilling and vibrating functions includes: a drill bit, a vibration part, a flexible shock absorption device, a slotted connection part, a connection tail part, and a rigid-flexible conversion device; wherein the vibration part, the flexible shock absorption device, the slotted connection part and the connection tail part are sequentially jointed to form a grouting rod body, and the grouting rod body has a holding cavity; the drill bit is provided at a front end of the vibration part; and the rigid-flexible conversion device is movably sleeved on the flexible shock absorption device, which is configured to move up and down in a bar-shaped slot of the slotted connection part. The rigid-flexible conversion device can be pushed down to a rigid mode for drilling, and pulled up to a flexible mode for grouting with vibration concentrated around the vibration part.

Abstract: A horizontal directional drilling machine having a modular pipe loader system. The system comprises a first and second pipe loader assembly supported on a drill frame. Each assembly supports a shuttle arm. The shuttle arms are configured to move independently of one another along a shuttle path that is traverse to a longitudinal axis of the drill frame. Movement of each shuttle arm is powered by an actuator supported on each pipe loader assembly. Each pipe loader assembly includes a sensor used to measure parameters related to the position of each shuttle arm relative to the drill frame. A controller analyzes the measured parameters and directs operation of each actuator in order to keep the shuttle arms moving in unison during operation.

Abstract: Systems and methods for downhole drilling and, more particularly, hydraulic control systems and methods for hydraulically locking and unlocking moveable elements of a drill bit are provided. A drill bit may include a body; a moveable element secured to the body, wherein the moveable element is configured to extend or retract from a surface of the drill bit; a communication channel from the moveable element to a bore in the body; and a hydraulic control system at least partially disposed in the body, wherein the hydraulic control system is configured to at least provide fluid communication from the bore to the communication channel to thereby lock or unlock the moveable element.

Abstract: Provided herein are PDC drill bits for engaging subterranean formations and for drilling wellbores, wherein the PDC drill bits are adapted to reduce erosion of a bit head face by the inclusion of openings in a portion of the shank of a PDC drill bit. The present disclosure also relates to systems and methods of drilling subterranean formations using the PDC drill bits disclosed herein.

Abstract: A rotary flow control apparatus may comprise a rotary drive mechanism coupled to a ball controller comprising a ball disposed within a cavity. The apparatus may be disposed within a tubing string in a wellbore. Fluid flow is provided though the tubing, causing the rotation of the rotary drive mechanism. The flow passes through a ball cage above a seat disc that incorporates a flow port. The ball orbits around the cavity in response to the motion of an axially extending surface or “kicker.” When the ball obstructs the flow port, it substantially blocks the flow of fluid through the assembly, generating a water hammer impulse in the tubing above the rotary drive mechanism. The rotating kicker moves the ball off the flow port at one angular position and then allows the ball to reseat at a second angular position.

Abstract: A thrust bearing for an electric submersible pump includes a housing including an axial surface and an inner circumferential surface. Holes and bores are formed in the axial surface. The thrust bearing further includes sockets respectively disposed in the holes and pads each including a fluid interface surface. Two open counterbores are formed in each of the pads. The inner circumferential surface radially constrains the pads. The thrust bearing further includes balls each engaging one of the sockets and one of the pads and retaining bolts each including a head and a shaft extending from the head. Each of the shafts is disposed in one of the bores. The thrust bearing further includes biasing members each disposed between a bearing surface of one of the heads and bottom surfaces of two of the open counterbores. The pads are able to pivot on the ball.

Abstract: Embodiments disclosed herein are directed to a flow pulsing system including a rotor, a stator, a dart which is configured to releasably couple with the rotor, and a nozzle releasably coupled to the rotor which is configured to control a fluid flow through the rotor. In some embodiments, the system uses a screen disposed therein which includes an inner bore in fluid communication with a plurality of lobe cavities along the rotor. In some embodiments, the system uses a stationary valve and an oscillating valve having a plurality of oscillating valve ports which are in fluid communication with the plurality of lobe cavities.

Abstract: A cutter element for a fixed cutter drill bit has a central axis and includes a cylindrical substrate and a cutting layer mounted to the substrate. The cutting layer includes a first end engaged with the substrate, a second end opposite the first end, and a radially outer surface extending axially between the first and second ends. In addition, the cutting layer includes a cutting surface positioned at the second end and a cutting tip positioned between the cutting surface and the radially outer surface. Further, the cutting layer includes a first region on the cutting surface having a first surface roughness, and a second region on the cutting surface having a second surface roughness that is higher than the first surface roughness. The second region covers the central axis along the cutting surface, and the first region extends from the second region to the cutting tip.

Abstract: An insert for a slip in a hydraulic spider, including an engagement body. The engagement body including an engagement surface. The engagement surface including a first concave surface portion and a second concave surface portion. The first concave surface portion including teeth with a first radius of curvature. The second concave surface portion including teeth with a second radius of curvature that is different than the first radius of curvature.

Abstract: A downhole drilling system comprises a drill string and a drill bit coupled to the drill string. The drill bit comprises a bit body with primary and secondary blades disposed thereon. Some of the secondary blades are alternately disposed between some of the primary blades. Two first layer cutting elements are disposed on different ones of the primary blades, and substantially diametrically opposed to each other along a first track set radius of the bit body, while two second layer cutting elements are disposed on different ones of the secondary blades, and substantially diametrically opposed to each other along the first track set radius. The second layer cutting elements are sized to provide a selected amount of underexposure greater than zero with respect to the first layer cutting elements.

Abstract: A drill-bit may include a head which includes a face and a gage. The face may include a plurality of face button bits. The gage may include a plurality of gage button bits evenly spaced around the head. A plurality of major chip gage gashes may be evenly spaced around the head. A plurality of minor chip gage gashes may be evenly spaced around the head. An axis extending through centers of the plurality of face button bits may extend through one of the plurality of major chip gage gashes and one of the plurality of minor chip gage gashes. The plurality of major chip gage gashes may alternate with the plurality of minor chip gage gashes around the head. One of the plurality of gage button bits may be disposed in-between every set of the alternating major chip gage gashes and minor chip gage gashes.

Abstract: System and method for determining an updated location of a bottom hole assembly (BHA) during drilling of a well are provided. During drilling, a computer system may receive tool face updates and may determine build rate estimates and a borehole depth increase during a toolface update period. The computer system may also calculate an updated estimate of the borehole position.

Abstract: The present invention relates to a method and apparatus for cleaning an oil and gas well riser section or assembly. Even more particularly, the present invention relates to an improved method and apparatus for cleaning oil and gas well riser sections wherein a specially configured cap or pair of caps are fitted to the ends of the riser which enable pressure washing cleaning tools (or a camera) to be inserted into and through the riser cleaner fluid continuously recirculates so that relatively small volume of cleaning fluid (for example between about 700 and 1,000 gallons) is required. The cleaning process uses a volume of cleaning fluid that is discharged from the riser pipe at a relatively high temperature of about between 10° and 180° F. Such a high temperature cleaning fluid could possibly damage the pump that is used for supplying pressurized fluid to the cleaning tool.

Abstract: A cutting element may include a substrate having a base. A cutting element may include an ultrahard layer bonded to the substrate, the ultrahard layer formed from an ultrahard material, the ultrahard layer including: a side surface adjacent to the base, the side surface including a plurality of cutting surfaces; and an upper surface extending into the ultrahard layer.

Abstract: The apparatus may include a tool conveyed by a conveyance device. The tool has a body with a load bearing section, an outer surface defined by a diameter, a rotational axis, and a channel in the body extending from an opening at the outer surface. At least a part of the channel is inclined relative to the rotational axis of the body at the axial location of the opening in the body. The apparatus also includes at least one functional element disposed in the channel; and a conduit operatively connected to the at least one functional element transferring at least one of: (i) energy, (ii) a signal, (iii) a fluid, (iv) and formation material. Alternatively, the apparatus includes at least one self-contained functional element disposed in the channel.

Abstract: Orientation system for downhole device (10), wherein the orientation system comprises an outer magnetic orientation lock assembly (460) arranged in connection with or integrated in the downhole device (10) and an orientation instrument assembly (400) for insertion into the outer magnetic orientation lock assembly (460), and wherein the orientation instrument assembly (400) comprises a sensor assembly (420) rotatably arranged in the orientation instrument assembly (400) and arranged for aligning or orienting in relation to the outer magnetic orientation lock assembly (460).

Abstract: A device for characterizing and testing on-site basic parameter of a natural gas hydrate includes a servo transmission mechanism, a pressure-resistant manipulator, a sealing mechanism, a data acquisition system, a resistivity testing system, an outlet metering system and an undisturbed permeability testing module; the undisturbed permeability testing module is used for testing a permeability of a hydrate sample subjected to sample transfer; the pressurizing system is used for adjusting a pressure of each point in the device; the servo transmission mechanism includes a pressure-resistant sample transfer manipulator and a servo driver; the servo driver is used for driving the pressure-resistant sample transfer manipulator to reciprocating motion, and the pressure-resistant sample transfer manipulator is used for separating the sample to be tested from the sheath under a pressure and pushing the sample into a holder; and the resistivity testing system is used for detecting a resistivity value.

Abstract: A progressive cavity pump system including a pump string disposed in a wellbore. The pump string includes a progressive cavity pump and a rod string, wherein the rod string is rotatable about a rod string axis to rotate a rotor of the progressive cavity pump. The progressive cavity pump system includes a permanent magnetic motor (“PMM”) configured to drive the rotation of the rod string. The PMM is oriented such that a drive shaft of the PMM rotates about a drive shaft axis that is not coaxial with the rod string axis.

Abstract: An example PCD body includes a top surface, a bottom surface opposite the top surface, and at least one lateral surface extending between the top surface and the bottom surface. The PCD body includes one or more threads that are configured to allow the PCD body to be threadedly attached to a component, such as a substrate, a drill bit body, or a support ring. In an embodiment, the one or more threads may be formed on at least a portion of the lateral surface.