Abstract: A system including a tool drill string having a downhole device. The system includes at least one external contact configured to be electrically coupled to the downhole device to communicate with the downhole device, one or more insulators that electrically insulate the at least one external contact from other parts of the system, and one or more seals situated between the one or more insulators and the at least one external contact to pressure seal the system from external fluids.

Abstract: A double wall pipe connection system for a production tubing joint is disclosed. The double wall pipe connection system including a box adaptor having a first end and a second end, the first end coupled to a first base pipe and a first screen joint; a pin adaptor having a first end and a second end, the first end coupled to a second base pipe and a second screen joint and the second end of the box adaptor coupled to the second end of the pin adaptor to form a junction between the box adaptor and the pin adaptor; and a communication sleeve positioned across the junction between the box adaptor and the pin adaptor.

Abstract: A device, such as a snubber or shock absorber, for mitigating shock and vibration in downhole tools is provided. The device can have a body and an insert, which are separated by an elastomer to inhibit direct metal-to-metal contact therebetween. The insert has a projecting portion located within a cavity of the body. The elastomer is disposed within a gap between the insert and the internal surface walls of the cavity, and the elastomer surrounds and contacts the projecting portion and the walls. The elastomer may be molded, for example by flowing it into the cavity and subsequent hardening. Injection holes may be provided for molding. The projecting portion may be shaped to limit rotation upon failure of the elastomer and/or may include ribs and splines for shock absorption. The body may include a cap that contains the projecting portion to inhibit pull-apart.

Abstract: A threaded pipe joint, when acted upon by a tensile load, does not break on the female thread-side of a first thread section of a second thread series that extends from an intermediate shoulder. The threaded pipe joint reliably undergoes tensile rupture on the female thread-side of a first thread section of a first thread series, which is the original critical cross-section site. The threaded pipe joint is configured so that when the male and female threads of the intermediate shoulder are screwed together, the load flank-side thread gaps L1G and L2G of a first thread series, which is the radially inward thread series, and a second thread series, which is the radially outward thread series, on the two sides of the intermediate shoulder always satisfy the relationship L1G<L2G.

Abstract: This invention relates to a stabilizer (10) for a steerable drilling system, in particular for use in drilling directional boreholes for oil and gas extraction. There is provided a stabilizer (10) for a steerable drilling system having a first passageway (16) and a second passageway (18) at its outer surface, the passageways being helical and extending along the length of the stabilizer, the first and second passageways being oppositely-oriented, the first and second passageways intersecting one another, the stabilizer having a number of blades (22) between the passageways, the cross-sectional area of the first passageway being larger than the cross-sectional area of the second passageway. The asymmetric passageways enable the stabilizer designer to enhance the performance of the stabilizer during drilling and tripping.

Abstract: A bearing (12) for a downhole apparatus (10) comprises a body (42) and an upset portion (44). The upset portion (44) extends radially outwards from the body (42), the body (42) and the upset portion (44) defining a channel (46) for receiving fluid flow for lubricating the bearing (12).

Abstract: A selective stimulation system includes coiled tubing in which a distributed sensor array is disposed. The distributed sensor array is to measure hydrocarbon production parameters along the distributed sensor array in a wellbore of a formation. A selective fracturing apparatus is coupled to the coiled tubing. The selective fracturing apparatus is to fracture selected areas of the wellbore. A controller is coupled to the distributed sensor array and controls operation of the selective fracturing apparatus based on the measured hydrocarbon production parameters.

Abstract: A system and a method for an offshore platform that is self-installing, not requiring use of a heavy lift vessel for installation at a site. The system has a built-in, retractable, suspended, conductor guide support frame assembly coupled to the hull of the platform and serves as lateral guide/support for the well conductors/casings during operational conditions. The conductor guide support frame assembly is generally raised during wet tow/transit. At the site, the conductor guide support frame assembly is lowered and secured into the sea to its designated elevation. The conductor guide support frame assembly generally remains suspended from the hull and does not need to extend all the way to the seabed foundation. After operations are completed, the conductor guide support frame assembly is generally raised up relative to the hull, and the whole platform with the conductor guide support frame assembly relocated for reuse at a new site.

Abstract: A slide cartridge having a base member and a channel defined by a pair of opposed walls. The walls extend from the base member and are configured to partially cover the rail of a horizontal directional drilling machine. The slide cartridge is supported on a carriage that is movable between the front and back of the drilling machine along the rail. The cartridge is positioned to engage the rail and to support the carriage for sliding movement along the rail.

Abstract: A drilling system for use at a wellhead has a plurality of modules each containing rig component equipment. The plurality of modules are connected or interconnected together so as to form a drilling rig. Each of the plurality of modules has a size adapted to be lifted by forklift or a front end loader. The plurality of modules are arranged such that one end of the plurality of modules is adjacent to the wellhead. A pipe handling system is positioned adjacent to one end of the plurality of modules. A ventilation system is cooperative with the plurality of modules so as to move air toward or away from heat-generating equipment in the plurality of modules.

Abstract: A catwalk and crane system for transporting equipment of a well system includes a substructure, a directing frame pivotally coupled to the substructure, a pipe transporter configured to transport a tubular along the directing frame, a first actuator coupled to the directing frame and configured to rotate the directing frame relative to the substructure, and a crane coupled to the directing frame, wherein the crane is extendable from a first end of the directing frame.

Abstract: A portable bucking frame for making and breaking tubular connections includes a base, a pair of back-up jaws movably mounted to the base for receiving a pipe and an adapter plate mounted on the front end of the base. The adapter plate is configured to receive one of a plurality of power tongs for making or breaking pipe connections.

Abstract: A sucker rod tong assembly for fastening together sucker rods to a rod coupling, where the assembly can include a two-stage mechanical drive mechanism. The first stage can connect an upper sucker rod to a lower sucker rod via a rod coupling. The first stage can be limited in mechanical ability to tighten the connection to a pre-set shoulder torque value. The second stage can then be hydraulically and mechanically sequenced, using a linear gear drive mechanism, to rotate a main tong pinion gear that can further rotate the sucker rod connection through a fixed circumferential displacement to a mechanical stop.

Abstract: The present disclosure generally relates to a method for making up a tubular joint. The method includes rotating a first tubular relative to a second tubular to engage the first and second tubulars while measuring a torque between the first and second tubulars, calculating a set point of a relative rotational speed between the first and second tubulars using the measured torque, and using the calculated set point with a closed-loop controller to control the relative rotational speed between the first and second tubulars.

Abstract: A shale shaker that includes a base, a basket, a vibrator interconnected with the basket, and two shaker screens releasably mounted on the basket, with the first shaker screen having a discharge end, with the second screen having a first end with a seal abutted thereto, with the second screen positioned such that the seal is positioned below the first shaker screen, and positioned so that discharge from the first screen will not discharge onto the seal.

Abstract: A method, comprising acquiring annular pressure data from a wellbore where the annular pressure data is acquired over a time interval and at least a portion of the annular pressure data is acquired during a pumps-off period. At least first and second values are identified from the annular pressure data and the variation between the first and second values are compared to a first threshold. Drilling equipment is operated based on the comparison with the first threshold.

Abstract: An electric driven hydraulic fracking system is disclosed. A pump configuration includes the single VFD, the single shaft electric motor, and the single hydraulic pump mounted on the single pump trailer. A controller associated with the single VFD and is mounted on the single pump trailer. The controller monitors operation parameters associated with an operation of the electric driven hydraulic fracking system as each component of the electric driven hydraulic fracking system operates to determine whether the operation parameters deviate beyond a corresponding operation parameter threshold. Each of the operation parameters provides an indicator as to an operation status of a corresponding component of the electric driven hydraulic fracking system. The controller initiates corrected actions when each operation parameter deviates beyond the corresponding operation threshold.

Abstract: A wellbore tractor is capable of being positioned in a wellbore that includes a cased section, a first uncased section downhole of the cased section, and a second uncased section downhole of the first uncased section. The wellbore tractor is capable of self-propelling itself through the wellbore. An anchoring system is connected to the wellbore tractor. The anchoring system includes an appendage. When the wellbore tractor is in the cased section, the anchoring system is capable of extending the appendage from the cased section through the first uncased section into the second uncased section, anchoring the appendage in the second uncased section, and guiding the wellbore tractor from the cased section past the first uncased section and into the second uncased section.

Abstract: A locking mandrel and running tool combination for setting equipment such as flow control devices in wellbore tubing is disclosed. The apparatus uses a translatable collet to move an expander mandrel to wedge against inwardly biased locking keys to force the locking keys outward into the recesses of landing nipples in the wellbore tubing. The translatable collect is released to move only b upward shearing forces on retaining pins and the running tool is released from the locking mandrel only by upward rather than downward shearing forces on retainer pins.

Abstract: An energy-saving environment-friendly paraffin-control scale preventing ultra-strong viscosity reduction device comprises: a hydrocyclone, a first-stage jet ultrasonic signal generator, a second-stage jet ultrasonic oscillator and an ultrasonic cavitation cavity which are butted in sequence; the hydrocyclone serves as an inlet end, the outer end of the ultrasonic cavitation cavity serves as an outlet, a section of oscillation cavity is additionally arranged behind the second-stage jet ultrasonic oscillator and before the ultrasonic cavitation cavity, the tail part of the oscillation cavity is provided with a third-stage jet ultrasonic oscillator, and the ultrasonic cavitation cavity is then connected behind the third-stage jet ultrasonic oscillator.

Abstract: A central shaft defines a first interior flow path. The central shaft disposed at least partially within a washover pipe. A lead tapered mill is positioned at a downhole end of the central shaft to center the downhole-type milling tool within a tubular. The lead tapered mill defines a second central flow path in line with the first interior flow path. Milling blades extend between the central shaft and the washover pipe. The milling blades are arranged to allow fluid flow around the milling blades. Each of the milling blades includes a tungsten-carbide hardened face and a soft steel body configured to support a load of the downhole-type milling tool during milling operations. A junk basket is positioned within the washover pipe uphole of the milling blades to receive and retain cuttings formed by the milling blades.

Abstract: The disclosure herein includes a tubular cutting assembly for cutting a downhole tubular string, which tubular cutting assembly may include: a landing seat capable of being disposed on the downhole tubular string; and a tubular cutting assembly including: a landing mandrel capable of being coupled to the landing seat; a motor disposed below the landing mandrel; and a cutter assembly coupled to the motor.

Abstract: A casing segmentation device and system, and a method for selectively providing a fluid flow passage through a casing segmentation device disposed within a well casing segment is provided. The casing segmentation device includes a body and a fracture mechanism. The body has a forward end, an aft end, a plug seat, and an internal passage. The plug seat is configured to receive a mating plug. The internal passage extends between the forward end and the aft end and through the plug seat. The fracture mechanism includes an amount of energetic material and a trigger mechanism. The trigger mechanism is configured to selectively cause a detonation of the amount of energetic material.

Abstract: A subsea wellhead assembly provides a positive indication of landing of a wellhead member and locking of a wellhead member to a wellhead. The subsea wellhead assembly includes at least one positive indicator assembly disposed within a wellhead member, and a communication line extending down a running string from a platform to a running tool disposed in a subsea wellhead. The at least one positive indicator assembly provides confirmation of setting of the wellhead member, and the communication line is in communication with the positive indicator assembly to communicate the confirmation of setting with the platform following setting of the wellhead member.

Abstract: A wellbore control device includes a housing defining a throughbore which can receive a tubular, a first gate with a first hole, and a second gate with a second hole. The first gate and the second gate are supported by the housing and and can perform a movement transverse to the throughbore between an open position and a closed position. The movement of the first gate and the second gate from the open position to the closed position splits the throughbore into an upper portion and a lower portion, the upper position and the lower positing being completely separate from each other. The first hole and the second hole are aligned substantially co-axially with the throughbore in the open position. A part of at least one of the first hole and the second hole remains aligned with the throughbore in the closed position.

Abstract: A fracturing tree having fracturing fluid connections horizontally offset from a wellhead is provided. In one embodiment a system includes a fracturing tree mounted over a wellhead. The fracturing tree includes a valve to control flow of a fracturing fluid from the fracturing tree to the wellhead. The fracturing tree also includes a set of multiple goathead connections that are horizontally offset from the wellhead such that, when the fracturing fluid is received in the fracturing tree via the set of multiple goathead connections during a fracturing operation, the fracturing fluid entering the fracturing tree through the multiple goathead connections is combined at a location horizontally offset from the wellhead and is subsequently routed laterally through a shared bore toward the wellhead. Additional systems, devices, and methods are also disclosed.

Abstract: A lubricator system according to which a lubricator defines an internal passage that extends along a curvilinear path. The lubricator is configured to be connected to a wellhead at the top or head of an oil and gas wellbore. A downhole tool is configured to be conveyed through the internal passage of the lubricator and along the curvilinear path in combination with a conveyance string connected to the downhole tool. The downhole tool may be, include, or be part of, for example, a perforating gun.

Abstract: In an embodiment, the present invention provides a pressure containment device which includes a housing with a returns outlet port, an injection port, and an overflow outlet port, and a seal assembly with a seal arranged in the housing to surround and enter into a sealing engagement with a tubular body extending along a passage in the housing via a sealing face. The injection port is arranged between the returns outlet port and a first end of the seal. The overflow outlet port is arranged adjacent to a second, opposite, end of the seal and communicates with an upper end of the passage. The upper end of the passage connects to a bell nipple or to a section of a riser pipe and, in use, the overflow outlet port is exposed to a hydrostatic head provided by a fluid in the bell nipple or the section of the riser pipe.

Abstract: The present invention relates to a downhole expandable metal tubular having an axial extension, to be expanded in a well downhole to abut against an inner face of a casing or a borehole, comprising a first section having a first outer diameter, two circumferential projections having a second outer diameter which is larger than the first outer diameter, a second section arranged between the two projections, each projection having an inclined face tapering from the second outer diameter towards the second section, wherein the second section has a third outer diameter which is smaller than the first outer diameter in an unexpanded condition, and a sealing element is arranged between the projections opposite the second section, so that during expansion the second section bulges more radially outwards than the first section, forcing the sealing element radially outwards. Furthermore, the present invention relates to an annular barrier, a downhole completion and a sealing expansion method.

Abstract: A wellbore sealing assembly including a downhole device with a sealing sleeve coupled to the uphole end. The downhole device has an internal channel allowing fluid communication through the device that is substantially blocked when a ball is seated in the sleeve. The walls of the sleeve are elastically or plastically deformable, and are shaped to be deformed when the ball is seated. When deformed, the walls are in contact with the wellbore surface substantially blocking fluid communication around the device. Elastically deformable walls of the sleeve may further include a plastically deformable layer on its inner surface that, once deformed by the seating of the ball, keep the elastically deformed walls in contact with the wellbore surface when the ball is not seated.

Abstract: A wellbore isolation device includes an elongate mandrel, a sealing element carried by the mandrel, and a slip wedge positioned about the mandrel axially adjacent the sealing element and providing an outer radial surface. A set of slip segments is circumferentially disposed about the mandrel and at least a portion of the slip wedge. An extrusion limiting ring has an annular body that provides a first axial end, a second axial end, and a scarf cut extending at least partially between the first and second axial ends. The extrusion limiting ring is movable between a contracted state, where the extrusion limiting ring is disposed about the sealing element, and an expanded state, where the extrusion limiting ring is disposed about the outer radial surface of the lower slip wedge.

Abstract: An annular barrier to be expanded in an annulus between a well tubular structure and a wall of a borehole downhole includes a tubular metal part having a first expansion opening, an axial extension and an outer face, an expandable sleeve surrounding the tubular metal part and having an inner face facing the tubular metal part and an outer face facing the wall of the borehole, each end of the expandable sleeve being connected with the tubular metal part, and an annular space between the expandable sleeve and the tubular metal part. Fluid inside the tubular metal part has a tubular pressure, and the annular barrier has an expansion unit having a first inlet in fluid communication with the expansion opening, a second inlet in fluid communication with the first zone and an outlet in fluid communication with the annular space.

Abstract: A downhole tool for use in a wellbore that includes a mandrel; a first slip disposed around the mandrel, the first slip further comprising a one-piece configuration; a first cone disposed around the mandrel, and proximate to the first slip; a second slip disposed around the mandrel; a second cone disposed around the mandrel; a sealing element disposed around the mandrel, and between the first cone and the second cone; and a lower sleeve disposed around the mandrel, and proximate to the first slip. The mandrel further includes a distal end having a first outer diameter; a proximate end having a second outer diameter; wherein a relief point is formed in the proximate end.

Abstract: A well treatment fluid is provided. The well treatment fluid comprises a base fluid, and a plurality of degradable metal alloy milling waste particulates. A method of treating a well using the well treatment fluid is also provided.

Abstract: A method for remediating a microannulus in a cased wellbore may include conveying a downhole tool into the cased wellbore to a location of interest. The location of interest may include one or more perforations in a casing and a microannulus. The downhole tool may include a heat generation device. The method may also include activating the heat generation device to melt a fill material at the location of interest such that the fill material flows through the perforations into one or more voids, including the microannulus, in or around cement disposed between the casing and the cased wellbore. Additionally, the method may include deactivating the heat generation device to facilitate solidification of the fill material in the one or more voids and sealing of the microannulus.

Abstract: An example wellbore cementing system includes a casing to line at least part of a wellbore, and a pipe to introduce cement slurry containing capsules into the wellbore. The capsules include an accelerator. The accelerator reacts with the cement slurry to affect a thickening time of the cement slurry. The example system also includes a substructure having shearing pins. The substructure is arranged to receive the cement slurry from the pipe. The substructure is configured rotate to break at least some of the capsules in the cement slurry.

Abstract: A frac pump valve seat assembly includes a seat body and a wiper seal. The seat assembly is configured to mitigate the risk of fluid end erosion in the valve seating area by automatically clearing or wiping the mating surface of the fluid end at the time of installation. The wiper seal is located at a lower portion of the seat body and is designed to interface therewith the mating surface of the fluid end. Upon installation, the wiper seal scrapes or cleans the mating surface of propellants, sand, and other contaminants that may remain after initial cleaning. The contact surface of the seat body is optionally further reinforced with material implants with greater hardness than the material of the seat body.

Abstract: A valve with a shuttle for use in a flow management system is capable of bypassing a backflow.

Abstract: A downhole fluid flow control system includes a fluid control module having an upstream side, a downstream side and a main fluid pathway in parallel with a secondary fluid pathway each extending between the upstream and downstream sides. A valve element disposed within the main fluid pathway has open and closed positions. A viscosity discriminator including a viscosity sensitive channel forms at least a portion of the secondary fluid pathway. A differential pressure switch operable to open and close the valve element includes a first pressure signal from the upstream side, a second pressure signal from the downstream side and a third pressure signal from the secondary fluid pathway. The fluid control module includes a dissolvable member operable to temporarily lockout the valve element in the open position or temporarily prevent fluid flow through the main and secondary fluid pathways. The dissolvable member is dissolvable by a dissolution solvent downhole.

Abstract: Methods and apparatus for utilizing a valve with a pump rotor passage with a downhole production string, the pump rotor being on a rotatable rod with a bobbin moving along the rod between a position for opening the passage to fluid flow, when the bobbin is not seated on a shuttle seat, and a position for closing the passage to fluid flow, when the bobbin is seated on the shuttle seat. The pump rotor and rod are removable through the passage while leaving the pump stator in place upstream of the valve.

Abstract: An injection device comprises a housing comprising an inlet and an outlet and an outlet sleeve mounted within the housing and comprising at least one radial flow port therethrough for permitting fluid communication between the inlet and the outlet. A flow sleeve is mounted over the outlet sleeve and is arranged to move between a first position in which the at least one radial flow port is at least partially closed and a second position in which the at least one radial flow port is opened. The injection device also includes a flow sleeve actuator operable by a biasing arrangement and inlet pressure at the inlet of the housing to permit the flow sleeve to be selectively moved between its first and second positions to vary flow through the at least one radial flow port between the inlet and the outlet.

Abstract: A completion string can have an outer surface and an inner surface, a first fluid passageway being defined between the outer surface and the inner surface. The inner surface can define an inner region of the completion string and can have a recess that is sized to receive a sleeve that is moveable between an open position and a closed position. The inner region can be sized to receive a work string at a position at which a surface of the work string cooperates with the sleeve and the inner surface of the completion string to define a first chamber on a side of the sleeve, the first chamber being hydraulically sealed by a plurality of sealing elements. The work string can define a second fluid passageway to provide fluid communication with the first chamber.

Abstract: A downhole apparatus comprises a piston mounted within a bore and being reconfigurable from a lock configuration to an unlock configuration in response to a pressure sequence applied within the bore. When the piston is in its lock configuration, a lock is supported by the piston such that the lock partially extends into the bore and engages a lock profile of the piston to restrict movement of the piston in a first direction towards its unlock configuration. In response to a first event of the pressure sequence, the piston is moveable in a second direction to desupport the lock and permit the lock to be wholly received into the bore and allow the piston to move in the second direction towards its unlock configuration in response to a subsequent event of the pressure sequence.

Abstract: A combined multicoupler for connecting a tool to a top drive is disclosed. The combined multicoupler includes a load frame comprising a frame body having a load shoulder, and a side door coupled to the frame body. The side door opens from the frame body to allow a tool sliding horizontally into the load shoulder, and the side door closes to lock the tool in the load frame. The combined multicoupler further comprises a drive stem movably coupled to the load frame, wherein the drive stem moves vertically to connect and disconnect with the tool in the load frame.

Abstract: A well tool assembly, system, and method for handling well debris is described. The assembly includes an electric submersible pump (ESP) configured to be positioned within a wellbore and a well debris cutting tool configured to be positioned downhole relative to the ESP within the wellbore. The ESP is configured to rotate in a first direction to pump well fluid in an uphole direction. The well debris cutting tool is configured to rotate in a second direction opposite the first direction and to grind debris carried by the well fluid in the uphole direction.

Abstract: The application is directed to a power system that may be provided in a portable form and operationally configured for use at a work site as a single source of electric power, hydraulic power and pneumatic power for work site operations. In regard to hydraulic fracturing stimulation of a wellbore, the power system is operationally configured as the source of hydraulic power for transportable pumping units of a fracturing operation and for hydraulic power tools, as the source of pneumatic power for pneumatic power tools and as the source of electric power for electric power tools and electronic equipment at a well site.

Abstract: A multi-oriented hydraulic fracturing (MOHF) model may incorporate the pseudo-plastic properties of the formation and tiny tectonic motions from fracturing to enhance MOHF operations.

Abstract: An umbilical end termination for a subsea umbilical comprising a plurality of functional elements and including at least one fluid line, wherein the umbilical end termination includes a pressure boosting system in line with the at least one fluid line.

Abstract: A wellscreen has a gravel pack assembly installed that can communicate slurry from a transport tube to a pack tube. A bypass has erosion resistant surfaces exposed to flow of the conveyed slurry and diverts portion of the conveyed slurry from the fluid bore of the transport tube to a tube opening, from which the pack tube extends. The bypass can be incorporated into the top ring for supporting the filter on the basepipes. A sheath of erosion resistance can be formed on or installed in a channel of the end ring to be covered by a cover.

Abstract: High power laser systems, high power laser tools, and methods of using these tools and systems for opening up damaged wells and for cutting, sectioning and removing structures objects, and materials, and in particular, for doing so in difficult to access locations and environments, such as offshore, underwater, or in hazardous environments, such as nuclear and chemical facilities. And, high power laser systems, high power laser tools, and methods of using these systems and tools for providing rock-to-rock plugs for decommissioning of wells.