Abstract: A connecting assembly (14) comprises a first connector (10) defining a profiled portion (16) and a second connector (12) comprising a coupling member (18) adapted to be translated to selectively engage with the profiled portion (16) of the first connector (10). The assembly (14) also comprises a supporting member (20) adapted to be translated to selectively secure said coupling member (18) in engagement with the profiled portion (16) of the first connector (10). Drive means (21) is contained within one of the first and second connectors (10, 12) and is adapted to translate the supporting member (20). One disclosed use of the connecting assembly (14) is in a wellbore tool deployment system.

Abstract: A cleaning tool (1) for use in cleaning ferrous material from a wellbore has a magnetic cleaning element (14) mounted to a tool body (2) within a slot (5) using a releasable concealed interference fit fastener assembly (15) comprising a fastener member having a head (16), and a shank (17) with a configured end (18) and a deformable fastener ring (20) adapted to fit closely over the shank, and a press-fit collar (21) adapted to deform the deformable fastener ring upon the configured end of the shank when assembled, and wherein the respective head and collar are each flanged to permit an interference fit with a corresponding contact surface of the tool body around said slot.

Abstract: A wellhead system is provided. In one embodiment, the wellhead system includes first and second wellhead components or members. An exemplary first wellhead member includes an internal bore and a first groove, while an exemplary second wellhead member is at least partially disposed within the internal bore such that a second groove of the second wellhead member is aligned with the first groove. The wellhead system may include a locking ring positioned within at least one of the first or second grooves, and a retaining ring at least partially disposed within the internal bore between the first and second wellhead members. Further, in one embodiment, the retaining ring is configured to selectively engage the locking ring to facilitate securing of the second wellhead member to the first wellhead member. Other embodiments of wellhead systems, devices, and methods of coupling the same are also provided.

Abstract: A kickover tool for placing and extracting a valve in a mandrel having a hydraulic piston, a kickover arm portion mechanically connected to the hydraulic piston, the kickover arm portion being actuated by application of pressure to the piston. Upon full stoke of the piston, pressure is relieved, and measurement of the pressure relief can be used to indicate proper placement in a side pocket mandrel.

Abstract: An apparatus for radially expanding and plastically deforming a tubular member includes a support member with a fluid passage. A mandrel is movably coupled to the support member and includes an expansion cone operable to radially expand and plastically deform the tubular member when moved relative to the tubular member. A pressure chamber is positioned between the support member and the mandrel, and the pressure chamber is fluidicly coupled to the fluid passage. A releasable support is coupled to the support member and operable to selectively couple the support member to the tubular member.

Abstract: An installation system and method configured to install a lower completion section is provided. The installation system may comprise an installation drill pipe configured to releasably couple with a lower completion section. The installation system may comprise an electrical wet connect. The electrical wet connect may be coupled with a connector configured to establish a communication pathway between the electrical wet connect and components of the lower completion section. The lower completion section may be run in hole. Communications between a surface location and the lower completion components may be established via the electrical wet connect. The lower completion components may be tested prior to setting a lower completion section packer.

Abstract: A riser for use in boring a subsea wellbore having a gooseneck assembly connected onto the riser. The gooseneck assembly has an outlet that couples with a flowline on the riser and a connector assembly that selectively decouples the gooseneck assembly from the flowline. A release member, such as a wire, cable, or rod, is attached to the connector so the connector assembly can be actuated by manipulating the release member from a remote location.

Abstract: A connector guard is provided to protect one or both downhole connectors during wellbore run in prior to mating downhole. The connector guard may comprise dissolvable or degradable material and include an engagement sections and a removal feature. The connector guard may be dissolved or degraded via a reactive agent or temperature either introduced downhole proximate to the guards or contained within a chamber included in or created by a connector guard. The connector guard may be further coupled by a non-reactive cover in order to control the rate of reaction of the dissolvable material. The cover may be breached prior to mating of the downhole connectors.

Abstract: A kickover tool is for placing and extracting a valve in a mandrel having a tool body extending in a longitudinal direction and having a hydraulic piston chamber therein. A hydraulic piston is located inside the hydraulic piston chamber. A kickover arm portion is mechanically connected to the hydraulic piston, the kickover arm portion comprising a kickover arm having a tool portion. The kickover arm has a non-kicked-over position where the kickover arm is substantially coaxial with the longitudinal direction and a kicked-over position where the kickover arm is substantially non-coaxial with the longitudinal direction. The kickover arm moves to the kicked-over position upon extension of the hydraulic piston.

Abstract: New locking connector assemblies and telescoping extension/retraction assemblies are disclosed that operate on the natural spring rate constraints of radial protrusions or radially constrained rings as they interact with engaging members to provide the locking force and permit the connector and extension retraction assemblies to be engage and disengaged or extended and retracted.

Abstract: A stop collar is assembled using a method including the steps of receiving a bore of a base having a set of fingers extending along an exterior of a tubular, receiving a bore of a sleeve onto the tubular adjacent the set of fingers, and receiving the sleeve onto the set of fingers in an interference-fit. In alternate embodiments, the base comprises a plurality of angularly distributed fingers and/or the base comprises a gap to permit conformance of the base to the tubular. A fingerless base may cooperate with one or more separate fingers to form a base. In an embodiment of the method, the sleeve may be thermally expanded prior to the step of receiving the sleeve onto the set of fingers. The sleeve may be heated to expand the bore prior to being received onto the set of fingers.

Abstract: A technique enables the efficient connection of communication lines in a well application by substantially reducing online rig assembly time. The technique reduces online time of the rig by sealably fastening a first connector of a downhole connection assembly to a segment of a communication line during offline assembly time to substantially reduce the online time requirements. The first connector is later connected to a corresponding second connector while the rig is online to complete the downhole connection assembly that joins communication line segments.

Abstract: ESP power cable is inserted into a length of tubing disposed in a wellbore. The device comprises a support attachable to the cable that is in frictional sliding contact with the tubing inner surface. The frictional sliding contact between the support and the tubing reduces axial stress in the cable. Support devices are added at intervals on the cable length, thereby distributing the cable axial stress along the cable.

Abstract: A non-metallic element system is provided as part of a downhole tool that can effectively seal or pack-off an annulus under elevated temperatures. The element system can also resist high differential pressures without sacrificing performance or suffering mechanical degradation, and is considerably faster to drill-up than a conventional element system. In one aspect, the composite material comprises an epoxy blend reinforced with glass fibers stacked layer upon layer at about 30 to about 70 degrees. In another aspect, a mandrel is formed of a non-metallic polymeric composite material. A downhole tool, such as a bridge plug, frac-plug, or packer, is also provided. The tool comprises a support ring having one or more wedges, an expansion ring, and a sealing member positioned with the expansion ring.

Abstract: A series of down hole tools are assembled from a common subassembly to which are added various specialty parts to make a flow back plug, a bridge plug or a plug with a disintegratable check valve. The subassembly may be used, as is, as a ball drop plug. The components may be added through either end of the subassembly without having to take the subassembly apart. The subassembly and specialty parts may be shipped to the customer so the end user may customize the subassembly to provide a plug operable to provide a variety of functions.

Abstract: A submersible pumping system for use downhole, wherein the system includes tubing disposed in a wellbore having a wet connection formed for coupling with a pumping system disposable in the tubing. An electrical power cable connects to the wet connection through the tubing. The wet connection comprises receptacles configured to mate with electrically conducting pins, the receptacles and the pins are oriented substantially parallel with the tubing axis. The receptacles are formed to receive the pins therein and form an electrical connection for connecting electrical power from the cable to the pumping system.

Abstract: A method for retrofitting a downhole drill string with a flow through subassembly having a hollow outer body or barrel with a plurality of outwardly extending blades. Fluid flow inlets are provided in the lower section of the body below the blade openings and flow outlets are provided in an upper section above the blades. A fluid flow bypass channel is formed in the outer body and extends between said blades and from said fluid inlet to said fluid outlet. Drilling fluids outside of the subassembly may flow through the inlet, up the fluid flow bypass channel and out the outlet thereby bypassing any plug or pack-off formed between the subassembly and the well bore. Thus, an existing subassembly may be retrofitted to provide a fluid flow bypass channel around the blades.

Abstract: A drilling system employs a set of bushings that protect seats used for casing hangers. The system includes one or more seat protectors that attach to a running tool. The running tool is lowered down the wellbore with the seat protectors attached and deposits a bushing at each surface to be protected. The running tool may retrieve the bushings as the running tool is withdrawn from the wellbore.

Abstract: A kit of parts which is assembled to form downhole apparatus comprises a swellable member, which expands upon contact with at least one predetermined fluid, and a connector. The swellable member has a first mating profile towards a first end and a second mating profile towards a second, opposing end. The connector has a mating profile configured to mate with each of the first and second mating profiles of the swellable member. The connector can therefore be connected to either the first and second ends of the swellable member. The connector may be an end connector, or may connect the swellable member to a second swellable member. In either case, the connector may define an arresting surface against which the swellable member abuts when expanding. The kit of parts can be adapted to and installed on any well tubular, and may form any of a variety of tools.

Abstract: The present invention generally relates to a pipe handling system for use with a tubular joining system (such as a welding or forging assembly) located on a drilling rig at a wellbore. In one aspect, a method of forming a string of pipe using a joining assembly at a wellbore is provided. The joining assembly includes an internal joining tool and an external joining tool. The method includes the step of picking up the pipe joint using an elevator. The method further includes the step of positioning a lower end of the pipe joint adjacent an end of a string of pipe disposed in the external joining tool. The method also includes the step of moving the internal joining tool from a first position to a second position relative to the elevator, wherein the second position is between the pipe joint and the string of pipe. The method further includes the step of forming a connection between the pipe joint and the string of pipe.

Abstract: A method for expanding a tubular member in a wellbore includes applying a downward force to an expansion cone through a work string to anchor the tubular member in the wellbore and pulling upwards on the expansion cone with the work string to expand the tubular member. The expansion cone is disposed in a launcher portion connected to the tubular member being expanded.

Abstract: A hybrid junction assembly is provided. The hybrid junction assembly may comprise a junction body configured to sealingly couple to a first control line and a second control line. In addition, the assembly may include a transfer conduit configured to fit within a hybrid control line such that an annulus is formed between the transfer conduit and the hybrid control line. The first control line and the transfer conduit may form a first communication pathway and the second control line and the annulus may form a second communication pathway. The transfer conduit and the hybrid control line may be sealingly coupled to the junction body.

Abstract: An apparatus (100) for controlling the connection speed of first and second downhole connectors (316, 146) in a subterranean well. The apparatus (100) includes a first assembly that is positionable in the well. The first assembly includes the first downhole connector (316) and a first communication medium. A second assembly includes the second downhole connector (146) and a second communication medium. The second assembly has an outer portion and an inner portion. The outer portion is selectively axially shiftable relative to an inner portion, such that upon engagement of the first assembly with the second assembly, the outer portion of the second assembly is axially shifted relative to the inner portion of the second assembly allowing the first and second downhole connectors (316, 146) to be operatively connected to each other, thereby enabling communication between the first communication medium and the second communication medium.

Abstract: Earth-boring rotary drill bits including a bit body attached to a shank. In some embodiments, the bit body and the shank may have abutting surfaces concentric to an interface axis offset relative to a longitudinal axis of the drill bit. In additional embodiments, the bit body and the shank may have generally frustoconical abutting surfaces. Methods for attaching a shank and a bit body of an earth-boring rotary drill bit include abutting a surface of a shank against a surface of a bit body, and causing the abutting surfaces to be concentric to an axis that is offset or shifted relative to a longitudinal axis of the drill bit.

Abstract: Drilling assemblies include a drill bit and a reamer apparatus in which the drill bit is configured to rotate in rotational direction about a longitudinal axis of a drill string and the reamer apparatus is configured to rotate in an opposite rotational direction about the longitudinal axis. Methods of forming a drilling assembly include configuring a drill bit to drill a subterranean formation when rotating in a counter-clockwise direction and configuring a reamer apparatus to ream a wellbore within the subterranean formation when rotating in a clockwise direction. Methods of drilling wellbores in subterranean formations include rotating a drill bit in a first rotational direction about a longitudinal axis of a drill string to drill a wellbore and rotating a reamer apparatus in an opposite rotational direction about the longitudinal axis of the drill string to ream the wellbore.

Abstract: Modular apparatus for remotely activating a wiper plug launching tool or other down-hole equipment by launching a dart or other projectile along tubing to the subsea equipment. A dart is loaded into a basket prior to launch and subsequently loaded into a modular tool piece. The pre-loaded tool pieces are configurable prior to use dependent on operational requirement and furthermore may be independently removable from the remaining equipment facilitating maintenance and serving of individual tool pieces.

Abstract: An annular coupler for transmitting data across a tool joint may include a first coupler segment spanning a first portion of the circumference of the annular coupler. The annular coupler may further include a second coupler segment, electrically insulated from the first coupler segment, which spans a second portion of the circumference of the annular coupler. In selected aspects, the first and second portions do not overlap one another along the circumference. In certain aspects, the first and second coupler segments each span about fifty percent of the circumference of the annular coupler. Thus, each coupler segment may make up roughly half of the annular coupler.

Abstract: An assembly that is usable with a well includes a base pipe, a screen and at least one perforating charge. The base pipe includes at least one radial port to communicate well fluid, and the base pipe has an outer surface. The screen is mounted to the base pipe and is adapted to at least partially surround the base pipe. The radial port(s) of the base pipe are covered by the screen. The perforating charge(s) are mounted to the outer surface of the base pipe.

Abstract: A ram blowout preventer for sealing a well, the ram blowout preventer including a body having a cavity with a recess; a ram block configured to move inside the cavity; a top seat disposed in the recess and configured to seal the well when in contact with the ram block; a movable lock ring extending inside a groove of the body and a corresponding groove of the top seat and configured to move inside the groove of the body, along a direction substantially parallel to the well; a first seal extending inside a groove of the top seat and configured to contact the body and the top seat; and a second seal extending inside a groove of the ram block and configured to contact the ram block and the top seat. A width of the groove of the body is larger than a width of the lock ring by a predetermined value, which is larger than normal tolerances, and a distance from a centerline of the well to the first seal is larger than a distance from the centerline of the well to the second seal.

Abstract: Systems and methods for improved hydraulic control systems for actuation of subsea equipment in deep water are disclosed. The hydraulic control system relies on smaller fluid flow associated with a hydraulic pressure pulse to actuate the small volume actuation control valve. In one embodiment, the system includes small diameter control umbilical hoses and pilot-operated valves with low actuation volumes. Particularly, a hydraulic control system for reducing the signal time to a subsea blowout preventer in water depth up to and greater than about 5000 feet. Some embodiments comprise a valve arrangement which hydraulically actuate one side of a hydraulic control function, while simultaneously evacuating the opposing circuit both at the seabed and at the surface. Some embodiments comprise an umbilical hose located proximate the center of an umbilical bundle. Preferably, the umbilical hose has a plurality of layers of reinforcing fibers which increase with the diameter of the reinforcement layer.

Abstract: An air swivel ring includes a non-rotating member having an air inlet, a rotating member having an air outlet, and a split seal having a first sealing surface and coupled to one of the non-rotating member and the rotating member so that the first sealing surface on the seal is disposed proximate a second sealing surface on the other of the non-rotating member and the rotating member.

Abstract: A fluid operated apparatus in the form of a flow cap, is mounted on an end of a downhole tool or sub, which itself has a screw thread fitting to a further tool, sub or tubular. The cap provides a number of fluid flow channels arranged in a spiral pattern upon the outer surface. The handedness of the channels matches the handedness of the screw thread fitting so that fluid flow from ports in the tool or sub, acts to tighten the screw thread fitting. A water injection valve including a flow cap is described.

Abstract: An expandable tubular connection includes coupled first and second tubular members and a sealing end on one of the first and second tubular members engaged with an angled shoulder coupled to the other of the first and second tubular members, wherein the sealing end deflects on the angled shoulder and plastically deforms into one of the first and second tubular members upon radial expansion and plastic deformation of the expandable tubular connection. A tubular sleeve including the angled shoulder may be coupled between the first and second tubular members. The sealing end may have an inner radial projection that is deflected into a surface on the first tubular member. A method includes pre-loading a sealing end of the second tubular member onto an angled shoulder of the tubular sleeve, radially expanding and plastically deforming the tubular connection, and deflecting the sealing end on the angled shoulder and into the first tubular member.

Abstract: An apparatus for aligning a component includes: a downhole sub including a plurality of first axially extending tapered members, the plurality of first axially extending tapered members configured to engage a plurality of second axially extending tapered members of a downhole carrier in an interlocking engagement and prevent rotation of the downhole carrier relative to the downhole sub.

Abstract: A downhole tool is described designed to be suspended from a surface location into a wellbore (11), the tool including at least one module (20) with elements susceptible to mechanical vibrations or shocks, having the module coupled to remaining parts of the tool with one or more transducers (31) comprising electroactive polymeric material.

Abstract: Disclosed herein is a method for centralizing a downhole component. The method includes, delivering a tubular member with a plurality of lines of weakness therein to a site requiring a centralizer, and actuating the tubular member by causing a portion of the tubular member to deform radially from an unactuated position. The actuated portion contacting a downhole tubular structure, while maintaining at least two separate fluid passages. A first fluid passage between the portion of the tubular member and an outside surface of the tubular member in the unactuated position and a second fluid passage at a dimension smaller than that of the outside surface of the tubular member in the unactuated position.

Abstract: A conductor delivery arrangement includes a length of feedable tubing; a landing tool in operable communication with the feedable tubing; and a conductor in operable communication with the landing tool and method.

Abstract: A method for inserting a tool into a wellbore includes uncoiling a coiled tubing into the wellbore to a selected depth therein. When the tubing is at the selected depth, the tubing is uncoupled. A tool is inserted into the interior of the tubing. The tubing is reconnected, and the tool is moved along the interior of the tubing.

Abstract: A cement head, comprising a first module comprising a first module outer profile, a second module comprising a second module outer profile, a bridge comprising a bridge profile engaged with each of the first module outer profile and the second module outer profile.

Abstract: An expandable downhole tool is disclosed that employs naturally occurring organic matter as the expandable material. The expandable material is located within an enclosure formed in part by an impermeable element, which may form a hydraulic seal, and a permeable membrane that permits fluids present in the wellbore to pass and interact with the organic matter. The heat and fluids present within the wellbore may cause the expandable matter to swell, and thus causing the enclosure to swell and possibly form a hydraulic seal against a wellbore or inner annulus. The expandable tool may be used as packer, plug, or other downhole tool, among others. Methods of manufacturing and using such tools are also disclosed.

Abstract: A wellbore instrument includes a housing configured to traverse a subsurface wellbore. A shock and vibration sensor disposed in the housing and is mounted on a carrier disposed in the housing. The carrier includes at least two, laterally movable elements each having an outer surface configured to contact an inner surface of the housing. The carrier includes an adjustable wedge disposed between the opposed elements. The wedge is arranged such that longitudinal movement thereof causes lateral separation of the laterally movable elements into frictional engagement with the inner surface of the housing.

Abstract: A method and apparatus for remotely performing a pipe handling operation is provided. In one aspect, the method and apparatus includes a false rotary table capable of supporting one or more tubulars during the pipe handling operation which is moveable between a position for landing one or more tubulars to a position for running one or more tubulars into a wellbore. In another aspect, the present invention provides a method and apparatus for remotely connecting elevator links alternatingly between interchangeable elevators which are capable of axially engaging one or more tubulars above the wellbore.

Abstract: A drill bit made according to one embodiment includes at least one of a weight sensor and a torque sensor configured to provide signals representative of the weight and torque on the drill bit when the drill bit is used for cutting into a formation. A circuit may be configured to process signals from the weight and torque sensors to provide an estimate the weight and torque on the bit when the drill bit used for cutting into the formation.

Abstract: A shoulder ring, for installation in a threaded pipe coupling between the installed pin ends of two pipes being connected by the coupling, has opposing end faces and a central opening, and may lobate or circular in shape. The shoulder ring provides enhanced axial retention within the coupling by incorporating a thread element which engages the internal threads of the coupling to prevent or deter displacement of the ring from the coupling. Alternatively, enhanced axial retention may be provided by means of an interference or interlocking fit that is plastically induced during the ring installation process. The shoulder ring may be of lobate or circular configuration, with the axial retention of lobate embodiments being further enhanced by forces acting radially outward against the coupling due to elastic deformation of the ring during installation. Also disclosed are tools for installing the shoulder rings in a threaded coupling.

Abstract: A protective pressure-resistant enclosure, or housing is provided, which can be incorporated into a production assembly within a wellbore. A conductor associated with the monitoring system is passed through a bulkhead using a hermetically sealed arrangement wherein fluid cannot pass between the conductor and the bulkhead. In a currently preferred embodiment, the sealed arrangement includes a conductor fitting which surrounds the conductor and forms a first fluid seal between the conductor fitting and the bulkhead. A compression member is then affixed to the conductor fitting. A pair of nested ferrules are disposed between the conductor fitting and the compression member. When the conductor fitting and the compression member are secured to one another, the ferrules are compressed together to form an active fluid seal against the conductor.

Abstract: An expanded non-bonded mesh well screen. A method of manufacturing a well screen includes the steps of: expanding at least a portion of a screen jacket; and then securing the screen jacket onto a base pipe. A well screen system includes a base pipe and an at least partially expanded screen jacket surrounding the base pipe. The screen jacket is expanded prior to being positioned on the base pipe.

Abstract: A low-clearance bow spring centralizer (10) can be made by providing a plurality of bow spring modules (54), each having an elongate rib (52) with a first integrally-formed collar segment (54) at a first end and a second integrally-formed collar segment (56) at a second end wherein the first collar segment (54) and the second collar segment (56) are joined to adjacent first and second collar segments, respectively. The bow spring modules may be interlinked by welding a seam (55) formed between abutting sides of adjacent pairs of first collar segments and/or second collar segments. The sides (54a) of the first collar segment and the sides (56a) of the second collar segment may each be perpendicular to the axis of the centralizer bore, and seams (55) therebetween may be welded to form a first centralizer collar and a second centralizer collar, coupled one to the other by the ribs (52).

Abstract: An expandable tubular member.

Abstract: A technique is employed to shift a well tool located in a wellbore. A shifting tool is moved downhole into proximity with a well tool that is to be shifted. The shifting tool comprises one or more engagement members that enable engagement with any of a variety of well tools having a variety of sizes. A sensor system provides an indication as to when the shifting tool is moved into proximity with a specific well tool.

Abstract: A method of coupling a first control line to a second control line is provided comprising the steps of prepping the first and second control lines to respectively produce a first end and a second end. Prepping may comprise inserting a plug assembly into at least one of the first or second ends prior to facing the end containing the plug assembly. The method may further include butt-welding the first end to the second end to form a splice and providing a protective assembly to cover the splice. The plug assembly may comprise a plug member, a seal, and an end piece to couple the seal to the plug member, in some embodiments. In other embodiments, the plug assembly may comprise a plug member and a seal coupled to the plug member.