Abstract: A steering tool system may provide a bottom hole assembly (BHA) and a surface control/interface (SCI). The steering tool may provide an improved electronic schematic that provides a data line that is separate from the power line. The BHA may provide a full bore flow path. The connectors of a cablehead section may be designed to ease make up with proper contact to the connectors. The BHA may also be suitable for pumping a ball to a hydraulic disconnect. The design of the system allows conductors to pass through the hydraulic disconnect and orienter control section.

Abstract: A downhole sealing apparatus includes a cup sealing assembly defining a central bore to permit mounting on a mandrel. At least a portion of the cup sealing assembly is configured to be rotatably coupled to a mandrel. Such a downhole sealing assembly may be millable when in situ.

Abstract: A down-hole packer is provided for positioning in a wellbore to establish a seal with a surrounding surface. The packer includes a sealing element that is responsive to compression by a setting piston to radially expand into the wellbore. An actuator is provided to longitudinally move the setting piston in response to a telemetry signal received by the down-hole packer. The actuator can include a hydraulic pump, an electromechanical motor or valves operable to control hydraulic energy to apply a down-hole force to the setting piston.

Abstract: A sensing and communication system for a gas lift well is provided. The gas lift well includes a casing, production tubing positioned within the casing, and a gas lift valve coupled to the production tubing. The sensing and communication system includes a turbine configured to rotate in response to an injected gas stream flowing through the turbine, wherein the turbine is positioned one of i) within an annulus defined between the production tubing and the casing and ii) within the gas lift valve, an alternator coupled to the turbine and configured to generate electrical power from rotation of the turbine, and at least one sensor coupled to the alternator and configured to operate using the generated electrical power.

Abstract: A loss mitigation bottom hole assembly for use in a wellbore to isolate a severe loss zone of a formation, including a drill bit for drilling a well bore, and a dual wall drill string connecting the drill bit to a fluid source, and having a first fluid passage for delivering fluid to a drill bit, and a separate second fluid passage for returning the fluid away from the drill bit. The assembly further includes a drilling liner circumscribing and attached to a bottom portion of the dual wall drill string, and surrounding the drill bit, the drilling liner having an end adjacent the drill bit to contain the fluid exiting the drill bit and prevent the fluid from entering the severe loss zone of the formation.

Abstract: A technique facilitates deployment and operation of actuatable plugs, e.g. frac plugs or bridge plugs. According to one embodiment, the plug comprises a flexible element slidably mounted on a portion of a cone, e.g. an upper cone. The upper cone comprises a tapered surface which works in cooperation with upper slips movably secured to the upper cone. The bridge plug also comprises a lower cone which comprises a lower tapered surface which works in cooperation with lower slips movably secured to the lower cone. Depending on the application, the plug may be constructed with each of these features combined into an overall assembly or with a portion of these features to facilitate plug operation in a specific environment and operation.

Abstract: A centralizer comprises a plurality of bow springs, wherein each bow spring has a first and second end. A first collar is coupled to the first end of each of the plurality of bow springs and includes a longitudinal frangible region. A second collar is coupled to the second end of each of the plurality of bow springs and also includes a longitudinal frangible region.

Abstract: A treatment tool can include a housing with longitudinal passages, a valve that controls flow between sections of one passage, another valve that controls flow between the one passage and a section of another passage, and a locking device that prevents the first valve from being transitioned to an open configuration from a closed configuration. A method can include flowing a fluid through a passage of a service string and into an annulus about a screen, the fluid entering the screen and flowing to another annulus via another passage of the service string, then installing a plug in the first passage, thereby preventing flow through the first passage to the annulus about the screen, and creating at least one pressure differential across the plug, thereby preventing flow from an interior of the screen to the other annulus and permitting flow from the first passage to the screen interior.

Abstract: An anchoring device includes at least one slip configured to fixedly engage the anchoring device to a structure when urged against the structure, and a member separate from the at least one slip positioned radially of the at least one slip having a portion that is radially deformable in response to longitudinal compression, the portion being configured to urge the at least one slip against the structure when deformed.

Abstract: This invention relates to an activating tool (1) for connecting to and displacing a component (40) in a well tube (4), activating tool (1) includes a driving device (8) axially displaced in two axial directions; a sleeve-shaped release element (14) with an annular end portion (52); a gripper holder (20) arranged axially displaceable in release element (14) and displaced by driving device (8); axially longitudinal recesses (24) in gripper holder (20); at least two radially displaceable gripping elements (26) spring-biased in a radial outward direction, positioned in respective recesses (24) and complementarily fitting respective cut-outs (42) in the component (40), and each gripping element (26) has a slanted rear portion (48); gripping elements (26) retracted into release element (14) in passive positions of gripping elements (26), and gripping elements (26), at least partially, displaced out of release element (14) in active positions of gripping elements (26) so end portion (52) hits slanted rear portions (

Abstract: A downhole actuator device comprises a central shaft formed with external threads; a sleeve formed with internal threads and placed substantially concentrically around the shaft; and an electromotor arranged to rotate at least a first one of said shaft and said sleeve so that a second one of said shaft and said sleeve may be moved linearly relative to the first one of said shaft and said sleeve. The actuator further comprises a plurality of roller screws that are rotatingly supported between the shall and sleeve in engagement with said external threads on the shaft and said internal threads on the sleeve.

Abstract: The present disclosure is directed toward a downhole tool used to free stuck tools in a wellbore and the method of using the downhole tool. The downhole tool includes at least one packer element for engaging a casing in a wellbore. The packer works to isolate one area of the casing from another. The downhole tool also includes at least one slip element for engaging the casing to maintain the position of the downhole tool in the casing or wellbore. Further, the downhole tool includes a mandrel slidably disposed within the at least one packer element and the at least one slip. The mandrel includes at least one port disposed therein above the at least one packer element when the mandrel is in a first position.

Abstract: Downhole stimulation tools include a housing and at least one propellant structure within the housing comprising at least one propellant grain of a formulation, at least another propellant grain of a formulation different from the formulation of the at least one propellant grain longitudinally adjacent the at least one propellant grain, and at least one initiation element proximate at least one of the propellant grains. At least one pressure containment structure is secured to the housing and comprises a seal element expandable in response to gas pressure generated by combustion of a propellant grain of the at least one propellant structure. Related methods are also disclosed.

Abstract: In one example a tool is provided, having a body configured to expand from a first diameter to a second diameter, an outer covering for the body, the outer surface having at least one inlet to accept fluid through the outer covering into the body, the outer covering to outer proximate ends and at least two anti-creep rings abutting the outer covering at each of the outer proximate ends, wherein the anti-creep rings constrain the outer covering from movement.

Abstract: An in-well type production device includes a tubing having a center bore. A valve is carried by the tubing and configured to control flow between the center bore and an exterior of the tubing. An electronic controller is carried by the tubing and is in communication with the valve. The controller has a timer and is configured to operate the valve after a specified time period.

Abstract: A well screen assembly includes a valve configured to control flow between the interior and exterior of the well screen assembly, and in certain instances control flow through a flow control device (e.g., inflow control device and/or other). The valve can be operated in response to a signal detected by an in-well sensor.

Abstract: A seal assembly for establishing a seal in an annulus between a mandrel and a bore wall includes a mandrel, a radially expandable seal element mounted on the mandrel, and a setting arrangement mounted on the mandrel and being arranged to displace the seal element radially outwardly from a retracted configuration to an extended configuration. The expandable seal element defines a cup seal when in the extended configuration.

Abstract: A fracturing system including a plug having a solid mandrel preventing fluid flow therepast when set. A setting tool in operable communication with the plug; and a perforating gun disposed adjacent to the setting tool. A method for fracturing a formation.

Abstract: An embodiment of a gripping arrangement includes a mandrel having an axially extending groove therein, a first slip ring about the mandrel, a first cone about the mandrel spaced from the first slip ring, and a key engaged with the groove such that the key is axially movable and rotationally fixed relative to the mandrel. The key is disposed to maintain the spacing between the first slip ring and the first cone. The gripping arrangement also includes a release feature releasably interconnected with the key and method.

Abstract: A cement retainer comprises a plug that may be run into casing on a wire line and set in a conventional manner. A passage through the plug allows cement to be pumped therethrough. A wiper plug follows the cement, wipes the inside of the casing and latches onto the retainer to prevent back flow of cement. In some embodiments, the cement retainer and wiper plug are made of drillable materials allowing a series of squeeze operations to be conducted, one after another without undue delay, and then be drilled up in a single bit run. In some embodiments, the cement retainer and wiper plug are made of metals, drillable or non-drillable, or other long lived materials in order to plug wells in the process of abandoning them.

Abstract: Certain aspects are directed to tools for setting production packers or actuating other downhole tools in response to activation signals received via an electrical control line within the wellbore. In one aspect, a downhole assembly for a wellbore is provided. The downhole assembly can include a reservoir and a pressuring module in fluid communication with the reservoir. The reservoir can contain a control fluid in communication with a fluid control path of a downhole tool. A quantity of the control fluid can be transmitted via the fluid control path for actuation of the downhole tool. The quantity of the control fluid can be controlled using a pressure change in the control fluid. The pressure change in the control fluid can be caused by the pressurizing module in response to an activation signal received by the pressurizing module via an electrical control line coupled to the pressurizing module.

Abstract: An apparatus for supporting tubing in casing includes a setting tool and a liner top packer, which can be used for tieback. A setting slip is disposed uphole of a packing assembly on the packer and is movable from a retracted to an extended state engaging the casing. The setting tool has a temporary connection to the packer and has a pack-off that seals the tool in the packer but allows for movement. After running downhole, the temporary connection of the setting tool to the packer is disconnected, and the setting slip is set in the casing by moving the setting tool in an uphole direction. To set the packing assembly, the packer is moved in the uphole direction by engaging the setting tool with the pack-off and compressing the packing element (e.g., packing element and opposing cones and slips) against the set setting slip. Eventually, the setting tool is disconnected from the packer by disengaging the pack-off.

Abstract: A method and apparatus for removing debris from a wellbore using a cleaning tool. The tool may comprise an inner mandrel and a cup member coupled to the inner mandrel. The cup member is moveable between a collapsed position where fluid may flow across the exterior of the cup member, and an extended position where fluid is diverted into a flow path disposed between the inner mandrel and the cup member. The fluid is diverted through a filter member that is coupled to the inner mandrel below the cup member.

Abstract: A single element hydraulic open hole packer is provided. A method is provided for multistage isolation and fluid treatment of a borehole, in which a first frac valve tool and a second frac valve tool are provided, a first packer is mounted downstream from the first frac valve tool, a second packer is mounted between the first frac valve tool and the second frac valve tool, a third packer is mounted upstream from the second frac valve tool, at least one of the first, second and third packers being a hydraulic set packer having a single packing element, the first frac valve tool being moveable between a closed and an open position, the second frac valve tool moveable between a closed and an open position; running the liner into a wellbore; hydraulically setting the single element packers; conveying means for moving the first frac valve tool to the open position; and forcing stimulation fluid out through the first frac sleeve tool.

Abstract: A system including a mineral extraction system, including a hanger, and a dual lock system configured to couple the mineral extraction system component to a tubular, wherein the dual lock system comprises an outer lock ring and an inner lock ring.

Abstract: A collet lock assembly for use on a downhole tool allows repeat cycling of a “RELEASE” and “SET” position. In the “RELEASE” position, the collet lock assembly allows bi-directional relative movement of the mandrel in relation to the collet lock assembly, while in the “SET” position, the assembly allows bi-directional load transfer along the mandrel directly into the slip assembly while diverting axial loads away from components positioned along the downhole tool.

Abstract: A lock open device for a running tool including a mandrel, the device including a collar located on the mandrel of the running tool and having an open position profile and a slot comprising a rotational travel section and an axial travel section. The lock open device also includes a top plate having a cog configured to engage with the open position profile to restrict the collar from relative rotation and a can including a pin configured to engage with the collar slot, in which the collar is rotatable upon overcoming a resistance of the top plate such that the pin is located in the axial travel section, allowing axial movement of the collar relative to the can.

Abstract: A handle assembly includes a handle, a handle seal recess, and a hub engaging portion. A hub has a lock receiving surface and a handle engaging portion. A shaft is receivable within the hub and has first and second ends, the first end engaged with the handle, and the second end rotatable by rotating the grasping portion of the handle. A V-ring is disposed within the handle seal recess and engages the hub to prevent moisture ingress between the handle and the hub. The hub has a seal recess and an X-ring and an O-ring disposed therein to seal against the shaft to prevent moisture ingress between the hub and the shaft. Axial pressure applied to the O-ring by the hub engaging portion of the handle causes the O-ring to press against the X-ring to force at least one lobe of the X-ring against the central portion of the shaft.

Abstract: A packer for use in a wellbore includes a packer mandrel. First and second pistons are slidably disposed about the packer mandrel defining first and second chambers therewith. A first activation assembly initially prevents movement of the first piston. A second activation assembly initially prevents movement of the second piston. A seal assembly is disposed about the packer mandrel between the first and second pistons such that actuation of the first activation assembly allows a force generated by a pressure difference between the wellbore and the first chamber to shift the first piston in a first direction toward the seal assembly to radially expand the seal assembly and actuation of the second activation assembly allows a force generated by a pressure difference between the wellbore and the second chamber to shift the second piston in a second direction toward the seal assembly to radially expand the seal assembly.

Abstract: Apparatuses and methods for operating a downhole tool are disclosed. A downhole tool configuration device includes an upper stem movable between an up position and a down position. The upper stem comprises an extended portion. An outer sleeve is selectively coupleable to the upper stem at the up position and the down position and an inner sleeve is selectively coupleable to the upper stem at the up position and the down position. In the up position, the upper stem is operable to transfer tension to the outer sleeve and torque to the inner sleeve. In the down position, the upper stem is operable to transfer torque to the outer sleeve.

Abstract: An apparatus for activating a wellbore tool includes a cylinder, a shaft, and a pressure dissipater. The cylinder has a first inner surface defining a smooth bore section and a second inner surface adjacent to the first inner surface. The shaft has a piston section that includes at least one seal forming a fluid seal with the first inner surface when the seal is at a nominal diameter. The pressure dissipater is formed along the second inner surface of the cylinder, the pressure dissipater contacts and physically destabilizes the at least one seal after the at least one seal exits the smooth bore section.

Abstract: A well bore packer includes a packer element and an anti-extrusion backup system disposed on a mandrel and located within a well bore wall. Packer element includes longitudinally spaced end regions and a central region. The backup system includes an anti-extrusion device adjacent each of the end regions. The devices each include a collar and a flexible wire mesh mat. The packer element and devices have a smaller diameter configuration before the packer element is expanded. When the packer element is expanded to seal its central region against the well bore wall, the expansion of the packer element activates or deploys the devices and expands the mats to reach between the mandrel and the wall to resist longitudinal extrusion of the packer element.

Abstract: A time actuated element includes a mandrel, a housing coupled to the mandrel, the housing defining a fluid expansion chamber. A piston is positioned within the fluid expansion chamber. A thermally expanding fluid is positioned within the fluid expansion chamber. An end ring coupled to the piston slides along the mandrel in response to a sliding of the piston. A packer having a first end and a second end, the first end adapted to slide along the mandrel in response to a sliding of the end ring, and the second end fixedly coupled to the mandrel, so that a sliding of the first end of the packer toward the second end causes the packer element to decrease in length and increase in radius.

Abstract: In a fracturing application a packer for a given zone to be fractured is reinforced during fracturing with an insert that is preferably a sleeve. During times of high collapse pressure loading, the sleeve provides the needed support. When fracking is over the liner sleeve is caused to disappear. The preferred material is controlled electrolytic materials but other materials that can disappear when the anticipated loading is diminished can also be used. The disappearing can be motivated chemically or thermally among other contemplated methods. As a result, there is a larger available bore when production is ready to start.

Abstract: A pulling tool for latching onto an object, such as a plug, downhole in a wellbore includes a base element extending in a longitudinal direction from a proximal end for being connected to a wireline tool to a distal end adapted to engage the object, and a latching mechanism encircling the base element and being movable in the longitudinal direction between a deactivated position and an activated position, having a piston sleeve, a key element for latching onto the downhole object, the key element being slidably received inside the piston sleeve and extending from an end of the piston sleeve towards the distal end of the base element, and a piston spring forcing the piston sleeve in the longitudinal direction towards the proximal end of the base element.

Abstract: A method of constructing a packer assembly can include installing a body lock ring on a mandrel, and then outwardly surrounding the body lock ring with a structure displaceable relative to the mandrel by a setting mechanism. A packer assembly can include a setting mechanism which displaces a structure relative to a mandrel, and a mandrel lock device which permits one way displacement of the structure relative to the mandrel, the mandrel lock device including a body lock ring and a bias sleeve which urges the body lock ring into gripping engagement with the mandrel, the bias sleeve and the structure being separate elements of the packer assembly. The bias sleeve can be secured against rotation relative to the mandrel while the structure is rotatable relative to the mandrel.

Abstract: An apparatus for suspending a liner within a bore comprising a central tubular member and first and second sets of radially expandable arms. Each set of arms are expandable by corresponding longitudinally movable cones spaced apart along the tubular member. The apparatus further includes a seal located between the first and second sets of radially expandable arms and a selectably longitudinally compressible sleeve located between the first and second sets of radially expandable arms.

Abstract: A test packer is lowered to a set liner hanger in a locked position that prevents the seal and slips from setting during running in. A first ball is dropped to shift a sleeve to release the grip of dogs to a groove on an outer housing. Setting down weight sets the test packer seal and sets the slips. After the casing integrity pressure test is done the test packer is lifted to again position the groove in the outer housing by the dogs. A second ball lands on the same seat now enlarged due to earlier movement and breaks a retainer on a locking sleeve. A spring return or continued downhole motion of the locking sleeve locks the packer in the run in position. Subsequent rotation and circulation can take place as completion fluid is circulated in. A circulation port above the packer can be opened optionally for circulation or reversing above the test packer.

Abstract: A temperature actuated element includes a mandrel, a housing coupled to the mandrel, the housing defining a fluid expansion chamber. A piston is positioned within the fluid expansion chamber. A thermally expanding fluid is positioned within the fluid expansion chamber. An end ring coupled to the piston slides along the mandrel in response to a sliding of the piston. A degradable ring is coupled to the mandrel to prevent movement of the end ring before the degradable ring is dissolved. A packer having a first end and a second end, the first end adapted to slide along the mandrel in response to a sliding of the end ring, and the second end fixedly coupled to the mandrel, so that a sliding of the first end of the packer toward the second end causes the packer element to decrease in length and increase in radius.

Abstract: A barrier assembly for use with a downhole pump includes a first tubular adapter, a second tubular adapter, and a braided sleeve disposed between the first tubular adapter and the second tubular adapter. The sleeve is configured to block passage of a particulate.

Abstract: A packer assembly is located in a compacted wellbore and a method of relieving compression on the packer assembly are disclosed. An initial load path that exists when the packer assembly is in a set position is altered. The alteration of the load path relieves substantially all of the compression on the packer assembly. This causes a lower packer mandrel to move towards an upper packer mandrel. This upward movement shortens the distance between the upper packer mandrel and the lower packer mandrel, which removes the compressive forces on the packer assembly.

Abstract: Anti-extrusion devices, packer elements, and inflatable packers include shape memory polymer (SMP) materials to enhance the operation of a packer, a bridge plug, or other downhole isolation tool. Seal system use seals of various material including SMP materials as booster for the seal produced. Tool for flow shut-off and sliding sleeve applications use SMP materials to open or close off flow through a tool.

Abstract: The present invention relates to a plugging device (1) comprising a housing (10), a packer device (2), a first supporting assembly (3) supporting a first side (2a) of the packer device (2) in the expanded state and a second supporting assembly (4) supporting a second side (2b) of the packer device (2) in the expanded state. The packer device (2) is provided circumferentially around the housing (10); where the packer device (2) is configured to be provided in a retracted state and an expanded state, where the radial radius (R2) of the packer body (20) in the expanded state is larger than the radial radius (R1) of the packer body (20) in the retracted state. The packer device (2) comprises a packer body (20) and a supporting device (30) for supporting the packer body (20) in the expanded state.

Abstract: A wear bushing (10) and a running tool (32) are provided for a subsea wellhead assembly including a wellhead housing and a casing hanger. The wear bushing is landed on the casing hanger, and a connector (16) axially connects the wear bushing and the wellhead housing. The running tool is actuated to connect the wear bushing, such that at least a portion of the connector is received within a corresponding recess in an interior wall of the wellhead housing. A bushing/casing hanger latch (18) axially connects the wear bushing and the casing hanger.

Abstract: Opposed cones for slips on a packer have an annular undercut in general alignment with the end of the cone that has the slip ramp. The undercut faces the mandrel on which the cones can be driven together to radially extend the slips. A high modulus insert sleeve is interference fitted to the undercut. This results in the cone exterior surface being in hoop stress tension before the slips are set. Once the slips are set and a reaction load comes radially back from the surrounding tubular into which the slips have extended there is a tendency for the reaction force to put the exterior surface of the cones into compressive hoop stress. The initial tensile hoop stress from the sleeve placement acts to at least in part offset the reaction force tending to create compressive hoop stress. The net loading and deflection of the mandrel is minimized.

Abstract: The present disclosure is directed toward a downhole tool used to free stuck tools in a wellbore and the method of using the downhole tool. The downhole tool includes at least one packer element for engaging a casing in a wellbore. The packer works to isolate one area of the casing from another. The downhole tool also includes at least one slip element for engaging the casing to maintain the position of the downhole tool in the casing or wellbore. Further, the downhole tool includes a mandrel slidably disposed within the at least one packer element and the at least one slip. The mandrel includes at least one port disposed therein above the at least one packer element when the mandrel is in a first position.

Abstract: Disclosed herein is a segmented seat for use in wellbore servicing systems, comprising an annular-shaped seat with an upward facing surface for receiving an obturator, the seat defining a central passageway. The segments are locked together at their faces by protrusions and matching recesses.

Abstract: A segmented seat adapted to be placed in subterranean wellbore equipment and engaged by an obturator. The segmented seat includes an annular body that is radially divided into a plurality of separate segments, the annular body defining a central bore extending axially therethrough, a generally cylindrical outer wall, and an end wall; an annular seat formed on the end wall and extending about the central bore of the annular body, the annular seat being of a size and shape to engage the obturator; at least one recess formed into each of the segments and offset from the outer wall of the annular body so that at least a portion of the annular body is located radially between the outer wall and the recess; and a non-metallic material disposed within the recess and joining adjacent segments together.

Abstract: A well tool for sealing an annular gap between a tubing string and a wellbore wall is described. In one implementation, the well tool includes an annular inner seal, an annular sleeve disposed over the inner seal, an annular outer seal residing over the sleeve and comprising a swellable elastomer adapted to swell when contacted by a specified fluid, the annular outer seal being axially shorter than the sleeve, and an end ring adapted to be disposed at an end of the sleeve, the sleeve configured to buckle against the end ring in response to a deformation of the outer seal due to directional pressure.

Abstract: A device and method allow a longer sealing element to be used on a packer or other downhole tool while providing an increase in the total amount of setting force that can be used and providing for more uniform or balanced setting of the sealing element. The packer may be first set using internal bore pressure to radially expand one end of the sealing element with a first hydraulic setting mechanism. The packer may then be set a second time using annulus pressure to continue the radial expansion of the sealing element with a second hydraulic setting mechanism.