Abstract: A packer assembly includes a mandrel and a packing element disposed about the mandrel. Upper and lower recovery sleeves are disposed about the mandrel and extend between the mandrel and respective upper and lower ends of the packing element. The upper and lower recovery sleeves each have a recovery profile embedded within the packing element. Upper and lower backup assemblies are movably disposed about the respective upper and lower recovery sleeves, adjacent to the respective upper and lower ends of the packing element. The packer assembly includes at least one release mechanism. When setting the packer assembly in a bore, the packing element is axially compressed between the upper and lower backup assemblies to contact the bore wall, and the upper and lower backup assemblies splay outwards. Upon release, the packing element and backup assemblies retract, thereby facilitating retrieval of the packer assembly from the bore.

Abstract: An element includes an elastomer having a temperature rating of at least 400° F. for enhanced geothermal system applications. The elastomer element may be manufactured via an additive manufacturing process, and the elastomer element may be a component of an isolation plug assembly having a plurality of structural components that may also be manufactured via the additive manufacturing process.

Abstract: A space-out mechanism that may be used in a tubing hanger system to install a tubing hanger and rigidize the tubing hanger and a casing hanger within a wellhead housing in a single trip is provided. The space-out mechanism may include two pieces that are configured to rotate against each other such that the axial length of the space-out mechanism can be adjusted to remove any axial gaps created in the installation of the tubing hanger or rigidizing of the tubing hanger and casing hanger within the wellhead housing. The two pieces of the space-out mechanism may include a ramp ring and a piston. The ramp ring and piston may each have ramp surfaces that rotate and bear against each other until the system is rigidized.

Abstract: A tubing hanger assembly including an outer hanger body (8) lands on a load shoulder (10) of a tubing head. Additionally, an inner hanger body (9) having at least one inner hanger groove (19) moves vertically up and down with respect to the outer hanger body and engages at least one downhole device. A first latch ring (11) expands into a groove (12) of the tubing head to lock the outer hanger body in position and a sleeve (14) with a plurality of grooves (20) is disposed between the outer hanger body and the inner hanger body of the tubing hanger assembly. Furthermore, a second latch ring (15), disposed between the sleeve and the inner hanger body, expands into or collapse out of the at least one inner hanger groove (19) and the plurality of grooves (20) on the sleeve (14), and the second latch ring (15) is a tension loading support for the inner hanger body.

Abstract: A sealing system includes a housing defining a bore having an internal surface. A rotatable shaft is rotatably disposed in the bore and includes an annular groove disposed in an exterior surface of the rotatable shaft. The annular groove includes a groove bottom and a pair of lateral sidewalls. A seal is formed as a cylindrical annular thermoplastic body having an axial length greater than an axial length of the annular groove and which is bent into a V-shaped cross-section and received in the annular groove so that opposite ends of the seal are disposed in opposite bottom corners of the annular groove. A peak portion of the V-shaped cross section extends radially outward of the annular groove and is engaged with the internal surface of the bore.

Abstract: An isolation tool that is installed in a well by a setting tool to isolate at least a portion of the well. Preferably, the isolation tool is a plug and the plug and setting tool are configured to prevent premature setting of the plug. Preferably, the plug includes one or more portions that directly connect the plug to a setting tool wherein the one or more portions of the plug shear during setting of the plug in an operating position. In a most preferred form, the plug includes first and second longitudinally spaced portions that directly connect the plug to a setting tool wherein the first and second portions shear during setting of the plug in an operating position. In a most preferred form, the plug and setting tool are configured so that no portion of the setting tool shears during the installation of the plug, separation of the plug from the setting tool and removal of the setting tool.

Abstract: An annulus seal for sealing an interface between a wellhead housing and a casing hanger. The annulus seal includes a central body portion, a first seal leg extending from the central body portion in a first direction and a second seal leg extending from the central body portion in the first direction across from the first seal leg. The first seal leg sealingly engages the casing hanger, and the second seal leg sealingly engages the wellhead housing. At least one of the first seal leg or the second seal leg includes at least one of a first cavity at least partially extending into the respective seal leg from the first direction or a second cavity at least partially extending into the respective seal leg from the second direction.

Abstract: Embodiments of a sleeve assembly, used for stimulating multiple stages in a completion string has a lower shifting sleeve and an upper shifting sleeve and stimulation ports formed therebetween. The sleeves are caused to shift by progressively larger objects pumped through a bore of the completion string and engaging seats formed thereon. The seat on the lower sleeve is a releasable seat. When shifted the lower sleeve opens the stimulation ports. The seat on the upper sleeve is sized to accept the same size object as is required to engage and shift the lower sleeve on the stage uphole therefrom to close the ports. Thereby, stimulation ports are opened and closed without increasing a number of objects required to stimulate the wellbore. Further, as the ports at each stage below the stage being stimulated are closed, the objects are not required to isolate the bore therebelow.

Abstract: Provided is a rubber member for downhole tools, of which a decrease rate of 50% strain compressive stress after immersion for 24 hours in 150° C. water relative to 50% strain compressive stress before immersion is not less than 5%, and preferably not less than 50%. The rubber member is suitable for a seal member, ball sealer, ball seat, and a protecting member. Also provided is a downhole tool comprising the rubber member, and a method for recovering a hydrocarbon resource using the downhole tool.

Abstract: The invention relates to an interlock and setting section for a downhole tool system, the interlock and setting section comprising: a shifting profile located within a throughbore of the downhole tool system, wherein the shifting profile is capable of being coupled to by a shifting tool in the throughbore of the downhole tool system, in order to move the shifting profile with respect to the downhole tool system; a load connector member coupled to the shifting profile and further coupled to a load setting member arranged to deliver a load to a tool as required; wherein there is further provided a selective locking mechanism to selectively lock at least the load setting member to at least one of the downhole tool system and the shifting profile.

Abstract: An embodiment of a tubing or casing hanger seal assembly includes a first carrier ring, a first energizing ring coupled to the first carrier ring and configured to set a first seal of the seal assembly in response to the application of a first load to the seal assembly, and a first lock ring configured to secure the first seal to the tubing or casing hanger in response to the application of the first load to the seal assembly, wherein the first carrier ring and the first lock ring include corresponding angled engagement profiles for providing a radial force against the first lock ring relative a central axis of the seal assembly in response to the application of the first load to the seal assembly.

Abstract: A sealing assembly configured to seal within an annulus, the sealing assembly including a support body including a backing ring having a substantially wavy sectional shape, and a plurality of ribs extending radially outwardly from the backing ring; and, a sealing member supported on the support body, the sealing member including a radially exterior sealing component, at least a portion of the radially exterior sealing component disposed between adjacent ribs on a radial exterior surface of the hacking ring, and, a radially interior sealing component disposed on a radial interior surface of the backing portion.

Abstract: A wellhead assembly has a casing hanger for supporting a string of casing, the casing hanger having an external upward-facing shoulder. A radially movable annular lockdown member is carried on the shoulder for movement between a retracted position while the casing hanger is being run and an expanded position. In the expanded position, the lockdown member is in engagement with a lockdown profile shoulder in a wellhead housing. A casing hanger seal is carried by the casing hanger above the lockdown member. The casing hanger seal has a lower extension that includes a connection leg and a nose ring. The nose ring has a cam surface that engages and moves the lockdown member to the expanded position while the casing hanger seal is being lowered into a set position. Slots are formed in the extension to reduce the axial stiffness.

Abstract: A system including a hanger lock system, including a positive lock system, including a load ring configured to engage a first tubular, and a lock ring configured to energize the load ring, a tool including a first piston configured to couple to a second tubular, a second piston configured to couple to the lock ring to energize the load ring.

Abstract: A system including a first tubular, a second tubular configured to rest within a bore of the first tubular, a multi-metal seal system configured to seal a space between the first tubular and the second tubular, wherein the multi-metal seal system includes, a first metal seal portion with a first angled surface and a second angled surface, a second metal seal portion with a third angled surface, and a third metal seal portion with a fourth angled surface, wherein the first angled surface selectively engages the third angled surface at a first angled interface and the second angled surface selectively engages the fourth angled surface at a second angled interface, and wherein the first and second angled interfaces are configured to drive the first metal seal portion radially away from the second and third metal seal portions.

Abstract: In accordance with embodiments of the present disclosure, a seal assembly for sealing and locking a casing hanger to a wellhead includes a lower seal body, an upper seal body connected to the lower seal body, an inner lock ring disposed between the upper seal body and the lower seal body, an external lock ring engaging the upper seal body, and an energizing ring. The lower seal body is structured and arranged to form a seal with the casing hanger and the wellhead. The upper seal body includes a load portion that overhangs a load shoulder of the casing hanger. At least a portion of the energizing ring is disposed within an inner groove disposed within the upper seal body. The energizing ring locks the inner lock ring into forcible engagement with the casing hanger, and locks the external lock ring into engagement with the wellhead.

Abstract: A wellbore system includes a sealing assembly for creating an annular seal between wellbore members. The sealing assembly includes a wicker profile defined a first sealing surface for engaging and embedding into a radially adjacent, second sealing surface. The wicker profile includes a first section having a first hardness and a second section adjacent to the first section and having a second hardness greater than the first hardness. Both the first and second sections of wickers are embedded into the second sealing surface, and can thus provide a high degree of both sealing and lockdown performance.

Abstract: A method of completing a well includes lowering a wellhead onto a base at an upper end of the well. A hub with internal threads and an external circumferential stepped recess is secured to external threads of the wellhead. A blowout preventer assembly with an annular locking member having a plurality of locking elements is landed on the hub, and the locking elements are engaged with the recess of the hub. The well is drilled through the blowout preventer assembly to a greater depth then the blowout preventer assembly and the hub are removed. A threaded flange with a plurality of bolt holes spaced around the flange is secured to the external threads of the wellhead and a wellhead member is bolted to the bolt holes of the threaded flange.

Abstract: A sealing member including a body having a recess; one or more backups extending from the body and tapering over a length thereof; and a sealing element disposed in the recess, the element including one or more steps, each step being adjacent one of the one or more backups and on a surface of the sealing element intended to make contact with a target sealing surface.

Abstract: Embodiments of the disclosure pertain to a mandrel for a downhole tool that may include a body having a proximate end with a first outer diameter and a distal end with a second outer diameter; a first set of threads disposed on the distal end; and a transition region formed on the body between the proximate end and the distal end. In aspects, the mandrel may be made from filament wound composite material.

Abstract: A packer tool has safety devices to prevent premature and reverse setting and release operations. The safety devices are independent of shear-pin safety systems. Confined annular segments prevent a setting actuator piston from moving absent tool-setting hydraulic pressure. The setting pressure first moves a cylinder in an opposite direction to unroof the segments allowing them to exit confinement and free the piston to set the packing and the anchor slips. Release safety pins extend radially inward from a packing-holder collar into short slots formed on a mandrel surface, preventing the mandrel from being turned. Previous set motion causes the pins to leave the slots thereby freeing the mandrel to turn only after the tool has been set. A third safety device comprises an expanded ring which is dragged by the release cone during release motion until it lodges in a circumferential groove in the mandrel, locking against reverse movement.

Abstract: A plug for sealing a conduit. The plug comprises a housing, a setting member, at least one anchor and at least one seal element. Rotation of the setting member with respect to the housing in a setting direction sets the at least one anchor and the at least one seal element.

Abstract: A setting tool comprises a slow stroke mandrel configured for engagement with an inner mandrel of a packer; a latching member configured to provide a releasable engagement between the setting tool mandrel and the inner mandrel of the packer; a centralizing member, wherein the centralizing member is slidingly disposed about the setting tool mandrel; a collet coupled to the centralizing member, wherein the collet is configured to engage the slow stroke mandrel; a driving member comprising a piston, wherein the piston is coupled to the centralizing member; a setting sleeve coupled to the centralizing member, wherein the setting sleeve is configured to engage a packer setting sleeve shoulder of the packer. The engagement between the collet and the slow stroke mandrel is configured to control the stroke speed of the setting sleeve when the piston is selectively energized.

Abstract: A downhole tool includes a first portion having a first metal protrusion configured to seal against a first metal surface and a second portion having a second metal protrusion configured to seal against a second metal surface. A ratcheting device includes a first element having a plurality of grooves, and a second element having at least two sets of teeth, wherein one of the at least two sets of teeth engages the plurality of grooves. Additionally, a method of forming a downhole seal includes disposing in a wellbore a downhole tool including an inner tubular, a lock ring, a lower ring, an upper ring, an insert ring, and a deformable element. The method further includes moving a wedge sleeve axially downward with respect to the downhole tool such that the wedge sleeve engages the deformable ring and forces a first metal protrusion on the deformable element into contact with an outer tubular.

Abstract: Through the combination of at least two polymer families, and the optimization of other components, a rubber compound has been developed for use in downhole applications that will swell in water-based fluids. A cellulose component, such as carboxy methyl cellulose (CMC), is used together with an acrylate copolymer (AC) that can increase the swelling capacity of an acrylonitrile butadiene rubber (NBR) in water. The amount of swelling achieved depends on physical boundaries and limitations, the salinity of the water, and the temperature.

Abstract: An isolation tool for use in a tubular. The isolation tool comprising gripping members and sealing members to engage and seal the isolation tool to an inner wall of the tubular at a desired location in the tubular. The isolation tool further comprising a locking system that allows the isolation tool to be set in a desired position within the tubular. The locking system prevents the isolation tool from any further movement which would unset it from the desired position.

Abstract: Devices and methods for setting a packer inside a wellbore with little appreciable reduction of the useable area of the wellbore. The outer casing or liner of the wellbore contains one or more integrated casing coupler joints having an increased diameter chamber portion. A large bore packing element is carried within the increased diameter chamber portion. The packing element may be selectively actuated to form a seal against an interior tubular member. Because the packing element is located within the chamber portion of the casing coupler, the packer may be set while saving useable cross-sectional area within the casing.

Abstract: An actuation assembly (100, 300) for actuating a downhole tool (200) having a tool housing (202) and an actuation member (208). The actuation assembly (100, 300) includes a downhole power unit (100) and a stroke extender (300). A power unit housing (150) is operably associated with an extender housing (302). A moveable shaft (130) of the power unit (100) is operably associated with an extender mandrel (304). The extender housing (302) is operably associated with the tool housing (202) and the actuation member (208). The extender mandrel (304) is operably associated with the actuation member (208) such that oscillatory movement of the moveable shaft (130) relative to the power unit housing (150) causes oscillatory movement of the extender mandrel (304) relative to the extender housing (302) which causes progressive movement in one direction of the actuation member (208) relative to the tool housing (202), thereby actuating the downhole tool (200).

Abstract: An anchoring device for tool is disclosed that can be positioned downhole and used in casing. The anchoring device can have an architecture that supports installation by running downhole and into engagement with a recess formed in the casing. The anchoring device can support the use of weak materials such as plastic.

Abstract: A high capacity running tool sets and internally tests a casing hanger packoff during the same trip. The running tool has a stem and a body. The body is secured by threads to the stem of the running tool so that rotation of the stem relative to the body will cause the stem to move longitudinally. An engagement element connects the tool body to the casing hanger by engaging the inner surface of the casing hanger. Longitudinal movement of the stem relative to the body moves the engaging element between inner and outer positions and lines up ports in the stem and in the body for setting and testing functions.

Abstract: Plug assemblies such as sealing devices comprise a vent tube disposed above the sealing device. The vent tube is selectively place in, and out of, fluid communication with a lower zone of a wellbore so that during curing of cement or other sealing material disposed on top of the sealing device, gas is permitted to flow from the lower zone to the surface of the wellbore. As a result, the likelihood of gas corrupting or otherwise leaking around the interface of the sealing element with the wall of the wellbore is decreased. After the cement has cured, fluid communication between the vent pipe and the lower zone is closed to isolate the lower zone from the upper zone disposed above the sealing device.

Abstract: A tubing string assembly is disclosed for fluid treatment of a wellbore. The tubing string can be used for staged wellbore fluid treatment where a selected segment of the wellbore is treated, while other segments are sealed off. The tubing string can also be used where a ported tubing string is required to be run in in a pressure tight condition and later is needed to be in an open-port condition.

Abstract: A well tool with multi-stage remedial system improves the durability of a subterranean well tool having an expanded elastomeric member, such as a packer, for use inside a tubular member. The well tool with multi-stage remedial system has a plurality of mandrel members shiftable within the tubular member for anchoring and for setting the seal system. A floating tandem mounted annularly around the lower mandrel members has one end (upon shifting) proximate an end of the seal system, and the floating tandem has an opening to ambient bottom-hole-pressure of the subterranean well. A locking tandem is interposed with the floating tandem and at least one of the lower mandrel members. The floating tandem and the locking tandem together assist in abating elastomeric member extrusion under high temperature, high pressure environments as well as other conditions lending to failure within the well.

Abstract: The present invention relates to an arrangement for affixing an expandable packer 22, 32 in a hole 30, wherein the arrangement includes a piston-and-cylinder device 11, 12 with which the piston can be caused to move in the cylinder with the aid of a pressurized medium. Expansion of the packer is effected with the aid of the movement of the piston 11, by transferring the force generated by piston movement to an expandable part 24, 34 of the packer 22, 32 so that said part will expand. Expansion of the packer results in the packer being firmly affixed in the hole by means of friction. The arrangement also includes an elongate main body 1 that has a through-penetrating aperture extending in the longitudinal direction of the body. The main body 1 has a front end 3, which faces inwardly of the hole when fastening the packer and towards the packer.

Abstract: Embodiments of the present invention generally relate to an adapter kit for use between a setting tool and a wellbore plug. In one embodiment, a method for setting a plug in a cased wellbore is provided. The method includes deploying a tool string in the wellbore using a run-in string, the tool string comprising: a setting tool coupled to the run-in string, an adapter kit, comprising an adapter sleeve, and a plug comprising a sealing member. The method further includes actuating the setting tool, wherein the setting tool exerts a force on the adapter sleeve which transfers the force to the plug, thereby expanding the sealing member into engagement with an inner surface of the casing. The method further includes separating the setting tool from the plug, wherein the adapter sleeve remains with the plug.

Abstract: A plug (10) for sealing a conduit is described. The plug comprises a housing (42), a setting member (14), at least one anchor (16) and at least one seal element (18). Rotation of the setting member with respect to the housing in a setting direction sets the at least one anchor and the at least one seal element.

Abstract: A wellhead seal assembly forms a metal-to-metal seal between inner and outer wellhead members. A metal seal ring has inner and outer walls separated by a slot. An energizing ring has a C-ring captured on its outer surface. When the energizing ring is moved farther into the slot, the C-ring is forced from its pocket and engages a profile on the seal ring, locking the energizing ring to the seal assembly.

Abstract: A system and method for perforating and fracturing enables sealing device on a working string to be actuated to substantially block passage of fluids through the wellbore. Without removing the working string from the wellbore, the working string is released from the sealing device, the wellbore is perforated, and the wellbore pressurized up-hole of the sealing device to fracture the wellbore.

Abstract: Devices and methods for setting a packer inside a wellbore with little appreciable reduction of the useable area of the wellbore. The outer casing or liner of the wellbore contains one or more integrated casing coupler joints having an increased diameter chamber portion. A large bore packing element is carried within the increased diameter chamber portion. The packing element may be selectively actuated to form a seal against an interior tubular member. Because the packing element is located within the chamber portion of the casing coupler, the packer may be set while saving useable cross-sectional area within the casing.

Abstract: A zonal isolation device comprises a packer assembly and an internal setting mechanism operable to actuate the packer assembly from an unset position to a set position, wherein the zonal isolation device is resettable and retrievable. Another zonal isolation device comprises a packer assembly, a setting mechanism operable to actuate the packer assembly from an unset position to a set position in response to hydraulic pressure alone, and a locking mechanism operable to lock and unlock the packer assembly from the set position in response to hydraulic pressure alone. A method for setting a zonal isolation device within a well bore comprises running the zonal isolation device in an unset position within the well bore on a work string, applying a differential pressure between the work string and the well bore, and actuating the zonal isolation device to a set position in response to the differential pressure alone.

Abstract: A tool that is easily convertible from a frac plug to a bridge plug is disclosed. The tool comprises a mandrel with a mule shoe connected to the lower end thereof. A closing ball is disposed in a cavity defined by the mule shoe. The mandrel is threaded to receive a plug at or near the upper end thereof to convert the frac plug to a bridge plug.

Abstract: Bridge plug and setting assembly may be used in a well with a tubular therein to control flow through the tubular. A plurality of fluid powered units 16, 24 are suspended in a well from a work string 14 for exerting a driving force. A plug member 50 is suspended below the plurality of fluid powered units. The plug member 50 is axially movable relative to an expansion sleeve 40 in response to the driving force to radially expand the sleeve 40 into sealing engagement with both the plug member 50 and the tubular 12. A release mechanism 68 is provided for releasing the one or more fluid powered units from the plug member and the expansion sleeve once set in the well.

Abstract: A system and a method for installing a liner conduit in a borehole. The system includes a packer assembly, a running tool or a packer assembly and a running tool. The method uses a packer assembly and a running tool for installing a liner conduit in a borehole. The system and the method both use pressure to perform functions relating to the system and the method.

Abstract: Various embodiments of an improved downhole disconnect tool are provided, some of which may include a first housing releasably connected to a second housing, a first piston releasably connected to the first housing, and a second piston releasably connected to the second housing. Various fluid communication ports and ball seats may be provided in various combinations in the first and second pistons and in the second housing to enable remote control of the tool by circulating one or more balls into engagement with one or more of the ball seats to disconnect the first housing from the second housing, and thereby disconnect any structures connected to the first and second housings, respectively. Other features and aspects of the invention are also provided.

Abstract: The present invention relates to an apparatus and method for isolating a wellbore condition such as formation pressure during a wellbore operation. The invention has particular application in connection with underbalanced drilling. In one arrangement, a formation isolation apparatus is provided that serves as a selectively actuatable plug. The plug in one aspect is selectively set and released by a setting/releasing tool. The setting/releasing tool includes a system for setting the plug in the wellbore, and a system for releasing the plug from the wellbore. The setting/releasing tool is releasably connected to the plug. Thus, after the plug has been set, the setting/releasing tool may be removed from the wellbore. The plug includes a flapper valve that is restrained in its open position by the setting/releasing tool. Removal of the setting/releasing tool from the wellbore allows the flapper valve to close, thereby isolating pressures in the wellbore below the flapper valve. The plug is wireline retrievable.

Abstract: Various embodiments of an improved downhole disconnect tool are provided, some of which may include a first housing releasably connected to a second housing, a first piston releasably connected to the first housing, and a second piston releasably connected to the second housing. Various fluid communication ports and ball seats may be provided in various combinations in the first and second pistons and in the second housing to enable remote control of the tool by circulating one or more balls into engagement with one or more of the ball seats to disconnect the first housing from the second housing, and thereby disconnect any structures connected to the first and second housings, respectively. Other features and aspects of the invention are also provided.

Abstract: The present invention is to a pre-selected set of packer tools having J tools and on/off tools (“stingers” and “washovers”) with varying strokes and varying set and release directions to enable the operator to individually address the various packers. By increasing the amount of travel necessary to set and/or release the subsequent packer tools, it is possible to select which tool is being manipulated or operated upon.

Abstract: A latching assembly for a lower collar on an inflatable is provided. After deflation, the lower collar is engaged to the mandrel so that the deflated inflatable can be advanced with other connected downhole equipment, such as screens to be expanded, in a location further downhole without swabbing.

Abstract: A hydrostatically set packer is disclosed. The actuating piston is locked for run in by a lock sleeve and lock dog arrangement. When the desired depth is reached well pressure is built up to break a rupture disc to allow hydrostatic pressure to act on one side of a lock sleeve. The other side of the lock sleeve is exposed to a chamber under atmospheric or low pressure. Movement of the lock sleeve releases the lock dog allowing piston movement to set the packer. The lock sleeve has a labyrinth seal so that seal leakage below a predetermined level will not prematurely activate the piston lock and prematurely set the packer. A variety of designs for the labyrinth are described.

Abstract: Disclosed is a system for using pressure differential between completion fluid in an oil well and produced fluids to power downhole devices, including instruments and actuators. A conduit is provided bypassing a packer which seals a production string to a well casing. A control system, including a flow valve, allows fluid to flow to an electrical generator as needed to charge an electrical storage device. Downhole electrically operated devices, e.g. a temperature sensor and signal transmitter, draw power from the storage device. Alternatively, fluid may also be directed to hydraulically driven actuators to, for example, operate a production fluid control valve.