Abstract: A kickover tool for retrieving a used gas lift valve installed within a gas lift mandrel connected along a wellbore tubular string and installing a new gas lift valve within the gas lift mandrel. The kickover tool may include a housing, a first holder configured to hold the used gas lift valve, a first displacement mechanism operable to move the first holder between a retracted first holder position in which the first holder is adjacent the housing and an extended first holder position in which the first holder is spaced away from the housing, a second holder configured to hold the new gas lift valve, and a second displacement mechanism operable to move the second holder between a retracted second holder position in which the second holder is adjacent the housing and an extended second holder position in which the second holder is spaced away from the housing.

Abstract: A wellbore whipstock tool assembly includes a body that includes an uphole axial surface that is slanted from one portion of an edge of the uphole axial surface to another portion of the edge of the uphole axial surface, a downhole axial surface opposite the uphole axial surface, and a radial surface between the uphole axial surface and the downhole axial surface; one or more keys formed on the radial surface and configured to secure into one or more keyholes formed in a casing of a wellbore; and a bore that extends between an opening in the uphole axial surface and an opening in the downhole axial surface, the bore sized to receive a bottom hole assembly of an intervention tool.

Abstract: For a side pocket mandrel that has a primary flow bore and an offset side pocket, a method for installing a guide sleeve begins with the step of compressing the guide sleeve to reduce an outer diameter of the guide sleeve. The method continues with the step of inserting the guide sleeve into a section of the primary flow bore that has a first inner diameter (D1). The method continues with the steps of allowing the guide sleeve to radially expand such that the outer diameter of the guide sleeve matches the first diameter, pushing the guide sleeve further into the primary flow bore to a guide sleeve section that has a second inner diameter (D2) that is larger than the first inner diameter (D1), and allowing the guide sleeve to radially expand to capture the guide sleeve within the guide sleeve section of the primary flow bore.

Abstract: A downhole tool for installing a gas lift valve in a well. The downhole tool may include a housing, a mandrel movably disposed with respect to the housing, a holder configured to hold the gas lift valve, and an arm supporting the holder. The arm may pivot between a retracted position in which the holder is adjacent the housing and an extended position in which the holder is disposed away from the housing. The mandrel and the arm may be operatively connected via a pin-slot joint having a pin disposed within a slot. The slot may have a first slot portion and a second slot portion. The pin-slot joint may prevent the arm from pivoting when the pin is within the first slot portion and permit the arm to pivot when the pin is within the second slot portion.

Abstract: A wellbore assembly can include a completion string having a side pocket. A downhole device can be positioned within the side pocket of the completion string. The downhole device can have a first end sized and shaped for coupling to a tool for inserting and removing the downhole device in the side pocket while the completion string is positioned downhole in a wellbore. The downhole device can be an electronic device.

Abstract: A method for setting a wellbore casing in a subterranean formation is described. The method includes: drilling a test wellbore in the subterranean formation; generating a density profile of a plurality of geological layers above a salt formation in the subterranean formation based on observations from the test wellbore; calculating an overburden stress imposed on the salt formation by weight of overlying formation based on the density profile of the plurality of geological layers; performing creep mechanical behavior tests on core samples from the salt formation to generate a strain-time curve for the salt formation; calibrating multiple analytical creep models with mechanical properties of the salt data generated by the creep mechanical behavior tests; implementing a wellbore closure model based on a best-fit analytical model and mechanical properties of the multiple analytical creep models; drilling a well; and setting a casing through the salt formation.

Abstract: One illustrative apparatus (1) disclosed herein includes a helix structure (20) that comprises at least one helical surface (15), a plurality of orientation slots (17) positioned around a perimeter of the helix structure, each of the orientation slots (17) being adapted to receive an orientation key (18), a component orientation slot (21) positioned adjacent a bottom end of the at least one helical surface (15) and a threaded bottom recess (43). The apparatus (1) also includes a threaded adjustable nut (30) that is adapted to be at least partially positioned in the bottom recess and threadingly coupled to the threaded bottom recess (43).

Abstract: Provided, in one aspect, is a deflector assembly. The deflector assembly, in one embodiment, includes a deflector body having a deflector window located therein, and a deflector ramp positioned at least partially across the deflector window, the deflector ramp configured to move between first ({circle around (1)}), second ({circle around (2)}) and third ({circle around (3)}) different positions when a downhole tool moves back and forth within the deflector body.

Abstract: An apparatus for miming production tubing string into a wellbore without rotating the production tubing string is disclosed. The apparatus is a muleshoe guide assembly utilizing a short coil spring to tilt a lower muleshoe guide into alignment with a packer bore or liner top. When the guide encounters an obstruction in the wellbore, the short coil spring will compress causing a lug to be driven into an angled milled slot causing the lower muleshoe guide to tilt inward.

Abstract: A system for supporting a borehole junction includes a device configured to deploy a material in a solid state to a downhole location proximate to the borehole junction, and a heat source configured to apply heat to the material to a temperature sufficient to liquefy the material. The liquified material is configured to flow into a formation region adjacent to the borehole junction and consolidate the formation region.

Abstract: An orientation sub includes a pair of connectors that consists of a first connector and a second connector with the first connector. A center section joins the first connector to the second connector. The second connector connects the orientation sub to a tool. The center section has a predetermined geometric configuration with that self-orients the tool when the orientation sub and the tool are inserted into a well defined by casing.

Abstract: A wellbore isolation system includes a junction positioned at an intersection of a first wellbore and a second wellbore, and a deflector disposed in the junction such that a path into the first leg of the junction is obstructed and engaged with the first leg of the junction to form a fluid and pressure tight seal. The junction includes a first leg extending downhole into the first wellbore, and a second leg extending downhole into the second wellbore.

Abstract: A wellbore sealing system is disclosed. The wellbore sealing system includes a deflection assembly positioned in a main wellbore and a junction coupled to an uphole end of the completion deflector and extending into the lateral wellbore to form a fluid and pressure tight seal. The deflection assembly includes a degradable whipstock configured to laterally deflect a drill bit such that the drill bit drills through a sidewall of the main wellbore to form a lateral wellbore, a completion deflector coupled to and located downhole from the whipstock, and an anchoring device coupled to and located downhole from the completion deflector to prevent the deflection assembly from rotating and moving in an uphole direction and a downhole direction within the main wellbore.

Abstract: A downhole tool includes a tubular having an outer surface and an inner surface defining a flowbore having a longitudinal axis, and a backpressure valve cartridge arranged in the flowbore. The backpressure valve cartridge includes a passage, a valve seat arranged in the passage, a flapper valve pivotally mounted relative to the valve seat in the passage, and a piston member configured to shift the flapper valve between a first position, wherein the flapper valve is free to pivot relative to the valve seat, and a second position, wherein the flapper valve is pivoted away from the valve seat and maintained in an open configuration.

Abstract: Hydrocarbon wells including electrically actuated gas lift valve assemblies and methods of providing gas lift in a hydrocarbon well. The hydrocarbon wells include a wellbore that extends within a subterranean formation and downhole tubing that extends within the wellbore. The hydrocarbon wells also include a lift gas supply system configured to provide a lift gas stream to a lift gas supply conduit of the wellbore, a plurality of electrically actuated gas lift valve assemblies, a valve power supply system, and a controller. The methods include measuring a respective pressure differential between a lift gas supply conduit and a production conduit of the hydrocarbon well at each electrically actuated gas lift valve assembly in a plurality of electrically actuated gas lift valve assemblies of the hydrocarbon well. The methods also include selectively opening a selected electrically actuated gas lift valve assembly based on the respective pressure differential.

Abstract: A wellbore system comprising an autofill and circulation assembly comprising a housing defining a flowbore and comprising a first port and a second port, and a first sleeve slidable within the housing from a first position to a second position and from the second position to a third position, when the first sleeve is in the first position, the assembly allows fluid communication from an exterior of the housing to the flowbore via the first port and does not allow fluid communication from the flowbore to the exterior of the housing via the first port, when the first sleeve is in the second position, the assembly allows bidirectional fluid communication between the exterior of the housing and the flowbore via the second port, and, when the first sleeve is in the third position, the assembly disallows fluid communication between the exterior of the housing and the flowbore.

Abstract: A side pocket mandrel, including defining a tubular body having opposing ends and a bore formed within the tubular body. The tubular body comprises an eccentric portion such that a first inner diameter (ID1) is formed at the opposing upper and lower ends, and a second larger inner diameter (ID2) is formed along an eccentric portion. The mandrel includes a movable curtain disposed along the eccentric portion, wherein in a first position the movable curtain covers a portion of the eccentric portion above the pocket to provide a reduced inner diameter that approximates (ID1), and in a second position the curtain is movable to a larger inner diameter (ID2) that enables access by a kick-over tool to install a gas lift valve in or to retrieve the gas lift from the pocket. A method of producing hydrocarbon fluids is also provided.

Abstract: A tubular system includes a side pocket mandrel having at least one side pocket defining a device storage zone. A conductor extends along the tubular system to the side pocket. A stored device is arranged in the device storage zone.

Abstract: A tubing pressure insensitive failsafe wireline retrievable safety valve including a tool housing, a flow tube disposed within the tool housing, an actuation piston disposed in the tool housing and operably connected to the flow tube, the actuation piston having an actuation pressure side and a relatively lower pressure chamber side, a fluid pathway between a potential leak site for the valve and the relatively lower pressure chamber side of the piston. A borehole system having a tubing pressure insensitive failsafe wireline retrievable safety valve. A tubing pressure insensitive failsafe wireline retrievable safety valve.

Abstract: An assembly for forming a lateral wellbore includes a mill having a bore and a plurality of blades; a whipstock having an inclined surface for guiding movement of the mill, the mill releasably connected to the whipstock; and a tubing disposed in the bore of the mill and the whipstock. In one example, at least one of the plurality of blades is disposed in a slot formed in the whipstock.

Abstract: A well support structure includes a well support base for urging below a bottom of a body of water. A first support is coupled to the well support base at a first longitudinal support level. A first load transfer device is operatively coupled between the first support and a wellbore tubular component. At least a second support is coupled to the well support base at a second longitudinal level below the first longitudinal support level. The wellbore tubular component extends between a longitudinal position above the first support to at least the longitudinal position of the at least a second support. Means for transferring load is provided between the wellbore tubular component and the at least a second support.

Abstract: Apparatus for deploying coiled tubing into a wellbore include a neck portion extending between end connections, where the end connections are configured to be attached to a coiled tubing tool string, and a main flow passage, at least one secondary flow passage and at least one electrical device passageway extending through the neck portion and the end connections. A wireline cable or an optical fiber is disposed in the electrical device passageway, and a well treatment fluid flows through the main flow passage. The main flow passage may have a substantially circular cross sectional shape. The apparatus includes at least one secondary flow passage having a substantially circular cross sectional shape, which may be a tube disposed within the main flow passage. The electrical device passageway may in some cases be a tube disposed within the main flow passage.

Abstract: A method of cutting a casing and a formation includes providing a rotatable cutting tool in a wellbore, wherein the rotatable cutting tool includes a first portion configured for cutting the casing and a second portion configured for cutting the formation. The method further includes engaging the first portion with the casing in the wellbore; and engaging the second portion with the casing after engaging the first portion with the casing.

Abstract: A liner string has a hanger/packer near its upper end for connection and sealing to a surrounding tubular. A polished bore assembly is located above the packer and is pushed down after the liner hanger is set to slide over a metal to metal seal on the packer body. A surface string is then tied into the polished bore with another metal to metal seal against the polished bore. The liner string has just metal to metal seals going up to the surface for well pressure containment. Elastomer seals to the polished bore are eliminated. Placement of the polished bore above the packer body allows for a larger diameter polished bore so as to minimize restriction to future production flow. The liner top packer seal is also metal to metal as offered by Baker Hughes Incorporated under the ZX trademark.

Abstract: A tubing hanger running too assembly comprising passive motion compensation and pressure testing capability is described. Specifically, a tubing hanger running tool assembly is described which comprises a tubing hanger running tool and a pressure containing slip joint comprising an inner mandrel and an outer mandrel located concentrically such that the inner mandrel and outer mandrel slide relative to each other providing compression and extension along a linear axis with pressure containing seals located between the inner and outer mandrels.

Abstract: A tubular system includes a tubular having an outer surface and an inner surface defining a flow path, one of the inner surface and the outer surface includes a hub receiving recess, and an electronics hub detachably mounted in the hub receiving recess, the electronics hub including an input conductor connector and at least one output conductor connectors and a control module that facilitates communication between a surface system and one or more downhole devices.

Abstract: A method for treating a subterranean region includes running a tubular string including a plurality of sealed fluid ports distributed along its length through an upper lined wellbore section and into a lower drilled bore section which intercepts a subterranean region, wherein the lower drilled bore section includes a first fluid. A second fluid is delivered through one of the tubular string and an annulus defined between the tubular string and a wall of the bore to displace the first fluid from the annulus, wherein fluid communication between the tubular member and the annulus is provided via a displacement port in a lower end region of the tubular string. At least one of the sealed fluid ports may subsequently be opened and a treating fluid is delivered through the tubular string and into the annulus via the at least one opened fluid port to treat the subterranean region.

Abstract: A system and method for selective isolation of multiple wellbore intervals that can include an isolation mandrel interconnected in a tubing string, where the isolation mandrel includes an entry bore, a transition chamber, and an exit bore, the transition chamber being positioned between the entry and exit bores, and the transition chamber being radially enlarged relative to the entry and exit bores. An isolation device, with a predetermined length, is displaced through the tubing string to the isolation mandrel, where the length of the isolation device relative to a length of the isolation mandrel can determine if the isolation device passes through the isolation mandrel or lands in the isolation mandrel.

Abstract: Apparatus, systems, and methods operable to perform production logging of a lateral wellbore of a multi-lateral well. For example, a downhole tool is conveyed into a main wellbore of a multi-lateral well via coiled tubing. A component of the downhole tool is used to locate a lateral wellbore extending from the main wellbore, and then the downhole tool is conveyed into the lateral wellbore via the coiled tubing. Production logging data is then obtained with the downhole tool in the lateral wellbore.

Abstract: An apparatus and method for locating multiple windows in a wellbore. The windows are associated with lateral wells.

Abstract: Downhole rotary steerable drill including a drilling shaft rotatably supported within a housing, the drilling shaft and housing each having a longitudinal axis. The drill can include a releasable locking mechanism for rotationally locking and releasing the drilling shaft relative to the housing, the releasable locking mechanism transitionable between locked and released configurations. The releasable locking mechanism includes a sliding plunger coupled to the housing by a coupling that permits longitudinal reciprocation of the sliding plunger relative to the housing and prevents rotation of the sliding plunger relative to the housing. The releasable locking mechanism can also include pressure-responsive piston that reciprocates between an unactuated configuration and actuated configuration in response to applied pressure from a pressuring pump.

Abstract: A drillable reamer shoe having a reamer body and a nose section having a metallic cage containing a plurality of ceramic inserts made from silicon nitride or aluminum oxide. The drillable reamer shoe is positioned on an end of a flexible wellbore casing guide comprising a tubular body having a stiffness lower than a wellbore casing.

Abstract: A telescoping joint is provided with one or more control lines and is usable for landing a subsea tubing hanger. The telescoping joint can include an inner mandrel, an outer mandrel, a seal between the inner mandrel and the outer mandrel, and a coiling chamber. The outer mandrel is controllably releasable from the inner mandrel by a release mechanism. The seal is sealably engaged with the outer mandrel for continuously sealing an inner area defined by the inner mandrel from a wellbore environment exterior to the telescoping joint as the outer mandrel axially moves relative to the inner mandrel. A control line is coiled in the coiling chamber and the coiling chamber is axially positioned between the release mechanism and the seal.

Abstract: A diverting system includes, a first tubular, a second tubular receptive to the first tubular having at least one lateral extending therefrom, the first tubular is runnable into the second tubular as well as into the at least one lateral, an engaging device in operable communication with both the first tubular and the second tubular, and a diverting tool in operable communication with the engaging device configured to selectively divert the first tubular into the at least one lateral.

Abstract: A system for placement of a liner in a lateral wellbore, access to which is provided through a window having a V-shaped downhole end. The system includes a running tool including an upper end through which the running tool is manipulated from surface, a lower end, a key positioned between the upper end and the lower end, the key protruding from the running tool for locating the V-shaped downhole end of the window and a liner-engaging portion on the downhole end for releasably securing the wellbore liner to the running tool, the liner-engaging portion configured to secure the liner adjacent the key with the key protruding above the liner and the liner extending from the lower end. The invention also provides methods for placing a wellbore liner in a lateral wellbore extending from a main wellbore.

Abstract: A valve system for use in a wellbore includes a side pocket mandrel and one or more well tools, where the side pocket mandrel includes an elongated body section provided with a connector at its ends, the elongated body section being provided with a substantially fully open main bore for alignment with the well tubing and an offset side pocket bore. At least one through opening is provided in the side pocket mandrel, leading into the side pocket bore, and at least one through opening is provided in the internal wall, leading into the main bore, where the at least two openings are in fluid communication through the side pocket bore, in which side pocket bore at least two valves are arranged in series to form a double fluid barrier between the main bore and an outside of the pocket mandrel, the at least two valves being independently retrievable through at least one installation opening arranged in the internal wall of the side pocket mandrel.

Abstract: In one aspect, a wellbore system is disclosed that in one non-limiting embodiment includes a first wellbore capable of producing a fluid from a first formation, a second wellbore intersecting the first wellbore at a junction, wherein the second wellbore is an open hole and capable of producing a fluid from a second formation and a sand screen at the junction configured to inhibit particles larger than a selected size from flowing from the second wellbore and the junction into the first wellbore.

Abstract: Methods and systems for providing or enabling cap rock restoration of at least a portion of a producible zone of a subterranean well include placing and supporting at least one cement equivalent well barrier member within an operable usable space. This cement equivalent well barrier is formed by at least one cable operable and rig-less string operable, annulus engagable member, comprising cable and rig-less string conveyable components that are conveyed through an innermost passageway and downward from a wellhead. Energy, conductible through said rig-less string or through movable fluid of a circulatable fluid column, is used to operate or access at least one annulus from said innermost passageway and displace at least one portion of a wall of at least one conduit about said innermost passageway, to provide at least one cement equivalent well barrier.

Abstract: An improved downhole well control tool (“WCT”) allows for the control of in-situ fluid flow from a production well having one or more production zones. The WCT is installed in a tubing string in a zone to be controlled. An extensible flow is provided having a threaded connection on its lower end for coupling a pressure gauge or other instrumentation. The extensible flow nipple at its upper end is coupled to a lock body, thereby forming a fully-assembled extensible seal. The seal stem and the gauge may then be lowered using wireline tool into engagement with a tubular sub-assembly having a port. Advantageously, the exterior lateral channels of the extensible flow nipple seal the ports in the tubular sub-assembly. Then, for example, a pressure test may be performed.

Abstract: A milling system includes an elongate body having a first end, a second end, and a mill window defined through a portion of the body between the first and second ends. A mill is movably arranged within the body, and a whipstock assembly is arranged at least partially within the body and configured to guide the mill out of the body through the mill window in order to mill a casing exit. A torque sleeve is coupled to the body and extends over a portion of the body between the first and second ends so as to increase a torsional resistance of the body.

Abstract: A location and orientation assembly suitable for use in a multi-lateral wellbore may include a coupling portion, an upper muleshoe, a muleshoe spacer and a bottom muleshoe. The bottom muleshoe may connect to the coupling portion through a threaded connection. A method for locating and orienting in a multi-lateral wellbore includes providing a locating and orientation assembly. In the orientation assembly a coupling portion is provided and an upper muleshoe is inserted into the coupling portion. A muleshoe spacer is inserted into the coupling portion so as to matingly contact the upper muleshoe portion. Part of a bottom muleshoe is inserted into the coupling portion so as to matingly contact the muleshoe spacer. The coupling portion is jointed to the bottom muleshoe by a threaded connection.

Abstract: A subsea well installation assembly for installing a tubing hanger in a subsea well includes a spool with a spool orientation feature and a running tool connectable to the tubing hanger with a running tool orientation feature. The tubing hanger is rotatable to the predetermined orientation by movement of the running tool with respect to the spool such that the running tool orientation feature engages the spool orientation feature, and the tubing hanger is landable in the predetermined orientation by movement of the running tool with respect to the spool such that the running tool orientation feature engages the spool orientation feature.

Abstract: In modeling operation of a well tool in applying a force to a device in a well, a computing system receives inputs representing a plurality of geometric characteristics of the well tool. The computing system also receives inputs representing a plurality of geometric characteristics of the well. The computing system determines based on the geometric characteristics of the well tool and the well, a predicted reaction force on a portion of the well tool that affects operation of the well tool in applying force to the device. The predicted reaction force is due to contact between a surface associated with the well tool and a surface of the well.

Abstract: A system and method for facilitating the drilling of a deviated borehole. The system and method employ a flexible conveyance. A hydraulic actuation assembly is coupled to the flexible conveyance and a whipstock is releasably coupled to the hydraulic actuation assembly. The whipstock and hydraulic actuation assembly are conveyed downhole in the wellbore. The hydraulic actuation assembly provides a hydraulic fluid under pressure to anchor the whipstock.

Abstract: A method includes introducing a bullnose assembly into a main bore of a wellbore, the bullnose assembly including a body and a bullnose tip arranged at a distal end of the body and being configured to move between a default configuration, where the bullnose tip exhibits a first diameter, and an actuated configuration, where the bullnose tip exhibits a second diameter different than the first diameter. The bullnose assembly is advanced to a deflector arranged within the main bore and defining a first channel that exhibits a predetermined diameter and communicates with a lower portion of the main bore, and a second channel that communicates with a lateral bore. The bullnose assembly is then directed into either the lower portion of the main bore or the lateral bore based on a diameter of the bullnose tip as compared to the predetermined diameter.

Abstract: The present invention provides systems and methods for protecting the lower main wellbore of whipstocks and completion deflectors from debris accumulation. A well system subassembly includes a deflector tool arranged within a casing string and defining a deflector surface and an inner bore extending longitudinally from the deflector surface and one or more seal stacks disposed about the inner bore of the deflector tool. A wellbore barrier device is disposed about the inner bore uphole from the one or more seal stacks and is expandable from an unswelled configuration to a swelled configuration. When the wellbore barrier device is in the swelled configuration, it protects the one or more seal stacks from debris generated from milling and/or drilling operations.

Abstract: A gas lift system has mandrels deploying downhole and has gas lift valves deploying on the mandrels. In general, the mandrel can have an interior and can have at least one port communicating outside the mandrel. To achieve higher gas injection while maintaining component sizes in desirable ranges, the gas lift valve of the present disclosure has multiple injection outlets, and a common opening pressure can control the opening of each of the injection outlets in the valve. The valve can open in two places, allowing gas to flow through the nose of the valve as well as through a ported latch at the top of the valve. In this way, that valve can offer larger injection capabilities while keeping a suitable outside diameter.

Abstract: A casing window assembly for completion of a lateral wellbore. The casing window assembly includes a tubular casing sleeve with a casing window and an inner sleeve releasably secured within the casing sleeve at a pre-released position adjacent the casing window.

Abstract: An assembly for use to cement an uncased wellbore and create a sidetrack of a wellbore with a single trip into the wellbore. The assembly includes a mill selectively connected to a whipstock. A snorkel tube is positioned within a bore of the mill and within a bore of the whipstock. The assembly is connected to drill string and positioned within an openhole portion of the wellbore. After the assembly has been anchored, cement may be pumped down the drill string and through the snorkel tube. The mill may be removed from the whipstock by shearing a shearable device connecting the mill to the whipstock. The mill is used engage a diverting surface on the whipstock and create a sidetrack. The mill may also mill a portion of the snorkel tube or the snorkel tube may be removed from wellbore up the drill string prior to milling the sidetrack.

Abstract: A system and method facilitate drilling of lateral wellbores by optionally eliminating one or more trips downhole. The system and method provide for drilling a lateral wellbore by enabling the milling of a casing window and the drilling of the desired lateral wellbore to a target depth during a single trip down hole. The system and method also facilitate better downhole dynamics control and improved overall bottom hole assembly functionality during drilling.