Abstract: A single-tube double-wellhead drilling and production apparatus is provided, which includes a suction pile, two first wellhead heads, two second wellhead heads, two second guiding pipes, two tubings, two tubing hangers, and two plugs located inside and connected with a corresponding second wellhead head. Each second wellhead head is connected to a corresponding first wellhead head and is connected through a connecting pipeline which is provided with a control valve and a check valve. One end of each first wellhead head is connected with a corresponding first guiding pipe connected with the suction pile. Each second guiding pipe is located inside a corresponding first guiding pipe and is connected to an end of a corresponding second wellhead head. Each tubing hanger is located in and connected with a corresponding second wellhead head, is located below and communicates with a corresponding plug, end of which is provided with a corresponding tubing.

Abstract: A bit breaker for making or breaking a connection between a drill bit and a drill string, and the bit breaker includes a support structure that has a bit aperture through which a portion of the drill bit may pass. The support structure also includes basket apertures positioned circumferentially around the bit aperture. The bit breaker also includes a flexible member that passes through the basket apertures of the support structure to form a basket extending from one side of the support structure that can receive a drill bit. Relative rotation between the support structure and the flexible member causes the flexible member to tighten to make or break the connection between the drill bit and the drill string.

Abstract: A docking fixture for removal of a valve core from a valve fitting of a pressurized system includes a main body defining a hollow main channel that receives a gripping probe to remove the core of a charging valve that is part of a pressurized HVAC system. The docking fixture has a proximal end that can be connected to the HVAC fitting that houses the valve core that is to be removed and replaced. The docking fixture has a side port integrated with a slide valve that can be closed to isolate and protect a sensitive vacuum pressure gauge that might be connected to the free end the fixture's side port. The slide valve includes a sleeve and a tactile feedback mechanism that is configured to provide tactile sensation when the sleeve is positioned in one of the open position and the closed position of the slide valve.

Abstract: A pull head assembly for quick attachment to a flexible pipe is provided. The pull head assembly has three subsections. A collet assembly is mounted to the end of a flexible pipe. A mandrel assembly is adapted to go over the collet assembly. A lead screw assembly positions the mandrel assembly over the collet assembly and acts as an attachment point for pulling the flexible pipe and pull head assembly from one location to another. After pulling the flexible pipe and pull head assembly from one location to another, the mandrel assembly and lead screw assembly can be removed, and the collet assembly can act as a temporary fitting for the flexible pipe.

Abstract: A wellhead may include a first back pressure valve, a second back pressure valve, and a tubing head adapter. The tubing head adapter may include a first and second back pressure valve set location that complements and engages an outer surface profile of the first and second back pressure valve, respectively. The first back pressure valve set location may be positioned below the second back pressure valve set location. A first back pressure valve receiving diameter of the first back pressure valve set location may be smaller than a second back pressure valve receiving diameter of the second back pressure valve set location. A method of isolating production tubing in fluid communication with a wellhead may include engaging a first and second back pressure valve at a first and second, respectively, back pressure valve set location of the tubing head adapter.

Abstract: Dynamic/static sealing of coiled tubing subsea for pipeline and well access with hydrostatic conditions up to 10,000 feet water depth while maintaining wellbore or pipeline pressures up to 10,000 psi may be achieved using a system comprising a subsea fluid source which utilizes a riserless open water coiled tubing system and an open water coiled tubing sealer to control hydrostatic pressure and fluid container pressures.

Abstract: A grille shutter is fixed to a radiator grille at end portions of the grille shutter in the vehicle right-left direction. A restriction mechanism includes a restriction member provided to the radiator grille and a restriction member abutting portion provided to an intermediate portion of the grille shutter in the vehicle right-left direction. The restriction mechanism restricts the intermediate portion of the grille shutter from moving toward the vehicle rear side relative to the radiator grille. The restriction member is configured to be movable toward the vehicle rear side relative to the restriction member abutting portion.

Abstract: A drilling rig includes an interchangeable plurality of drill pipes, wherein drill bits are arranged at an end section of an end drill pipe. The drill bit being attached to the end section by means of a threaded connection and torque being provided to the drill bit by means of a splines coupling. The drilling rig comprises a lower support device and a breaker device. The system includes a drill bit storage device arranged to hold a plurality of drill bits, a gripping arm for selective gripping of a drill bit. The gripping arm may further comprise a movement sensor, arranged to monitor movement of the gripping arm, and the system may further comprise a control unit. The control unit being arranged to receive input from the sensors and the drilling rig, and to control movement of the gripping arm, the gripping means, the drill bit storage device, and the breaker device of the drilling rig.

Abstract: A fluid management device includes a seal and a piston coupled to the seal and movable to an activated position to adjust the seal to an activated state. The seal includes first sealing elements extending radially inward towards a central axis of the fluid management device and second sealing elements extending radially inward towards the central axis, the first and second sealing elements together defining an opening sized to surround first and second pipes disposed within a wellbore containing wellbore fluid. In the activated state, the first sealing elements contact each other within the opening between the first and second pipes and seal against a first inner portion of the first pipe and a second inner portion of the second pipe to close the opening between the first and second pipes and a closed state of the opening prevents the wellbore fluid from exiting the wellbore through the opening.

Abstract: A directional drill stem loader and associated methods are shown. In one example, the drill stem loader operates in a linear motion. In one example, a drill stem gripper is configured to move the completely to one side of a drill stem during a retraction operation.

Abstract: Embodiments disclosed herein describe a rotating flow coupler that is configured to couple multiple sections of a casing for a horizontal well, wherein the rotating flow coupler is configured to rotate relative to the casing allowing an additional degree of freedom for equipment being lowered into the well. This may allow for equipment such as coil tubing, drilling string, casings strings, etc. to reach a total distance of deeper laterals.

Abstract: Present embodiments are directed a mineral extraction system comprising a locking clamp configured to be secured to a first tubular member, wherein the locking clamp comprises an outer radial surface having a first geometry and a rotary table adapter. The rotary table adapter comprises a base and an extension extending from the base, wherein the extension defines a recess, the recess comprises an inner radial surface having a second geometry, wherein the first geometry and the second geometry correspond with one another, and the rotary table adapter is configured to be disposed within a rotary table of a drilling rig.

Abstract: An apparatus is for a drill rig platform configured to be operative with a casing system having a check valve fixedly positioned in a casing joint. The apparatus includes a casing pressure relief assembly fixedly positionable relative to the check valve positioned in the casing system. The casing pressure relief assembly is configured to actuate the check valve in such a way that the check valve actuatably releases internal pressure from the casing system. In this manner, the internal fluid pressure of the pressurized fluid trapped in the casing system is released once the casing pressure relief assembly actuates the check valve.

Abstract: A wellhead securement arrangement releasably clamps casing strings such that they cannot move in an upwards or downwards longitudinal direction. Prior to being clamped, the securement arrangement secures the casing strings in a first position whereby cement returns are able to flow around the hangers towards the surface. Once cemented, the casing strings are released and moved upwardly, where the securement arrangement clamps the hangers into position, thus creating an axial load on the casing strings while also preventing movement in the upward and downward longitudinal directions.

Abstract: Clamping devices for hanging or pulling wellbore rod strings each feature housing with an axial bore in which a number of clamping pieces are placed to wedge in place between the housing and rod string to perform a self-tightening action against the rod string under the weight thereof due to cooperation of beveled surfaces at the bore wall and exterior of the clamping pieces. Threaded fasteners fed through the housing wall aid in placement of the slips against the rod string. For use in pulling operations, the housing is sized for receipt in the latching mechanism of a tubing elevator for support by the same, whereby the tubing elevator can be used to pull out a stuck rod string. Some embodiments feature a circumferential gap in the housing to enable the housing to be slipped laterally onto the rod string.

Abstract: An apparatus for clamping elongate elements in a parallel piggybacked arrangement during subsea laying of the elements is disclosed. The apparatus has opposed reciprocating jaws for forcing together clamp segments around the elongate elements to assemble a piggybacking clamp that applies clamping forces to the elongate elements.

Abstract: A die holder device includes a die holder that has an axial centre line and is adapted to receive a clamp die. The die holder is included in a clamp arm or slide block. The die holder is restricted from axial movement by at least a first complete or partial conical surface and possibly by a second complete or partial conical surface that directly or indirectly bears against the clamp arm or the slide block.

Abstract: A system, in certain embodiments, includes a horizontal fracturing tree. The horizontal fracturing tree includes a first hydraulic fracturing bore configured to flow a first fluid, wherein the first hydraulic fracturing bore extends along a first horizontal axis, and the first horizontal axis is generally perpendicular to a vertical axis of a wellhead.

Abstract: A device for covering a pipeline from a wellbore comprising a cover comprising at least one lower bearing surface suitable for being mounted on an end of a vertical annular pipeline of a wellbore. The device includes a distribution elbow comprising a lower end, intended to be connected to a pipe of the wellbore, that extends vertically downwards from the cover and an upper end extending horizontally. The cover and the distribution elbow form a monobloc assembly.

Abstract: A system for securing a first tubular to a second tubular including a housing having at least one group of at least one window therein. A gripping assembly is disposed in the housing and has at least one member operatively arranged for selectably extending through the at least one window for internally gripping the first tubular. A coupling unit is included having a first clamping mechanism and a second clamping mechanism. The first clamping mechanism is operatively arranged for externally clamping the housing, and the second clamping mechanism is operatively arranged for externally clamping the second tubular component. A method of securing together two tubular components is also included.

Abstract: A retention system for limiting axial and radial movement of a wellbore lock ring. The retention system includes pins for resisting axial movement of the lock ring and assemblies for limiting radial outward movement of the lock ring. The lock ring circumscribes and couples to a wellbore hanger. The pins project radially from the hanger into the lock ring and into slots, where the slots extend a distance along the inner surface of the lock ring. The assemblies also project radially into the hanger and each have a portion that registers with a channel on a lower end of the lock ring. Lock ring outer radial movement is limited by contact between the portions of the assemblies and inner surfaces of the channels.

Abstract: A technique facilitates avoidance of premature actuation of a liner hanger in a wellbore. The technique utilizes a running string which may be coupled to a liner having a liner hanger. The running string extends into the liner in a manner which creates an inner pressure region within the running string, an intermediate pressure region between the running string and the liner, and an outer or annulus pressure region surrounding the liner. The inner pressure region is initially isolated from the intermediate pressure region by a closure mechanism during, for example, movement downhole. The closure mechanism selectively closes off a port used to actuate the liner hanger.

Abstract: Present embodiments are directed to a device for a top drive drilling system. The device includes a movable sleeve configured to be disposed around at least a portion of a sub. The movable sleeve is configured to be selectively disposed around a tubular by sliding axially along the sub. The device also includes a plurality of engagement features extending inwardly from an inner circumference of the movable sleeve. When the movable sleeve is disposed around the tubular, the plurality of engagement features are configured to engage the tubular when the movable sleeve is rotated in a first direction and to not engage the tubular when the movable sleeve is rotated in a second direction.

Abstract: A method includes attaching a carriage support to a platform, the platform comprising a platform floor having an opening therein, with the carriage support located proximate the opening, attaching a drive carriage to the carriage support, and operably coupling to the drive carriage a first mast section of a mast comprising a plurality of mast sections, and wherein the first mast section is located above the opening. The method also includes arranging a second mast section below the first mast section, lowering, using the drive carriage, the first mast section through the opening, attaching the first mast section to the second mast section, and raising, using the drive carriage, the first mast section and the second mast section through the opening. In an exemplary embodiment, the platform floor is a rig floor.

Abstract: An apparatus includes a first housing portion comprising a first adjustable gripping system moveable between an engaged position that grips a cylindrical outer surface of a first tubular structure having a first diameter and a disengaged position that permits relative movement of the first housing portion and the first tubular structure. The apparatus also includes a second housing portion fixed relative to the first housing portion so that rotation of the first housing portion results in rotation of the second housing portion. The second housing portion includes a second gripping system to securely grip a cylindrical outer surface of a second tubular structure that is threadably attached to the first tubular structure and has a second diameter different than the first diameter. Methods of breaking tubing hanger connections are also disclosed.

Abstract: A mounting structure for a rig may include a base configured to support the mounting structure on an operating surface and a plurality of transport systems operatively connected to the base and configured to lift the mounting structure off of the operating surface. An elevated rig platform may be connected to the base by a plurality of support struts, wherein at least some of the support struts comprise a mounting connection that is configured to pivot to lower the elevated rig platform toward the base and place the mounting structure in a partially collapsed state. Additionally, a connecting member may be attached to one or more of the plurality of transport systems, wherein in response to the elevated rig platform being lowered to the partially collapsed state, the connecting member may be configured to displace at least a portion of the one or more transport systems.

Abstract: The present disclosure provides a drilling and tripping equipment package and control scheme and methods using two or more systems that operate simultaneously and continuously in a synchronized manner such that the feeding of tubulars into or out of a well bore is achieved with continuous or near continuous movement, without the need for periodic interruptions. The drilling and tripping equipment package and control scheme is also able to rotate the tubulars in the well bore with continuous speed and torque sufficient for both drilling and back-reaming operations. The drilling and tripping equipment package and control scheme is additionally able to circulate drilling fluid into the internal bore of the tubulars with sufficient pressure and flow to facilitate both drilling and back-reaming operations, with minimal interruption to circulation.

Abstract: A system and method is provided for hydraulically presetting a metal-to-metal seal, which may be installed in an annular space between wellhead components. A hydraulic running tool may be landed on a first wellhead component and coupled to a second wellhead component, for example, via a hydraulic or mechanical coupling assembly. Fluid pressure may then be applied to the hydraulic running tool to move the components axially together, thereby setting the metal-to-metal seal (i.e., axially compressing and radially expanding the seal). A coupling may secure the wellhead components in place relative to one another, while fluid pressure is being applied so that the metal-to-metal seal remains in the set position after the hydraulic tool is removed.

Abstract: A pipe clamp mechanism and method for use with a pipe arm retracts beneath two laterally positioned pipe guide surfaces in a retracted position to allow a pipe to roll laterally into a pipe receptacle on the pipe arm along either of the two pipe guide surfaces. After at least one pipe is positioned within the pipe receptacle, then the pipe clamp utilizes one or more pipe clamps which extend outwardly of the pipe guide surfaces to clamp the pipe into the pipe receptacle.

Abstract: A device and a method for handling rod-shaped elements on drilling gear are disclosed. The device for handling rod-shaped elements on drilling gear includes a drill rod magazine on which the rod components are deposited between a center of a drill hole and a center of a drilling mast, an elevator with a guide that lifts the drill rods above a drill hole, and a drive for displacing the elevator, a gripper attached to the elevator for picking up the rod component from the drill rod magazine, and a plurality of monitors. The plurality of monitors automatically monitor the movement of the rod-shaped components amongst the magazine, the elevator, and the gripper.

Abstract: The invention relates to a handling unit for drill rods having an elevator bracket (30) which can be swiveled by means of a tilt arm (34) under the influence of a tilt cylinder (32), and means (42) for detecting a position of the at least one elevator bracket (30), in which is provided at least one valve (50) as means for detecting the position of the or each elevator bracket (30) and as part of a hydraulic switching control circuit (54) which continues outside the handling unit, and at least one connecting member (52) for the at least one valve (50), which connecting member can be moved by a movement of the tilt arm (34), wherein the or each valve (50) opens or closes the hydraulic switching control circuit (54) such that the state of the switching control circuit (54) can be evaluated as position information.

Abstract: A wellhead system includes a bypass sleeve for temporarily isolating portions of a wellhead assembly from pressurized fracing fluid. The bypass sleeve may include a generally tubular body having a tool interface, a lock ring disposed at least partially around the body, and an anti-rotation device coupled to the body. The anti-rotation device includes a resilient member disposed in a cavity in the body, and an anti-rotation member biased away from the body by the resilient member. The anti-rotation member extends radially outward from the body.

Abstract: An apparatus for installing and removing a rotary control device insert or an element thereof has a first clamp with a receptacle suitable for receiving a flange of the rotary control device insert therein, a second clamp having an interior suitable for extending around a pipe, and a plurality of lines extending between the first clamp and the second clamp. The first clamp is movable between an open position and a closed position. The second clamp is movable between an open position and a closed position. Each of the clamps includes a first jaw and a second jaw connected to the first jaw by a hinged connection.

Abstract: An oil field system comprising a main body having a bore therethrough, the main body having a connection at one end of the bore for, in use, connecting the main body to an existing wellhead, tree or other oil field equipment, a transverse cavity through the bore, the cavity having at least one opening to the outside of the main body, a plurality of flow control devices for insertion, at different times, into the cavity in order to selectively control fluid flow through the bore, wherein the plurality of flow control devices includes a gate valve and drilling BOP rams.

Abstract: A jack system may provide subsea or surface operation. The jack system includes a top plate and a base plate with at least two pistons disposed between the base and top plate. The pistons are extendable to increase a separation distance between the base and top plate, and said pistons are retractable to decrease the separation distance between the base and top plate. The jack system also includes a bottom slip bowl assembly, a top slip bowl assembly, and rotary assembly. The top slip bowl and rotary assembly are rotatably coupled to the top plate wherein the rotary assembly and the top slip bowl assembly rotate relative to the top plate.

Abstract: A top drive system for wellbore operations and method for facilitating rotation thereof. The system includes a main body and a motor, preferably a salient pole motor. A motor shaft extends from the motor and a gear system is driven by the shaft and interconnected with a drive shaft. The gear system has a housing and a bearing retainer integral with the housing and is driven by the motor apparatus so that driving the gear system drives the drive shaft.

Abstract: A connection lift system and method for handling oil and gas drilling tubular components includes a core component and a ring-shaped component, where a range of ring-shaped components may be screwed onto the core component, such that the ring-shaped component may be configured based on the tubular component to be handled, and the core may be compatible with lifting equipment.

Abstract: A tool circulates drilling fluid through and rotates a pipe string while making up or breaking out a stand of pipe. The tool includes a tubular member defining a central bore having an axis, wherein the tubular member comprises an upper tubular member and a lower tubular member, and wherein the upper tubular member and the lower tubular member are configured to alternately rotate independently and in unison. The tool also includes a central bore valve coupled to the upper member, and at least one radial valve coupled to the upper tubular member axially below the central bore valve.

Abstract: Apparatuses and methods to cut a control line and/or to run a control line on a rig may include a movable cutting apparatus to cut a control line, a load transfer member to engage a control line, a load measuring device to measure a load imparted to a load transfer member, and a drive member to engage and drive a control line. The apparatuses and methods may be used with a control line positioning apparatus, a pipe engaging apparatus, and/or may be used by themselves.

Abstract: A tool is provided for installing a mandrel in a wellhead assembly. The tool includes an assembly having multiple independently translatable and rotatable members. The tool includes an inner member disposed in an inner sleeve. The inner member may be disposed in a first position and second position, such that in the first position the inner sleeve freely rotates and in the second position rotation of the inner sleeve causes rotation of the inner member. An outer sleeve is disposed over the inner sleeve and may be coupled to a hold down ring. The inner member may be coupled to mandrel. The tool may be inserted into a wellhead assembly and the outer rotated to engage the hold down ring, the inner and outer sleeve may be translated axially to allow rotation of the inner member to disengage the tool from the mandrel.

Abstract: A wellbore machining device is proposed for machining a tubular component of a wellbore. The device includes a control unit at the surface level of the wellbore and a down-hole tool unit connected to the control unit through a wire line. The tool unit includes an elongated guide member, a tool member movably supported on the guide member with respect to at least three axes of motion and a plurality of actuators controlled by the control unit and adapted to move the tool member with respect to the axes of motion. The tool unit further includes two anchor members each mounted to an axial end of the guide member and adapted to releasably clamp the tool unit to the tubular component. The control unit and the tool unit form a computer numerical control device (CNC device) wherein the actuators are electric servo motors controlling an actual position of the tool member with respect to a path and/or a sequence of desired position defined by the control unit.

Abstract: A system is provided that includes a safety device configured to mount in a mineral extraction system and block axial movement of a plug in the mineral extraction system while the plug is released from a retainer. The safety device may be a sleeve configured to receive screws or other retention mechanism in a tubular. A method is provided that includes installing a plug safety catch into a tubular of a mineral extraction system in which the safety device is configured to block axial movement of a plug in response to a pressure differential while the plug is released from a mount position.

Abstract: A portable frame assembly having a skid assembly for supporting a vertically oriented mast assembly is disclosed. The mast assembly is comprised of at least two column assemblies that may be extended or retracted vertically as desired. The mast assembly is translatable horizontally on the skid assembly without the need for tracks or rollers. The skid assembly may be positioned adjacent a wellhead for the purpose of performing plug and abandon operations. The skid assembly may include a power swivel and other such hydraulic or mechanical tools for performing a variety of operations on a well including removing and plugging well casing strings, milling pipe strings, cement drilling, removing wellhead assemblies, or setting and pulling plugs from pipe strings.

Abstract: The invention concerns a tool for a tool for connecting an end of a first pipeline (22) to an end of a second pipeline (3) supported by a subsea structure (1) and being provided by at least two guide elements (11, 12). The tool comprising means for connecting the pipelines, and it comprises a receiving portion (32) provided to accommodate the end of the first pipeline in a slideable manner, and guiding means comprising at least two guiding sections (34, 35) extending from receiving portion (32). Each guiding section has an end arranged with an attachment portion (36, 37) interfacing with the guide elements (11, 12).

Abstract: A snubbing apparatus for a wellhead has a snubbing stack with a upper sealing element and a lower sealing element that seal between the elongate string and the snubbing stack. A string driver carried by the snubbing stack manipulates the elongate string through the upper and lower sealing elements. There is a source of inert liquid connected to the snubbing stack between the upper sealing element and the lower sealing element. A pressure sensor is connected to sense the pressure below the lower sealing element and is connected to provide a pressure signal to the source of inert liquid. The source of inert liquid is configured to pressurize the snubbing stack between the upper sealing element and the lower sealing element in response to the pressure signal.

Abstract: A downhole tool for incorporation in a drill pipe for selective operation of the tool from surface level when the tool is in a wellbore. The tool comprises a controller electrically powered by a power source separate from surface level, a first sensor of the controller to detect a dynamic variable of the tool in the wellbore and produce an output signal dependent thereon; a second sensor of the controller to detect a mechanical signal transmitted from an operator at surface level; a motor driven by the power source under the control of the controller when said mechanical signal is received; and an actuator driven by the motor to actuate the tool; wherein the controller switches between at least two states in response to changes in said dynamic variable, only in said second state the controller being receptive to said mechanical signal from the operator to drive the motor.

Abstract: Apparatuses, systems, and methods in accordance with the present disclosure are disclosed herein. The system includes a gripping tool operatively connected to and suspended from the top drive assembly, in which the gripping tool includes an axis defined therethrough and a gripping member, and an adaptor apparatus having a first end and a second end. The at least one gripping member engages the adaptor apparatus, and the second end includes a connection member to connect with the tubular member.

Abstract: A setting tool for hanging a tubular string includes: a tubular mandrel having an actuation port formed through a wall thereof; a debris barrier for engaging an upper end of the tubular string; and a piston having an upper face in fluid communication with the actuation port. The setting tool further includes: an actuator sleeve extending along the mandrel and connected to the piston; a latch releasably connecting the debris barrier to the actuator sleeve and for releasably connecting the debris barrier to the tubular string; a packoff connected to the mandrel below the piston and operable to seal against an inner surface of the tubular string, thereby forming a buffer chamber between the debris barrier and the packoff; and a passage. The passage: is in fluid communication with a lower face of the piston, is formed in a wall of and along the mandrel, and bypasses the packoff.

Abstract: An RCD is used to provide a system and method for sealing a marine riser having a rotatable tubular. A bypass internal channel or external line may be used to allow fluid to bypass the RCD seal. An RCD holding member seal could be a mechanically extrudable seal or a hydraulically expanded seal to seal the RCD with the riser.

Abstract: A well servicing system includes a frame adapted to mount to a pipe handling system that includes a hanger adapted to guide a load coupled to a cable towards a wellhead, where the load exerts at least a portion of a tensile force on the cable; and a winch including a drum and a brake. The brake is adapted to control rotational motion of the drum to spool a portion of the cable over the drum and set the drum to substantially prevent rotational motion of the drum. The well servicing system also includes a hydraulic piston-cylinder coupled to a sheave. The piston is adapted to stroke into or out of the cylinder when the tensile force exceeds a desired load when the drum is set to substantially prevent rotational motion to spool the cable from the drum.