Abstract: A riser system is provided to eliminate the consequences associated with damage to the annular system while also maintaining the availability of critical safety systems. The riser system may comprise a customizable control housing and external seal control subs that facilitate reciprocation and rotation of a drillpipe or workstring while eliminating damage to the upper annular blow out preventer and allowing the upper annular blow out preventer to function as intended.

Abstract: A variety of methods, systems, and apparatus are disclosed. In one example, a well tool is deployed downhole on a conveyance (e.g., tubing string) with the well tool in an open condition, wherein a flow path of the tool is in fluid communication with the tubing string. A swellable metallic material is arranged along the flow path. A service operation may be performed while the tool is in the open condition, including flowing a well fluid down the tubing string and through the flow path of the tool. After performing the service operation, an activation fluid may be delivered downhole to the well tool to activate the swellable metallic material to close the flow path of the tool.

Abstract: The present disclosure describes a subsea well installation including an Xmas tree coupled to a wellhead. A guide frame is located at a lower region of the Xmas tree. A flush and cap tool (FACT) adaptor is mounted on an upper region of the Xmas tree. A tension arrangement extends between the guide frame and the FACT adaptor, to apply a compressive force through the Xmas tree.

Abstract: An improved mandrel head for use with a wellhead isolation tool for protecting a wellhead. In an exemplary embodiment, the wellhead isolation tool includes a lock assembly with a mandrel head with a longitudinally extending annular sleeve. The inner surface of the mandrel head is connected to the mandrel and adapted to sealingly engage the mandrel. The outer surface of the mandrel head also sealingly engages with a seal pack within the wellhead isolation tool, and the mandrel head is configured such that the point of the connection between the mandrel and mandrel head is axially located below the engagement with the seal pack.

Abstract: The present invention relates to a downhole completion system for providing a well tubular metal structure in a borehole of a well having a top, comprising a well tubular metal structure configured to be arranged in the borehole.

Abstract: The present disclosure relates to subsea tool apparatus and methods, particularly but not exclusively tool apparatus and methods relating to subsea trees or so-called “Christmas trees”. The subsea tool is for reinstating the functionality of a subsea tree valve actuator, by applying a thrust force to the subsea tree valve actuator stem, characterised in that: the tool gets its power supply to provide load on the actuator stem, directly or indirectly from the subsea tree SCM (subsea control module) supply.

Abstract: Systems and methods providing a tree cap that allows power, signal, and/or hydraulic function connections to be established between an Electrical Submersible Pump and a vertical Christmas tree (VXT) control system are provided. The tree cap includes an Electrical Feed-through System (EFS) having an electro-hydraulic stinger configured to form a connection to an ESP hanger plug of the Electrical Submersible Pump (ESP). The tree cap is configured to lock onto the vertical Christmas tree (VXT) and provide a secondary seal barrier element to the environment.

Abstract: A device for setting and retrieving a crown plug in a well head. The device has a mandrel device, an outer housing device, a snap sleeve device downwardly protruding from the lower end of the mandrel device and a locking element. The device has an upper plug connection device and a lower plug connection device for connection to the upper connection interface and a lower plug connection device of the crown plug, respectively. An annular compartment is provided radially outside at least parts of the locking element and radially inside a lower end section of the mandrel device. An upper end of the snap sleeve device is provided axially displaceable in the annular compartment. The lower plug connection device may be configured between a locked state and an unlocked state by axial displacement of the snap sleeve device in relation to the locking element.

Abstract: An adapter assembly having a sealing element, a drive bushing, and an adapter flange disposed between the sealing element and the drive bushing. Also, a method of assembling a rotational control device that includes coupling mechanically an adapter flange to a sealing element, coupling mechanically the adapter flange to a drive bushing, and installing the adapter flange, sealing element, and drive bushing in the rotational control device.

Abstract: The riser tensioning system (10) includes a tensioning ring (18) for secured engagement with the riser and plurality of hydraulic cylinders (12) extending between the tensioning ring and a floating platform. A gimbal mechanism (42) acts between the platform and the riser to allow the riser axis to tilt relative to the floating platform. One or more elongate torque transfer members (38) extend between the tensioning ring and the gimbal mechanism and allow axial movement of the tensioning ring and the riser with respect to the floating platform.

Abstract: Systems, apparatus, and methods for longitudinally moving or running a tubular, with the system including an elevator suspended from a rig. The elevator includes a body defining a bore to receive a tubular and wedges defining channels therebetween, with the wedges being configured to engage the tubular. The system may also include a spider including a body defining a bore to receive the tubular and wedges defining channels therebetween. The wedges of the spider may be configured to engage the tubular, and the wedges of the elevator may be configured to slide axially at least partially in the channels of the spider. The wedges of the spider may be configured to slide axially at least partially in the channels of the elevator.

Abstract: A system for drilling and/or producing a subsea wellbore comprises a primary BOP comprising a primary ram BOP. In addition, the system comprises a secondary BOP releasably connected to the primary BOP, the secondary BOP comprising a secondary ram BOP. The primary rain BOP is actuatable by a first control signal. The secondary ram BOP is actuatable by a second control signal. The secondary rain BOP is not actuatable by the first control signal.

Abstract: A method and a device are for extending the lifetime of a Christmas tree. The Christmas tree is provided with at least a first high-pressure hydraulic valve pack, a first low-pressure hydraulic valve pack or a first chemical valve pack, and the Christmas tree is arranged to be connectable to an umbilical, which comprises at least electrical power or control cables, hydraulic tubes or chemical tubes.

Abstract: A system and method for replacing equipment at a wellsite is provided. The wellsite has a subsea stripper installed proximate a subsea borehole. The system has a conveyance for delivering a BHA into the subsea borehole. The system has a subsea stripper having a central bore for passing the conveyance and the BHA therethrough, and at least one actuator connected to the subsea stripper for actuating a packer whereby the wellbore is sealed. The system has at least one replaceable seal assembly for installation within the stripper. The replaceable seal assembly has at least one packer extendable within the subsea stripper to form a seal thereabout and at least one locator sleeve for positioning the seal assembly in an install position within the subsea stripper. The replaceable seal assembly has a frangible member for connecting the seal assembly to the conveyance prior to deployment in the subsea stripper.

Abstract: The present invention regards a riser system comprising at least one riser extending from a subsea wellhead to a surface vessel, tension means for keeping the at least one riser tensioned, which tension means are connected to the vessel, a upper workover riser package (UWRP) located at the upper section of the riser and arranged to seal off the riser passage.According to the invention the UWRP is located below the connection point of the tension means to the vessel, giving the UWRP a position stationary relative a seabed, and that the UWRP comprises an interface adapted for the connection of different kinds of workover equipment. The invention also regards a method for inserting tools into a riser.

Abstract: A wellsite connector (110) includes a connector body (232) having an end adapted for coupling to a first of the components and a cavity (265) to receive a second of the components, a piston (234) axially movable in the connector body and having a piston profile along an inner surface thereof, and a plurality of collets (236). The collets are positionable about the connector body adjacent the piston and radially movable thereabout. The collets have a collet profile along an outer surface thereof corresponding to the piston profile of the piston. The collets also have a grip profile along an inner surface thereof selectively engageable with the second of the components whereby the collets are selectively latchable about the second of the components.

Abstract: A fingerboard latch assembly includes a latch configured for operational engagement with a fingerboard for lockingly retaining at least one tubular to the fingerboard. The latch is movable within a range of motion extending from at least a locked position to an unlocked position. A positioner operatively engaged with the latch is communicably couplable to a process control network (PCN), and is sized and shaped for receipt within a latch channel of the fingerboard. The positioner is configured to move the latch within the range of motion in response to signals received from the PCN, to capture position data for the latch, including the position of the latch at a plurality of points within the range of motion, and to communicate the captured position data to the PCN.

Abstract: A subsea connection assembly has a stab plate a first stab plate which carries a first plurality of couplers and a second stab plate which carries a second plurality of couplers for mating engagement with the couplers in the first plurality as the stab plates are moved together. The assembly includes a mounting plate, a support which is disposed for lateral movement in at least one direction relative to the mounting plate, and a pivot which allows tilting movement of the first stab plate relative to the support. The tilting and translational features accommodate many different possible trajectories of a pulling unit. In particular, the assembly tolerates a separating action which is oblique to the normal mating and demating direction.

Abstract: A flow head system, comprising a one or more load diversion devices releaseably attached to a first set of components. Said one or more load diversion devices comprising a lower load diversion device releaseably attached to said first set of components. Said one or more load diversion devices attached to an offshore facility. Said one or more load diversion devices holding a load created by said first set of components. Said first set of components releaseably attached to a string of pipe. Said first set of components capable of rotating about a center axis relative to said one or more load diversion devices. Said one or more load diversion devices comprising a one or more lower load bypass devices attached to said lower load diversion device. Said well control equipment releaseably attached to said first set of components.

Abstract: A method for making a riser component includes: positioning a coupler adjacent and end of a tube such that a region of the coupler forms an interface with the tube's end, wherein the region includes a material (in some embodiments an aluminum alloy), and the tube's end includes a groove and another material (in some embodiments a steel alloy) that is different than the region's material; heating the region of the coupler to increase the region's malleability; and exerting pressure on the region of the coupler to plastically deform the region to insert some of the region's material into the groove in the tube's end. By fixing the coupler to the tube in this manner, the coupler may be strongly secured to the tube, and thus able to withstand high, dynamic loads frequently experienced in service. Also, the material of the coupler may be different than the material of the tube, and thus the material of the coupler may be lighter than the material of the tube.

Abstract: A SALT ring handling system having a platform, a track system operatively connected to a lower side of the platform, and a pickle fork operatively connected to the track system. The platform may include an upper deck, a lower deck, a spacer for positioning the deck near a riser, and an engaging mechanism for operatively connecting the platform to a carrier system. The track system may include a vertical track assembly and a horizontal track assembly for transferring the vertical track assembly in a substantially horizontal direction. The vertical track assembly may include a lift mechanism that is operatively connected to the pickle fork, and the lift mechanism may transfer the pickle fork in a substantially vertical direction. The pickle fork may include one or more extensions for engaging a portion of a SALT ring.

Abstract: A sealing arrangement and method for dynamic sealing around a drill stem (50) in water-carrying, drilling fluid-carrying or hydrocarbon-carrying wells, comprising at least one dynamic sealing (35a) which is arranged to envelop the drill stem (50), and a receiver unit (30) arranged to receive the at least one sealing (35a), with the dynamic sealing being arranged to be driven into the receiver unit (30) with the help of the drill stem, and to be securely locked in the receiver unit, and also that internal pressure support in the sealing arrangement is provided corresponding to at least the surrounding pressure.

Abstract: A technique facilitates formation of subsea connections. A free portion of a stab plate connection system is moved into proximity with a fixed portion of the stab plate connection system at a subsea location. The free portion is initially engaged with the fixed portion via a docking probe. Subsequently, a local actuator is used to draw the free portion into an operating engagement with the fixed portion in which line couplers of the fixed portion are engaged with corresponding line couplers of the free portion.

Abstract: A seal seals an annulus in a subsea assembly between a wellhead and a casing hanger landed on a shoulder within a bore of the wellhead. The seal includes a casing hanger seal ring disposed within the annulus. The seal ring engaged with an inner diameter surface of the wellhead, and engaged with an outer diameter surface of the casing hanger so that the seal ring prevents flow through the annulus. A nose ring is secured to a lower end of the seal ring so that, when the seal ring is energized, a conical surface of the nose ring engages a mating conical profile formed in the inner diameter surface portion of the wellhead and the nose ring engages a surface opposite the conical surface with a substantially smooth outer diameter surface portion of the casing hanger to limit upwards axial movement of the casing hanger.

Abstract: Systems and methods for riser coupling are disclosed. A riser coupling system comprises a riser joint connector comprising a first tubular assembly coupled to a second tubular assembly. The riser coupling system further comprises a spider assembly which receives the riser joint connector and has a connector actuation tool. The connector actuation tool comprises a dog assembly, a clamping tool and a splined member. The dog assembly selectively extends a dog to engage the riser joint connector. The clamping tool couples the first tubular assembly and the second tubular assembly. Finally, the splined member actuates a locking member of the riser joint connector.

Abstract: A wellhead assembly for use subsea includes a high pressure housing landed within a low pressure housing. The low pressure housing is an annular member that mounts into the sea floor and having an inner surface engaging the high pressure housing along a loading interface. Upper and lower sockets are formed along axially spaced apart portions of the outer surface of the high pressure housing. As the high pressure housing inserts into the low pressure housing, the high pressure housing sockets engage corresponding sockets formed along axially spaced apart sockets on portions of the inner surface of the low pressure housing. The sockets each have cylindrically shaped outer surfaces, and when engaged with one another define the loading interface. The sockets are strategically located on the upper and lower portions of the housings to maximize their distance apart.

Abstract: An apparatus and method for controlling fluid flow in a blowout preventer. In one embodiment, an apparatus for connecting fluid lines includes a socket fluid connector and a plug fluid connector. Each connector includes a flow channel. The plug fluid connector is detachably connectable to the socket fluid connector at a connection end of the plug and socket fluid connectors such that the flow channels align. Each of the socket and plug fluid connectors includes a check valve in the flow channel. The check valve is configured to prevent fluid flow through the connector flow channels while the plug and socket fluid connectors are not connected, and to enable bidirectional fluid flow through the connector flow channels while plug and socket fluid connectors are connected.

Abstract: An offshore well system for a subsea well. The system includes a floating platform, an external riser and an internal riser nested within the external riser. A external riser tension device tensions the external riser. The drilling system also includes a surface wellhead system that includes a wellhead, a collet, and a flange assembly. The wellhead, collet, and flange assembly are assembled to establish a common bore for receiving the top of the internal riser. A gasket located between the top of the internal riser and an inner shoulder of the flange assembly seals between the wellhead system and the top of the internal riser. The surface wellhead system also retains the internal riser in tension with the wellhead, the internal riser extending above the wellhead into the collet.

Abstract: A subsea wellhead assembly having a tubing hanger set in a tubing hanger spool and a ring with axial passages set in an upper end of the tubing hanger. The wellhead assembly includes a production tree that lands on the tubing hanger spool. Tubing extends from the axial passages in the ring through axial bores provided in a sidewall of the tubing hanger. When landed, a lower end of the production tree engages an upper surface of the ring causing the ring to rotate and align its axial passages with axial passages in the production tree. The respective lower and upper surfaces of the tree and ring are strategically castellated to orient the passages.

Abstract: A riser clamp (20) comprising a first jaw portion (211) and a second jaw portion (212) that can be opened and closed relative to each other. The jaw portions (211/212) each comprise a thermoplastic body (301/302) that can be, for example, injection molded pieces of polyethylene (e.g., HDPE). The jaw portions (211/212) can be connected by a hinge (39) that is integrally formed therewith. The clamp (20) can also include cradles (701/702) and caps (711/712) for holding auxiliary lines.

Abstract: A subsea cap method and system having a canister attached to a port in a subsea cap that is positioned on a subsea structure and materials contained within the canister for release through the port into the defined area beneath the subsea cap and around the open upper end of the subsea structure. That is, the materials treat the water inside the cap and may optionally also treat the water outside the cap. The canister can be attached to, or removed from, the subsea cap subsea without removing the subsea cap from its resting place on the subsea structure. The system can be deployed via an ROV, diver or other means. The positioning of the subsea cap on the subsea structure and the placement and active or passive release of the material through the port into the defined area provides a system that protects the subsea structure from such problems as falling debris, silt, corrosion and organic growth while saving valuable time and resources.

Abstract: Force-dampening arrangement (100) for dampening forces between two interconnectable parts in a tube string, of which interconnectable parts a lower part (101) is connected to the upper end of a string element (105, 3a) extending into a subsea well (5) and an upper part (103) is suspended from a floating surface installation (1) through at least one suspension element (3b) extending up to said surface installation. The force-dampening arrangement (100) is connected to the tube string above a string-portion (3a) extending into said subsea well, and below at least a portion of said suspension element (3b). The force dampening arrangement (100) exhibits an upper and lower section (109, 111) that are vertically movable in relation to each other, thereby yielding for impact forces between said interconnectable upper and lower parts (103, 101) resulting from vertical heave movement of said portion of suspension elements (3b) moving vertically in respect of the string element (3a).

Abstract: A subsea wireline system for soft landing equipment during installation. The subsea soft landing wireline system includes coarse alignment members that can be part of a tree and interact with a funnel located on the equipment to be installed by the soft landing system. Smaller alignment members can provide fine alignment and also interact with a funnel located on the equipment to be installed. The funnels are used to trap sea water that provides a cushion for the equipment being installed. Once in alignment, trapped water can be released from the funnel or funnels via a restricted orifice and/or a control valve located on an ROV. The system achieves soft landing without the use of a running tool, thus reducing expense.

Abstract: A wellhead for subsea use and a method of making same where the wellhead is constituted by a body having a bore (3) therethrough and at least one side bore (9, 11) for provision of fluid communication through the wall of the wellhead (1), and where the wellhead (1) includes a pipe hanger (30) provided with a bore (34) therethrough and a side bore (36) for provision of fluid communication between a tubing string (9?) connected to the pipe hanger (30) and one of the side bores (9) of the wellhead (1), where the wellhead (1) is provided with at least one internal safety valve (42, 44) arranged to be able to shut off fluid communication through the wellhead.

Abstract: A subsea wellhead assembly comprising a casing housing and a casing extending down inside the well, and a tubing hanger. The tubing hanger comprises first and second valves, each valve being a fail safe valve.

Abstract: A well production system including a wellhead and a first casing string supported from a first casing hanger landed on a shoulder in the wellhead bore. A loading shoulder assembly is installable in the wellhead and includes an energizing ring, a loading ring threaded into the interior of the energizing ring, a lock ring, and a hold-down ring threaded into the interior of the loading ring. The hold-down ring engages the first casing hanger to prevent rotation of the hold-down ring and restrain rotation of the loading ring. The lock ring is expandable from an unset position into supporting engagement with the wellhead in a set position upon rotation of the energizing ring. The hold-down ring is also moveable axially out of the loading ring to restrain the first casing hanger.

Abstract: A seal seals an annulus in a subsea assembly between a wellhead and a casing hanger landed on a shoulder within a bore of the wellhead. The seal includes a casing hanger seal ring disposed within the annulus. The seal ring engaged with an inner diameter surface of the wellhead, and engaged with an outer diameter surface of the casing hanger so that the seal ring prevents flow through the annulus. A lockdown slip ring is secured to a lower end of the seal ring so that, when the seal ring is energized, the lockdown slip ring engages a substantially smooth inner diameter surface portion of the wellhead and a substantially smooth outer diameter surface portion of the casing hanger to limit upwards axial movement of the casing hanger.

Abstract: A technique enables protection of subsea wells. The technique employs a subsea test tree designed to ensure control over the well in a variety of situations. The subsea test tree is formed with at least one shut-off valve to protect against unwanted release of fluids from the subsea test tree. The subsea test tree also is coupled with and controlled by a control system having a subsea control module mounted to an interior mandrel.

Abstract: A leadscrew has first and second housing portions—which slide telescopically together. A shaft having an externally threaded portion screws into a complimentary internal threaded portion in the first housing portion, the shaft extending out of the second housing portion at a point where a fluid tight seal is provided_between the shaft and the other of the housings and allows rotation during a screwing action. The second housing includes a flanged end to which a ROV drive bucket is bolted. The shaft has a squared end so that it can be rotated relative to the bucket by the ROV. O-rings provide fluid tight seals between the two housing portions, between the flanged end and bucket, and between the shaft and bucket. A deep sea version incorporating oil bath the pressure of which is equalised to that of the surrounding sea so that O-rings do not have to withstand large pressure differences.

Abstract: A riser pipe for drilling an offshore well comprises a main tube extending the well up to a floating support, an auxiliary line being arranged parallel to main tube (4a, 4b). The auxiliary line comprises tubular sections (7a, 7b) made of steel and assembled end to end with a sliding fit by means of a tubular end part (25). According to the invention, a material, a titanium alloy for example, having an elastic limit at least 25% higher than that of the steel tubular sections (7a, 7b), is selected to manufacture said end part (25), and the end part as well as the end of said sections are dimensioned by taking account of the elastic limit of said material so as to reduce the sealing section of the end part.

Abstract: A riser clamp (20) comprising a first jaw portion (211) and a second jaw portion (212) that can be opened and closed relative to each other. The jaw portions (211/212) each comprise a thermoplastic body (301/302) that can be, for example, injection molded pieces of polyethylene (e.g., HDPE). The jaw portions (211/212) can be connected by a hinge (39) that is integrally formed therewith. The clamp (20) can also include cradles (701/702) and caps (711/712) for holding auxiliary lines.

Abstract: A wellbore sealing assembly can include a sealing ring, an energizing ring, and a multifunctional key for engaging the sealing ring and the energizing ring. The multifunctional key can have a key body, a guide member, and a retainer stud. The key body can be located in an aperture in a sidewall of the sealing ring and the guide member and retainer stud can protrude through the sidewall into a guide slot and recess of the energizing ring. Downward force on the energizing ring can cause the retainer stud to shear away while the guide member travels in the guide slot to prevent rotation of the energizing ring relative to the sealing ring. The guide member can also aid in complete seal retrieval by locking against the bottom of the key-way slot in the energizing ring.

Abstract: A connection system for connecting flow interface equipment to a subsea manifold is disclosed. The connection system relates particularly to a connection apparatus adapted to land a conduit means on a subsea manifold in a first stage of the connection and to connect a conduit means of the connection apparatus to a choke body of the manifold in a second stage of the connection.

Abstract: A device and method of handling a plug in a tubing hanger includes a pressure actuated sequence valve that has multiple outlets. Hydraulic fluid from a remotely operated vehicle (ROV) provides hydraulic fluid that selectively flows through the valve for operating a tool that handles the plug. The valve outlets are ported to separate lines for operating different functions of the tool. Flow to a specific outlet occurs by sequencing the valve to a corresponding position, where the valve is sequenced by changing pressure of the hydraulic fluid. The sequence valve is disposed in a piston that is axially movable within the tool. A stroking rod attaches to the piston, and is actuated by diverting flow to sides of the piston.

Abstract: A method and apparatus for setting an inner wellhead member in a subsea wellhead housing includes connecting an inner wellhead member to a running tool and running the running tool and wellhead member through a tubular member to a wellhead housing. A plurality of pistons urge fluid through a closed-loop hydraulic system. That fluid actuates a locking mechanism to lock the inner wellhead member into the wellhead housing, and also actuates a release mechanism to release the running tool from the inner wellhead member. The pistons are moved from one position to another in response to fluid pressure from the running string to which the running tool is connected, fluid pressure from the tubular member in which the running tool is located, or in response to fluid in the closed-loop hydraulic system that is being moved in response to the other one of the pistons.

Abstract: Arrangement in a hose connector of a riser provided between a wellhead and a floating surface installation. One or more hoses form a flexible fluid communicating connection between an upper portion of the riser and the floating surface installation. The first end portion of at least one fluid conduit is fixed to the riser by an upwardly directed, first pipe muzzle and is provided with a rotatable connecting sleeve. Each of one or more flexible hoses is connected to a conduit spool of a connecting assembly provided with a second and pipe muzzle that is arranged for releasable mating with the first end portion of the fluid conduit. A lifting yoke is connected to the connecting assembly and forms an actuator which is able to effect rotary motion to the connecting sleeve to enable engagement.

Abstract: The assembly comprises a housing (1) having a first end having an inlet channel and a second end having an outlet channel, said channels being connected by a central passage (3), said housing further comprising a side-entry bore (2) providing communication between said central passage and the external of said housing, the assembly also comprising a hanger positioned below said side-entry bore, supporting a coiled tubing and provided with a first passage communicating with said coiled tubing and a second separate fluid passage communicating with the annulus surrounding said coiled tubing.

Abstract: A connector includes a male flange and a female flange allowing to assemble a main tube and auxiliary line tubes. A locking ring assembles the male flange and the female flange. The locking ring is mounted mobile in rotation on the outer periphery of the male flange while cooperating with the outer periphery of the male and female flanges.

Abstract: A method of mounting a subsea control module (1) on a mounting plate (10) of an underwater tree of a subsea hydrocarbon well comprises lowering the module to the plate and attaching the module to the plate with an adapter (6) between it and the plate and with portions of the module being coupled with portions of the mounting plate.

Abstract: A technique for subsea operations utilizes a surface vessel to perform the installation and retrieval of submersible pumps or other tools with respect to a subsea well. A submersible pump is conveyed from a surface vessel to a subsea installation which is used to temporarily secure the submersible pump. Subsequently, the surface vessel is again used in cooperation with a conveyance to deliver the submersible pump to a desired location in a wellbore beneath the subsea installation.