Abstract: A wellhead load relief device for reducing riser system induced load effects on a subsea wellhead and a method of installing a subsea wellhead assembly onto a subsea wellhead using the wellhead load relief device. The wellhead load relief device includes: a receptacle for receiving well control equipment, wherein the receptacle has an open top to permit the well control equipment to be received in the receptacle; and an adjustable support mechanism for rigidly supporting well control equipment received in the receptacle. The adjustable support mechanism is located within the receptacle and the adjustable support mechanism has a lateral extent that is adjustable relative to the receptacle. The wellhead load relief device is for providing a load path for forces exerted on the well control equipment to the seabed without going via the subsea wellhead. A subsea wellhead assembly including the wellhead load relief device is also provided.

Abstract: The present invention provides a nonresident system for depressurizing subsea apparatus and lines comprising a depressurizing tool (5) adapted for being coupled to an ROV interface (6) of a subsea apparatus, wherein the depressurizing tool (5) is coupled to an ROV (4), wherein: the ROV interface (6) comprises a first pipeline (6a) for connection to a first hydrocarbon transport line (8), a second pipeline (6b) for connection to second hydrocarbon transport line (9), and a connection mandrel (6d); and the depressurizing tool (5) comprises a suction line (5a) adapted for being connected to the first pipeline (6a) for connection to the first hydrocarbon transport line; a discharge line (5b) adapted for being connected to the second pipeline (6b) for connection to the second hydrocarbon transport line; a pump (5c); and a connector (5d) adapted for being connected to the connection mandrel (6d) of the ROV interface (6).

Abstract: A mobile well servicing system and method are provided for performing well services. The mobile well servicing system can include a work surface on a platform supporting an equipment such a jack, a blowout preventer (BOP), a coiled tubing (CT) injector and a mast. The mast is pivotable between a first position, with a lifting point positioned over the work surface, and a second position, with the lifting point positioned behind the platform. A hoist winch assembly mounted at the platform raises the equipment from the platform when the mast is at the first position. The equipment then pass through a space between two parallel legs of the mast, and lowered to a wellhead when the mast is at the second position. Multiple tasks such as well completion, change of dynamic temperature sensor (DTS) and electric submersible pump (ESP) can be achieved using this system.

Abstract: A landing system for subsea equipment includes a heavy component having a latch affixed thereto and having a mechanism attached to enable lowering the heavy component from a platform above the bottom of a body of water. A landing system frame has a connection point matable with the latch. A linear motor is functionally coupled to the landing system frame and at least one of the subsea well structure and a movable frame on the landing system. The linear motor is operable to control a distance between the landing system frame and the subsea well structure or the movable frame.

Abstract: A coiled tubing string may be moved into and/or out from water by deploying an open water coiled tubing control system at sea such as via a vessel. The open water coiled tubing control system comprises a reel configured to accept a coiled tubing string, a surface injector, a reel tensioner configured to control an arch formed by the coiled tubing string between the reel and the surface injector, a controller, a subsea assist jack, and a predetermined set of a predetermined set of sensors. Motion of the surface injector and the subsea assist jack are used in part to move the coiled tubing string accepted by the reel into and/or out of a subsea well by receiving various information at the controller from the predetermined set of sensors and using the controller to resolve the received information to move the coiled tubing string into or out from the subsea well at a predetermined desired speed to achieve an outcome commanded by a single input from an operator.

Abstract: A method for controlling a coiled tubing unit at a well site having a wellbore that extends downhole from a surface of the well site is provided. The method includes creating a coiled tubing simulation for performing a coiled tubing operation. The method further includes receiving wellbore data. The wellbore data includes downhole data collected using a downhole sensor downhole in the wellbore, and the downhole data includes a differential pressure measurement. The method further includes generating an automated coiled tubing control plan for the coiled tubing unit based at least in part on the wellbore data and the coiled tubing simulation. The method further includes controlling the coiled tubing unit using the automated coiled tubing control plan to regulate at least one of a rate-of-penetration of the coiled tubing unit or a weight-on-bit of the coiled tubing unit based at least in part on the differential pressure measurement.

Abstract: Systems and methods for landing a tubing hanger in a wellhead and then orienting a tree (or spool, or flowline connection body) relative to the tubing hanger while landing the tree on the wellhead are provided. This alignment is accomplished without the use of either a tubing spool or a BOP stack with an orientation pin. The tubing hanger alignment devices may be used to orientate the tree as the tree is landed so that the couplings and stabs between the tree and the tubing hanger line up with each other just at the moment of landing.

Abstract: A subsea wellhead assembly 1 comprises: a subsea wellhead 2; a template 6 associated with the wellhead; subsea riser system equipment 4 connected to the wellhead and one or more connection members. The subsea riser system equipment 4 is also connected to the template 6 by the one or more connection members so that lateral support is provided to the subsea riser system equipment 4 from the template. A method of installing the subsea wellhead assembly 1 is also provided.

Abstract: A method for replacing a first control pod of a BOP stack includes (a) lowering a control pod exchange device subsea. In addition, the method includes (b) coupling the control pod exchange device to the BOP stack. Further, the method includes (c) transferring the first control pod from the BOP stack to the control pod exchange device after (b). Still further, the method includes (d) lifting the control pod exchange device to the surface after (c).

Abstract: A hoisting system includes a hoisting tower, a yoke which is movable relative to the hoisting tower and which carries a tool, a first winch, a second winch, a first sheave arranged in a top section of the hoisting tower, a second sheave arranged in the top section of the hoisting tower, a first hoisting member arranged to extend from the first winch to the yoke via the first sheave, a second hoisting member arranged to extend from the second winch to the yoke via the second sheave, and at least one first releasable connector which selectively connects the second hoisting member to the yoke.

Abstract: A method and apparatus for testing a blowout preventer which includes a plurality of safety devices and an assembly of fluid control valves that are remotely actuatable to an open and closed position for controlling flow of drilling fluids into a well includes a hydraulic power unit control station for remotely and selectively actuating one or more safety devices and fluid control valves to a test orientation. A hydrostatic test system supplies fluid under first and second test pressure and documents any pressure loss due to fluid leaks within a closed system.

Abstract: A method of installing a subsea pipeline having a direct tie-in to a subsea structure includes, during introduction of the pipeline into the sea from a pipe laying vessel, applying a plastic deformation to a region of the pipeline at or close to an end of the pipeline to be tied-in and, either during or following tie-in, elastically deforming the region to increase its radius of curvature.

Abstract: The present invention provides a system for auto-alignment and tensioning of flexible pipes (24) in a stationary production unit, said system comprising (i) at least one tensioner (10) comprising an upper cone (10s) and a lower cone (10i), the upper cone (10s) and the lower cone (10i) being fixed together and forming a symmetrical double cone structure provided with an internally hollow cylindrical opening suitable for passage of a flexible pipe (24), (ii) at least one supporting fork (12) with pivoted connection to the at least one tensioner (10) and (iii) at least one coupling device (16) which, at a first end, is connected detachably to the at least one supporting fork (12) and, at a second end, is connected to the stationary production unit. A method for installing flexible pipes by means of said system is also provided.

Abstract: A method and apparatus for testing a blowout preventer, which includes a plurality of safety devices and an assembly of fluid control valves that are remotely actuatable to an open and closed position for controlling flow of drillings fluids into a well, includes a hydraulic power unit control valves to a test orientation. A hydrostatic test system supplies fluid under first and second test pressure and documents any pressure loss due to fluid leaks within a closed system.

Abstract: A technique facilitates use and operation of a tree cap which may be deployed into engagement with a subsea tree located over a subsea well. The subsea tree may comprise a production flow passage and an annulus flow passage in communication with a tree cap receiving area. The tree cap may be moved via a remotely operated vehicle (ROV) into position in the tree cap receiving area. The ROV also may be operated to selectively lock and/or release the tree cap with respect to its position in the subsea tree.

Abstract: High pressure seals for pressure control fittings are disclosed, where such pressure control fittings are located at a wellhead, for example. Embodiments of cam lock seals, a spring-driven ball race seal and wedge seals are disclosed.

Abstract: A connection system for connecting a structure fluid line on an offshore structure with a riser fluid line on a subsea riser. The system includes a connector attachable to the subsea riser and a gooseneck comprising a gooseneck connector in fluid communication with the structure fluid line. A frame is supportable on the connector and comprises a slide releasably engageable with the gooseneck and moveable within the frame. The slide is remotely controllable to move the gooseneck connector into and out of a connected position to establish or break fluid communication between the structure fluid line and the riser fluid line.

Abstract: A towable unit for subsea processing of well fluids comprises a pipeline bundle extending between, and capable of acting in tension between, a first towhead at an upstream end of the bundle and a second towhead at a downstream end of the bundle. At least one of the towheads has an on-board processing facility for processing the well fluids, which facility effects at least separation of water phases that are present in the well fluids.

Abstract: An acoustic control system wirelessly operates a subsea latching assembly or other subsea device, such as an active seal. The acoustic control system may control a subsea first accumulator to release its stored hydraulic fluid to operate the latch assembly or other subsea device, such as an active seal. An RCD or other oilfield device may be unlatched or latched with the latching assembly. The acoustic control system may have a surface control unit, a subsea control unit, and two or more acoustic signal devices. A valve may allow switching from an umbilical line system to the acoustic control system accumulator.

Abstract: A coupling device for connecting a first coupling housing and a second coupling housing. The first coupling housing has a guiding element extending from the first coupling housing and having a free end at a distance (h) from the first coupling housing central axis (a-a). The second coupling housing has a receptacle for the guiding element and pull-in means for pulling the guiding element into the receptacle, said pull-in means being connected to the guiding element free end. The invention allows the first coupling housing to be pulled towards the receptacle at an angle which is not coincident with the central axis (a-a), and when the guiding element is in place inside the receptacle, the first coupling housing central axis (a-a) and the central axis (b-b) of the second coupling housing are aligned and coincident, and the two housings are rotationally aligned.

Abstract: A method for removing a hydrocarbon production platform at sea, the production platform being connected to a hydrocarbon well, and including a support structure and an upper part being supported by the support structure, where the method includes the steps of; temporarily closing the well, removing at least part of the upper part from the support structure, positioning a well abandonment module on the support structure, which well abandonment module is constructed and arranged to perform well abandonment operations, performing abandonment operations from the well abandonment module to abandon the well, removing the well abandonment module from the support structure after the well abandonment operations are completed.

Abstract: A cap for protecting a sealing surface of a hub of a subsea device includes an equalization valve and a fluid conduit. The equalization valve includes a valve body having a pressure equalization conduit, a sleeve disposed about the valve body and having a port allowing fluid communication across the sleeve, and a valve spring configured to bias the sleeve to a closed position. The sleeve is configured to move to an open position in response to a force that depresses the sleeve and causes the valve spring to compress and the port is fluidly isolated from the pressure equalization conduit in the closed position and is in fluid communication with the pressure equalization conduit in the open position. In the open position, an interior environment of the subsea device is in fluid communication with the environment outside the cap through the equalization valve.

Abstract: The disclosure provides an in-situ system and method for transferring a load from a tensioned flexible link between at least two bodies, such as between a buoyancy can and a subsea riser or between a moored offshore platform and a pile. The system and method provides a tether assembly having a hydraulic cylinder and/or a transfer assembly, where the hydraulic cylinder is configured upon actuation to decrease a distance between the two bodies; and the transfer assembly includes a mechanical interlock configured upon actuation to maintain the decreased distance between the two bodies independent of the hydraulic cylinder. The mechanical interlock can include various embodiments that can be selectively activated and deactivated position to allow the hydraulic cylinder to operate at various times in the transfer process. A support assembly can provide additional support to the flexible link independent of or in addition to the transfer assembly.

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 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: Various implementations include a system for introducing upwardly a flexible member into a tubular fixed structure with a sleeve surrounding the flexible member in the region where the flexible member attaches to the tubular fixed structure. The system allows for the flexible member to be drawn upwardly into a bore of the tubular fixed structure. In one implementation, a plurality of locking dogs are attached to and are radially moveable with respect to the sleeve between an inner locking position in which they engage with the flexible member, and an outer release position in which they are disengaged from the flexible member. In addition, a latch ring is disposed on a substantially cylindrical surface so that it may be deflected axially along said surface on contact between the sleeve and tubular fixed structure to permit release of the locking dogs.

Abstract: A containment system having a containment dome and a seal plate which is attached to an oil wellhead casing or riser to prevent oil spills and contamination when an oil leak occurs. The containment dome is sealed to the seal plate by a compression mechanism so that oil will not leak from the containment dome. The containment dome can provide a wellhead patch to a wellhead system wherein the wellhead patch can interface with a capping stack. Chemicals can be injected into the containment dome to prevent hydrates from forming. All aspects of controlling and operating an oil wellhead can be performed through the containment dome and seal plate, and all aspects of installation, regulation, and control of the containment dome can be performed by remote operating vehicles under water.

Abstract: A blowout preventer and flow regulator, comprising blocks, each having a channel and plates to close it. The blocks are placed over a pipe through which oil or other fluid is escaping, so that the pipe is in their channels. Alongside the channel in each block are one or more plates, having diameters somewhat larger than the diameter of the channel. One or more pistons are attached to each of the plates. Explosive charges, or other suitable means, move the pistons to propel the plates across the channel to seal it off and stop the leak. Flanges may limit the pistons' movement. Gears can engage teeth on the pistons to withdraw the plates from the channel, to reopen it and allow the flow of oil or other fluid to resume. Plates may be withdrawn part way from the channel, to reduce and control the flow, without cutting it off completely.

Abstract: A combination blowout preventer and recovery device, comprising a lower part that is placed over a well pipe, and an upper part having a channel and plates to close it. The large end of the valve is placed over a well pipe through which fluid is flowing out. The small end of the valve is connected to the channel. A sleeve connected to the return pipe is placed over the well pipe. Positioning rings are attached to a high pressure pipe, that can fit inside the well pipe. Grinders remove matter from the well pipe. Pistons are attached to each of the plates. The pistons propel the plates across the channel to seal it off and stop the leak. Flanges may limit the pistons' movement. Gears can engage teeth on the pistons to withdraw the plates from the channel, to reopen it and allow the flow of fluid to resume.

Abstract: A tubular clamp for gripping a tubular is disclosed. In one aspect, a tubular clamp for use with a cutting and lifting system is provided. The tubular clamp is configured to move between an opened position and a closed position. The tubular clamp further includes at least one slip member to permit the clamp to bear the weight of a severed tubular string. Lifting lugs on an outer surface of the clamp permit attachment to a lifting assembly.

Abstract: Flexible hang-off arrangement is provided for a catenary riser suspended from an offshore or inshore platform, which includes floating or fixed platforms, vessels or/and buoys. The bending loads in the top segments of the said riser are reduced by incorporating a pivot at the riser hang-off. Pressure containing welded, bolted, rolled or swaged pipe spools transfer fluids, including hydrocarbons between the riser and the platform. Along significant spool lengths the tangents to the center lines of said spools are orthogonal to and offset from the tangent to the center line of the riser at the hang-off. The said pressure containing spools include arbitrary looped, spiral and helicoidal designs that are subject to torsion.

Abstract: A variable buoyancy subsea running tool for use with subsea transportable devices, such as a tree cap. The buoyancy of the running tool may be varied through fluid or gas displacement in one or more containers. Alternatively, the running tool may be configured with a buoy that has static buoyancy, with the buoyancy of the running tool being varied through the addition of a counterweight. The running tool can be used to install or uninstall a tree cap on a subsea tree. Installation of a tree cap may be actuated by a remotely operated vehicle. Additionally, the running tool may be moved by a remotely operated vehicle and may have additional features such as a position locator device.

Abstract: removable blowout recovery valve. The large end of the valve (or funnel) is placed over a well pipe (or other pipe) through which oil (or other fluid) is flowing out. The small end of the valve is connected to a return pipe. A high pressure pipe with a smaller diameter is inserted into the well pipe. A sleeve connected to the return pipe is placed over the well pipe. A locking collar is attached to the sleeve. Positioning rings are attached to the high pressure pipe, that can fit inside the well pipe. A sharp edge extends from the sleeve, by which irregularities in the well pipe can be cut. Lasers or other cutting devices are attached to extension arms, that can also cut irregularities in the well pipe. The slope of the valve can be changed. The valve can be removed and raised with the aid of floats.

Abstract: A containment fitting for a wellhead capping device including a truncated conical section capable of fitting into a central aperture of a flange that is attached to a ruptured wellhead pipe end and which can be fitted into position by several wires or cables that are pulled through apertures in the pipe wellhead flange. A method of installation includes undersea welding of the flange onto the end of the ruptured wellhead and inserting plural bobbin structures attached to cable wires into through holes extending at angularly opposed sides of the flange such and when completely in line through a second flange on constriction equipment, can bring the flanges adjacent and in line to permit attachment therebetween by bolts.

Abstract: An automatic release system for a riser includes a guide funnel assembly that receives a shaft coupled to the riser. A pull-head is located inside at least a portion of the shaft and coupled to the shaft. The pull-head is coupled to a pulling mechanism. One or more spring-loaded dogs are mounted on the outside of the shaft. The dogs radially move in and out through one or more openings in the shaft aligned with the dogs and engage a groove on the pull-head when radially moved in through the openings. One or more stopper mechanisms are mounted on the outside of the shaft and aligned with the dogs. In a first position, the stopper mechanisms inhibit the dogs from disengaging from the groove in the pull-head. In a second position, the stopper mechanisms allow the dogs to disengage from the groove in the pull-head.

Abstract: The present invention is a blowout preventer including a large funnel. The large end of the funnel is placed over a well pipe (or other pipe) through which oil (or other fluid) is blowing out. The small end of the funnel is connected to a return pipe. A high pressure pipe with a smaller diameter is inserted into the well pipe. Air is pumped under high pressure through the high pressure pipe, separating the oil and forcing the oil, that is not kept down in the well pipe by the pressure, up through the return pipe. The funnel can be moved into alignment with the well pipe using positioning arms. A stopper may be forced into the well pipe. There are propellers near an end of the high pressure pipe. There are stacked turbines in the return pipe. There is a gasket with pivoting overlapping plates, to seal the pipe.

Abstract: A connector (1) for connecting components of a subsea system, the connector comprising male and female components (3, 2), guide means (11) for assisting preliminary orientation of the male component within the female component and means (18; 20; 21) for drawing the male component into the female component and latch means (22) for securing the male component within the female component.

Abstract: A mechanism for clamping first and second stabplates together comprises a pivoted cam member and clamping means for co-operating with the cam member. The mechanism is such that the cam member is displaceable between a first position in which, in co-operation with the clamping means, it clamps the stabplates together and a second position in which it has rotated to be between the stabplates with the stabplates separate from each other.

Abstract: Well apparatus comprises a tower, and a support for supporting well intervention, completion, testing, or drilling equipment, the support being attached to the tower and being movable laterally from a parked position on the tower, where preparation of the equipment can be carried out without occupying an operational area where the equipment is to operate on the well, and an operational position in the operational area, and the support being arranged to be lowered or lifted, the apparatus further comprising a guide mechanism for guiding the support so that as the support is - lowered or lifted it is guided along a path involving lateral movement from the parked position to the operational position in the operational area.

Abstract: The disclosure provides an in-situ system and method for transferring a load from a tensioned flexible link between at least two bodies, such as between a buoyancy can and a subsea riser or between a moored offshore platform and a pile. The system and method provides a tether assembly having a hydraulic cylinder and/or a transfer assembly, where the hydraulic cylinder is configured upon actuation to decrease a distance between the two bodies; and the transfer assembly includes a mechanical interlock configured upon actuation to maintain the decreased distance between the two bodies independent of the hydraulic cylinder. The mechanical interlock can include various embodiments that can be selectively activated and deactivated position to allow the hydraulic cylinder to operate at various times in the transfer process. A support assembly can provide additional support to the flexible link independent of or in addition to the transfer assembly.

Abstract: An underwater connection installation (26) and a laying method for connecting a riser and a flexible pipe (22) that are intended for carrying hydrocarbons. A post (28) is attached to a float (20) to suspend the riser (12) below the surface. The post (28) supports a gooseneck shape pipe (54) that has a bent-over outlet free end (58) ending in a first coupling (60). A coupling end piece (32) mounted on the flexible pipe (22) includes a second coupling (86). The coupling end piece (32) and the post (28) define mechanical guides including complementary frustoconical rings (64, 84). The driving of the coupling end piece (32) and of the bent-over free end (58) toward each other causes the frustoconical rings (64, 84) to engage one another to bring about coaxial alignment of the couplings (60, 86).

Abstract: The present invention is a blowout preventer including a large frustoconical funnel. The large end of the funnel is placed over a well pipe (or other pipe) through which oil (or gas or other fluid) is blowing out. The small end of the funnel is connected to a return pipe. A high pressure pipe with a smaller diameter is inserted into the well pipe. Air is pumped under high pressure through the high pressure pipe, separating the oil and forcing the oil, that is not kept down in the well pipe by the pressure, up through the return pipe. The funnel can be moved into alignment with the well pipe using jets. There are sensing devices on moveable arms. A stopper is forced into the well pipe. There are one-way valves in the stopper. There are stacked turbines in the return pipe. There is a gasket with pivoting overlapping plates.

Abstract: A combined piloting method of remote operated underwater vehicles includes: connecting, to a vertical profile, a constraint device including at least two arms arranged at a reciprocal fixed angular position, each of the at least two docking arms including at a first end a device for the hooking of a remote operated underwater vehicle, the at least two docking arms being constrained at one of their second ends to a device for the sliding and rotating hooking to the vertical profile; connecting at least two remote operated vehicles to the constraint device; detecting the position of the overall structure consisting of the constraint device and remote operated vehicles; detecting the orientation of each of the remote operated vehicles; receiving data relating to the position and orientation to be reached; determining the power required by each remote operated vehicle; and transmitting related commands to each vehicle.

Abstract: A spider assembly is a round platform with a central bore used to support sections of casing as the sections of casing are joined to one another and lowered below a drilling platform. The spider assembly comprises two c-shaped section joined together at two seams, one seam at the end of each leg of the c-shape. A clamping plate is used to join each seam and apply a preload force on the joint. The preload force minimizes axial deflection at the joint.

Abstract: A subsea connection assembly comprises a stab plate a first stab plate which carries a first plurality of couplers and a second stab platewhich 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: The disclosure provides a subsea overload release system and method. The disclosure provides a releasable connection system than can be overridden during an overload condition, and is resettable in a subsea location in situ. During normal operation, a collet sleeve is slidably engageable with a collet having one or more fingers that can releasably couple a first member with a second member. During an overload condition, an overload piston acting on fluid in an overload reservoir causes an overload pressure and a rupture or other release of fluid through an overload pressure member, causing the overload reservoir to at least partially collapse. The collapse allows the system to extend and force open the fingers to disengage the second member from the first member. When the overload symptom is rectified, the overload reservoir can be reset and the overload pressure member reset or replaced without requiring repairs above sea surface.

Abstract: The present invention is a blowout preventer including a large frustoconical funnel, made of metal or other material. The large end of the funnel is placed over a well pipe (or other pipe) through which oil (or gas or other fluid) is blowing out. The small end of the funnel is connected to a return pipe. A high pressure pipe with a smaller diameter is inserted into the well pipe. Air is pumped under high pressure through the high pressure pipe, separating the oil and forcing the oil that is not kept down in the well pipe by the pressure up through the return pipe. The Bernoulli effect keeps the funnel on the well pipe. A gasket at the top end of the channel prevents leaks. Channels and rotating blades near the top of the funnel accelerate the flow, reducing pressure and increasing the suction due to the Bernoulli effect.

Abstract: Flexible riser, comprising a length of a flexible pipe with an upper end, a bend restrictor and a termination for hanging up on a vessel, a floating installation or a platform, distinguished in that the bend restrictor in the upper end is connected to an adapter pipe extending from a lower end at the bend restrictor to an upper end, to an end coupling to which the upper ends of both the flexible pipe and the adapter pipe are fastened, the flexible riser extending through the bend restrictor and the adapter pipe and the end connection comprising a means for hanging up at deck level of the vessel, the installation or the platform. Method for pulling-in and hanging up of the flexible riser.

Abstract: A method for the extinction or oil well-killing or killing of an underwater well for the extraction of hydrocarbons under uncontrolled fluid discharge conditions, also called blowout, by assembling, in correspondence with the lower end portion of a string of pipes for the extinction or killing string, a constraint group for rigid connection between a plurality of remote-operated underwater vehicles and the killing string; detecting the position of a flow of fluids and positioning the killing string substantially in correspondence with said flow; lowering a plurality of remote-operated vehicles close to the lower end portion of the killing string; connecting the remote-operated vehicles to the constraint group; detecting in real time the relative position of the flow of fluids with respect to the vehicles and calculating the position of the outlet hole of the flow; on the basis of the calculated position of the outlet hole, coordinately piloting the vehicles so as to bring the lower end of the string in corres

Abstract: A connector is lowered onto and secured to a subsea member, effecting a seal between subsea member and the connector. The connector includes an outer body defining a cavity, and an inner body defining a bore, wherein the lower end of the inner body resides within the cavity. The connector also includes an engaging member coupled to the outer body and adapted to engage the subsea device, the engaging member radially movable between a disengaged position and an engaged position. The connector includes a seal carried by the inner body and adapted to form a seal between the bore and the subsea device. Finally, the connector includes a pre-loading member coupled to the outer body, operable to urge the inner body and seal against the subsea device to exert a pre-loading force on the seal. A differential pressure between the bore and a subsea environment energizes the seal.