Abstract: A payload deployment tool is provided. The tool includes a housing having a coupler configured to couple to a fluid delivery conduit; a pressure chamber in communication with the coupler; a plurality of payload chambers in communication with the pressure chamber, each of the payload chambers having an upstream opening and a downstream opening; and a plurality of upstream pressure-rupturable seals respectively covering the upstream openings.

Abstract: An apparatus for predicting a deformed shape of a structure, and method of operating and forming the same. In an embodiment, the apparatus is formed with a riser with ends coupled respectively to an upper location and a lower location. The apparatus includes sensors configured to sense an inclination of the riser at riser nodes positioned on the riser between the upper location and the lower location. The apparatus further includes a data processing system configured to produce an estimate of a deformed shape of the riser employing deformed shaped functions to represent, respectively, the estimate of the deformed shape of the riser above and below the riser nodes.

Abstract: A motion compensating system is usable on a vessel during well intervention operations through a riser. The system includes a first floor; a second floor; a plurality of hydraulic cylinders connecting the first floor to the second floor; a bearing retainer attachable to the second floor; a spherical bearing provided between the second floor and the bearing retainer, wherein the spherical bearing includes a central opening therethrough for the riser to allow angular movement of the riser relative to the first and second floors; an insert bearing sleeve at least partially located inside the central opening of the spherical bearing; and a slip bowl attachable to the insert bearing sleeve. Each of the first floor, the second floor, the bearing retainer, the insert bearing sleeve and the slip bowl have an opening therethrough for the riser, and each opening is aligned with the central opening of the spherical bearing.

Abstract: Provided is a method for connecting coiled tubing strings, as well as a flexible stabbing snake. In one aspect, the method for connecting coiled tubing strings includes lowering a downhole end of a first coiled tubing string within a wellbore, and coupling an uphole end of the first coiled tubing string to a downhole end of a second coiled tubing string at a location between a coiled tubing injector and the wellbore to form a combined coiled tubing string. In at least one aspect, the method further includes lowering the combined coiled tubing string within the wellbore.

Abstract: The invention relates to the fluid treatment, such as acid stimulation, of a subsea hydrocarbon well via a subsea wellhead/Christmas tree. Fluid is delivered directly to the subsea wellhead from a pumping vessel. Control of the delivery of fluid is from the pumping vessel via a fail-safe close valve in the delivery line. The Christmas tree subsea module is controlled directly from a host platform via a subsea cable, whilst a radio data link between the vessel and host platform provides communication of downhole data to the pumping vessel during the operation.

Abstract: An offloading system for conveying hydrocarbons from a buoyancy-supported subsea riser to a surface tanker vessel comprises a flexible hose that hangs from the riser structure in a U-shape having first and second limbs. An upper end of the first limb communicates with the riser and an upper end of the second limb terminates in a pulling head for connecting the hose to the tanker. A clump weight acts on a lowermost bend of the hose between the limbs to maintain tension in the limbs. A subsurface holder fixed to the riser structure is arranged to hold the pulling head against the tension in the second limb of the hose when the system is in a standby state. The holder is offset laterally from a central longitudinal axis of the riser structure and a counterweight is positioned to a side of that axis opposed to the holder.

Abstract: A system is provided to compensate for heave of a vessel in which the compensation system has a first panel with a first magnetic field having magnetic flux disposed in a first direction and a second panel parallel to the first panel. The second panel has a second magnetic field having magnetic flux disposed in a second direction with the first magnetic field parallel to the second magnetic field. A conducting loop is located between the first panel and the second panel. The conducting loop is attachable to a cable connected to a load suspended in water. Compensating force generated by the first magnetic field and the second magnetic field transfers to the cable to compensate for heaving motion of the vessel and stabilize the cable-connected load in the water.

Abstract: Provided is an offshore wind turbine installation arrangement, including a lifting assembly realized to hoist a suspended load between a floating installation vessel and a wind turbine assembly, the lifting assembly including a crane supported by the floating installation vessel; a sensor arrangement realized to sense at least a motion of the floating installation vessel; and a controller realized to control elements of the lifting assembly on the basis of the sensed installation vessel motion to adjust the position of the suspended load relative to the wind turbine assembly. Also provided is a method of hoisting a load between a floating installation vessel and an offshore wind turbine assembly.

Abstract: The publication describes a mobile active heave compensator provided with an attachment device for suspending the compensator from a load bearing device and an attachment device for carrying a payload. The compensator comprises a passive heave compensation part and an active heave compensation part and is associated with a sensor arrangement producing input signals for a control unit and a power source. The compensator incorporates a hydraulic fluid pump and/or motor device, affecting the active heave compensating part, producing output signal(s) to the hydraulic fluid and/or motor device to transport the hydraulic fluid as required, based on input signals received from the sensor arrangement.

Abstract: This disclosure includes auxiliary-line riser segment assemblies (e.g., with isolation units) that are suitable for managed pressure drilling (MPD) and that can be lowered (e.g., when connected to other riser segment assemblies) through a rotary of a drilling rig. Some embodiments are configured to have portions of the auxiliary lines connected (e.g., without welding) below the rotary.

Abstract: The publication relates to a depth compensated actuator, for a transportable inline depth compensated heave com-pensator for subsea lifting operations. The actuator comprises a cylinder shaped body and a piston with a piston rod, the piston rod being intended for exposure to external water pressure, a first and second connection means associated with the actuator. Further, the actuator comprises a depth compensator comprising a cylinder, a piston and a piston rod, the end of which being exposed to surrounding water; and conduit means between at least one volume in the actuator and one volume in the depth compensator. The pistons and piston rods are shaped as any of: hollow piston rod, ring shaped piston, ring piston rod. The depth compensated actuator solves the problem if improving depth compensation performance regarding size, weight, required fluid consumption, internal/inherent friction and adaptability. Further, use of a depth compensated actuator is claimed.

Abstract: A slide-in structural interface between a Sea Water Intake Riser (SWIR) and a floating unit hull or sump tank bottom plate permits a pull-in, diver-less installation of the SWIR. Certain embodiments include an integrated, easily maintainable strainer.

Abstract: A mobile offshore drilling unit is converted to provide drilling, completion and workover access to multiple dry tree wells from a drilling derrick to allow production and export of oil and gas from high pressure, high temperature reservoirs in deep offshore waters. Existing practice has been for the drilling derrick on a production platform supporting dry tree wells to be moved over a fixed well slot. The present invention provides a movable wellbay that supports multiple top-tensioned subsea well tieback risers, which may be positioned directly below the derrick's rotary table and/or beneath another operating device. The use of top-tensioned subsea well tieback risers supported by the movable wellbay allows the converted facility to drill, complete, maintain, improve and produce from subsea wells through dry trees.

Abstract: A system and method is provided for determining curvature for subsea riser system, including but not limited to drilling risers, steel catenary risers, lazy-wave catenary risers and riser jumpers, comprising the steps of: periodically measuring acceleration in a first lateral direction at said vertical position to obtain a first acceleration timetrace processing said first acceleration timetrace to obtain a first acceleration spectra; applying a transfer function to said first acceleration spectra to obtain a first curvature spectra; and processing said first curvature spectra to obtain a first curvature timetrace. Preferably the transfer function is determined by a method comprising the step of modelling the riser as a Tensioned Timoshenko Beam. The curvature may be used to determine stress and fatigue damage in a structure from motions measured at a single location or a combination of motions measured at a single location with or without tension measurement.

Abstract: A vessel adapted to perform subsea wellbore related operations involving a riser string that is assembled from releasably interconnected riser sections and extends between a subsea wellbore and the vessel. The riser string vertical handling system of the vessel comprises a controlled motion device that is adapted to displace the riser string lifting tool in at least one horizontal direction relative to the riser spider device at least whilst travelling between said elevated and lowered position thereof loaded by the riser string suspended from the riser string lifting tool, thereby allowing to establish an inclined travel path with selectively variable inclination of the riser string lifting tool relative to an imaginary vertical line through the riser string passage of the riser spider device, e.g. said inclined travel path having an inclination selected to correspond to an actual water current induced inclination of an upper portion of the riser string during the riser string assembly process.

Abstract: A system for mitigating slugging in the conveyance of a subterranean resource can include at least one first pipe disposed proximate to a subterranean formation, where the at least one first pipe has a first cavity through which the subterranean resource traverses from the subterranean formation. The system can also include at least one second pipe disposed proximate to field equipment at an operating platform, where the at least one second pipe has a second cavity through which the subterranean resource traverses, where the field equipment is used to extract the subterranean resource. The system can also include a first slug mitigation assembly disposed between the at least one first pipe and the at least one second pipe, where the first slug mitigation assembly includes a first plurality of non-linear segments for reducing accumulation of gas or liquid pockets in the subterranean resource as the subterranean resource flows therethrough.

Abstract: Systems, methods, and apparatuses for adjusting and repositioning a coiled tubing tensioning device while deployed. The system comprises a tubing guide for receiving a coiled tubing, a tensioning device for maintaining the coiled tubing in tension, and a tower frame having a moveable platform supporting the weight of the tensioning device. The moveable platform is adjustable vertically to raise and lower the tensioning device with respect to the tower frame, and the tower frame permits the tensioning device to move horizontally with respect to a fixed ground point.

Abstract: In accordance with embodiments of the present disclosure, system and methods for controlling borehole pressure in a MPD system to compensate for heave effects on a drilling rig are provided. The systems and method described herein involve calculating and implementing set points for two or more MPD system components in real time. These MPD components that are controlled via the dynamic set points may include a choke, a backpressure pump (BPP), a rig pump diverter (RPD), a continuous circulation device, one or more mud pumps, a pressure relief system, or some combination thereof. By calculating and providing these set points in real-time during various well and drilling operations, non-productive time, well control events, and costs to remedy issues resulting from improper pressure levels within the borehole may be mitigated or avoided.

Abstract: An offshore drilling rig comprising a drill deck, at least one primary well center and a diverter system arranged below the primary well center, a drilling support structure extending upwardly from the drill deck and above the primary well center and the other work center and a first and a second hoisting system supported by the drilling support structure and being adapted for raising or lowering a first and a second load carrier, respectively, and where the offshore drilling rig comprises a positioning system adapted for selectively positioning at least the first load carrier in at least a first or a second horizontal position different from the first horizontal position, where the first load carrier in the first horizontal position is positioned above the primary well center, and in the second horizontal position is positioned above the other work center.

Abstract: An enhanced system and various methods for detangling and positioning of automatic fender positioning systems, comprising a system for stowing a boat fender in a fender receptacle, the receptacle having an opening for threading through a line, the line being attached to the fender, the line operable to pull up the fender into the receptacle through a second opening at the bottom of the receptacle, where upon while retracting the fender, the motor is configured to detect changes in current, and is configured to shut down if an overcurrent state is detected, the overcurrent state detection being based at least in part on a configured current limit.

Abstract: A connection assembly for engaging a tubular member underwater to restrain the tubular member from radial movement relative to the connection assembly includes a plurality of pads for engaging the tubular member at circumferentially spaced positions; and a plurality of biasing arrangements, each for biasing a respective pad radially inwardly into engagement with the tubular member; wherein each biasing arrangement includes a pre-loadable, mechanical, compressed spring arrangement for resiliently pressing its respective pad against the tubular member. The assembly need not employ any hydraulic components.

Abstract: A fluid containment system for a riser slip joint includes a fluid container sealingly engaged to a fixed part of the slip joint. A movable part of the slip joint is axially movably engaged with the fixed part. An annular seal is disposed between the fixed part and the movable part. A body of fluid disposed in the fluid container has a level selected to submerge the annular seal and at least a portion of the movable part. The system includes means for maintaining a level of the body of fluid substantially constant.

Abstract: Methods and apparatus for diverting fluids either into or from a well are described. Some embodiments include a diverter conduit that is located in a bore of a tree. The invention relates especially but not exclusively to a diverter assembly connected to a wing branch of a tree. Some embodiments allow diversion of fluids out of a tree to a subsea processing apparatus followed by the return of at least some of these fluids to the tree for recovery. Alternative embodiments provide only one flowpath and do not include the return of any fluids to the tree. Some embodiments can be retro-fitted to existing trees, which can allow the performance of a new function without having to replacing the tree. Multiple diverter assembly embodiments are also described.

Abstract: Flexible riser hang-off for rigid risers deployed offshore is provided and called a spoolflex hang-off. The spoolflex hang-off utilizes combined torsional and bending flexibilities of a rigid tubular jumper deployed between a top of the riser and a floater piping. The rigid jumper transports fluids, contains the fluid pressure and accommodates angular deflections of the riser. The riser top is suspended from a pivoting arrangement that transfers the riser tension to the floater structure. The rigid jumper can be made of titanium or of other metallic or nonmetallic materials. The flexible riser hang-off provided has rotational stiffness independent on riser tension. Low static and fatigue bending loads on the riser and on the floater structure result. The hang-off allows large riser deflection angles.

Abstract: The present disclosure provides a centralizing device and a method for using the centralizing device to immovably centralize a conductor casing within an aperture of a supporting framework. The centralizing device has one or more body portions, each having an inner surface and an outer surface, wherein the inner surface(s) are arranged for abutting the conductor casing and the outer surface(s) are arranged for abutting the framework. The body portion(s) are located within the aperture between the conductor casing and the framework for limiting movement of the conductor casing relative to the framework. Each body portion includes a first member providing the outer surface and a second member providing the inner surface. The first member and second member are movable relative to each other, to thereby permit adjusting the position of the inner surface relative to the position of the outer surface, so as to centralize the conductor casing within the aperture.

Abstract: A method of heave compensation between a floating installation, which has a drilling floor, and at least a riser or a pipe extending down towards, possibly through, a blowout preventer, the method including the steps of—installing an electromechanical actuator with attachment points, in the form of an end cap and an anchoring point, between the floating installation and a suspension device for the riser or the pipe; connecting the electromechanical actuator to a power supply and a control system; and heave-compensating for the relative displacement between the floating installation and the riser or the pipe by letting the control system adjust the length and power output of the electromechanical actuator.

Abstract: A wireline riser tensioner system includes a set of tensioning units arranged about a first well with at least one tensioning cable connected to a first and a second tension ring of the first and second wells, respectively. Both wells can be serviced using the same set of tensioning units. The at least one tensioning cable is routed through a plurality of sheaves. If not being serviced, the first or the second well might serve as an anchor.

Abstract: A system is provided for maneuvering a payload in an air space constrained by one or more obstacles, and may include first and second aerial vehicles coupled by a tether to a ground station. Sensor systems and processors in the ground station and aerial vehicles may track obstacles and the tether's and the vehicles' positions and attitude to maneuver the payload and the tether to carry out a mission. The sensor system may include airborne cameras providing data for a scene reconstruction process and simultaneous mapping of obstacles and localization of aerial vehicles relative to the obstacles. The aerial vehicles may include a frame formed substantially of a composite material for preventing contact of the rotors with the tether segments.

Abstract: A system for planning and predetermination of boat fender heights and dock location information, comprising a boat fender controller configured to calculate a required fender deployment height prior to arrival at a predetermined dock location, based on real-time information, and to raise or lower a plurality of boat fenders based on the calculated fender deployment height on final approach to the predetermined dock location.

Abstract: In accordance with embodiments of the present disclosure, a ram-style riser tensioner system includes a plurality of cylinders for applying a desired tension to a riser, a support structure coupled to the riser, and a plurality of gas accumulators. Each of the cylinders is coupled to the support structure, and each of the gas accumulators is configured to provide pressurized gas to a corresponding one of the cylinders. The ram-style riser tensioner also includes a plurality of support rods coupled to the support structure for reducing bending moments on the plurality of cylinders.

Abstract: A moon pool control device (5) for a marine vessel (1) comprises one or more closure members (8a,b) arranged for movement in the moon pool, between a moon pool closing position in a region of the moon pool opening (7), a moon pool open position, and a retracted position, and guiding means (14a,b; 15a,b; 17a,b; 18a,b) and motive means (9a,b; 10a,b; 22) configured for moving the closure member between said positions. In a particular embodiment, a pair of closure members (8a,b) and corresponding guiding means (14a,b; 15a,b; 17a,b; 18a,b) and motive means (9a,b; 10a,b; 22) are arranged on opposite lateral sides of the moon pool and configured to cooperate to close the opening (7) when both closure member s are in the closing position. The closure members comprise a continuous surface that forms a fluid barrier. The closure members may be retrieved onto the deck of the vessel.

Abstract: Offshore drilling system for performing subsea wellbore related activities including a drilling vessel, with a floating hull subjected to heave motion. A main cable heave compensation sheave is provided for heave compensation of a travelling block. A connection cable heave compensation sheave is provided between a connection cable winch and a top sheave assembly supported on the hull of the vessel in or above the moonpool. The main cable heave compensation cable sheave and the connection cable heave compensation sheave are mechanically interconnected so as to allow for synchronous motion thereof.

Abstract: A deep water drilling riser pressure relief system includes a drilling riser extending from a surface down to a BOP stack arranged subsea. The drilling riser comprises a drilling riser slip joint, an annular preventer arranged below the drilling riser slip joint, and at least one pressure relief device arranged in a lower part of the drilling riser. The at least one pressure relief device is configured to open so as to discharge a fluid from the drilling riser to the sea if a pressure difference between an inside and an outside of the drilling riser exceeds a predetermined threshold.

Abstract: A system for aligning an auxiliary line connection in a termination assembly of a marine riser assembly includes a terminal block secured to an outer diameter of a termination ring. The terminal block has a piston housing that extends through a sidewall of the termination ring. A ring adapter has an outer diameter sized to engage an inner diameter of the termination ring when a shoulder of the ring adapter is landed on a load shoulder of the termination ring. A moveable floating ring assembly is retained within the piston pocket of the ring adapter. A piston housed within piston housing is moveable between a retracted position where an outer end of the piston is spaced apart from the floating ring assembly, and an extended position for forming a sealed auxiliary path from the terminal block to the ring adapter.

Abstract: An offshore drilling rig including a drill floor deck having one or more holes, each defining a well center; one or more masts upwardly extending relative to the drill floor deck, and one or more hoisting systems, each supported by at least one of the one or more masts and configured for hoisting and lowering tubular equipment through at least one of the one or more well centers; a storage area for accommodating marine riser joints in upright orientation side by side in respective upright storage positions; a riser handling apparatus, different from the hoisting systems, adapted to move at least one of said marine riser joints along a movement path between its upright storage position and a prostrate maintenance/transfer position on a maintenance/transfer area, which movement path does not intersect any of the well centers.

Abstract: A gooseneck assembly having a body disposed circumferentially about a portion of a riser string. A stab member is inwardly radially extendable relative to the body and engages a receptacle disposed on the riser string. A cartridge assembly engages the stab member and has a flexible hose coupling that is rotatable relative to a central axis of the stab member. The coupling is in fluid communication with the receptacle via the stab member. The assembly includes an actuator that is operable to rotate the flexible hose coupling relative to the central axis of the stab member.

Abstract: A tensions compensator assembly for a slip type joint in an offshore work string. The assembly includes a chamber at the joint which is constructed in a manner to offset or minimize a pressure differential in a production channel that runs through the work string. Thus, potentially very high pressures running through the string are less apt to prematurely force actuation and expansiveness of the slip joint. Rather, the expansive movement of the joint is more properly responsive to heave, changes in offshore platform elevation and other outside forces of structural concern.

Abstract: In some aspects, an in-line passive heave compensator system includes a damper actuator, a fluid vessel, and a hydraulic manifold. The damper actuator extends and retracts in response to an external dynamic load, and the fluid vessel transfers hydraulic fluid between itself and the damper actuator (e.g., back and forth) as the damper actuator extends and retracts. The hydraulic manifold provides the channel of fluid transfer between the damper actuator and the fluid vessel. The hydraulic manifold includes an extension flow control device in an extension fluid path between the damper actuator and the fluid vessel. The extension fluid path receives fluid flow only during extension of the damper actuator. The hydraulic manifold includes a retraction flow control device in a retraction flow path between the damper actuator and the fluid vessel. The retraction flow path receives fluid flow only during the retraction of the damper actuator.

Abstract: A telescopic joint for a marine drilling riser has an outer barrel and an inner barrel defining a central lumen for passage of a drill pipe string. The inner barrel is received within the outer barrel, and there is a clearance fit between the barrels for sliding of the inner barrel with respect to the outer barrel while maintaining a coaxial relationship between the barrels. A tubular rolling elastomeric membrane is disposed within the outer barrel and has one end secured to an outer circumference of the inner barrel and another end secured to an inner circumference of the outer barrel for sealing drilling fluid within the central lumen. As the inner barrel slides with respect to the outer barrel, the elastomeric membrane rolls with respect to the inner barrel and the outer barrel so that wear of the seal due to abrasion is eliminated.

Abstract: A wellbore cleaning tool for removing irregularities along the inner surface of a wellbore tubular may include a top sub, a cutting assembly, and a bottom sub. The tool is operable to remove irregularities, such as debris, burrs, and jagged edges, along the inside of the wellbore tubular, and thereby provide a clean, inner surface finish. The tool may be actuated into a retracted position, an extended position, and/or a deactivated position.

Abstract: A buoyancy compensating element for connection to a flexible pipe and method of producing a buoyancy compensating element are disclosed. The buoyancy compensating element includes a first body portion and a further body portion, wherein the first and further body portion are configured to be connectable to each other and in use to encompass a portion of flexible pipe.

Abstract: A gooseneck conduit system for use with a telescoping joint of a subsea riser. In one embodiment, a riser telescoping joint includes a tube and a gooseneck conduit assembly affixed to the tube. The gooseneck conduit assembly includes a gooseneck conduit extending radially from the tube, and a tenon projecting from a rear face of the gooseneck conduit. The width of the tenon increases with distance from the rear face. The riser telescoping joint also includes a mortise channel extending along the length of the tube. The mortise channel is interlocks with the tenon and laterally secures the gooseneck conduit assembly to the tube.

Abstract: A backup heave compensation system and an associated lifting arrangement are for a floating drilling vessel comprising a rig structure with a primary heave compensation system. The backup heave compensation system comprises: a vertically extendable and retractable lifting arrangement; a hydraulic system operatively connected to said lifting arrangement; and a control system operatively connected to said lifting arrangement and hydraulic system for selective control and operation thereof. The lifting arrangement comprises: a rigid frame structure comprised of: at least two vertically extending cylinders; a first transverse element connecting first end portions of said cylinders; and a second transverse element connecting second end portions of said cylinders; and a portal structure comprised of: at least two vertically extending piston rods having first end portions provided each with a piston; and a transverse portal element connecting second end portions of said piston rods.

Abstract: An offshore vessel capable of installing and removing a subsea well control device and a riser string includes a hoisting device having a travelling block for connecting a load. The travelling block is displaceable along a firing line which extends through a moonpool and a heave compensation system. The vessel further includes a working deck supported by the hull of the vessel which covers at least a portion of the moonpool to allow the assembly of a riser string. The working deck is provided with a riser string suspension device that allows to suspend a top end of a string of risers. A heave compensation connection system is adapted to connect the working deck to the travelling block, such that the hoisting device can move the working deck when the working deck is connected to the travelling block between a lowered riser assembly position and a raised heave compensated position.

Abstract: The present disclosure shows a crane controller for a crane which includes a hoisting gear for lifting a load hanging on a cable, with an active heave compensation which by actuating the hoisting gear at least partly compensates the movement of the cable suspension point and/or a load deposition point due to the heave, wherein the heave compensation takes account of at least one constraint of the hoisting gear when calculating the actuation of the hoisting gear.

Abstract: An extendable conductor stand allowing for rapid alignment and installation. The conductor stand having capacity to accept a BOP to protect against all blowouts, including behind the casing blowouts.

Abstract: The riser system of the present invention includes an external production riser for floating structures with interfaces to the dry and subsea wellheads, internal tieback riser with a special lower overshot/slipping connector for elevated temperatures. The seals can be metallic and/or non-metallic dynamic seals. Special centralizing pipe connectors and a special subsea wellhead tubing hanger are also included. This riser system avoids the penalty of pipe within pipe differential thermal growth and the resulting unwanted effects on the floating structure. This is accomplished by allowing an overshot sealing slipping connector to swallow an expanding polished rod as thermal conditions cause pipe elongation axially. When elevated temperatures fall to ambient the opposite occurs as the pipe shrinks axially. Alternatively, a system is possible where a two pipe drilling riser is needed. The internal pipe in this case would be an inner riser rather than a tubing string.

Abstract: Telescoping riser arrangement forming part of a riser string (1) connecting a subsea well and a floating installation. The riser arrangement is adapted to be switched between a high pressure mode, in which an upper part of the riser assembly will move vertically with respect to the installation when the installation heaves, and a low pressure mode in which the upper part of the riser assembly will move vertically along with the installation when the installation heaves. In the low pressure mode, a low pressure inner sleeve (9) is adapted to reciprocate inside a high pressure outer sleeve (1a), the reciprocating heave path being above the position of the inner sleeve (9) in the high pressure mode. In the high pressure mode, the telescoping section of the low pressure inner sleeve (9) is enclosed within a high pressure compartment.

Abstract: A bottom-to-surface connection installation having a floating support and a turret and having: a plurality of risers having their top ends secured to a carrier structure a plurality of flexible pipes extending from the turret to the top ends of the risers; the flexible pipes including at least two first flexible pipes with positive buoyancy positioned at different heights; and guide modules secured to a tension leg and suitable for sliding along floats of the risers.

Abstract: A fluid recovery system is provided. In one embodiment, the fluid recovery system includes a telescoping joint of a marine riser having an inner barrel and an outer barrel configured to extend and retract with respect to one another when installed as part of the marine riser. A drip pan is coupled to the outer barrel to enable the drip pan to catch fluid, such as drilling mud, leaking from the telescoping joint between the inner barrel and the outer barrel. In this embodiment, the fluid recovery system also includes a pump and a return conduit that are coupled to enable the pump to pump caught fluid from the drip pan back into the telescoping joint via the return conduit. Additional systems, devices, and methods are also disclosed.