Abstract: Systems and methods for initiating an emergency disconnect sequence (EDS) are provided. In an aspect, a disconnection system is provided and configured to initiate the EDS, and includes a controller including a processor and a memory operably coupled to the processor. The controller receives, from a set of motion reference units (MRU(s)) operably coupled to a flexible joint, position data generated by the set of motion references units and associated with the joint when the joint is operably coupled to and disposed between a drilling riser and a lower marine riser package (LMRP). The controller determines, based on the position data, an angular offset of the joint. The controller sends, to a subsea control pod disposed at or adjacent to the LMRP, a trigger signal in response to determining that the angular offset exceeds a predetermined threshold, such that the subsea control pod initiates the EDS.

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 pipeline bundle for a riser tower or tie-back is manufactured offshore by suspending the bundle from an installation vessel, adding structural core sections successively to an upper end of the suspended bundle, lowering the bundle after adding each successive core section, and feeding one or more lengths of flowline pipe beside the core sections for incorporation into the bundle. The flowline pipe is coiled on a reel or carousel as a full-length piece before being uncoiled progressively as core sections are added to the lengthening bundle. The flowline pipe is then engaged with guide frames and/or buoyancy blocks supported by the core sections, by movement in a radially-inward direction through a radially-outer opening in a retainer formation. The opening is then closed to hold the flowline pipe in the retainer formation.

Abstract: A system for locking a bearing assembly to a rotating control device (RCD) housing is provided. The RCD housing can be coupled to a blowout preventer, and the bearing assembly can be received within the housing, and can comprise a stationary bearing housing having a perimeter channel. A plurality of locking block assemblies are each supported by the housing and are operable between a locked position and an unlocked position. Each locking block assembly comprises a movable block configured to interface with the perimeter channel when in the locked position, and at least one elastic component is situated between the housing and the movable block. The at least one elastic component is configured to automatically bias the movable block in the locked position. Upon supplying fluid pressure via a valve device, the movable block moves to the unlocked position and the at least one elastic component compresses to facilitate removal of the bearing assembly from the RCD housing.

Abstract: A rotating control device (RCD) having an anti-rotation locking system for restricting rotation of a bearing assembly housing of the RCD comprises an RCD housing operable with a blowout preventer, and a bearing assembly operable to be received within the RCD housing and comprising a stationary bearing housing. The bearing assembly can be configured to receive and engage with and seal a pipe of a drill string of a drill rig. The stationary bearing housing can have secured thereto a locking ring. The anti-rotation locking system of the RCD can further comprise one or more anti-rotation devices moveable between a locked position and an unlocked position. The anti-rotation device(s) are operable to engage the locking ring, when in the locked position, to lock the stationary bearing housing to the RCD housing independent of the rotational position of the stationary bearing housing relative to the RCD housing.

Abstract: A downhole tool coupling system, comprising a drive stem, a sleeve, and a plurality of locking clamps. The sleeve is longitudinally movable relative to the drive stem. The locking clamps are at least partially encompassed by the sleeve. The locking clamps are adjustable between an open position and a locked position. The sleeve is oriented relative to the locking clamps to adjust the locking clamps from the open position to the locked position as the sleeve moves longitudinally from an upper position to a lower position. Each locking clamp has an interior recessed region configured to clamp the drive stem to a tool stem when in the locked position.

Abstract: A subsea structure includes a support in the form of a foundation or a supporting structure mounted to a foundation. A method for installing a pipeline includes: providing the support with a pull-in point at a proximal location at a first side of the support; providing the support with a strong point at a distal location, which is spaced apart from the proximal location, there being a straight clear path between the pull-in point and the strong point bridging some of or all of a width of the support; passing a pull down wire through a guide at the strong point and using the pull down wire to pull in the pipeline; laying down the pipeline and passing the pull down wire along the clear path; and continuing the laying down and/or pulling in until a tie-in head of the pipeline is at a required location at the pull-in point.

Abstract: A casing adapter and related systems and methods are provided for a lubricate and bleed operation in a wellbore where heavy fluids are directly deposited downwell. The casing adapter allows a hose to be positioned downwell and to be operably connected to a tank of heavy fluid. Once the heavy fluid is deposited, the casing adapter receives lighter fluids from the well bore, and the casing adapter is operably connected to a return tank that stores lighter fluids.

Abstract: A connector system configured to couple a first tubular member to a second tubular member includes a body, an outer sleeve positioned circumferentially about the body, and an actuator assembly positioned within an annular space defined between the body and the outer sleeve. The actuator assembly includes one or more piston rods, a primary piston ring coupled to respective first ends of the one or more piston rods, and an actuator ring coupled to respective second ends of the one or more piston rods, wherein the actuator assembly is configured to move axially within the annular space to drive multiple collet segments from an unlocked position in which the multiple collet segments do not engage the first tubular member and a locked position in which the multiple collet segments engage the first tubular member.

Abstract: A method of protecting a component in a wet environment includes disposing a component into a wet environment, deploying a granulated disintegrable material into the wet environment and temporarily covering a portion of the component with the granulated disintegrable material, at least partially disintegrating the granulated disintegrable material, and flushing the granulated disintegrable material away from the portion.

Abstract: A subsea connector system (10) for providing a connection with a subsea well component comprises a latch assembly (14) defining a through bore and a latch member (18) mounted on the latch assembly. A mandrel (20) extends through said bore of the latch assembly, wherein the mandrel and the latch assembly are axially and rotatably moveable relative to each other in a predefined relative movement sequence to operate the latch member and configure the connector system between connected and disconnected configurations. The connector system also comprises a conveyance connector (22) for providing a connection between a conveyance member (24) and the mandrel such that a conveyance member may permit an axial movement component of the predefined movement sequence. A rotation interface (26) is mounted on one of the mandrel and the latch assembly such that a subsea manipulator may permit a rotational movement component of the predefined relative movement sequence.

Abstract: A connector includes a cylindrical body and a plurality of longitudinal latching fingers arranged around the body. Each finger has a first end region which includes a first latching structure, a second end region and an intermediate region. Each finger is pivotally supported at the intermediate region and is movable between a non-latching position and a latching position. An actuating device is operable to force the second end region of each finger towards the body by exerting a force on at least a portion of the second end region. The actuating device includes a force-imparting member which cooperates with a force-receiving region located on the second end region. The force-receiving region includes a first outer surface portion which is curved radially outwardly to define an apex and a trough, the latter being located between the apex and the intermediate region and configured to accommodate the force-imparting member.

Abstract: An apparatus and methods for installing and selectively retrieving a casing hanger locking device within a wellhead system during the bit run and retrieval operations are provided. An embodiment is an apparatus comprising: a bit sub comprising a tong neck, a cylindrical portion below the tong neck, and at least one stabilizing fin below the cylindrical section, wherein the at least one stabilizing fin comprises a keyway; a casing hanger locking device comprising an annular structure and an expandable ring disposed around an upper portion of the annular structure, the casing hanger locking device disposed around the bit sub; an actuation sleeve that engages with the casing hanger locking device; and a selective retrieval collar comprising a segmented retrieval ring, wherein the selective retrieval collar is attached to the bit sub, the actuation sleeve, and the casing hanger locking device.

Abstract: A connector can include multiple circumferentially distributed engagement structures which clamp two hubs together, and a biasing device which biases the engagement structures toward an open configuration thereof, in which the hubs are separable from each other. Another connector can include multiple circumferentially distributed engagement structures, each having a recess which receives hubs therein, and a sleeve which encircles the engagement structures and prevents the engagement structures from displacing radially outward from an open configuration thereof, in which the hubs are separable from each other. A method of making a connection to a wellhead can include applying pressure to a connector, thereby allowing multiple circumferentially distributed engagement structures to displace outward to an open configuration thereof, and displacing one hub of the connector into contact with another hub secured to the wellhead, the engagement structures axially aligning the hubs during the displacing.

Abstract: A system including a mineral extraction system, including a tubular with a fluid passage, a hydraulic connector system configured to couple to the tubular, the hydraulic connector system, including a hydraulic block configured to couple to one or more fluid lines, and a sleeve coupled to the hydraulic block and configured to move axially with respect to the hydraulic block to couple and uncouple the hydraulic connector system with the tubular.

Abstract: The present invention relates to offshore oil and gas exploration drilling field and, in particular, to a surface layer conductor running tool for deep-water well drilling, which is used to run a conductor to a designated position, so that the drill stem can be released and the drilling can be continued. The surface layer conductor running tool for deep-water well drilling comprises a mandrel, an inner sleeve, an outer sleeve, and a main body, wherein the inner sleeve, the outer sleeve, and the main body are fitted over the mandrel sequentially; the inner sleeve can slide up and down but cannot rotate in relation to the mandrel, the outer sleeve and the inner sleeve are connected via a transmission thread pair, and the main body is situated on the inner sleeve; a retaining pawl penetrating the main body and radially slidable in horizontal direction; and an anti-rotation pin penetrating the main body and the outer sleeve, so that the outer sleeve can move up and down in the main body only, but cannot rotate.

Abstract: A method of inducing fracture in at least a portion of a geologic structure includes inducing acoustic waves into a fluid medium present in a borehole extending at least partially into the structure. Embodiments may include preheating or pressurizing the fluid medium prior to inducing the acoustic wave therein. A device for fracturing at least a portion of a geologic structure includes electrodes for producing a spark to generate ordinary acoustic waves in the fluid medium. Embodiments may include structures for preheating or pressurizing the fluid medium prior to inducing the acoustic wave therein.

Abstract: A device for the application of a preload between a subsea wellhead and a conductor housing comprises an activating member (1), a support housing (2), a locking member (3), end means (9) for securing the support housing relative to the well-head. Movement of the activating member causes an inclined lateral movement of the locking member. The activating member carries a ratchet (7) comprising a multiplicity of serrations which have a regular pitch in the activating direction and the support housing (1, 2) cames at least two latches (19, 20) which allow the relative movement and can engage the ratchet to inhibit movement reverse to the activating direction. The discrete locking positions provided by one of the latches are positionally out of phase with the discrete locking positions provided by the other latch or latches.

Abstract: A subsea umbilical system can be provided for connecting a topside structure at a proximal end of the system to subsea equipment at a distal end of the system. The system can include an umbilical configured to allow one or more cables for powering or communicating with subsea equipment to be passed through at least a portion of the umbilical. The system can further include reinforcing elements radially surrounding a portion of the umbilical. The system can further include a breakout box disposed along the umbilical and configured to be positioned between the reinforcing element and the subsea equipment. The breakout box can include a breakout opening configured to allow one or more breakout cables to exit the umbilical and run along the outside of the reinforcing elements to the topside structure. Related methods of making and using such systems are also described.

Abstract: An apparatus for performing a drilling operation or a non-drilling wellbore operation may include a string that has a rigid tubular, a connector coupled to the rigid tubular, a non-rigid tubular coupled to the connector; and at least one motor positioned along the string. In some embodiments, a plurality of motors may be positioned along the string to rotate one or both of the non-rigid tubular and a drill bit connected to the string. In some embodiments, the connector may be configured to release the non-rigid tubular from the rigid tubular and thereby leave the non-rigid tubular in the wellbore.

Abstract: A tensioning apparatus for applying a substantially constant tension to a workover riser (12) includes a first portion (40) adapted to be coupled to a workover riser, a second portion (44) adapted to be coupled to a marine riser (14) and tensioning means (46) for providing relative movement between the first portion and the second portion to, in use, tension the workover riser.

Abstract: A subsea wellhead assembly is provided. The subsea wellhead assembly comprises a tubing head structure with a tree above the tubing head structure, and a recoverable module attached to the tubing head structure below said tree, the recoverable module comprising at least one valve and at least one sensor.

Abstract: A mud motor for use in a wellbore includes: a stator; a rotor, the stator and rotor operable to rotate the rotor in response to fluid pumped between the rotor and the stator; and a lock. The lock is operable to: rotationally couple the rotor to the stator in a locked position, receive an instruction signal from the surface, release the rotor in an unlocked position, and actuate from the locked position to the unlocked position in response to receiving the instruction signal.

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 device including a fluid transport pipe (24), a superstructure (16), and a floating barge (18) rotatably mounted on the superstructure (16) about an axis of rotation (A-A?). The pipe (24) includes a hose section (150) wound around the axis of rotation (A-A?) supported by an intermediate structure (20) mounted between the superstructure (16) and the barge (18), between a configuration rotatably driven with the barge (18) about the axis of rotation and a configuration rotatably retained about the axis of rotation (A-A?) by the superstructure (16). During a step of connecting the pipe (24), the intermediate structure (20) is placed in either the driven configuration or the retained configuration, a step of disconnecting the pipe (24) including switching the intermediate structure (20) to the other one of the driven configuration and the retained configuration.

Abstract: A method of separating a riser, comprising providing a riser having an inner and an outer surface, a circumference of said outer surface, a longitudinal axis and a first end and a second end; radially surrounding said riser with an explosive shaped charge material, wherein said shaped charge explosive material is capable of generating a high-velocity plasma jet in response to an activation signal, and wherein said explosive material comprises an electrically conductive layer; transmitting said activation signal to said explosive material; generating said high-velocity plasma jet; and separating said riser into a first portion comprising said first end and a second portion comprising said second end when said high-velocity plasma jet penetrates said outer surface of said riser and exits said inner surface of said riser.

Abstract: A tubing hanger landing system includes a tubing hanger running tool, a locking flowline to lock the tubing hanger running tool into a tubing hanger, and a lower body shear joint having a recovery valve. The recovery valve includes a valve body having an operational port, a bi-directional port, a relief port, and an internal piston cavity. The piston cavity includes a radially inwardly extending stop and a valve piston movable between an operational position and a relief position relative to the radially inwardly extending stop. The valve body further includes a shear port that allows pressure communication between the exterior of the recovery valve and the valve piston, a shear ring attached and surrounding a piston collar and sized larger than the radially inwardly extending stop such that the valve piston is prevented from moving from the operational position to the relief position.

Abstract: A subsea intervention system including at least one control station, at least one programmable logic controller system in each control station, at least one supervisory control and data acquisition system, at least one safety system capable of interacting with each control station, wherein the safety system is capable of controlling a process shutdown process, an emergency shutdown process, and an emergency quick-disconnect process. The system may also include subsea distribution units, safety manifold subsea control modules, system hydraulic power units, client hydraulic power units, grease skids, flushing and chemical injection units, or umbilical reelers.

Abstract: A subsea communication system is used to communicate between a position that is proximal to a surface of the sea and an apparatus of the seabed. The subsea communication system includes an umbilicalless communication system.

Abstract: There is provided a high power laser riser blowout preventer system and controller for operation thereof. The system utilizes high power laser cutters that are associated with the riser and the blowout preventer to provide an integrated operation to quickly weaken or cut tubulars to address potential emergency and emergency situations that can arise during deep sea drilling.

Abstract: A method is presented for connecting and disconnecting sections of a work string for use in a subterranean wellbore. A preferred method of disconnecting includes the steps of positioning a stinger and a downhole tool assembly of a work string adjacent upper and lower sealing rams, such as in a BOP and lubricator assembly. The sealing rams are closed, defining a first and second pressure zone adjacent the tool. A differential pressure is applied across the pressure zones, moving a piston element in the tool assembly. Axial movement of the piston element causes relative rotational movement of cooperating locking elements. In one embodiment, the locking elements are rotated to an unlocked position and then move relative to one another axially in response to a biasing spring. The relative axial movement of the locking elements results in unlatching of a latching assembly, thereby disconnecting the tool and stinger.

Abstract: A subsea well safing method and apparatus to secure a subsea well in the event of a perceived blowout in a manner to mitigate the environmental damage and the physical damage to the subsea wellhead equipment to promote the ability to reconnect and recover control of the well. The safing assembly is connectable to a subsea well and a marine riser. Pursuant to a safing sequence, the well tubular is secured in the upper and lower safing assemblies and the tubular is then sheared between the locations at which it has been secured. Subsequently, an ejection device may be actuated to physically separate the upper safing assembly and the connected marine riser from the lower safing assembly the subsea well.

Abstract: This installation comprises an upper structure (12), and a flexible hose (16) capable of moving through the expanse of water (11 B) between an upper connected configuration and a lower disconnected configuration. The installation comprises a lower structure (14) having a base (60) extending at a distance from the bottom (11A) of the expanse of water (11 B). The upper structure (12) is capable of moving relative to the lower structure (14) between an extraction position and an evacuation position. The base (60) defines a passage (68) for travel of the flexible hose (16) as it moves between the upper connected configuration and the lower disconnected configuration and a stop (74) for retaining a connection head (92) of the hose (14), disposed in the travel passage (68), to keep the connection head (92) at a distance from the bottom (11A) of the expanse of water (11 B) in the lower disconnected configuration.

Abstract: A connector for a hydrocarbon system includes a first duct section, a first connector part slidably attached to the first duct section for connecting to a complementary connector part attached to a second duct section and a retraction member for moving the first connector part in an axial direction between an extended position and a retracted position.

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

Abstract: A riser disconnect/reconnect system including a disconnection package (RDP) and a modified lower marine riser package (LMRP) are provided for quick disconnection of the marine drilling riser (MDR) from the LMRP. The RDP includes a flex joint and a release connector (RC) with a mandrel that engages a modified LMRP. In an emergency event, the RDP is disconnected from the LMRP allowing access to the BOP stack for emergency intervention. In routine drilling operations, the RDP is disconnected from the LMRP facilitating the recovery of the LMRP or BOP stack to the surface for repair or maintenance without recovering the MDR. The RC joins the flex joint to the uppermost annular blowout preventer in the LMRP. The RC is configured for use in a standard or inverted position. Also provided is a mechanical locking connector, a resident ROV and sonar technology and methods of using same with the RDP.

Abstract: A modular control system consisting of multiple, remotely retrievable functional modules for controlling a blowout preventer stack. The various functional modules can be located on the lower marine riser package and blowout preventer stack positioned near the equipment with which they are associated, wherein this distribution of modules nearly eliminates the complex interface connection between the lower marine riser package and blowout preventer stack. Each of the functional modules is capable of being installed, retrieved or replaced with a single remotely operated vehicle (ROV) deployment from a vessel. The functional modules can be used to operate as a complete control system for a blowout preventer stack or can be used selectively individually or in various combinations to accommodate multiple control applications or upgrades of other control systems.

Abstract: A subsea well safing method and apparatus adapted to secure a subsea well in the event of a perceived blowout in a manner to mitigate the environmental damage and the physical damage to the subsea wellhead equipment to promote the ability to reconnect and recover control of the well. The safing assembly is adapted to connect the marine riser to the BOP stack. Pursuant to a safing sequence, the well tubular is secured in the upper and lower safing assemblies and the tubular is then sheared between the locations at which it has been secured. Subsequently, an ejection device is actuated to physically separate the upper safing assembly and connected marine riser from the lower safing assembly that is connected to the BOP stack.

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: An independently operable disconnect device remotely disconnectable from an LMRP to reveal a riser profile compatible with a capping device connecter. A capping device including a capping device connector to be coupled to said riser profile. The capping device includes at least one blow-out preventer operable to stop the overflow of petroleum products from a well. Thus, a drilling marine riser may be fully disconnected from an LMRP in an emergency. Then the well may be subsequently capped.

Abstract: A gasket test protector sleeve is provided for subsea mineral extraction equipment. The gasket test protector sleeve includes a gasket test isolation portion. The gasket test isolation portion is configured to isolate a gasket between a first tubular and a second tubular of a subsea mineral extraction system. The bore protection portion is configured to protect a first bore of the first tubular during downhole procedures.

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 subsea connector that includes a connector capable of selectively connecting to a spool body to form a connector assembly. The subsea connector may include an adapter ring that is capable of connecting the spool body to the connector. The connector assembly may be lowered onto a wellhead member and locked into place by a movable piston and split lock ring. While the connector assembly is in the unlocked state, the adapter ring may be rotated moving the connector up or down with respect to the spool body, which lands on the wellhead member. The movement of the connector may be used to vary the alignment of the connector locking means with respect to the locking profile of the wellhead member. This change in position may be used to modify the preload force applied to the connector when locked onto the wellhead member.

Abstract: A method for removing a plug from and setting a plug into a subsea installation is provided. The method for removing the plug includes the steps of deploying an intervention package having at least one valve, pipe rams, and a lubricator into a subsea environment and latching the intervention package to the subsea installation. The method further includes lowering a stroking tool into the intervention package by conveyance from a surface facility, and grabbing the stroking tool with the pipe rams that form a part of the intervention package. Once the stroking tool is held by the pipe rams, the method further includes activating the stroking tool to stroke in an upwards or downwards direction to remove the plug positioned in the subsea installation. Once the plug has been removed by the stroking tool, the method further includes pulling the stroking tool out of the intervention package and retrieving the stroking tool and plug at surface.

Abstract: A retrievable bridge is provided which mounts to the top of a subsea tree to provide fluid communication between the production line of the subsea tree and a production flowline. The retrievable bridge mounts to the top of the subsea tree and preferably connects to a vertically oriented pipe of the production flowline. The retrievable bridge can be utilized to carry wear items such as chokes, subsea control modules, and flow meters which may require maintenance more often than other components of the subsea tree. By mounting these items along the flow passageway in the retrievable bridge the components are securely mounted and still available for maintenance/replacement without the need to remove the entire tree. In one embodiment, Intervention into the well is available without removing the retrievable bridge.

Abstract: The invention relates to a manifold structure that includes a frame construction (1), a number of pipes (2), a pipe bend and possible valves, deployed in a pipe system having a number of pipe terminations projecting from the frame construction. The frame construction (1) is designed with a number of support brackets (5) for respective coupling parts associated with said pipe terminations. Each support bracket (5) is made as a separate, standardized unit that includes several securing means for releasable assembly to the frame construction, where each securing means is arranged for defined adjustability in height and lateral direction for adaption to a preinstalled pipe termination.

Abstract: The riser pipe section comprises a main tube 22 and auxiliary line elements 23 arranged parallel to tube 22. The ends of the main tube comprise connectors 20a and 20b allowing longitudinal stresses to be transmitted. The ends of auxiliary line elements 23 comprise connectors 20c and 20d. Auxiliary line elements 23 consist of two parts 23a and 23b assembled by an adjustment device 23c or 30 allowing the axial length of each auxiliary line element to be adjusted.

Abstract: The tool includes a bearing member (70), a traction assembly (72) of the object (28), movably mounted in a first direction relative to the bearing member (70). It includes a plurality of hooking members (160), mounted radially mobile relative to the traction assembly (72) between a contracted configuration and a deployed configuration. The tool comprises means (164; 166) for keeping each hooking member (160) in its deployed configuration. It includes unlocking means (168; 170) that include an elastic stressing member (202; 222) applied on the holding means (164; 166). The elastic stressing member (202; 222) is capable of being compressed to cause the unlocking of the holding means (164; 166) and the passage of the hooking members (160) from their deployed configuration to their contracted configuration.

Abstract: The disclosure is directed to a method for retrieving a drilling riser connected to a blow-out-preventer (BOP) located on a sea bed. The method includes the steps of: a) attaching the first end of the retrieval line to a vessel; b) attaching the second end of the retrieval line to a drilling riser; c) disconnecting the riser from the BOP; d) initiating the assent of the disconnected riser from the sea bed; e) maintaining tension on the riser as it ascends to the sea surface by creating a horizontal load that is opposite to a current load on a bottom end of the riser; f) releasing tension on the retrieval line as the riser approaches the bottom of the drilling vessel; and/or g) disconnecting the retrieval line from the riser, whereby the riser is pulled through the bottom opening in the drilling vessel.

Abstract: A subsea line monitoring device includes a diagnostic unit adapted to be deployed, in use, in a subsea location and having a first connector, the diagnostic unit being operable, in use, to output a signal indicative of the integrity of a line or device connected to the first connector. The subsea line monitoring device may be deployed on a long term or permanent basis at the subsea location.