Abstract: Provided is a method and apparatus for pulling a crown plug from a subsea horizontal christmas tree, the method comprising: (a) providing a subsea lubricator having a longitudinal through bore and a jack attached to the subsea lubricator, the jack having a landing area, and the landing area having an opening which is fluidly connected to the lubricator's through bore; (b) providing a jacking string which includes a landing sub and a crown plug connector, the sub having a landing surface; (c) without the jacking string in step “b”, lowering the subsea lubricator of step “a”, to the horizontal christmas tree and attaching the lubricator to the christmas tree; (d) lowering the jacking string to the lubricator, and, while the landing surface of the landing sub is spaced above and not supported by the landing area of the jack, connecting the plug connector to the crown plug while the landing sub is above and not touching the landing area of the jack; (e) jacking up the jack such that the landing area of the jack c

Abstract: An apparatus (10) for remotely running a subsea production tree (12) and desuspending a well is described. The apparatus comprises a tree running tool (16) adapted to be connected to a production tree, at least one downhole tool, at least one of the tools being a plug retrieval tool (22) and a tool deployment device (18) in hydraulic communication with at least the plug retrieval tool to hydraulically operate the plug retrieval tool.

Abstract: A cap assembly for use with a tubing spool of a wellhead has a body with an interior passageway body and a mandrel extending upwardly therefrom. The body has a connector extending from an opposite end thereof. The interior passageway extends though the mandrel and the connector. A valve is affixed to the body and extends into the interior passageway. The valve is movable between a first position closing the interior passageway and a second position opening the interior passageway. An actuator is connected to the valve so as to move the valve between the first and second positions. A tubing hanger stab is affixed to the body and extends through the connector so as to join with a tubing hanger in the tubing spool.

Abstract: A subsea separation device for use in separating a pair of stabplate connector plates, the subsea separation device comprising a first engagement member adapted to engage, in use, a first one of the connector plates, or a component rigidly secured thereto, a second engagement member adapted to engage, in use, a second one of the connector plates or a component rigidly secured thereto, and drive means operable to urge the first and second engagement members apart and so urge the connector plates apart.

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 comprising a recovery valve. The recovery valve includes a valve body with a functional port, an operational port, a bi-directional port, and a relief port, and a valve piston positioned within the valve body and movable between an operational position and a relief position within the valve body. The functional port enables pressure to be communicated to the valve piston to move the valve piston from the operational position to the relief position, and, in the relief position, the valve piston provides fluid communication through a relief flowpath between the bi-directional port and the relief port to release pressure from the locking flowline.

Abstract: An apparatus and method for providing a controllable supply of fluid, and optionally power and/or communication signals, to a subsea equipment are provided. The fluid may be a water-based fluid, oil-based fluid, or chemicals. The apparatus includes a reservoir disposed on a seabed for storing a supply of fluid for delivery to the subsea well equipment. A subsea pumping device is configured to receive the fluid from the reservoir, pressurize the fluid, and deliver the pressurized fluid to an accumulator of a hydraulic power unit disposed on the seabed. The hydraulic power unit can store the pressurized fluid and control an output of the pressurized fluid to the subsea well equipment, thereby providing a subsea fluid source for the subsea equipment.

Abstract: A cap having a stinger adapted to be inserted into a bore of a subsea well element. The stinger includes locking means for locking to a profile in said bore, which locking means include a plurality of locking dogs. The locking dogs exhibit a large inclination face and a small inclination face, and are adapted to be actuated in a radial direction by an actuation sleeve. The small inclination face is divided by a slot, in which slot the large inclination face is arranged. A cam is arranged on the actuation sleeve and is adapted to extend into said slot. Alternatively, the small inclination face is divided by a cam arranged on the locking dog, on which the large inclination face is arranged, which cam is adapted to extend into a slot in the actuation sleeve.

Abstract: What is provided is a method and apparatus which can be detachably connected to an annular blowout preventer thereby separating the drilling fluid or mud into upper and lower sections and allowing the fluid to be displaced in two stages, such as while the drill string is being rotated and/or reciprocated. In one embodiment the sleeve can be rotatably and sealably connected to a mandrel. The swivel can be incorporated into a drill or well string and enabling string sections both above and below the sleeve to be rotated in relation to the sleeve. In one embodiment the drill or well string does not move in a longitudinal direction relative to the swivel. In one embodiment, the drill or well string does move longitudinally relative to the sleeve of the swivel.

Abstract: What is provided is a method and apparatus which can be detachably connected to an annular blowout preventer thereby separating the drilling fluid or mud into upper and lower sections and allowing the fluid to be displaced in two stages, such as while the drill string is being rotated and/or reciprocated. In one embodiment the sleeve can be rotatably and sealably connected to a mandrel. The swivel can be incorporated into a drill or well string and enabling string sections both above and below the sleeve to be rotated in relation to the sleeve. In one embodiment the drill or well string does not move in a longitudinal direction relative to the swivel. In one embodiment, the drill or well string does move longitudinally relative to the sleeve of the swivel.

Abstract: An offshore universal riser system. A riser system includes a valve module which selectively permits and prevents fluid flow through a flow passage extending longitudinally through a riser string. An anchoring device releasably secures the valve module in the flow passage. A method of constructing a riser system includes the steps of installing the valve module in the flow passage, and installing at least one annular seal module in the flow passage. The annular seal module is operative to prevent fluid flow through an annular space between the riser string and a tubular string positioned in the flow passage. Drilling methods include injecting relatively low density fluid compositions into the annular space, and selectively varying a restriction to flow through a subsea choke in a drilling fluid return line. The riser string, including housings for the various modules and external control systems, is dimensioned for installation through a rotary table.

Abstract: A bore selector for coupling a monobore riser to a dual bore subsea installation, the bore selector comprising a lower base part comprising a first and a second through bores connected to the respective bore of the dual bore subsea installation, an upper selector part comprising a through bore connected to a bore of the monobore riser, the upper selector part is movable relating to the lower base part to and fro between a first and a second positions, an actuator configured to move the upper selector part relating to the lower base part between the first and the second positions, and a connector sleeve slidably mounted in the through bore, wherein the connector sleeve is configured to selectively engage with the first and the second through bores, and is movable in the axial direction of the through bore to and fro between a raised and a lowered position.

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: An offshore universal riser system may include a valve module which selectively permits and prevents fluid flow through a flow passage extending longitudinally through a riser string. An anchoring device may releasably secure the valve module in the passage. A method of constructing a riser system may include the steps of installing the valve module in the passage, and installing at least one annular seal module in the passage. The annular seal module may prevent fluid flow through an annular space between the riser string and a tubular string positioned in the passage. Drilling methods may include injecting relatively low density fluid compositions into the annular space, and selectively varying a restriction to flow through a subsea choke in a drilling fluid return line. The riser string, including housings for the various modules and external control systems, may be dimensioned for installation through a rotary table.

Abstract: Systems and methods for replacing equipment at a wellsite, the wellsite having a subsea stripper installed proximate a subsea borehole. The system has at least one seal assembly portion, at least one seal replacement arm and an actuator. The seal assembly portion(s) is (are) positionable in the subsea stripper and replaceable therefrom. The seal assembly portion(s) has (have) a packer extendable within the subsea stripper to form a seal about the subsea stripper. The seal replacement arm(s) is (are) for replacing the seal assembly portion(s) through a door of the subsea stripper. The actuator is for remotely actuating the seal replacement arm(s) to engage the seal assembly portion(s) whereby the seal assembly portion(s) is (are) remotely replaceable.

Abstract: In one embodiment, a tubular lifting system for lifting a wellbore tubular includes an outer tubular; an inner tubular disposed in the outer tubular; an annular chamber defined between the inner tubular and the outer tubular; and a tubular piston selectively movable in the annular chamber, wherein the wellbore tubular is connected to the tubular piston and movable thereby.

Abstract: Provided is a method and apparatus for pulling a crown plug comprising: (a) providing a subsea lubricator having a longitudinal through bore and a jack attached to the subsea lubricator, the jack having a landing area; (b) providing a jacking string which includes a landing sub and a crown plug connector, the sub having a landing surface; (c) without the jacking string in step “b”, lowering the subsea lubricator of step “a”, to the horizontal christmas tree and attaching the lubricator to the christmas tree; (d) lowering the jacking string to the lubricator; (e) jacking up the jack such that the landing area of the jack contacts the landing surface of the landing sub; and (f) while the lubricator remains attached to the christmas tree, raising the jacking string and crown plug through and out of the lubricator.

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 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: The present invention is directed to methods and apparatus to construct subsea wells with redundant parallel fluid flow control systems to allow new methods to stop subsea blow outs. More specifically, this invention provides methods and apparatus to construct subsea wells with a plurality of redundant parallel paths allowing for the first time drill pipe and other intervention conduits, wire line, and fluids to be deployed below a damaged drilling riser and or a damaged blow out preventer through a separate blow out preventer and riser system presented in this invention.

Abstract: An embodiment of a method of deploying a cable into a wellbore penetrating a subterranean formation comprises providing a cable, wherein the cable comprises at least one insulated conductor, at least one armor wire layer surrounding the insulated conductor, a polymeric material disposed in interstitial spaces formed between armor wires forming the at least one armor wire layer, and interstitial spaces formed between the at least one armor wire layer and insulated conductor, the polymeric material forming a continuously bonded layer which separates and encapsulates the armor wires forming the at least one armor wire layer, and whereby the polymeric material is extended to form a smooth polymeric jacket around the at least one armor wire layer, introducing the cable into a wellbore and performing at least one operation in the wellbore utilizing the cable.

Abstract: A modular well intervention assembly includes a jack assembly having increased stroke length that can be installed directly over a well or above a BOP assembly. Modular work platforms and a telescoping mast assembly can be installed and secured in place around the jack assembly. Tongs can be suspended from a hydraulically operated “track system”, eliminating the need for a conventional tong pole and spring. Pipe can be manipulated relative to the well intervention assembly using a hydraulically powered pipe handling device.

Abstract: Systems and methods for visually indicating an engagement status of a submerged subsea connector are provided. An example of a system includes a measurement device positioned to provide a signal indicating positive engagement of a locking mechanism for a submerged subsea connector, and a visual engagement status indicator assembly including a visual engagement status indicator positioned on an outside portion of a surrounding frame to provide a visual indication corresponding to an engagement status of the locking mechanism provided by the measurement device. A power supply assembly is configured to interface with portions of an adjacent cathodic protection system to provide supply power or voltage multiplication to the visual engagement status indicator.

Abstract: A system for rotating an element inside a pressure containing housing. In some embodiments, the mechanism includes a pressure containing housing having an opening through a wall of the housing into an internal chamber in which, in use, the element to be rotated is located, a bushing located within the opening, and a worm gear rotatably mounted in the bushing. The worm gear is offset from the axial centre of the bushing such that rotation of the bushing moves the worm gear between an extended position, wherein the thread of the worm gear engages an element in the chamber, and a retracted position, wherein the thread is disengaged from the element in the chamber.

Abstract: A subsea control module for subsea well equipment has an actuator having a rod with a remote operated vehicle (ROV) interface on one end and a latch on an opposite end that latches to a subsea receptacle. Segments are releasably mounted around and to the actuator. Each of the segments has a sealed housing containing at least one internal control component. Couplings depend from the housing for engaging mating couplings in the receptacle. The housing has two radial walls, each extending along a radial line from an axis of the rod. An outer wall joins outer ends of the radial walls, the outer wall being a portion of a cylinder. An inner wall joins inner edges of the radial walls. The radial walls of adjacent ones of the segments abut each other.

Abstract: A method of pressure testing a lower marine riser package includes forming an inflatable packer having exposed slats and an inflatable packer element. The packer is positioned within the lower marine riser package above the cap seal with the exposed slats above the packer element. The packer is inflated and fluid pressure is then applied to test the integrity of the cap seal. The packer may be inverted, then positioned below the BOP/riser connection, the packer inflated, and pressure increased above the inflated packer element to test the fluid integrity of the BOP/riser connection.

Abstract: What is provided is a method and apparatus which can be detachably connected to an annular blowout preventer thereby separating the drilling fluid or mud into upper and lower sections and allowing the fluid to be displaced in two stages, such as while the drill string is being rotated and/or reciprocated. In one embodiment the sleeve can be rotatably and sealably connected to a mandrel. The swivel can be incorporated into a drill or well string and enabling string sections both above and below the sleeve to be rotated in relation to the sleeve. In one embodiment the drill or well string does not move in a longitudinal direction relative to the swivel. In one embodiment, the drill or well string does move longitudinally relative to the sleeve of the swivel.

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: An autonomous underwater vehicle (AUV) may be programmed and launched to interface with an emergency blowout preventer which has been fitted, either when new or retrofitted, with an emergency BOP control system (EBOP). The EBOP is a “black box” drop-in solution for projects such as emergency well control that can be retrofitted to existing BOP systems or added to new BOP systems and comprises one or more control docking stations, each adapted to receive autonomous underwater vehicle (AUV); one or more interface units connected to the control docking station and used to provide an interface between the control docking station and a BOP; and the AUV which is dimensioned and configured to autonomously mate with the control docking station and effect controls of the BOP.

Abstract: An offshore unit includes a hull and/or a deck frame, a mat attached to at least one connecting leg or a spud can attached to each of at least one connecting leg or lower hull attached to at least one connecting means. A wellhead deck is removably attached to the hull and/or deck frame and a sub-sea clamp in conjunction with a caisson or a sub-sea conductor frame is removably attached to the mat or to the at least one connecting leg, where a spud can is attached to each of the at least one connecting leg, or to the lower hull. The offshore unit is relocatable and is a platform or a rig capable of performing drilling, production, construction, accommodation, hook-up and commissioning or a combination of any of these functions thereof. The offshore unit is a self-elevating mobile platform or submersible platform or semi-submersible platform.

Abstract: The disclosure provides a method and system of installing subsea well trees, comprising: creating a glory hole having a depth below a seabed at a well location of a hydrocarbon reservoir; moving a floating offshore platform coupled with a foundation, the platform having a topsides and a caisson with downwardly extending walls defining an inner volume between the walls, the foundation coupled to the caisson walls, and the caisson walls having adjustable buoyancy; lowering the offshore platform with the foundation into the glory hole; drilling from the topsides into the hydrocarbon reservoir below the foundation to create a well; installing a well tree on the well, the well tree being disposed in the glory hole below the height of the seabed; coupling the well tree to a flow line; releasing the offshore platform from the foundation; and reusing the offshore platform to install other foundations at other predetermined well locations.

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: A distributed function control module adapted for use in a modular blowout preventer (BOP) stack for use subsea comprises a housing adapted to be manipulated by a remotely operated vehicle (ROV) with a stab portion adapted to be received into a BOP stack control module receiver. Control electronics, adapted to control a predetermined function with respect to the BOP stack, are disposed within the housing and connected to one or more controllable devices by a wet mateable connector interface. It is emphasized that this abstract is provided to comply with the rules requiring an abstract which will allow a searcher or other reader to quickly ascertain the subject matter of the technical disclosure. It is submitted with the understanding that it will not be used to interpret or limit the scope of meaning of the claims.

Abstract: A method for determining a position of a fluid discharge in an underwater environment, the method including: collecting data relating to an underwater area through at least two acoustic sensors; filtering and processing the data collected to identify the presence of the discharged fluid and the underwater area involved; forming a single stereoscopic image by combining the plurality of single three-dimensional images; and estimating the position of the fluid discharge on the basis of the stereoscopic image thus obtained.

Abstract: An apparatus for use in providing an intervention workover control system for an underwater well, comprising a first structure for connecting to a hydraulic flying lead, a first support for supporting at least one electrical flying lead, a second support for supporting the hydraulic flying lead, a second structure, a third structure, and a third support for supporting the at least one electrical flying lead, the second and third structures can be connected to respective ones of opposite sides of the first structure. The structures are configured to provide an intervention workover control system of a first configuration, wherein the first structure is usable with the second and third structures connected to the first structure, and to provide an intervention workover control system of a second configuration, wherein the first structure is usable without the second and third structures connected to the first structure.

Abstract: Apparatus for improving the safety and recovery of wells to be installed in oil wells comprising a Deep Set Well Head (DSWH), a Casing Receptacle (1), a Deep Set Tubing Hanger (DSTH) (2), Sub-Surface Safety Valves (SSSVs) (12) (13) with one or two independent Control Lines and Connection elements between the DSTH and well head.

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: What is provided is a method and apparatus wherein a swivel can be detachably connected to an annular blowout preventer while the drill string is being rotated and/or reciprocated. In one embodiment the sleeve or housing can be rotatably and sealably connected to a mandrel. The swivel can be incorporated into a drill or well string and enabling string sections both above and below the sleeve to be rotated in relation to the sleeve. In one embodiment the drill or well string does not move in a longitudinal direction relative to the swivel. In one embodiment, the drill or well string does move longitudinally relative to the sleeve or housing of the swivel.

Abstract: A system for maneuvering a plug in and out of a tubing hanger mounts to a subsea wellhead assembly. The system includes a tractor and an end effector that are sheltered in a housing. A control cable spools from a reel mounted on the housing and attaches to the tractor. The control cable provides communication from a remotely operated vehicle (ROV) to the tractor and end effector so that commands from the ROV via the control cable control the tractor and end effector. After the housing connects to the wellhead assembly, control signals from the ROV activate the tractor to drive the end effector into the wellhead assembly and command the end effector to set the plug in the tubing hanger, or to remove the plug from the tubing hanger.

Abstract: A wear bushing having a lead impression block is landed axially above a casing hanger and actuated to test an elevation of lock ring grooves formed in a wellhead. Then, drilling operations are performed through the wear bushing. The wear bushing includes a first tubular member having an axis and a second tubular member coaxial with the first tubular member. The second tubular member moves down to actuate a lead impression assembly to measure an elevation within the wellhead with the lead impression block. After the drilling operations are completed, the deformed lead impression block is retrieved along with the wear bushing.

Abstract: The connection system allows to assemble two sections of a riser pipe used for offshore drilling, the riser pipe comprising a main tube and at least one auxiliary line arranged parallel to said tube. The connection system comprises a connector A for assembling two main tube sections and connecting means B1 for assembling two auxiliary line sections. Connecting means B1 are arranged, with respect to connector A, in such a way that the overall dimensions E of the connection system are smaller than the sum of the overall dimensions EA of the connector and of the overall dimensions EB1 of the connecting means.

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 remote operated vehicle (ROV) interface has a retrievable portion and a permanent portion. The permanent portion includes a housing that has a cavity that secures to a drive stem of the subsea well device. The housing has a pod cavity on an opposite end that receives a pod body, which is part of the retrievable portion. The pod body is secured by spring-biased retainer within the pod cavity. The pod body has a cylindrical receptacle that receives a drive pin, which forms another part of the retrievable portion. The drive pin and the cylindrical receptacle are engaged for rotation by a shear element. The pod body has an ROV retrieval profile that is accessible by an ROV. In the event the shear element shears due to excessive torque, an ROV retrieval tool engages the pod body and retrieves the pod body along with the drive pin.

Abstract: Methods and devices for restoring control of at an offshore oil well following an uncontrolled fluid release after an explosion include lowering through a riser of successive flow restricting inserts into the oil well to gradually reduce the uncontrolled fluid release. Flow restricting inserts may be inserted in parallel or in series with each other. Following attachment of the riser to the oil well, provisions are made to restore oil production from the well. Flow restricting inserts may further be used to adjust flow resistance from the well in order to optimize oil production. Passages between the riser and the flow restricting inserts may also be used to form a gas lift in order to maximize production of oil from the well.

Abstract: A floating structure includes a riser support system. The riser support system includes multiple carts, each suitable for moveably connecting a risers to the riser support system. A cart includes a support frame and one or more riser tensioners for connecting the support frame to a riser. Each cart is designed for being supported by a cart support structure in a production dock and in a drilling dock, and for being transferred by a crane between the production dock and the drilling dock. Thus, the riser support system enables transferring risers and their riser tensioners within the moonpool from a production dock to a drilling dock without the need of disconnecting and/or reconnecting the risers to extra riser tensioners for support in the drilling dock or during transport.

Abstract: A retrievable module assembly can be used to install and/or de-install a blowout preventer (BOP) module from a BOP subsea where the BOP comprises one or more corresponding BOP module receivers. The retrievable module assembly typically comprises a frame configured to house and support the subsea BOP module; and a modular storage unit disposed at least partially within the frame. The modular storage unit further comprises a storage area configured to removably accept the subsea BOP module; a rotator configured to attach to and rotate the subsea BOP module, the rotator disposed at least partially within the frame; a rotator mover, slidably mounted in the frame and operatively in communication with the rotator; and a power connector operatively connected to the rotator and rotator mover and configured to interface with a power source.

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: A cap is lowered onto and secured to a subsea member with an external flange, effecting a seal between the external flange and cap. The cap includes a tubular outer body defining a cavity, and a tubular inner body defining a bore, wherein the lower end of the inner body resides within the cavity. The cap also includes a lower engaging member coupled to the outer body that is radially movable between an inward state and an outward state and configured to alternately engage and disengage at least one of a backside of the external flange. Finally, the cap includes an upper engaging member coupled to the outer body and being radially movable independently of the lower engaging member between an inward state and an outward state and configured to engage and disengage the inner body.

Abstract: A modular wellhead system having the capability for single or dual annulus via interchangeable heads, a unique capping system, and other features. A unique wellhead manual positive lock system incorporating an energizable inner bite ring for engaging the casing tubing, a compressible slip hanger for the tubing, as well as a hydraulic jack for lifting the tubing from the well to reintroduce tension are provided, the system being particularly suitable for use in conjunction with repair or low pressure plug and abandon (P&A) operations. Components of the system are designed for assembly via locking pins for diver friendly operation, While the present system is designed principally for use in subsea environments, the system can likewise be utilized on land or platforms.

Abstract: A method and an apparatus for killing of uncontrolled oil fountain include a series of rods with the first rod having the smallest diameter and successive rods having increasing diameters. Such telescopic assembly of rods is lowered into the well to cause gradual reduction in cross-sectional area available for oil flow discharge. Once sufficiently large rods are lowered into the well, the oil fountain discharge will be greatly diminished. Final sealing may be accomplished by pumping cement into a space formed between the well pipe and the rod assembly. A novel system for aligning the rods to the center of the well is also described.