Abstract: A float apparatus includes a buoyant device that has an outer surface with a first end portion, a second end portion and an elongated portion. The elongated portion extends from the first end portion to the second end portion. The buoyant device is shaped and configured to attach to a conduit. The elongated portion of the outer surface has a concaved section that extends from the first end portion to the second end, portion. The concaved section has a shape that complements an cuter radius of the conduit with the buoyant device attached to the conduit.

Abstract: A hydraulic protection system for preventing collapse of a hydraulic line is provided. The system includes a pressure sensing assembly which is arranged to monitor a pressure differential between fluid external to and fluid contained within the hydraulic line; a pressure compensation assembly adapted to be coupled to the hydraulic line. In the event of a loss of pressure in the hydraulic line occurring, the pressure compensation assembly employs the pressure of the fluid external to the hydraulic line to increase the pressure of the fluid contained within the hydraulic line. The system is arranged so that the pressure compensation assembly is operated when the pressure differential monitored by the pressure sensing assembly reaches a predetermined level, which is below a collapse pressure of the hydraulic line, so that exposure of the hydraulic line to the collapse pressure is avoided.

Abstract: Systems and methods for coupling a platform to a subsea wellhead are provided. The systems may include a riser extending between the platform and the subsea wellhead. The systems may further include an inner drilling riser tie-back connector (“ITBC”) coupled to an inner riser and having an outer body and an inner body. The inner body is at least partially disposed within the outer body, and the inner body is translatable along a longitudinal axis of the ITBC between a first unlocked position and a second locked position. The systems may additionally include a locking mechanism for the ITBC.

Abstract: An assembly for hanging a tubular string includes a packoff (56) having a fastener and a seal for engaging an inner surface of the tubular string and a setting tool. The setting tool includes: a debris cap (84) for engaging an upper end of the tubular string, thereby forming a buffer chamber between the debris cap (84) and the packoff (56); a mandrel (66) having a port formed through a wall thereof; a piston (71): disposed along the mandrel, having an upper face in fluid communication with the port, and operable to stroke the debris cap relative to the mandrel, thereby setting a hanger of the tubular string; an actuator sleeve (71) extending along the mandrel and connected to the piston; a packer actuator (62) including a housing connected to the debris cap above the buffer chamber and a fastener for engaging a profile of the actuator sleeve; and a latch releasably connecting the housing to the mandrel.

Abstract: The present invention provides an experimental device for simulating invasion of shallow fluid into a wellbore, comprising: a casing pipe; a drilling-in device including a drill string extending into the casing pipe, and a drill bit located within the casing pipe and connected to the drill string; a driving device for driving rotation of the drill string, the driving device being disposed outside the casing pipe and connected to the drill string; a drilling fluid injection device for injecting drilling fluid into the drill string, the drilling fluid injection device being disposed outside the casing pipe and connected to the drill string; a shallow fluid injection device for injecting shallow fluids into the casing pipe, the shallow fluid injection device being disposed outside the casing pipe and communicating with the casing pipe; a pressure detection device for detecting a pressure within the casing pipe, the pressure detection device being connected to the casing pipe.

Abstract: Techniques and systems to reduce deflection of a riser extending from an offshore platform. A device may include a main tube disposed along a length of the device. The device may also include a support member that may be coupled to the main tube, wherein the support member may surround the main tube. The device may include a buoyancy assembly that may at least partially surround the main tube, wherein the buoyancy assembly may have an elongated non-circular and non-cylindrical shape. The buoyancy assembly may also include buoyancy foam.

Abstract: The invention relates to the field of stratum drilling, and in particular to a control method and a control device for drilling operations. The control method comprises: detecting whether an overflow occurs in a well; controlling the wellhead back pressure based on a preset bottom hole pressure when no overflow occurs in the well, in order to keep the bottom hole pressure stable; and performing a shut-in operation and controlling the wellhead back pressure based on the increase in fluid discharge returned from an annulus of the well when an overflow occurs in the well, so as to keep the bottom hole pressure stable and prevent the gas in the stratum from continuing to invade into the drilling fluid during the process that the overflow drilling fluid is discharged from the bottom of the well.

Abstract: The invention relates to an apparatus (10) for installing a wellbore (12) on a seabed (14). The apparatus includes a suction member (16) including a housing (17) defining a chamber (18). The housing (17) has an open end (20). The open end (20) defines a leading edge (22) for engagement with the seabed (14). The apparatus (10) includes a wellhead located (24) at an end opposite the open end (20) for engagement with a conduit (28). The conduit (28) is coupled to the housing (17). The conduit (28) extends from the wellhead means (24) through the chamber (18). When the wellbore (12) is installed on the seabed, the apparatus (10) provides a barrier or well barrier, which is capable of isolating and/or maintaining a wellbore pressure. The apparatus (10) allows for the installation of a wellhead (24) and/or a conduit (28) without the need of prior drilling and/or jetting operations at a wellbore site.

Abstract: Techniques and systems to reduce deflection of a riser extending from an offshore platform. A device may include a main tube disposed along a length of the device. The device may also include a support member that may be coupled to the main tube, wherein the support member may surround the main tube. The device may include a buoyancy assembly that may at least partially surround the main tube, wherein the buoyancy assembly may have an elongated non-circular and non-cylindrical shape. The buoyancy assembly may also include buoyancy foam.

Abstract: The present invention relates to a riser joint for a riser with a joint connecting two parts of a riser where the two parts are allowed angular displacement. According to the invention the riser joint comprises means for connection to the two parts of the riser at a distance from the joint, and means for adding a force between the two parts. The invention also relates to a method for reducing bending moments in a riser at a connection between the riser and a subsea installation.

Abstract: A system for producing well production fluids through a tubing hanger connected with a tubing string, in certain embodiments, includes a subsea tree and a tubing spool. The subsea tree includes a production flow passage, and the tubing spool includes a longitudinal bore configured to receive the tubing hanger and a lateral production flow passage configured to transfer well production fluids to the production flow passage of the subsea tree. The subsea tree and the tubing spool are configured to be run and retrieved independently of one another in any order.

Abstract: A top-tensioned riser system comprises a substantially vertical riser extending upward from the seafloor; a conductor surrounding an upper portion of the riser in spaced-apart relation; a coaxial keel guide surrounding a lower portion of the conductor; a tensioner attached to the conductor and the riser; a keel guide support structure attached to the keel guide and connected to the keel of a dry-tree, semi-submersible vessel; and, a keel joint centralizer attached to the riser proximate the keel guide and sized to prevent radial movement of the riser relative to the conductor. Side loads on the riser (such as those arising from displacement of the vessel from its nominal position or currents acting on the riser) are reacted from the riser to the conductor via the keel joint centralizer and then to the keel of the vessel via the keel guide.

Abstract: A method and apparatus for bundling flexible risers uses a vertically-hanging riser support shaft extending below the turret of a turret-moored FPSO to manage the motions of the risers. The risers may transition to a catenary configuration as they exit a bottom structure at the lower end of the riser support shaft and connect to wellheads or flowlines on the seafloor. Certain embodiments are suitable for use with a disconnectable buoyant turret mooring system while other embodiments may be used with spread-moored FPSOs.

Abstract: A drilling system includes a first section of a drilling tool having a collar configured to hold internal components of the first section. The drilling system also includes a second section of the drilling tool configured to be coupled with the first section in a specific orientation relative to the first section. The second section is interchangeable with at least one different section.

Abstract: A control system for a subsea well is provided. The control system comprises a tree comprising a hydraulic control supply line for use in opening a downhole safety valve as a result of hydraulic pressure in the line. A part of the line is carried by a structure which is subject to the pressure of a production fluid from the well used in the control system so that the line is separable in response to a failure of the integrity of the structure.

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: What is provided is a method and apparatus wherein a rotating and reciprocating swivel can be detachably connected to an annular blowout preventer thereby separating the drilling fluid or mud into upper and lower sections with the mandrel of the swivel being comprised of double box end joints and using double pin end subs to connect a plurality of such mandrel joints together.

Abstract: A subsea contaminate remediation apparatus is provided. The apparatus includes a conduit. The conduit includes a first end adapted to receive a first liquid stream having at least one contaminate; a second end adapted to release a second liquid stream; a grating associated with the second end of the housing; and at least one chemical injection port. The chemical injection port is adapted to introduce a chemical to the first liquid stream to form the second liquid stream.

Abstract: A riser assembly for transporting a fluid from a vessel and on a seabed includes an elongate frame having a first frame end and a second frame end, where the first frame end is connected to the seabed and the second frame end is connected to a buoy, at least one riser for transporting a fluid and connecting the at least one riser to the second frame end and/or the buoy.

Abstract: A method of completing a subsea borehole including connecting a first vessel to a subsea wellhead assembly via a riser. A borehole is drilled with a drill string communicated to the subsea wellhead assembly through the riser. A lower completion assembly is run on a service string into the borehole through the riser. At least two barrier valves of the lower completion assembly are set with the service string in order to form a mechanical barrier to fluid flow with each of the at least two barrier valves. The riser is disconnected from the subsea wellhead assembly. An upper completion string is run through open water to the borehole and connected to the lower completion assembly. An lower completion assembly for a subsea borehole is also included.

Abstract: Adapters for inclusion on the lower end of a completion/work-over riser includes a flow loop in fluid communication with a production flow loop hub and a production bore to facilitate testing and calibration of a subsea multi-phase flow meter during completion operations. The flow loop can be in fluid communication with one or more flow loop isolation valves, one or more production bore isolation valves, one or more annulus bore isolation valves, or one or more cross-over valves. In addition, a pressure/temperature sensor can also be included in the adapter. The adapters disclosed herein permit production fluid to flow through the subsea multi-phase flow meter while the riser is still attached to the subsea Christmas tree and before production operations have begun.

Abstract: Disclosed are methods, systems and apparatus for circulating fluid within the annulus of a flexible pipe used in a riser in an offshore hydrocarbon production facility. Fluid, such corrosion inhibitors, can be introduced into the annulus by pumping fluid from a storage tank located on a platform or vessel into tubes within the annulus. Use of the system to flow the fluid through the annulus can prevent or reduce corrosion of the steel members within the annulus and increase the fatigue life of the riser.

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

Abstract: 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: Blowout preventer (BOP) stack and lower marine riser package for sealing an undersea well. The blowout preventer stack includes a frame extending along an axis and configured to be attached to a head of the well; an accumulator attached to the frame and configured to provide high pressure; two or more BOPs attached to the frame, the two or more BOPs being disposed within the frame and attached one on top of the other along the axis; each BOP having a body and a pair of bonnets attached to the body, where the bonnets are configured to be detachably attached to the body; each BOP having a corresponding cavity extending along the axis through which a fluid from the well is circulating; each BOP being configured to seal the well when the high pressure from the accumulator is released to the BOPs; plural brackets attached to the body of at least one BOP; and a safety bar attached to the plural brackets and configured to partially encircle the body of the at least one BOP.

Abstract: A drilling riser adapter variably connects and releases a riser from a subsea wellhead assembly. The drilling riser adapter has a hydraulically actuated engagement assembly for selectively engaging and disengaging a lower end of the marine riser. The drilling riser adapter also includes a control panel communicatively coupled to the engagement assembly for actuating the engagement assembly to engage and disengage the lower end of the marine riser. The drilling riser adapter also includes a hydraulic fluid pressure receptacle on the control panel for engagement by a remotely operated vehicle to supply hydraulic fluid pressure to the engagement assembly. The drilling riser adapter may be actuated subsea to release a first riser from the wellhead assembly, and connect to a second riser.

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

Abstract: A device includes a hollow rigid member (40) and a curvature limiter (42) movable relative to the hollow rigid member (40). A releasable device (46) for axial immobilization of the curvature limiter (42) on the flexible line (18) in at least one first direction along a travel axis (X-X?). The axial immobilization device (46) includes a locking member (90) axially secured to the flexible line (18), and a member (92) for fitting the locking member (90), axially secured to the curvature limiter (42). Those members (90, 92) are movable relative to each other around the travel axis (X-X?) between a configuration for axial immobilization of the flexible line (18) on the curvature limiter (42), and a configuration for axial travel of the flexible line (18) across the curvature limiter (42).

Abstract: A rig control interface, system, and method. The rig control interface includes an emergency disconnect sequence button configured to initiate an emergency disconnect sequence signal to be sent to multiplex pods resulting in an emergency disconnect sequence including a plurality of functions being performed by devices in one or both of a lower marine riser package and a blowout preventer stack; and an emergency disconnect sequence timer display triggered by initiation of the emergency disconnect sequence signal, the emergency disconnect sequence timer display configured to indicate one or both of time elapsed after initiation of the emergency disconnect sequence signal and a status of the plurality of functions being performed by the devices in the one or both of the lower marine riser package and the blowout preventer stack.

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

Abstract: A clamp for securing about annular casing via a centrally oriented aperture having a radius includes at least one aperture for grasping a longitudinally extending accessory disposed about the radius of the centrally oriented aperture and at least one fastening member for securing the longitudinally extending accessory about the clamp. At least one fastening member and at least one aperture act to secure a longitudinally extending accessory relative to the annular casing.

Abstract: A device for containing fluid flow from a borehole includes: a containment assembly including a body having a cavity configured to receive a leaking portion of a borehole termination structure extending from the borehole and surround the leaking portion, the cavity configured to be adapted to at least partially conform to a shape of at least one of the leaking portion and the borehole termination structure; and a flow control assembly configured to connect a fluid conduit in fluid communication with the containment assembly and direct downhole fluid into the fluid conduit.

Abstract: A device for inhibiting severe slug flow in a multiphase fluid stream flowing through a pipeline and into a riser, wherein, the device is positioned immediately upstream of the riser and comprises at least one unit comprising (i) an upwardly inclined section of pipe having a lower end and an upper end and (ii) either a substantially horizontal section of pipe having a first end and a second end or a downwardly inclined section of pipe having an upper end and a lower end, wherein the lower end of the upwardly inclined section of pipe is connected either directly or indirectly with the pipeline, the upper end of the upwardly inclined section of pipe is connected either directly or indirectly with the first end of the horizontal section of pipe or with the upper end of the downwardly inclined section of pipe, and the second end of the horizontal section of pipe or the lower end of the downwardly inclined section of pipe is connected either directly or indirectly with the riser, and wherein the angle of inclinati

Abstract: Systems and methods for running and cementing casing into wells drilled with dual-gradient mud systems include running casing through a subsea wellhead connected to a marine riser, the casing having an auto-fill float collar, and connecting a landing string to the last casing run. The landing string includes a surface-controlled valve (SCV) and a surface-controlled ported circulating sub (PCS). The SCV and PCS are manipulated as needed when running casing, washing it down while preventing u-tubing on connections and prior to cementing to displace mixed density mud from the landing string and replace it with heavy-density mud prior to circulating below the mudline thus maintaining the dual gradient effect.

Abstract: A heave compensation system that facilitates the transfer of pipe between a floating platform and a snubbing jack. The heave compensation system includes a first end connected to the floating platform and a second end in connection with a traveling slip assembly of the snubbing jack, the heave compensation system is operable between a disengaged position and an engaged position. When the heave compensation system is in the disengaged position the traveling slip assembly moves separate and independent from the movement of the floating platform, and when the heave compensation system is in the engaged position the traveling slip assembly is locked in a constant position relative to the floating platform.

Abstract: An offshore riser system has riser joints, each having a pin and a box. The pin has an external grooved profile that is engaged by a locking element carried by the box of another riser joint. An actuating ring engages with the locking element to move it into the locked position. A retractable spider supports the string of riser while the new joint is being made up. A makeup tool on the riser deploying floor moves the ring relative to the locking element, causing the locking element to move to the locked position.

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

Abstract: Systems and methods for well intervention include a lower riser package (LRP), and an emergency disconnect package (EDP). The LRP includes a tree connector, a connector and seal stab adapter (CSSA), and a LRP body; the tree connector has a profile for mating to the CSSA. The CSSA has at least one seal stab assembly for fluidly connecting with a subsea tree. The body of the LRP includes one or more sealing elements that are capable of sealing upon command, an integral annulus with an annulus isolation valve, an upper hub profile compatible with the EDP, and a lower flange profile that mates with the CSSA. The EDP includes a quick disconnect connector, at least one annulus isolation valve, and one or more sealing elements that are capable of sealing upon command. In some embodiments, an internal tie-back tool connects to the EDP via an EDP internal tie-back profile.

Abstract: A subsea connection apparatus to allow connecting a surface blowout preventer stack and riser to a subsea wellhead is disclosed. The subsea connection apparatus uses a single cavity blowout preventer with a set of shearing blind rams. Hydraulically actuated wellhead connectors are secured to the top and bottom of the blowout preventer to allow connection to a subsea wellhead below the subsea connection apparatus and a well head hub profile on the lower end of a riser above the apparatus. A control system can operate both of the hydraulically actuated connectors and the blowout preventer independently. A frangible bore protector is disposed in the bore of the blowout preventer to protect the shearing blind rams from pipe, tools, and fluids being passed through the blowout preventer and can be sheared by the shearing blind rams along with any drill pipe in the bore.

Abstract: A connector (10) for releasable connection between an anchorage in the form of a female part (1) arranged on a floating means and a male part (2) formed at the end of a retrievable umbilical (3) provided with a bend stiffener (4) is disclosed. The male part (2) comprises a mandrel body (5) having a pulling head (6) for connection to a pulling means at one end and the umbilical (3) at the other end. The male part (2) comprises a sleeve formed body (7) that is fixed to the mandrel body (5) by shearable elements (8). The bend stiffener (4) is fixed directly to the sleeve formed body (7) and is designed for abutment against and parking together with the bend stiffener (4) within the female part (1) while the remaining part of the male part (2) including the umbilical (3) is designed to be pulled further up through the female part (1) for fluid communication and connection on a floating means or a vessel.

Abstract: A subsea well assembly has a tubing hanger that lands and seals in a wellhead housing. A tree block is lowered through the drilling riser into engagement with the tubing hanger. The tree block has a lower portion that inserts and latches into the bore of the wellhead housing. The drilling riser is disconnected, and a module is lowered onto the tree block, the module having a choke and controls for controlling the well. The master valve for production is the downhole safety valve in the tubing. The wing production valve is a ball valve located in the flow passage of the tree block.

Abstract: An offshore riser system has riser joints, each having a pin and a box. The pin has an external grooved profile that is engaged by a locking element carried by the box of another riser joint. An actuating ring engages with the locking element to move it into the locked position. A retractable spider supports the string of riser while the new joint is being made up. A makeup tool on the riser deploying floor moves the ring relative to the locking element, causing the locking element to move to the locked position.

Abstract: An offshore riser system has riser joints, each having a pin and a box. The pin has an external grooved profile that is engaged by a locking element carried by the box of another riser joint. An actuating ring engages with the locking element to move it into the locked position. A retractable spider supports the string of riser while the new joint is being made up. A makeup tool on the riser deploying floor moves the ring relative to the locking element, causing the locking element to move to the locked position.

Abstract: A bottom-surface connection installation for at least two undersea pipes resting on the sea bottom, the installation comprising: a first hybrid tower having a vertical riser anchored to a first base and connected to an undersea pipe resting on the sea bottom and having its top end connected to a first float below the surface, and a first connection pipe, preferably a flexible pipe, providing a connection between a floating support and the top end of said riser; and at least one second rigid pipe rising from the sea bottom where it rests or from a second undersea pipe resting on the sea bottom and to which its bottom end that is not anchored to said first base is connected, up to below the surface, where its top end is connected to a second float situated at substantially the same depth as said first float, and fastened to said first float to at least one respective said connection pipe that is flexible and serves to connect it to the same said floating support.

Abstract: Blowout preventer (BOP) stack and lower marine riser package for sealing an undersea well. The blowout preventer stack includes a frame extending along an axis and configured to be attached to a head of the well; an accumulator attached to the frame and configured to provide high pressure; two or more BOPs attached to the frame, the two or more BOPs being disposed within the frame and attached one on top of the other along the axis; each BOP having a body and a pair of bonnets attached to the body, where the bonnets are configured to be detachably attached to the body; each BOP having a corresponding cavity extending along the axis through which a fluid from the well is circulating; each BOP being configured to seal the well when the high pressure from the accumulator is released to the BOPs; plural brackets attached to the body of at least one BOP; and a safety bar attached to the plural brackets and configured to partially encircle the body of the at least one BOP.

Abstract: A technique for monitoring and evaluating parameters related to the use of a compliant guide system in intervention operations. A compliant guide enables movement of a conveyance within its interior and is coupled between a subsea installation and a surface vessel. A sensor system is provided with sensors deployed in subsea locations to detect operational parameters related to operation of the compliant guide. A control system is coupled to the sensor system to receive data output from the sensor system.

Abstract: Methods for deploying a subsea blowout preventer stack system comprising a lower marine riser package, a blowout preventer stack with a first ram blowout preventer, and an additional blowout preventer package releasably coupled to the blowout preventer stack and comprising a second ram blowout preventer. The subsea blowout preventer stack assembly can be deployed by coupling a drilling riser to the lower marine riser package that is releasably connected to the blowout preventer stack. The lower marine riser package and blowout preventer stack are then toward a subsea wellhead and then landed on the additional blowout preventer package that is coupled to the subsea wellhead.

Abstract: A technique for securing drilling riser joints in a drilling riser string is presented. The drilling riser joints have a tubular housing that has a box configuration on one end and a pin configuration on the other end. The drilling riser string is assembled by connecting the pin end of one drilling riser joint to the box end of an adjoining drilling riser joint. A moveable ring is used to connect adjoining drilling riser joints. The moveable ring is used to drive a fastener of one drilling riser joint against the adjoining drilling riser joint. The moveable ring is driven axially from a position where the fastener is not engaged against the adjoining drilling riser joint to a position where the fastener is engaged against the adjoining drilling riser joint. A latch is used to prevent the moveable ring from moving inadvertently from the second position.

Abstract: A floating vessel for supporting top tension drilling and production risers having a hull and an operation deck disposed on top of the hull. A tensioner assembly for moveably carrying a conductor that communicates from a wellhead to a piece of well access equipment. The well access equipment is connected to the floating vessel. The tensioner assembly is supported by the floating vessel.

Abstract: A subsea connection apparatus to allow connecting a surface blowout preventer stack and riser to a subsea wellhead is disclosed. The subsea connection apparatus uses a single cavity blowout preventer with a set of shearing blind rams. Hydraulically actuated wellhead connectors are secured to the top and bottom of the blowout preventer to allow connection to a subsea wellhead below the subsea connection apparatus and a wellhead hub profile on the lower end of a riser above the apparatus. A control system can operate both of the hydraulically actuated connectors and the blowout preventer independently. A frangible bore protector is disposed in the bore of the blowout preventer to protect the shearing blind rams from pipe, tools and fluids being passed through the blowout preventer and can be sheared by the shearing blind rams along with any drill pipe in the bore.