313 results about "Drilling riser" patented technology

An arrangement and a method to control and regulate the bottom hole pressure in a well during subsea drilling at deep waters: The method involves adjustment of a liquid / gas interface level in a drilling riser up or down. The arrangement comprises a high pressure drilling riser and a surface BOP at the upper end of the drilling riser. The surface BOP havs a gas bleeding outlet. The riser also comprises a BOP, with a by-pass line. The drilling riser has an outlet at a depth below the water surface, and the outlet is connected to a pumping system with a flow return conduit running back to a drilling vessel / platform.

Method and system for connecting a joint of pipe to a top drive motor just above the drilling platform of a drilling rig where the connection can be made quickly and safely by a drilling operator. The system includes a top drive motor that tilts about a horizontal axis and a pipe launcher that brings joints of pipe up to the drilling platform for connection with a top drive motor at a safe and convenient height above the platform. The top drive motor further includes a clamping assembly that grasps and pulls the joint of pipe to the motor as the connection is being made. The clamp assembly supports the motor-pipe connection as the top-drive motor is raised in the drilling mast of the rig bringing the joint of pipe up into a vertical orientation for connection with the drill tubing string.

Subsea wells are drilled and completed with an offshore floating platform in a manner that allows simultaneous work on more than one well. A first well is drilled and cased. Then a tubing hanger is run through a drilling riser and landed in the wellhead housing. Then, with the same floating platform, the drilling riser is disconnected and moved to a second well. While performing operations on the second well, the operator lowers a production tree from the floating platform on a lift line, and connects it to the first wellhead housing. An ROV assisted subsea plug removal tool is used for plug removal and setting operations. Seabed separation is configured upstream of a production choke valve.

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.

Method for drilling and lining a well wherein at least one liner (1, 2, 32) with a larger external diameter than the substantial part of a drilling riser (10) is pre-installed at a point below the substantial part of the drilling riser (10). A bore hole section (21) is drilled after the drilling riser (10) has been installed, the bore hole section having a larger diameter than the at least one pre-installed liner (1, 2, 32). The at least one pre-installed liner (1, 2, 32) is subsequently lowered into the bore hole section (21, 22). A drilling and liner system for implementing the method is also described.

A subsea drilling method and system for controlling the drilling fluid pressure, where drilling fluid is pumped down into the borehole through a drill string and returned back through the annulus between the drill string and the well bore. The drilling fluid pressure is controlled by draining drilling fluid out of the drilling riser (8) or BOP (6) at a level between the seabed and the sea water in order to adjust the hydrostatic head of drilling fluid. The drained drilling fluid and gas is separated in a subsea separator (28) where the gas is vented to surface through a vent line (39), and the fluid is pumped to surface via pump (40).

A subsea mud pump can be used to return heavy drilling fluid to the surface. In order to provide a less stringent requirement for such a pump and to better manage the bottom hole pressure in the case of a gas kick or well control event, the gas should be separated from the drilling fluid before the drilling fluid enters the subsea mud pump and the pressure within the separating chamber. The mud pump suction should be controlled and kept equal or lower than the ambient seawater pressure. This can be achieved within the cavities of the subsea BOP by a system arrangement and methods explained. This function can be used with or without a drilling riser connecting the subsea BOP to a drilling unit above the body of water.

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.

A riser for use in boring a subsea wellbore having a gooseneck assembly connected onto the riser. The gooseneck assembly has an outlet that couples with a flowline on the riser and a connector assembly that selectively decouples the gooseneck assembly from the flowline. A release member, such as a wire, cable, or rod, is attached to the connector so the connector assembly can be actuated by manipulating the release member from a remote location.

A tensioner for providing a conduit, e.g., drilling and production riser strings, from a floating vessel at the surface of the ocean to the blowout preventer stack, production tree, or other assembly which is connected to the wellhead at the sea floor. The tensioner compensates for vessel motion induced by wave action and heave and maintains a variable tension to the riser string alleviating the potential for compression and thus buckling or failure of the riser string. The tensioner of the present invention preferably includes at least one mandrel having at least one hang-off donut; at least one upper flexjoint swivel assembly, at least one radially ported manifold, and at least one tensioning cylinder co-linearly combined in a single unit. Methods for assembling risers are also disclosed.

A riser assembly for offshore drilling has an inner conduit suspended within an outer riser. A seal assembly seals an annular space between the inner conduit and the riser at the lower end of the inner conduit. The seal assembly has a pressure area that is independent of the inner conduit, so that any forces acting on the assembly due to pressure in the annulus below the seal assembly pass through the assembly to the riser and not to the inner conduit.

In an offshore drilling facility, apparatus is disclosed comprising: a drilling floor centralizer for receiving the upper end of a string of drilling riser sections; a moonpool centralizer for receiving another portion of the drilling riser; and at least one roto-track, removably and rotationally carried by at least one of the pin end of one drilling riser section and the box end of the adjacent drilling riser section, for extending the outer diameter of each of the adjacent ends to the outer diameter of the adjacent drilling risers sections intermediate the ends of the drilling riser sections.

A fairing includes two half-shells of fiber reinforced plastic or fiberglass. The shell halves are shaped to close around the buoyancy modules (e.g., cylindrical syntactic foam buoyancy modules) commonly used on deep-water risers, but with an extended trailing edge. The fairing includes a tail that streamlines the riser and reduces / prevents formation of the vortex, which causes drag and vibration. Hinges at the tail join the halves and enable them to be opened for assembly around the riser pipe as it is being run into the water. The fairing may be fastened together by bolted stainless steel tensioners that tightly draw together straps of high strength aramid fiber, such as KEVLAR®. The fairing is positioned on the riser such that the fairing is free to swivel and rotate into the current, while integral buoyancy blocks support the tail. To prevent movement up or down the riser string, the fairing is held in place by a channel clamp gripping the outside diameter of the syntactic foam buoyancy module.

Methods and systems for drilling subsea wells bores with dual-gradient mud systems include drilling the subsea well bore while employing a subsea pumping system, a subsea choke manifold and one or more mud return risers to implement the dual gradient mud system. When a well bore influx is detected, the well bore is shut in, and components determine if pressure control may be used to circulate the influx out of the well bore, the size of the influx, and how much the mud system weight will need to be reduced to match the dual gradient hydrostatic head before the influx reaches the subsea pump take point. The subsea pumping system, subsea choke manifold, and mud risers are isolated while the influx is circulated up one or more fluid passages in the drilling riser package using the surface pump, through the wellhead, and out the surface choke manifold.

A drilling rig having a deck capable of being used offshore and a method for commissioning a well using the drilling rig and a method for decommissioning a well using the drilling rig, wherein the drilling rig comprises: a cantilever which is mounted so as to be moveable in a first direction and a second direction; a Multi Purpose Tower mounted on the cantilever; a supporting cart disposed between the cantilever and the deck which in turn is movably fixed on the deck of the drilling rig; at least two friction reducing devices attached to the supporting cart; and wherein the cantilever can slide relative to the drilling platform.

Buoyancy modules for subsea riser pipes are made of syntactic foam solid cores covered with tough high density polyethylene shells. Inner surfaces have partial semi-cylindrical surfaces to fit the riser pipes. Internal radial grooves hold flexible contact pads. Recesses in the inner surfaces hold auxiliary lines. Flat surfaces between the inner and outer semi-cylindrical surfaces have complementary longitudinally extending semi-cylindrical grooves to position choke and kill lines. Grooves in the outer semi-cylindrical surfaces hold composite fiber tensioning straps directly outward from the flexible contact pads. Flat areas of the grooves hold tensioning hardware. Tensioning the straps grips the riser pipe with the pads and grips the choke and kill lines in the semi-circular grooves. Cavities in the ends allow the buoyancy module halves to be assembled on the riser pipe around clamps which hold the accompanying lines.

A subsea wellhead assembly having a completion landing string inside a drilling riser is described herein and comprises a power source for generating an alternating electrical current; a connector for connecting the power source to a receptacle in the subsea well assembly; a first inductor electrically connected to the power source through the connector; a subsea control module delivering power and control signals to the subsea well assembly; and a second inductor spaced from the first inductor, and located in the subsea control module, the second inductor positioned so that an EMF is produced on the second inductor when the alternating electrical current is passed through the first inductor to thereby generate an alternating current signal on the second inductor.

A connector for connecting sections of drilling riser pipe wherein a first riser contains a pin assembly with an external first grooved profile and a second riser contains a housing assembly. An internal split pivoting latch segment assembly carried by the housing assembly contains a second grooved profile adapted to mate to the first grooved profile and a split actuation ring movably carried by the housing assembly forces the second grooved profile of the latch segment assembly into engagement with the first grooved profile of the pin assembly. A plurality of retraction links engage an upper edge of the latch segment assembly to disengage the second grooved profile of the latch segment assembly from the first grooved profile of the pin assembly if the risers are to be disconnected.

The invention relates to a deepwater semi-submerged drilling platform, which comprises floating tanks, an upright post, a transverse supporting rod and a main deck, wherein a drilling block is arranged above a moon pool in the middle of the main deck; and a derrick is arranged on the drilling block. The deepwater semi-submerged drilling platform is characterized in that: a half derrick space for pre-connecting a drilling tool is reserved on one side of the derrick; a water isolating pipe, a drilling stem, a blowout preventer and a production tree are arranged on the main deck around the moon pool respectively; and an anchor moored positioning and dynamic positioning combined position system which consists of front and back four groups of anchor gears distributed on the left and right sides of the main deck is adopted, each group of anchor gears are provided with 3 anchor chains, a dynamic positioning system consists of 8 dynamic thrusters capable of rotating 360 degrees at the front and back four corners of the bottom of the two floating tanks. In the deepwater semi-submerged drilling platform, the maximum operation water depth is up to 3,000 meters, the maximum drilling depth is up to 12,000 meters, and the maximum variable load is up to 9,000 tons. The deepwater semi-submerged drilling platform can operate in the South China Sea, Southeast Asian sea area and West Africa sea area with severe sea conditions efficiently and safely.

Methods and systems for drilling subsea wells bores with dual-gradient mud systems include drilling the subsea well bore while employing a subsea pumping system, a subsea choke manifold and one or more mud return risers to implement the dual gradient mud system. When a well bore influx is detected, the well bore is shut in, and components determine if pressure control may be used to circulate the influx out of the well bore, the size of the influx, and how much the mud system weight will need to be reduced to match the dual gradient hydrostatic head before the influx reaches the subsea pump take point. The subsea pumping system, subsea choke manifold, and mud risers are isolated while the influx is circulated up one or more fluid passages in the drilling riser package using the surface pump, through the wellhead, and out the surface choke manifold.

Segments of open framework auxiliary clamps are fastened together around a drilling riser. The clamps have depressions which mate with recesses in caps to hold auxiliary lines. Larger depressions and recesses hold choke and kill lines. The caps of the choke and kill clamps are extended radially through openings in buoyancy covers as mux clamp mounts. Extensions on mux clamps engage slots in the mux clamp mounts. Opposing channels in the mux clamps and covers hold inserts, with grooves in which multiplex lines are mounted.

A subsea wellhead assembly having a completion landing string inside a drilling riser is described herein and comprises a power source for generating an alternating electrical current; a connector for connecting the power source to a receptacle in the subsea well assembly; a first inductor electrically connected to the power source through the connector; a subsea control module delivering power and control signals to the subsea well assembly; and a second inductor spaced from the first inductor, and located in the subsea control module, the second inductor positioned so that an EMF is produced on the second inductor when the alternating electrical current is passed through the first inductor to thereby generate an alternating current signal on the second inductor.

The invention discloses a marine drilling riser tensioning system which comprises a plurality of tensioner assemblies respectively arranged around a floating type drilling platform, wherein each tensioner assembly comprises a tensioning cylinder and an energy storage device, wherein the upper end and the lower end of the tensioning cylinder are respectively provided with an upper tackle block and a lower tackle block, the distance between the upper tackle block and the lower tackle block is changed with the flexibility of a piston; a lower cavity of the energy storage device is filled with a high-pressure liquid, an upper cavity of the energy storage device is filled with a high-pressure gas, the lower cavity of the energy storage device is communicated with a piston cavity of the tensioning cylinder, the upper cavity of the energy storage device is communicated with a high-pressure air system; and a steel rope sequentially bypasses through the upper tackle block and the lower tackle block and is connected with a connection device after guided by a guide pulley, and the connection device is connected with a tensioning ring hung on a riser system. The marine drilling riser tensioning system has the advantages of simple structure, convenience for control, reliability in control, low manufacture cost and large bearing capacity.

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