Abstract: A connecting assembly for connecting a first body and a second body includes a connector having a plurality of segments and a main piston positioned around at least a portion of the connector. The connector includes: a channel that extends longitudinally through the connector from a first end to a second end; a plurality of teeth formed on an inside of the connector near the first end and near the second end; a first jaw formed of at least one teeth near the first end; and a second jaw formed of at least one teeth near the second end and axially spaced apart from the first jaw. Each of the plurality of teeth has a leading side facing an axial center of the connector, a top side, a contact point at a transition between the leading side and the top side, and a trailing side opposite the leading side.

Abstract: Disclosed are systems, apparatuses, and methods for and related to dynamic control of torque and or lateral thrust applied to a load suspended load on a suspension cable to thereby achieve a target orientation or position or to otherwise move with reduced self-induced cyclic motion, with better behavior, and or to respond to changes in the load or disturbance forces.

Abstract: An underwater robotic system includes a frame for deployment in a body of water and having a control panel with multiple controls. A first actuator on the frame selectively actuates a control from a front side of the panel. A second actuator on the frame selectively actuates a control from a back side of the panel. One or more controls on the panel is configured to regulate distribution of a fluid. The frame is configured to couple to a blowout preventer. A method for robotic fluid distribution in an underwater environment.

Abstract: A well has an outer housing with a vertical main bore and a wing bore. The well is completed by: running an upper completion into the well; locating a tubing hanger in the main bore of the outer housing for fluid communication with the wing bore, the tubing hanger including a services line connected to downhole equipment; connecting a further services line to the services line of the tubing hanger, after the tubing hanger has obtained said operational position; and installing a cap on an end of the main bore. The connected services lines are arranged to communicate a service between the tubing hanger and an exterior of the capped well through either or both of: the end of the main bore; and the cap. Related apparatus, a cap, and a tubing hanger are also described.

Abstract: A blowout preventer system including a lower blowout preventer stack comprising a number of hydraulic components, and a lower marine riser package comprising a first control pod and a second control pod adapted to provide, during use, redundant control of hydraulic components of the lower blowout preventer stack where the first and the second control pods are adapted to being connected, during use, to a surface control system and to be controlled, during use, by the surface control system. The blowout preventer system further including at least one additional control pod connected to at least one additional surface control system and to be controlled, during use, by the additional surface control system.

Abstract: Disclosed are systems, apparatuses, and methods to determine, communicate, and/or respond to state information of at least one of a suspended load control apparatus, carrier, or load suspended by a cable from the carrier, wherein response to the state information may be to control at least one of the suspended load control apparatus, carrier, or load suspended by a cable from the carrier.

Abstract: The present invention relates to methods of inserting and removing tools and/or robots into/from inside subsea oil wells. In this scenario, the present invention provides a system for insertion and removal of a device (30) in a subsea oil well (20), said system comprising (i) a WCT assembly (10) comprising a removable protective cap (40) and (ii) a WCT tool (50) connected to a receptacle (60) comprising within it the device (30), wherein the WCT tool (50) is suitable for being inserted in the place where the protective cap (40) is coupled, wherein at least one of receptacle (60) and WCT tool (50) is able to be opened or closed, releasing the device (30) into the subsea oil well (20) or retaining same inside the receptacle (60). The invention further provides methods of inserting and removing a device (30) into/from a subsea oil well (20).

Abstract: A liner and a method of setting the liner. The liner includes an outer tubular member, a hydraulic actuator on an outer surface of the outer tubular member for hydraulically setting a packer of the liner, and a hydraulic channel for directing fluid through the outer tubular member and into the hydraulic actuator to set the packer. The hydraulic channel has a first port at an inner surface of the outer tubular member and a second port at the outer surface of the outer tubular member at an axial location of the hydraulic actuator. The first port is at a different axial location of the outer tubular member than the second port. A fluid is pumped through the hydraulic channel into the hydraulic actuator to set the packer.

Abstract: A downhole component including a member having an outer surface, a constrained element configured to move relative to the member between a first position and a second position, and an on-demand hydrostatic/hydraulic trigger system including a constraining element operable to selectively release the constrained element. The on-demand hydrostatic/hydraulic trigger system includes a piston cylinder.

Abstract: The present invention provides an improved hydraulically activated clamping device for connecting a wellhead and or Christmas tree positioned on a wellhead to a fracing tree that may comprise a connector body; a mandrel body; two or more clamp segments; two or more actuating bolts; a seal ring to provide sealing engagement between said connector body and said mandrel body; one or more motors driving each of said two or more actuating bolts; and control means to reduce or retard the power to the first of said two or more actuating bolts to release and prevent its further movement until the other of said actuating bolts release also.

Abstract: A pipe is used for control and forced circulation of corrosion-inhibiting fluids in an annulus thereof, the annulus located between an inner pressure barrier and an outer cover of the pipe and containing a number of layers. The pipe includes two layers of tensile armor within the annulus; at least one injection pipe laid helicoidally on the longitudinal extension of the pipe; at least one return pipe laid helicoidally on the longitudinal extension of the pipe; and a ventilation layer within the annulus, the ventilation layer being configured to facilitate the flow of fluids longitudinally through the annulus of the pipe.

Abstract: A fracturing system can include a fracturing manifold coupled to a plurality of fracturing trees. The fracturing manifold may include adjustment joints that enable adjustment of the length of the fracturing manifold. The fracturing manifold can also include pivot joints that allow angular displacement of portions of the fracturing manifold with respect to other portions. The adjustment and pivot joints can accommodate spacing and elevation differences between the fracturing trees.

Abstract: A wellhead assembly of a well system for installation in a wellbore, the wellhead assembly having a longitudinal axis and including a wellhead housing including a central passage defined by an inner surface, a hanger configured to be received within the passage of the wellhead housing and couple to the inner surface of the housing, a tubular string configured to be received in the passage of the wellhead housing, wherein the tubular string includes a passage, a choke coupled to the tubular string and configured to control a fluid flow through the passage of the tubular string, and a wellhead connector configured to releasably couple to an end of the wellhead housing and including a first passage in fluid communication with passage of the tubular string when the wellhead connector is coupled to the wellhead housing.

Abstract: A fluid system includes a pumping flowline, wherein the pumping flowline is in selectable fluid communication with a production flowline, a cylinder including a first port and a second port, a piston slidably disposed in the cylinder, the piston sealing against an inner surface of the cylinder to form a first chamber and a second chamber, wherein the first chamber is in fluid communication with the first port and the second chamber is in fluid communication with the second port, and a first flowline in fluid communication with the first port of the cylinder and the pumping flowline, the first flowline including a first flowline valve, wherein, in response to opening the first flowline valve, the piston is displaced through the cylinder in a first direction to expand a volume of the first chamber of the cylinder.

Abstract: A versatile flying lead (VHL) termination head system comprises an underwater vehicle interface, an interface plate, a termination frame, and an adjuster, disposed proximate the termination frame's connection end, which is configured to provide a configurable declination angle which sets a hang-off angle of a device connected to the interface plate with respect to the underwater vehicle interface. A subsea termination head may be manufactured and assembled by obtaining a predetermined set of standardized structural building blocks that fit together to form a complete termination frame which is as described herein, using the predetermined set of standardized structural building blocks to construct a subsea termination head from the predetermined set of standardized structural building blocks substantially in parallel and connecting the underwater vehicle interface to the frame at a predetermined angle using the adjuster.

Abstract: A fill device for use with a water reservoir tank in an earth reduction system, the fill device comprising a ring having a top surface and a bottom surface, a pipe having a first end connected to the top surface of the ring and a second end for connection to a water supply, a skirt affixed to the bottom surface of the center ring, an opening surrounded by a plate and defining a tortuous path and positioned below the first end of the pipe and the skirt, and a check valve support with a check valve mounted below the opening and the plate.

Abstract: A system includes a housing section positioned within a wellhead area, the housing section also includes a removable wellhead bushing arranged over at least one engagement feature of the housing. The system also includes a Christmas tree including a treehead area, the treehead area includes a removable treehead bushing arranged over at least one engagement feature of the treehead area. The system further includes a tubular extending through both the wellhead bushing and the treehead bushing, wherein the tubular includes an installation and removal tool adapted to remove at least one of the wellhead bushing and the treehead bushing during wellbore operations.

Abstract: Systems and methods are provided for detecting potential failures in logging winch systems to enable efficient maintenance are provided. An example of such a system may include a logging winch system that conveys a downhole tool into a wellbore on a cable and a data processing system. The logging winch system may include sensors that measure observed quantities relating to operation of the logging winch system. The data processing system may determine correlation signatures that relate the observed quantities to the operation of the logging winch system and may identify when one or more of the correlation signatures indicates abnormal operation.

Abstract: A system includes a support structure that is configured to be positioned at a fixed location relative to a component of a mineral extraction system. The system also includes a drive assembly having a drive motor and a valve attachment, and the drive assembly is configured to move about the support structure and to actuate multiple valves of the component of the mineral extraction system.

Abstract: A high capacity universal connector for use in connecting tubular members and a method for sealing the tubular members is provided. First and second tubular members are provided which each have ends that are brought into face-to-face engagement by a connector. A metal sealing element seals against conical surfaces at the ends of the first and second tubular members and enables the entire surface of the end of one tubular member to be bought into engagement with the surface of the end of the other tubular member so as to improve the bending and compression capacity of the assembly comprising the tubular members and the metal sealing element. A metal sealing ring for use in this assembly is also provided, along with a gasket retention assembly.

Abstract: A method of manufacturing a gripping element can include depositing a gripping element material, and thereby gradually building up the gripping element and forming a gripping surface thereon, the gripping surface being configured to grippingly engage a well surface. A gripping system can include at least one extendable gripping element configured to grip a well surface, and the gripping element including a gripping element material enclosing one or more voids in the gripping element. Another gripping system can include at least one extendable gripping element having a gripping surface configured to grip a well surface, and the gripping element including at least two gripping element materials deposited to form the gripping element. Properties or characteristics may gradually change or vary from one gripping element material to another gripping element material in the gripping element. The gripping element materials may each include the same basic matrix material.

Abstract: In accordance with embodiments of the present disclosure, a travel joint includes a tube disposed at one end of the travel joint and a mandrel disposed at an opposite end of the travel joint. The mandrel is partially disposed in a hollow portion of the tube, and the tube and the mandrel are axially slidable relative to each other to extend or compress the travel joint. The travel joint also may include a housing coupled to the tube and disposed around the mandrel and a locking mechanism between the housing and the mandrel disposed in a position to selectively lock the mandrel and the tube in an axial position relative to each other to partially compress the travel joint. In some embodiments, the travel joint may include a fluid brake having a fluid chamber disposed between the mandrel and the tube to dampen axial movement between the mandrel and tube.

Abstract: A rotating control device can include an annular seal, and a latch including a rotary cam and an engagement member which releasably secures the seal and/or a bearing relative to the housing, such that rotation of the cam relative to the housing displaces the member. A method of latching an annular seal relative to an outer housing of a rotating control device can include rotating a rotary cam, thereby linearly displacing an engagement member that releasably secures the seal relative to the housing while permitting rotation of the seal relative to the housing. Another rotating control device can include an outer housing, an annular seal, and a latch including a rotary cam and multiple separate engagement members disposed in the housing, and in which rotation of the cam relative to the housing displaces the members in the housing.

Abstract: A technique facilitates failsafe closure of a valve used in, for example, a subsea test tree. The technique utilizes a valve combined with a cutter oriented to sever well equipment passing through an interior passage of the valve. The valve is operatively coupled with an actuation system having an actuator piston which controls cutting and valve closure. The failsafe valve and the cutter are shifted to an open position by applying pressure in a control fluid chamber to shift the actuator piston. However, the actuator piston, and thus the valve and cutter, are biased toward a closed position via pressure applied in a pressure chamber and a gas precharge chamber. The combined pressure ensures adequate force for shearing of the well equipment and closure of the valve when hydraulic control pressure is lost. In some applications, additional closing force may be selectively provided to the actuator piston.

Abstract: An apparatus including a drilling tool for locating in a wellhead has fluid ports therein. The apparatus further includes a collar which is mateable with the drilling tool, such that the fluid ports in the drilling tool are blocked by the collar when the collar is mated with the drilling tool. The drilling tool can be a bit runnable drill string tool. The apparatus may also include a bit runnable wear bushing. The apparatus can advantageously be used to perform a method of testing a blowout preventer (BOP) on a subsea wellhead.

Abstract: This disclosure includes manifolds, subsea valve modules, and related methods. Some manifolds and/or subsea valve modules include one or more inlets, each configured to receive hydraulic fluid from a fluid source, one or more outlets, each in selective fluid communication with at least one of the inlets, and one or more subsea valve assemblies, each configured to selectively control hydraulic fluid communication from at least one of the inlets to at least one of the outlets, where at least one of the outlets is configured to be in fluid communication with an actuation port of the hydraulically actuated device.

Abstract: Systems and methods contain fluids discharged from a subsea well or at the surface by capping the well blowout with a pre-positioned capping device. The capping device includes at least one blind shear ram and is separate from a blowout preventer. The blowout preventer may operate to control well events up to a certain pressure, above which the capping device is employed since the capping device has a higher pressure rating than the blowout preventer.

Abstract: A tool insert is removable from a fluid passage in a drill tool body by pressurizing fluid in a removal volume defined between the tool insert and the drill tool body, to by exerting a net fluid pressure bias on the tool insert in a removal direction along the fluid passage. The tool insert can be an annulus sealing assembly mounted in a rotating control device (RCD), with the removal volume being defined radially between a body of the RCD and a bearing assembly of the annulus sealing assembly. A common hydraulic liquid may be used for lubricating the bearing assembly and for hydraulically actuated removal of the annulus sealing assembly.

Abstract: A method for wireline intervention in a subsea well from a floating vessel.

Abstract: A system and method to monitor a cable using noise-domain reflectometry. A receiver is configured to receive a signal and a reflection of the signal transmitted through the cable. The reflection of the signal can be indicative of a fault condition relating to the integrity of the cable. A processor is in communication with the receiver and configured to analyze the signal and the reflection using noise-domain reflectometry and determine the fault condition of the cable.

Abstract: A subsea blowout preventer (BOP) hydraulic control system to reduce water hammer that includes a hydraulic fluid source. The system further includes a fluid supply conduit in fluid communication with the hydraulic fluid source at an upstream end, and with a BOP function at a downstream end. The system further includes a supply valve in the fluid supply conduit that controls the amount of fluid flow through the fluid supply conduit to the BOP function, the supply valve having an open state and a closed state. The supply valve has a choke that controls movement of the supply valve between the open state and the closed state and vice versa so that such movement is retarded when the supply valve state approaches the fully open or the fully closed state to reduce pressure spikes in the fluid of the fluid supply conduit.

Abstract: A hydraulically-powered subsea tool system has a tool (26) and a tool power unit (12). The tool (26) communicates with a first connector element (30) on a hydraulic drive circuit (82). The tool power unit (12) has a hydraulic supply circuit (88) communicating with a second connector element (20). The connector elements are wet-mated with each other to connect the circuits for powering the tool. The circuits are pressure-compensated by respective compensators (136,90). When the circuits are connected, a valve (140) is operable to transfer pressure compensation of one of the circuits from the compensator (136) of that circuit to the compensator (90) of the other circuit. The valve (140) suitably transfers pressure compensation of the drive circuit from a drive circuit compensator to a supply circuit compensator.

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: Latch position indicator systems remotely determine whether a latch assembly is latched or unlatched. The latch assembly may be a single latch assembly or a dual latch assembly. An oilfield device may be positioned with the latch assembly. Non-contact (position), contact (on/off and/or position) and hydraulic (flowmeter), both direct and indirect, embodiments include fluid measurement systems, an electrical switch system, a mechanical valve system, and proximity sensor systems.

Abstract: A production string for use in a wellbore is disclosed that in a non-limiting embodiment includes a lower section that includes a first tubular having a first connection device at a top end thereof, and an upper section that includes a second tubular that sealingly slides against the first tubular, a second connection device associated with the second tubular configured to engage with the first connection device, and an expansion joint above the second tubular.

Abstract: A lockdown tool for locking down a high pressure wellhead with a conductor wellhead housing includes a housing that includes a conductor wellhead housing facing surface designed to come in contact with a conductor wellhead housing positioned at or near a seafloor. The housing further includes a lockdown mechanism facing surface designed to come in contact with a lockdown mechanism that is between the conductor wellhead housing and a high pressure wellhead seated in the conductor wellhead housing. The housing also includes a wellhead facing surface having a profile that matches a profile of the high pressure wellhead formed on an outer surface of the high pressure wellhead. The lockdown tool further includes a piston positioned in a cavity of the housing and a hydraulic pressure port extending through a wall of the housing for applying hydraulic pressure by an external hydraulic pressure source into the cavity of the housing.

Abstract: A rotating locking device includes a locking arm, including a throughbore, coupled to a housing and axially rotatable relative to the housing. The rotating locking device also includes a plunger including a biasing profile disposed within the throughbore and a locking head coupled to a distal end of the locking arm, the locking head including a recess to at least partially receive the distal end of the locking arm. The rotating locking device further comprises a load pin that couples the locking head to the distal end of the locking arm and is configured to resist separation of the locking head and the locking arm when in a securing position. Axial translation of the plunger causes the biasing profile to engage the load pin and cause the load pin to transition to a breakaway position.

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 subsea connection system for connecting to a hub of a subsea structure has an outer sleeve, a collet having a plurality of collet segments in which the collet segments are movable between a lock position and an unlock position, a connection hub positioned in the interior of the hollow sleeve such that the collet extends around the connection hub, and a translation mechanism cooperative with the outer sleeve so as to move the outer sleeve between a forward position and a rearward position. The connection hub is suitable for abutting the hub of the subsea structure when the plurality of collet segments are in the lock position. The plurality of collet segments are in the unlock position when the outer sleeve is in the forward position. The plurality of collet segments are in the lock position when the outer sleeve is in the rearward position.

Abstract: The system for inserting a tubular member from a surface into a subsea well includes a riserless vessel, a surface injector being mounted on the vessel at the surface and delivering tubular member, such as coiled tubing, to the subsea well from the surface, a subsea snubbing jack releasably engaged to the tubular member, a subsea hydraulic power unit connected to the snubbing jack, and a device to maintain tension of the tubular member between the surface injector and the snubbing jack. The dynamic control of the subsea snubbing jack provides either active additional force for pipe light and pipe heavy conditions or passive support of the tubular member for equilibrium conditions without a riser. The method is responsive to transitions between well conditions. A riserless system without a subsea injector can more efficiently and reliably insert coiled tubing under various well conditions and during changes in the well conditions.

Abstract: A subsea drilling method and system controls drilling fluid pressure in the borehole of a subsea well, and separates gas from the drilling fluid. Drilling fluid is pumped into the borehole through a drill string and returned through an annulus between the drill string and the well bore and between the drill string and a riser. Drilling fluid pressure is controlled by draining fluid out of the riser or a BOP at a level between the seabed and the surface in order to adjust the hydrostatic head of drilling fluid in the riser. The drained drilling fluid and gas is separated in a subsea separator, where the gas is vented to the surface through a vent line, and the fluid is pumped to the surface via a subsea pump. A closing device and a choke line and valve can release pressure after a gas kick in the well.

Abstract: The invention relates to a device (1) for removing a material (4) welling out from the seabed (2), said device having an outer casing (6) and a tubular guide device (10) that has a longitudinal direction, a later surface and a plurality of segments (12) that can be moved into an open position and a closed position. The lateral surface is closed in the closed position of the segments (12), and therefore the guide device (10) allows a flow of the material (4) only along the longitudinal direction, and the lateral surface has at least one opening in the opening position of the segments (12).

Abstract: This disclosure includes manifolds, subsea valve modules, and related methods. Some manifolds and/or subsea valve modules include one or more inlets, each configured to receive hydraulic fluid from a fluid source, one or more outlets, each in selective fluid communication with at least one of the inlets, and one or more subsea valve assemblies, each configured to selectively control hydraulic fluid communication from at least one of the inlets to at least one of the outlets, where at least one of the outlets is configured to be in fluid communication with an actuation port of the hydraulically actuated device.

Abstract: The invention in one of its aspects provides a connection apparatus for a subsea hydraulic circuit and method of use in a sampling application. The apparatus comprises a longitudinal body configured to be removably docked with a subsea hydraulic circuit receptacle. The body comprises a plurality of radial ports axially displaced along the body, and an axial bore accommodating a spool having at least one fluid barrier. The spool and fluid barrier are actuable to be axially moved in the bore to control axial flow paths along the bore between the plurality of radial ports. The apparatus may be configured as a sampling hot stab in an application to sampling a production fluid from a subsea hydrocarbon production system.

Abstract: A casing hanger assembly is provided. In one embodiment, a system includes a casing hanger and a landing shoulder for receiving the casing hanger and supporting the casing hanger within a wellhead. The casing hanger and the landing shoulder have complementary features that cooperate to inhibit rotation of the casing hanger with respect to the landing shoulder. Additional systems, devices, and methods are also disclosed.

Abstract: A floating offshore facility for offshore hydrocarbon production, comprising an upper deck, a lower deck, a well bay comprising a plurality of drilling slots and a plurality of production slots surrounding said drilling slots, a cart supporting a drilling riser and being movable together with said drilling riser inside the opening of the plurality of the drilling slots, and a drilling rig movable above the well bay to drill the well through the drilling riser.

Abstract: In various embodiments, fluid conduits such as high pressure hoses deployed in-between two sea-fairing vessels may be released during an emergency by using a rapid release emergency disconnect system as described herein, where the rapid release emergency disconnect system may engage with a hanger such as an industry standard frac hanger and be used in-line with fluid conduits such as high-pressure lines. Various skid embodiments are described which can be configured to interface with one or more of the described rapid release emergency disconnect systems.

Abstract: A diverter system having stabbing dogs is provided. In one embodiment, such a system includes a diverter, a housing, and a plurality of stabbing dogs coupled to the housing. The stabbing dogs are positioned to enable locking elements of the stabbing dogs to be extended into recesses in the diverter to secure the diverter within the housing. At least one of the recesses in the diverter is connected to a fluid conduit within the diverter, and at least one stabbing dog includes a fluid passage that enables fluid to be routed into the fluid conduit within the diverter through the at least one stabbing dog. Additional systems, devices, and methods are also disclosed.

Abstract: A tool string having a pressure dependent mandrel and actuator assembly can operate at the annulus pressure within a wellbore to lock the mandrel actuator assembly and prevent further motion of the mandrel within the tool string as the tool string is moved upward or downward in the wellbore. The tool string can further include a valve connected to the actuator assembly, where the valve can be in an open configuration within the wellbore due to the annulus pressure and related motion of the mandrel, and then be locked in an open configuration regardless of the annulus pressure as the tool string is moved upward or downward in the wellbore.

Abstract: The present invention provides monitoring means for monitoring the space and volume within a lower annulus. In particular, the monitoring means monitors the space and volume within the lower annulus 52 located between the inner surface of the 22 intermediate casing string 22 and the outer surface of the inner casing string 32. Furthermore, the monitoring means provides the capability to retrieve and/or introduce fluid(s) into the annular space 52. The monitoring means provides a port, specifically a passageway 100, which extends upwardly from the annular space 52 to an outlet located above the hanger 36 for the intermediate casing string 22. The passageway 100 is provided in a sleeve 102. The monitoring means includes a sensor located above the hanger 36 which means that the fluid in the annular space 52 can be monitored without the need for penetrating a casing in the wellhead.