Abstract: A subsea production system on a sea floor has a pump flowline jumper with a straight intermediate portion and two end portions. Each end portion has a connector for ROV assisted connection between production units. A submersible pump assembly is mounted in the straight portion of the flowline jumper and is lowered along with the flowline jumper into engagement with the production receptacles. The pump assembly boosts pressure of fluid flowing from one of the receptacles to the other. A gas separator may be mounted in the same flowline jumper or in a separate flowline jumper.

Abstract: The present invention concerns a pressure containment device for use in a lubricator. The device includes a housing having a first main bore extending throughout its length a number of transversal bores intersecting the main bore. Pairs of opposing rams are located in the transversal bores to grip and seal around a cable in the main bore.

Abstract: A system for assuring subsea hydrocarbon production flow in pipelines by chilling the hydrocarbon production flow in a heat exchanger and causing solids to form, periodically removing deposits and placing them in a slurry utilizing a closed loop pig launching and receiving systems.

Abstract: A system and method to allow backup or alternate fluid flow routes around malfunctioning components using removable, modular component sets. In one exemplary embodiment, an ROV establishes a backup hydraulic flow to a BOP function by attaching one end of a hose to a modular valve block and the other end to an intervention shuttle valve, thus circumventing and isolating malfunctioning components. A compound intervention shuttle valve is provided that comprises first and second primary inlets, first and second secondary inlets, and an outlet. A modular valve block is provided that comprises a directional control valve, a pilot valve, a manifold pressure regulator, a pilot pressure regulator, stab type hydraulic connections and an electrical wet-make connection.

Abstract: A connector for severed pipes in a wellbore has an elongated tubular mandrel, a sealing pack-off ring mounted on the mandrel, an activator ring for pressing against the pack-off ring and causing the pack-off ring to seal an interior of a casing above a shut-off valve. A grapple member is slidable mounted on the mandrel above the activator ring; the grapple member has an enlarged diameter plate, which rests on an upper edge of a severed casing. A production pipe, control lines and production casing can be lowered through the large opening in the mandrel and re-establish connection with the severed casing and production pipes.

Abstract: A connection system for connecting flow interface equipment to a subsea manifold is disclosed. The connection system relates particularly to a connection apparatus adapted to land a conduit means on a subsea manifold in a first stage of the connection and to connect a conduit means of the connection apparatus to a choke body of the manifold in a second stage of the connection.

Abstract: A system for assuring subsea hydrocarbon production flow in pipelines by chilling the hydrocarbon production flow in a heat exchanger and causing solids to form, periodically removing deposits and placing them in a slurry utilizing a closed loop pig launching and receiving systems.

Abstract: An inflow control device is disclosed for use in controlling the flow of fluid into a production tubing in a subterranean wellbore. The device is especially adapted for use with sand screen apparatus, but is modular in that it is manufactured separately from the sand screen apparatus. An inflow control device according to the present invention contains an orifice having an opening which is adjustable in size and which is disposed in the device to permit communication of fluid from one end of the body to the other. An inflow control device according to the present invention may be utilized with multiple sand screen assemblies.

Abstract: A wellhead assembly with high pressure interface is provided. The wellhead assembly includes a tubing spool that connects the wellhead to a BOP and a casing hanger that is landed in the wellhead and connected thereto. The wellhead assembly further includes a gasket that is disposed between opposing ends of the tubing spool and casing hanger. A connector engages the wellhead and tubing spool forcing the opposing ends of the tubing spool and casing hanger together, which thereby applies a compressive load to the gasket, which in turn forms a fluid tight seal therebetween.

Abstract: An installation apparatus comprises a coupling member, a guide member, and a securing member operable to secure a termination system to the coupling member.

Abstract: During the completion of a subsea horizontal tree, a tubing hanger and internal tree cap are run together with the same running tool and running string. The running tool has a linking assembly that connects the tree cap to the tubing hanger during running, retrieval, or workover, so that the tree cap supports the weight of the tubing hanger and string of tubing. The linking assembly can be retrieved with the running tool or retrieved on wireline through the running string.

Abstract: A spool piece termination structure to be mounted to a spool piece so as to support a spool piece hub during the connection of the spool piece hub to a corresponding pipeline hub. The termination structure includes a clamping device for clamping together the spool piece hub and pipeline hub, and a base frame openly shaped downwards so as to allow the termination structure to receive a pipeline end section provided with the pipeline hub by lowering the termination structure downwards onto the pipeline end section. A connection arrangement includes such a spool piece termination structure and a method for subsea connection of a pipeline to a spool piece.

Abstract: A retrievable tree cap for use on a subsea tree having a concentric bore. The tree cap may be installed and retrieved using a remotely operated vehicle. Hydraulic pressure may be used to lock the tree cap onto the subsea tree and to set the tree cap seals. The tree cap is locked onto the subsea tree before setting the seals within the concentric bore. The tree cap includes a locking means that may engage a profile within the subsea tree regardless of the radial orientation of the tree cap. The tree cap may be used to hydraulically isolate an annulus bore from the production bore of the subsea tree. The tree cap may provide for the injection of a corrosion inhibitor within a cavity of the tree cap and may also provide for the removal of water trapped between the tree cap and the subsea tree.

Abstract: A subsea tubing hanger assembly is disclosed which comprises a tubing hanger (12) having a plurality of conduits (14). A pup joint (16) is connected to the hanger (12) and a shroud (20) surrounds the pup joint (16). A plurality of extension capillary tubings (30) are connected to respective conduits (14) and extend between the shroud (20) and pup joint (16) to a position exterior of the shroud (20). The tubings (30) are provided with a connector (40) at their ends to facilitate connection of the tubings (30) to capillary tubings (50) of a well.

Abstract: A coupling switches control fluid from a tubing hanger to a downhole completion of a subsea well. The coupling, located between a tubing hanging running tool and a downhole completion, includes a coupling body and a tubing hanger. A hydraulic poppet switches control fluid flow from a first and second flow path. The hydraulic poppet includes an isolation sleeve for opening and closing a first and second inlet port. At least two perimeter seals provide fluid isolation for the first flow path. A retainer seal seals the coupling body against the second inlet port. A retaining sleeve holds the coupling body against the tubing hanger. A first and second circumferential seal are located on opposite ends between the coupling body and tubing hanger. The hydraulic poppet is adapted to move perimeter seals and the retainer seal to open and close the first and second inlet ports.

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: The present invention contemplates a system comprising a pumping module coupled to an intermediate flow inlet (IFI) wherein said IFI is coupled to a base structure disposed on the flow line that routes production from one or more oil wells, allowing for the quick and easy installation or recovery of a subsea pumping module by cable from an inexpensive vessel. The present invention also allows for the hydraulic isolation of the subsea pumping module by means of on-off valves on the IFI whereby the pumping module can be easily installed or removed without causing underwater oil spills. Sealing of the connection is of the metal-metal type. It is also possible to pass a pig through the present system for clearing the flow lines.

Abstract: A subsea production system that is adapted to be coupled to a subsea wellhead and includes a tubing hanger adapted to be positioned in the wellhead. The tubing hanger has a flow opening extending therethrough and has at least one eccentrically located opening extending through the tubing hanger. In some cases, the tubing hanger is adapted to be not precisely oriented with respect to a fixed reference point when positioned in the wellhead. The system also includes a production tree adapted to be operatively coupled to the tubing hanger, wherein the production tree is oriented relative to the tubing hanger. In other embodiments, the tubing hanger is riot oriented with respect to the wellhead or other fixed reference point.

Abstract: A subsea wellhead assembly has a tubing hanger landed in a wellhead housing. A spool lands on the wellhead housing and has a bore with a laterally extending production flow outlet. A tree cap having an axially extending flow passage and a laterally extending production flow outlet lands within the bore of the spool. Upper and lower seals on the tree cap seal between the tree cap and the bore of the spool above and below the production flow outlet of the spool. An isolation tube on a lower end of the tree cap sealingly engages the production flow passage of the tubing hanger. The tree cap may be ran with the spool as an assembly and retrieved from the spool for workover operations.

Abstract: A subsea wellhead including a wellhead housing having a bore with a grooved profile. An upper portion of the bore has a greater diameter than a lower portion of the bore, and a central conical portion of the bore joins the upper portion of the bore and the lower portion of the bore. A connector body lands in the wellhead housing. The connector body has a conical section that interfaces with the central conical portion of the bore. A seal is secured between the central conical portion of the bore of the wellhead housing and the conical section of the connector body at the interface of the wellhead housing and the connector body. A locking element is carried on the connector body. The locking element has an outer side that engages the grooved profile of the wellhead housing.

Abstract: A system for subsea transfer of intervention fluids to a subsea intervention apparatus, the system, in certain aspects, including a structure and a frame pivotably mounted thereto, a plurality of frame fluid conduits on the frame for conducting fluid from a connector to conduit apparatus in fluid communication with the subsea intervention apparatus, a connector at an end of the frame for releasably holding an end of a fluid stab assembly, and having a connector fluid conduits in communication with the frame fluid conduits, the connector fluid conduits located for receiving fluid from a fluid stab assembly releasably held by the connector.

Abstract: A well production and multi-purpose intervention access hub for flowing fluids from multiple wells to a host facility through a flowline. The hub comprises a production header module and a flowline header module configured for fluid communication with the flowline. The production header module and the flowline header module connect to form a hub bore that is in fluid communication with the flowline and extends through the utility interface. A utility module may connect with the hub for fluid communication and mechanical tool intervention access with the hub bore. The hub comprises valves for isolating the fluid communication between a well the hub bore from the fluid communication between another well and the hub bore. The valves also allow fluid communication between an isolated well and the utility module upon connection of the utility module to the hub.

Abstract: An inner tubular member of a subsea wellhead assembly carries a locking member that moves between a locked and unlocked positions lands within an outer tubular member having a grooved profile in its bore. The inner tubular member joins to a portion of the conductor casing extending from a low pressure wellhead housing above the mudline of the seafloor. In the locked position, the locking member engages the grooved profile on the outer tubular member to connect the outer tubular member and inner tubular member. The inner tubular member also carries a hydraulically actuated, axially moveable locking sleeve that slidingly engages the locking member to move the locking member between the locked and unlocked positions. An ROV supplies hydraulic fluid through an ROV port to actuate the locking sleeve.

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.

Abstract: A subsea production tree has an external annular profile formed on an upper portion of the tree. A vertical passage extending from a lower end of the tree to an upper end of the tree for communicating with a string of tubing extending into the well. A lateral passage in the tree extending from the vertical passage. A flow path in fluid communication with the lateral passage extends laterally from the tree, the flow path having an upward facing receptacle. An adapter lands on the upper portion of the tree and connects to the profile, the adapter having a passage that registers with the vertical passage of the tree while the adapter lands on the tree. A flow interface device mounts to and lands with the adapter, the flow interface device having an inlet conduit and an outlet conduit, one of the conduits being connected to the passage in the adapter, the other of the conduits stabbing into sealing engagement with the receptacle as the adapter lands on the tree.

Abstract: A deflectable in-line swivel that permits axial deflection of a tubular string is presented. The in-line swivel is preferably constructed as a ball and socket design whereby the ball of a swivel mandrel is permitted to articulate within a socket of a retainer sub. The system preferably includes a thrust bearing to allow the tensile loads to be carried across the swivel.

Abstract: A well completion system includes a completion device defining a bore therein attached to a wellhead and a tool, disposed within the bore, comprising an operational element and a control receptacle in communication with the operational element. The system further includes a horizontal penetrator assembly disposed external to the completion device and comprising at least one horizontal penetrator capable of being extended into and retracted from the bore to engage the control receptacle such that the horizontal penetrator is in communication with the operational element of the tool. A method includes inserting a tool into a bore of a completion device, engaging a horizontal penetrator with a control receptacle of the tool, and operating an element of the tool via the horizontal penetrator.

Abstract: A lockdown device for securing a tubing hanger to a production member comprises a lockdown member which is mounted on the production member and is movable into and out of engagement with a corresponding locking profile on the tubing hanger, and an actuating mechanism for moving the lockdown member into and out of engagement with the locking profile.

Abstract: A system, method, and software for optimizing the commingling of well fluids from a plurality of producing subsea wells. The mixing temperature and water content in each header of a collection manifold are calculated for each subsea well and header combinations, responsive to data from sensors at the collection manifold. Combinations with conditions outside operational limits are then discarded. Remaining combinations are ranked based on predetermined optimization criteria. The ranked combinations are provided for the operator for optimizing flow properties and well fluid production. The calculations can restart with new, real-time sensed values from the subsea collection manifold.

Abstract: The annulus pressure is controlled by displacing incompressible fluid with compressible fluid in the annulus. The displaced fluid is filtered to avoid clogging small lines. The presence of compressible fluid minimizes the thermal effect of warm fluid in the production tubing on annulus pressure. As a result, thinner wall casing can be used, for considerable savings in material and installation cost.

Abstract: A completion system comprises a christmas tree (10) mounted on a wellhead housing (11), a tubing hanger (12) landed in the tree or wellhead housing, the wellhead housing (11) being mounted on a casing string (100) and a tubing string (14) being suspended from the tubing hanger within the casing string; wherein, in use, the annulus defined between the tubing (14) and the casing (100) serves as a production bore. A second tubing string (98) is expanded into sealing engagement with the casing string (100) over at least a portion of their lengths. The annulus normally used to provide well service functions is thus eliminated. Well servicing is instead provided via the tubing string (14), which may be coiled tubing.

Abstract: A method and apparatus for logging, controlling, or monitoring a subsea well or group of wells through a path not within production tubing. Preferred embodiments allow logging tools, wire rope, optic fibers, electrical cables, monitoring and measuring instruments and other items known to those skilled in the art of oil and gas production to be disposed into the well without interfering with the flow path through the production string. A further preferred embodiment includes the mooring or tethering of an instrument pod over the subsea well. The instrument pod is designed to provide on-board data storage, data processing, data receiving, and data transmission equipment, such that data from the well can be transmitted back to a receiving network where the data may be stored and processed into useful information for reservoir operators.

Abstract: A latchdown mechanism 11 latches a control pod 10 to a lower mounting plate 14 of a subsea tree. A receptacle housing 12 secured to subsea tree receives the control pod therein and has an interior latching surface 13 at an upper end of the receptacle housing. A latchdown actuator 15 is supported on the control pod, and moves a plurality of gripping arms 22 for engagement and disengagement with the latching surface to selectively connect and disconnect the control pod 12 to the structure in response to the latchdown actuator.

Abstract: A jumper for transferring fluids from an umbilical to a subsea tree assembly has a plurality of steel tubes. The steel tubes are bent so that the jumper is in a serpentine or w-shape while in a natural state. The steel allows resists damage to the jumper from the fluids and chemicals being transferred to the tree assembly. The w-shape of the jumper allows the jumper to be stretched or contracted so that the distance between the connectors on each end of the jumper can vary. The contracted width jumper is attached to a terminal plate located on the tree assembly as it is landed on a subsea wellhead. An ROV disconnects the jumper and connects the jumper to receptors on the tree assembly and the umbilical, while stretching the jumper to the necessary length to reach the receptors. The jumper can be disconnected from the tree assembly when maintenance is necessary without moving the umbilical.

Abstract: A subsea communications module includes an interface to communicate with a surface facility over a communications link using a packet-based protocol. The communications link can be implemented with a fiber optic line, wire-based line, and/or other types of communications lines.

Abstract: To install a modular seabed processing system (1) on a seabed, a monopile foundation (3) is first lowered down and driven into the seabed. A docking unit (4) is lowered towards the installed foundation (3) so that a mating clamp system (6) mounted on the docking unit is aligned with a spigot (5) on the foundation. The clamp system then clamps the spigot to fix the docking unit onto the foundation. Flowlines (2) and an electrical power connector plug (18) are connected to the docking unit. A first retrievable substantially autonomous module (8) is lowered and connected to the docking unit (4) by a multi-bored connector (10, 11) and the plug (18) on the docking unit is engaged by a corresponding socket (17) on the module. Isolation valves (14, 16) in the docking unit and module are opened so that the module (8) is able to act on fluid received from the flowlines (2) via the multi-bored connector (10, 11).

Abstract: A method and apparatus for inserting or removing a string of tubulars from a subsea borehole. The apparatus includes a first, lower, gripping mechanism locatable subsea in the vicinity of the subsea borehole. The first gripping mechanism is capable of gripping a portion of the string of tubulars. The apparatus further includes a second, upper, gripping mechanism locatable subsea in the vicinity of the subsea borehole, the second gripping mechanism being capable of-gripping a portion of the sting of tubulars. The first and second gripping mechanisms are moveable with respect to one another. The apparatus further includes a movement mechanism which, when actuated, moves one of the first and second gripping mechanisms with respect to the other of the first and second gripping mechanisms, such that the string of tubulars is inserted into or removed from the subsea borehole.

Abstract: The present invention comprises a system and method to measure positioning with respect to deploying a subsea load, the system comprising a subsea metering head having a position sensor; a controllable winch operatively connected to the winch flexible cable; and a controller operatively in communication with the controllable winch and the position sensor. The controller is capable of controlling the controllable winch in response to a received position feedback sensor signal. 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 tool lands a flowline connector on a base and soft land the connector to a mandrel. After the tool lands on the base, the tool locks to the base and then pushes the connector the mandrel until it abuts locks to the member. The tool has at least one ring assembly with a number of dogs per ring assembly. Each dog moves in unison with a follower relative to a cam ring in a slot. The movement along the slot moves the dogs radially and circumferentially relative to the cam ring. An actuator moves a follower ring that slides relative to the cam ring which moves the follower. Each dog remains in contact with the cam ring after moving radially inward because of protuberances on each dog that slide from a recess as the dog moves circumferentially and radially inward.

Abstract: Methods and devices are described for efficiently installing sea-borne wellhead components and tying back sub-sea wellhead components with them. In specific aspects, a single running and setting tool is used to land a tubing head housing upon the stem of a floating platform and tension and pressure testing casing string risers extending between a subsea wellhead and a floating vessel.

Abstract: A tool lands a flowline connector on a base and soft land the connector to a mandrel. After the tool lands on the base, the tool locks to the base and then pushes the connector the mandrel until it abuts locks to the member. The tool has at least one ring assembly with a number of dogs per ring assembly. Each dog moves in unison with a follower relative to a cam ring in a slot. The movement along the slot moves the dogs radially and circumferentially relative to the cam ring. An actuator moves a follower ring that slides relative to the cam ring which moves the follower. Each dog remains in contact with the cam ring after moving radially inward because of protuberances on each dog that slide from a recess as the dog moves circumferentially and radially inward.

Abstract: A completion system for a subsea well includes a tree having a generally cylindrical wall forming an internal bore therethrough and a production port extending laterally through the wall in communication with the internal bore. The internal wall has a landing arranged to support a tubing hanger having seals for sealing the production port between the tubing hanger and the internal wall, the production port being arranged to communicate with a lateral production fluid outlet port in the tubing hanger. A workover port extends laterally from an opening in the internal wall below the production port and the production port seals and a tubing annulus seal sealing the workover port from the tubing annulus. A tubing annulus port extends from an opening in the tree below the tubing annulus seal and the tubing annulus port and workover port being arranged to be in fluid communication externally of the internal bore.

Abstract: A wellhead system for petroleum producing wells comprises a “stack-down” casing hanger configuration. In this stack-down system, the hanger for each successively smaller diameter casing string is landed or “nested” within the hanger for the next larger casing string. This approach allows the pack-off for each casing hanger to be retrieved independently, thus allowing fluid communication to be established with any of the casing annuli after all of the casing strings and hangers have been installed. Thus the pressure in each annulus may be monitored while the well is in production mode.

Abstract: The subsea intervention system (SIM) includes a BOP module 10 and CT module 20. A tool positioning system 76 is used for positioning a selected subsea tool 22 stored within a rack 18 with a tool axis in line with the BOP axis, while a marinized coiled string injector 80 is moved by positioning system 81 to an inactive position. Power to the subsea electric motors 162 is supplied by an electrical line umbilical extending from the surface for powering the pumps 164, with the hydraulic system controlled by power control unit 198. The injector 80 preferably includes a pressure compensator roller bearing 220 and a pressure compensated drive system case 254.

Abstract: A device for intervention of a subsea oil and/or gas well by means of a tool (8) suspended by a cable (9), fed from or withdrawn to a vessel (1) and driven by a drive mechanism (12) located on the vessel. The device comprises a lubricator (5) having a tool housing for the insertion of the tool into the well, and a stuffing box (40) sealing around the cable after the tool is inserted into the well. According to the invention an injector which drives the cable in the well is located on the lubricator, and is controllable independently of the drive mechanism for the cable located on the vessel. The drive mechanism and the injector may be synchronized in a manner, among others, providing that the cable is hanging in a predetermined arc during the intervention, whereby the vessel may be moved from the well. Moreover, the invention relates to a method and a cable used together with the device.

Abstract: A subsea wellhead assembly has the capabilities of communicating from a tree assembly mounted on an inner wellhead housing to a casing annulus. A passage in the wellhead assembly extends within the bore of the wellhead housing from the casing annulus to the tree assembly. A portion of the passage is located within a casing hanger. The passage is opened and closed by a valve. The valve does not open the passage until the tree assembly is connected to the wellhead housing and a tubing hanger orientation sleeve lands in the wellhead assembly. The tubing hanger orientation sleeve actuates the valve when it lands to open the passage. When the passage is opened, the casing annulus is in fluid communication with the interior surface of the wellhead housing, which is in communication with the tree assembly.

Abstract: The disclosure defined by this invention is a method and assembly for conducting wireline operations in a deep, subsea location, which includes providing a rig on the surface of a body of water, having a riser extending from the rig floor to the floor of the deep body of water; an annular preventer positioned on the end of the riser on the sea floor; a plurality of blowout preventers positioned below the riser to prevent a blowout into the riser; and, a wireline subsea blowout preventer control head assembly. A lubricator is lowered into the riser, with the control head assembly attached thereto, and wherein the wireline tool is disposed within the control head assembly. The lubricator is position within the annular preventer. Wireline operations may then be conducted. If a blowout occurs during wireline operations, any pressure would be prevented from entering the riser, and would be contained by the control head assembly. Thereafter, the assembly and lubricator is rigged down.

Abstract: A subsea wellhead assembly has a tree that connects internally to the bore of wellhead housing. The tree has a lower end that has a lock member that is moved radially outward into engagement with a profile in the bore of the wellhead housing. The tree is a monobore, having a production passage but no tubing annulus passage extending through it. The tubing hanger has a tubing annulus passage and a production passage. A valve is mounted in the tubing hanger for controlling flow through the tubing annulus passage.

Abstract: Modern subsea wells utilise an electrohydraulic control system which switches hydraulic power to various control components in dependence on received control signals. The mounting and interconnection of the control components tends to be complicated. The invention provides a manifold comprising a first manifold body 6 having a number of openings and flow passageways therethrough. The manifold body is selectively configurable by selecting predetermined openings in order to achieve a desired configuration of flow passageways between control devices 1, 2, 13, 4. The manifold simplifies the interconnection of the hydraulic components and provides greater flexibility in the location of the components. The manifold body also provides a platform for mounting the control devices.