Abstract: A method of monitoring a subsea pipeline system connecting one or more wells to a floating production system, wherein the pipeline system is at least partially flexible, the method comprises installing a continuous optical fibre distributed sensor as part of the pipeline system, the sensor capable of providing a distributed measurement of temperature, vibration, pressure or strain, or any combination thereof; using the sensor to obtain a distributed measurement of temperature, vibration, pressure and/or strain along at least part of the pipeline system indexed to a length thereof; and using the distributed measurement to predict the actual condition of the fluid, the pipeline system and/or the adjacent sea water using a model.

Abstract: A technique enables a simplified approach for providing subsea hydraulic control. A subsea installation comprises one or more devices that are actuated hydraulically. A simple signal carrier, such as a wireline logging cable, can be routed down to the subsea installation. However, hydraulic fluid for controlling the one or more hydraulic devices in the subsea installation is delivered via an open water umbilical that extends to the subsea installation from a separate workover control system.

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 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 well is drilled and casing installed utilizing a casing drilling technique. A bottom hole assembly having a drill bit and a fluid diverter is secured to a string of drill pipe and installed within a casing string. Drilling fluid is pumped down the drill pipe string to cause the drill bit to rotate and drill the well while the fluid diverter is in a drilling mode position. At the total depth for the casing string, the operator moves the fluid diverter to a cementing position and pumps cement down the drill pipe and up the casing string annulus. After cementing, the operator moves the fluid diverter to a packer set position and again pumps drilling fluid down the drill string to set the packer.

Abstract: This invention relates to equipment and a subsea pumping system using a subsea module installed on the sea bed, preferably away from a production well and intended to pump hydrocarbons having a high associated gas fraction produced by one or more subsea production wells to the surface. One object of this invention is achieved by means of the design of a pumping module (PM) which is linked to pumping equipment already present in a production well and which basically comprises: an inlet pipe (2), separator equipment (3), a first pump (4) and a second pump (8). In the subsea pumping system for the production of hydrocarbons with a high gas fraction, the other object of this invention, when oil is pumped from the production well (P) the well pump (13) increases the energy of the fluid in the form of pressure and transmits this increase in energy in the form of an increase in suction pressure in the second pump (8) of the subsea module (PM).

Abstract: A subsea and modular tanker-based hydrocarbon production system comprising a plurality of interlinked individual tank units which is wholly submersible, is wholly detachable from, and wholly re-attachable to, its associated subsea wellhead infrastructure. Modularity of the interlinked tank unit system allows for the processing, measurement, and storage of hydrocarbons from a wide variety of offshore hazard and water-depth related conditions and situations. In addition to being both detachable and re-attachable, the modularity of the system provides for a number of unit systems to be conjoined at surface and towed to market.

Abstract: A seafloor pump assembly is installed within a caisson that has an upper end for receiving a flow of fluid containing gas and liquid. The pump assembly is enclosed within a shroud that has an upper end that seals around the pump assembly and a lower end that is below the motor and is open. An eduction tube has an upper end above the shroud within the upper portion of the caisson and a lower end in fluid communication with an interior portion of the shroud. The eduction tube causes gas that separates from the liquid and collects in the upper portion of the caisson to be drawn into the pump and mixed with the liquid as the liquid is being pumped.

Abstract: A system for sampling production well production fluids from a manifold interface panel on a subsea production manifold. In some embodiments, the system includes a remotely operated vehicle, a skid coupled to the remotely operated vehicle, a sample tank supported on the skid, and a fluid transfer pump operable to convey production fluid from at least one of the production wells through the manifold interface panel into the sample tank.

Abstract: The invention concerns a tool for a tool for connecting an end of a first pipeline (22) to an end of a second pipeline (3) supported by a subsea structure (1) and being provided by at least two guide elements (11, 12). The tool comprising means for connecting the pipelines, and it comprises a receiving portion (32) provided to accommodate the end of the first pipeline in a slideable manner, and guiding means comprising at least two guiding sections (34, 35) extending from receiving portion (32). Each guiding section has an end arranged with an attachment portion (36, 37) interfacing with the guide elements (11, 12).

Abstract: An underwater termination assembly for use with a subsea system such as a well tree, comprises a construction having first and second limbs substantially at a right-angle to each other, which construction may be lowered having an umbilical connected to one of the limbs so that said one of the limbs sits on the bed of a body of water.

Abstract: A drilling system employing a main tubular having a plurality of fluid inlet and outlet conduits positioned thereon and a concentric inner tubular having a plurality seals for sealing the annular space between the concentric inner and main tubulars. The fluid inlet and outlet conduits work in cooperation with the annular seals to selectively open and close for effective management of pressure within the tubulars.

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: A system for mitigating slugging in the conveyance of hydrocarbons in a flowline includes a first portion of flowline that extends substantially longitudinally along a declining surface. The first flowline portion carries multiphase hydrocarbons. A second portion of flowline extends upward from adjacent the first portion of flowline, and is in fluid communication with the first portion of flowline. A slug-mitigating region is between the first and second portions of flowline so slug-mitigating assembly receives the hydrocarbons from the first portion of flowline and conveys the hydrocarbons to the second portion of flowline. The slug-mitigating region has consecutively joined tubular segments that are each arcuate along a predetermined arcuate angle, with substantially uniform cross-sections. The first portion of flowline can be a subsea flowline extending along a sea floor, and the second portion of flowline can be a riser.

Abstract: Embodiments of the present invention relate to a volumetric compensating annular bellows used to compensate two fluid volumes by an annular displacement. This is achieved using a bellows welded on to a tube with a varying shape radius. A bellows is arranged within the annulus and is deformable in an annular direction in response to fluid volume expansion. The bellows can be used in several oilfield applications for fluid compensation.

Abstract: An apparatus having a hot stab having a fluid conduit connector thereon, a hydraulic hose having a connector assembly at an end thereof suitable for joining to the fluid conduit connector of the hot stab, and a sleeve affixed to the hot stab and to the hydraulic hose so as to extend over and surround the fluid conduit connector and the connector assembly. A jam nut is affixed to the tubular portion of the fluid conduit connector. The sleeve is threadedly connected to the threaded exterior surface of the jam nut. A crimp fitting is secured to an end of the hydraulic hose. A hose swivel extends around a crimp fitting and is affixed around the fluid conduit connector of the hot stab.

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: An underwater stabplate connection is provided by lowering a counterbalanced first part of the connection in a horizontal disposition by a lift line, the first part being attached to an umbilical. The first part of the connection mates with a second part of the connection, the second part being attached to an underwater structure such as a well tree.

Abstract: A technique facilitates formation of connections between compliant tubular members and subsea facilities. A compliant tubular member is deployed to a subsea location in a manner that arranges the compliant tubular member in a curvilinear shape. The distal end of the compliant tubular member is drawn down into proximity with the subsea facility and then moved horizontally into alignment with the subsea facility. Subsequently, the distal end is lowered into engagement with the subsea facility without being detrimentally affected by motion of an upper end of the compliant tubular member.

Abstract: A subsea intervention system is disclosed comprising a floating vessel and a source of coiled tubing at the floating vessel. The system includes a seabed installation including a wellhead and compliant guide having one end operatively connected to the floating vessel and the second end operatively connected to the seabed installation. The compliant guide provides a conduit between the floating vessel and the wellhead for the coiled tubing. At least one injector is present at the floating vessel for inserting the coiled tubing into the compliant guide, and a carousel is proximate the wellhead which comprises a plurality of chambers with intervention tools in at least two of those chambers. The system may also include a plurality of sensing units that are disposed at spaced intervals along the compliant guide to monitor various aspects of the compliant guide and to transmit that information to a repositioning system.

Abstract: A horizontal tree has a lateral passage extending from its bore. A tubing hanger having a lateral passage lands in the bore of the tree. The tubing hanger has an orientation guide mounted to it. A retractable pin is mounted in the sidewall of the tree. The orientation guide on the tubing hanger engages the pin to rotate the tubing hanger as it is being landed.

Abstract: A locking device for locking an exchangeable unit in an insertion opening of an associated housing, particular in maritime mineral oil or mineral gas extraction, comprises locking elements adjustable between an insertion opening and a locking position, wherein in its insertion direction the unit can be inserted into the insertion opening, and is locked in the locking position within the insertion opening and relative to the housing. The locking elements are formed as thread segments spaced apart by insertion gaps in the circumferential direction and arranged on the outer side of the unit and being aligned with the insertion opening, said thread segments being arranged in the insertion opening at a gap and being in thread engagement in the locking position.

Abstract: A submersible process environment for sub-sea processing is provided. Such environment can include a modular encapsulated unit having an interior volume and one or more processing units disposed therein, a first valve in fluid communication with the interior and exterior of the unit, and a second valve in fluid communication with the interior and exterior of the unit. The first valve and the second valve can be in fluid communication with the processing unit, and the processing unit can receive a fluid from the first valve and discharges the fluid to the second valve.

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 pressure driven pumping system includes a piston disposed within a first bore of a housing to separate a process chamber from a working chamber. A rod member coupled to the separating member extends into a reduced pressure chamber. The piston has a first face exposed to the process chamber and a second face exposed to the working chamber. The second face has an effective area less than an effective area of the first face. The housing may be placed in seawater at a selected depth. The process chamber can be in fluid communication with a well to pass well fluid into the process chamber at well pressure to move the piston, to discharge seawater from the seawater chamber. The working fluid, typically seawater in a subsea application, is pumped into the working chamber to move the piston, which discharges well fluid from the process chamber.

Abstract: A utility line connector assembly having a male stab having a central bore with a port that communicates with a second bore in a receptacle where the stab is fixedly inserted into a receiving female opening in the receptacle, the receptacle has an L shaped opening with a protruding partial spherical pocket, a ring groove for sealing said stab to a riser package, and where the stab and receptacle are placed between a lower marine riser and the blow out preventer in fluid communication therebetween. The stab and receptacle may be sealed with ring seals and the assembly may be used in riser auxiliary line connections, sub sea production tree connections, drape hose connections and surface bop auxiliary line connections.

Abstract: A subsea completion assembly for a subsea well including installed casing and a wellhead. The assembly includes a production casing forming a B annulus between the outside of the production casing and the installed casing. The assembly also includes an annulus access adapter installed in the wellhead, the adapter including a manipulatable valve controlling fluid communication with the fluid in the B annulus across the annulus access adapter. A property of the fluid in the B annulus can be monitored by fluid communicated across the annulus access adapter.

Abstract: A flow diverter tool assembly is employed for flushing debris from a portion of the bore of a subsea production tree. The flow diverter tool assembly has a housing having a passageway there-through and a seal disposed on an exterior surface of the housing. The seal contacts the inner wall surface of the bore of the production tree, dividing a lower portion of the bore below the seal from an upper portion of the bore above the seal. One or more outlets from the passageway through the exterior surface are disposed along the housing below the seal. A bypass device such as a slip-joint is disposed above the seal to facilitate removal of the flow diverter tool assembly from the bore of the production tree after its use.

Abstract: In combination, the loose tube flying lead includes: a) a pair of improved cobra head assemblies, each being able to receive a variety of different stab-plates with minimal modification; b) a pair of bend limiters, one extending from each cobra head assembly and c) an elongate bundle of non-constrained interior conduits surrounded by an over-hose, the over-hose being connected to each bend limiter. The over-hose may rotate independently of the bend limiters and the cobra head assemblies.

Abstract: A riser disconnect and support mechanism for flexible risers and umbilicals on an offshore structure with low under keel clearance. A main body portion includes an inverted and truncated conical or convex section substantially at the center of the main body portion. The main body portion and conical section receive risers therethrough by means of a plurality of conduits through the main body portion and conical section. A plurality of projections extend radially outward from the main body portion. A plurality of arch-shaped riser supports are provided on each projection to support risers and/or umbilical lines and control their bending radii. The projections extend out from the main body portion at a distance that allows the portions of the risers below the main body portion to hang at an angle and bend radius in accordance with the design tolerances of the risers to prevent buckling or damage due to excessive bending while keeping the risers from contacting the sea floor.

Abstract: A method and an apparatus for establishing a hydrate free regime in a subsea production flowline before discharging into the subsea production flowline a production flow of hydrate prone hydrocarbon product pursuant to a shutdown or at an initial start of production. The hydrate free regime is achieved by injecting into the flowline a heated water volume in advance of discharging the hydrocarbon product from the subsea production system.

Abstract: A purge system for use with a well intervention system and apparatus is disclosed. The purge system permits well fluids contained in a subsea intervention system to be purged prior to retrieval of the intervention system to the surface. The system comprises a vessel (44) for storing and deploying wireline tooling, the vessel being exposed to well fluids via the well control package (16) and first fluid communication means (58) connected between a purging fluid supply and the well control package, and second fluid communication means (60) connected between the vessel and the well control package wherein, in use, the purging fluid supply to the vessel via the first fluid communication means displaces fluid from the vessel into a second fluid communication means and into the well control package.

Abstract: A subsea gas compressor module having a housing comprising a sealing element generally defining within the pressure housing a first compartment holding as compressor and a second compartment holding an electric motor, the compressor and motor being driveably connected by at least one shaft. The first compartment is connected to an inlet line and an outlet line for sealing hydro carbon gas and for discharging gas. The second compartment has magnetic bearings for supporting the at least one shaft, and a pressure and volume regulator is fluidly connected to the second compartment and a gas supply, and includes elements for sensing respective pressures in the inlet and outlet lines whereby, based on the magnitude of sensed pressure, the pressure and volume regulator controls the pressure at which gas is injected into the second compartment.

Abstract: In one aspect, a method and apparatus for intervening in an offshore pipeline while diverting fluid flow to a storage site is provided, so that production through the offshore pipeline may continue while conducting a pipeline intervention operation. An offshore vessel may be used to divert and store fluid flow while intervening in the pipeline. In another aspect, a method and apparatus for drilling a subsea wellbore with an offshore vessel is provided. The method and apparatus involve drilling the wellbore and casing the wellbore with continuous casing lowered from the offshore vessel.

Abstract: A subsea wellhead assembly has separable tree modules that interconnect together. The lower tree module has a lower tree member having a bore with a valve for controlling production fluid flow. The upper tree module has an upper tree member with a bore and interface devices for monitoring the fluid flow as well as controlling the flow. A production line sub is carried alongside the upper tree member. The sub has a stab interface that stabs sealingly into a stab interface mounted alongside the lower tree member.

Abstract: A variable buoyancy subsea running tool for use with subsea transportable devices, such as a tree cap. The buoyancy of the running tool may be varied through fluid or gas displacement in one or more containers. Alternatively, the running tool may be configured with a buoy that has static buoyancy, with the buoyancy of the running tool being varied through the addition of a counterweight. The running tool can be used to install or uninstall a tree cap on a subsea tree. Installation of a tree cap may be actuated by a remotely operated vehicle. Additionally, the running tool may be moved by a remotely operated vehicle and may have additional features such as a position locator device.

Abstract: Pressure-balanced accumulator apparatus for use in subsea operations is disclosed which comprises a housing and an accumulator within the housing at the first end of the housing. The accumulator has first and second chambers that are hermetically sealed from one another, with a pressurized gas in the first chamber and a pressurized fluid in the second chamber. A third chamber in the housing abuts the accumulator and contains silicon oil fluid. A movable piston is located within the housing proximate the second end of the housing. Ambient pressure is communicated to one end of the piston, and ambient pressure plus the pressure in the second chamber is communicated to the second end of the piston. The cross-sectional areas of the two ends of the piston are selected to optimize the pressure at which the piston begins to expel fluid from the second chamber.

Abstract: A method for interchangeably connecting undersea a marine package with first and second pressure control devices. The method includes lowering undersea the marine package toward the first pressure control device such that a first half of a feed-thru component mounted to the marine package contacts a second half of the feed-thru component mounted on the first pressure control device; engaging the first and second halves, wherein the first and second halves of the feed-thru component were not previously engaged while the marine package and the first pressure control device were each assembled above sea; and locking the first half to the second half by using an external pressure such that a functionality of the feed-thru component is achieved.

Abstract: A tieback connector connects a tieback conduit from an offshore platform to a subsea wellhead assembly. The tieback connector has a mandrel that is connected to a string of tieback conduit and a sleeve and load ring that are carried by the mandrel. The load ring is radially expansible and has a conical portion with internal threads. The load ring has an external grooved profile that engages an internal grooved profile in the subsea assembly. The mandrel is rotatable relative to the sleeve while in its lower position, causing the load ring to further expand outward into engagement with the internal profile. A locking member is carried below the load ring on an exterior cam surface of the mandrel. The cam surface moves the locking member outward when the mandrel moves downward into engagement with an internal profile in the subsea assembly.

Abstract: A method for repairing damaged wells, especially in marine environments utilizing an alignment apparatus having a substantially cylindrical body member, a lower spear extension and a plurality of blades extending radially outward from the body member and spear extension. The alignment apparatus is concentrically inserted into the upper opening of a damaged well having a substantially vertical orientation. The alignment apparatus serves as an alignment guide for larger diameter pipe to be installed (typically driven) around a portion of the well to provide structural integrity to the well, as well as to serve as a conduit into the well for subsequent operations.

Abstract: A subsea wellhead assembly has a tubing annulus path that extends partly through the tubing hanger and partly through the wellhead housing. A tubing hanger tubing annulus passage extends through part of the tubing hanger from a lower port on the lower end of the tubing hanger to an upper port on the exterior surface of the tubing hanger below the tubing hanger seal. A wellhead housing tubing annulus passage within the sidewall of the wellhead housing has a lower end at the bore below the tubing hanger seal and an upper end at the bore above the tubing hanger seal. A valve is mounted to the wellhead housing and accessible by an ROV from the exterior for opening and closing the inner wellhead housing tubing annulus passage.

Abstract: A subsea wellhead assembly that includes a wellhead housing, a production tree, a tubing hanger adapted to land in the wellhead assembly inside the wellhead housing, and a bore formed through the production tree having an inner diameter greater than the tubing hanger outer diameter. A hanger adapter may be included having an annular body disposed on the tubing hanger upper surface and a flange member projecting radially outward from the annular body.

Abstract: A method and a device for installing a sub-sea riser for an offshore operation, between a base installation disposed on the sea bed and a sea installation protruding above the base installation. The sub-sea riser is provided with a first end and a second end. The method comprises the following stages in the following order: a) the first end of the riser is joined to the sea installation; b) the sub-sea riser is deployed; c) the second end of the riser is guided towards the base installation; d) the second end is coupled to the base installation by releasing the second end and the efforts of the recoil force exerted on the base installation are transferred; e) the second end and the base installation are connected to each other.

Abstract: A subsea completion testing tree (SCTT) for connection in a tubular string includes a lower tree portion having a control valve; an upper tree portion separably connected to the lower tree portion at a latch; a circulation valve connected with the upper tree portion; and a retainer valve connected with the upper tree portion between the circulation valve and the latch.

Abstract: The present application concerns apparatus for a hydrocarbon production facility, and a method of launching a pig into a pipeline. The apparatus may include export riser that provides a first flow path for production fluid from a production well, a pig launcher for launching a pig into the export riser at a first location, together with bypass tubing providing a second flow path for the production fluid which bypasses the export riser at the first location. This may allow production fluid to continue to flow from a production well through the export riser even when a pig or pig train is being located in the export riser.

Abstract: An apparatus (10) for coupling a monobore riser or lubricator system (11) to a dual bore (12) subsea well, the apparatus has a rotatable bore selector (30) within a housing (20). The bore selector has at least one conduit (35) to provide through bore communication between the riser bore or lubricator (11) and selectively at least one or other of main (60) and annulus (70) bores in the dual bore (12) well. The bore selector in a first position connects the conduit between the riser or lubricator bore and the main bore, and in a second position connects the conduit between the riser or lubricator bore and the annulus bore. The rotatable selector can be offset or set at a tilt angle of up to ±5° with respect to the length of the apparatus.

Abstract: The present invention discloses apparatus and methods for a lightweight subsea intervention package that may be installed using vessels with a smaller lifting capacity than semi-submersible platforms so that the subsea intervention package can be transported, installed, and removed from a subsea well in less time and with less cost. In one embodiment, the present invention comprises a lower riser package for controlling the subsea well which utilizes two hydraulically activated gate valves. An emergency disconnect package is secured to the lower riser package utilizing a disconnect mechanism. The emergency disconnect package is operable to seal the bottom of a riser if the disconnect mechanism is activated to thereby minimize environmental leakage of fluid from the riser.

Abstract: A line termination assembly for a riser string has a ring adapter mounted to a slip joint and a ring body mounted on top of the ring adapter. The ring adapter radially aligns with the ring body, which forms an inner diameter for receiving the slip joint. The ring body also has a discontinuity for radial access to the inner diameter, such that the ring body is circumferentially discontinuous. The discontinuity defines a chord dimension that exceeds the outer diameter of the slip joint, such that the slip joint may move radially through the discontinuity and into the inner diameter during assembly and disassembly of the system. Fluid bearings and tension rings are mounted to the slip joint and are axially spaced apart from the ring adapter and the ring body.

Abstract: A modular control system consisting of multiple, remotely retrievable functional modules for controlling a blowout preventer stack. The various functional modules can be located on the lower marine riser package and blowout preventer stack positioned near the equipment with which they are associated, wherein this distribution of modules nearly eliminates the complex interface connection between the lower marine riser package and blowout preventer stack. Each of the functional modules is capable of being installed, retrieved or replaced with a single remotely operated vehicle (ROV) deployment from a vessel. The functional modules can be used to operate as a complete control system for a blowout preventer stack or can be used selectively individually or in various combinations to accommodate multiple control applications or upgrades of other control systems.

Abstract: A dual bore well jumper establishing fluid communication between a subsea well and a subsea flowline. The dual bore well jumper comprises a first pipe comprising a first pipe bore and a second pipe comprising a second pipe bore, the second pipe being located within the first pipe bore or side-by side with the first pipe. The dual bore well jumper further comprises termination couplings at each for establishing fluid communication with either the subsea flowline or the subsea well. The first and second pipe bores isolate fluid flow in the first pipe bore from fluid flow in the second pipe bore. The dual bore well jumper may optionally further comprise junction assemblies allowing a change in fluid flow direction. The dual bore well jumper may further optionally comprise a bore access module attached to a junction assembly for selective fluid communication with the first and second bores.