Abstract: There is provided a subsea system for increasing pressure and/or flow rate in a flow line, the subsea system being arranged in fluid communication with said flow line which receives fluid from at least one fluid source. The subsea system comprises at least one compressor or pump and at least one subsea cooler which is arranged in the flow line in series with the at least one compressor. The subsea system further comprises a recirculation line which is configured such that at least a portion of the fluid flowing in the flow line downstream the at least one compressor and the at least one subsea cooler may be recirculated back to the flow line upstream the at least one compressor and the at least one subsea cooler such that the recirculating line can be used for capacity regulation of the at least one compressor and cleaning of the at least one subsea cooler.

Abstract: Systems and methods of production control are contemplated in which one or more multiphase flow meters are operationally coupled to a production conduit to provide flow and compositional information for the fluid in the production conduit. Data from the multiphase flow meter are then provided to a control system that uses the data to control operation of one or more choke valves of one or more well heads that are fluidly coupled to the production conduit.

Abstract: Subsea well intervention module (100) for performing well intervention operations in a well (101) through a well head (120) from a surface vessel (102), comprising a supporting structure (110), a pipe assembly (170) fastened to the supporting structure and having two opposite ends, an inner diameter and a cavity (182) in which an intervention tool (171) may be arranged for pressurizing the cavity (182) when connected to the well head or a blowout preventer arranged on top of the well head to wellbore pressure before at least one valve (121) of a well head is opened and the tool is submerged into the well, a connection member connected with a first end (202) of the pipe assembly for providing a connection to the well head, a wireless intervention tool (171) having an outer diameter and comprising an electrical power device (196). The connection member has an open first end connectable with the well head or blowout preventer and a through-bore providing fluid passage from the first end to the cavity.

Abstract: A method and a device are for extending at least the lifetime of a Christmas tree or an umbilical. The Christmas tree is provided with a high-pressure hydraulic valve package and a low-pressure hydraulic valve package and the umbilical includes electrical power and control cables and hydraulic pipes. The method includes: retrofitting an upgrading module including at least a control unit, a hydraulic high-pressure pump, a second high-pressure hydraulic valve package, and a hydraulic reservoir onto or at the Christmas tree; supplying the high-pressure pump, directly or via the reservoir, with hydraulic fluid from a pipe in the umbilical, the high-pressure pump being connected to the second high-pressure hydraulic valve package; connecting the second high-pressure hydraulic valve package to a downhole safety valve; connecting the electrical power and control cables of the umbilical to the control unit; and connecting control cables between the control unit and valves in the low-pressure hydraulic valve package.

Abstract: A releasable guidepost extension is used on the seabed together with a bottom fixed guidepost part. These parts make up a guidepost for use during the lowering of a component from the surface of the water to a subsea structure. The guidepost part includes an upward (in use position) projecting end designed for engagement with a lower (in use position) end of the guidepost extension. The guidepost extension is loosely connected to the bottom fixed guidepost part via a pin and socket part on respective ends. A gap, or clearance, exists between the pin and socket part in the longitudinal direction, and at least one friction forming device arranged in the gap on either the pin part or in the socket part. The friction forming device does not get in contact, or engaged, with the other part unless the guidepost extension is subjected to a lateral force.

Abstract: An apparatus for causing an indication of a connector of a subsea structure has a lifting structure pivotally affixed adjacent an upper end of the subsea structure, an extension extending outwardly adjacent a bottom of the subsea structure and an inclination tool cooperative with the extension so as to move the lower end of the subsea structure in an angular direction offset from horizontal. The inclination tool has a ratchet mechanism cooperative with a line extending from the lifting structure. Hydraulic actuators serve to draw the ratchet mechanism upwardly in a direction toward the lifting structure.

Abstract: The present invention provides a method and system for providing on-site electrical power to a fracturing operation, and an electrically powered fracturing system. Natural gas can be used to drive a turbine generator in the production of electrical power. A scalable, electrically powered fracturing fleet is provided to pump fluids for the fracturing operation, obviating the need for a constant supply of diesel fuel to the site and reducing the site footprint and infrastructure required for the fracturing operation, when compared with conventional systems. The treatment fluid can comprise a water-based fracturing fluid or a waterless liquefied petroleum gas (LPG) fracturing fluid.

Abstract: A device for the application of a preload between a subsea wellhead and a conductor housing comprises an activating member (1), a support housing (2), a locking member (3), end means (9) for securing the support housing relative to the well-head. Movement of the activating member causes an inclined lateral movement of the locking member. The activating member carries a ratchet (7) comprising a multiplicity of serrations which have a regular pitch in the activating direction and the support housing (1, 2) cames at least two latches (19, 20) which allow the relative movement and can engage the ratchet to inhibit movement reverse to the activating direction. The discrete locking positions provided by one of the latches are positionally out of phase with the discrete locking positions provided by the other latch or latches.

Abstract: A thermal insulation of pipes of a drill pipe riser, the novelty consisting basically in the fact that the thermal insulation comprises several layers around the pipe and between the first layer and the pipe, and between two adjacent layers, there are spaces where sea water penetrates. A thermal insulation system of joint couplings of pipes for a drill pipe riser comprising a tubular segment that circumferentially surrounds the region of the joint coupling and, so that between the tubular segment and the pipes is formed a space where sea water penetrates.

Abstract: The riser system of the present invention includes an external production riser for floating structures with interfaces to the dry and subsea wellheads, internal tieback riser with a special lower overshot/slipping connector for elevated temperatures. The seals can be metallic and/or non-metallic dynamic seals. Special centralizing pipe connectors and a special subsea wellhead tubing hanger are also included. This riser system avoids the penalty of pipe within pipe differential thermal growth and the resulting unwanted effects on the floating structure. This is accomplished by allowing an overshot sealing slipping connector to swallow an expanding polished rod as thermal conditions cause pipe elongation axially. When elevated temperatures fall to ambient the opposite occurs as the pipe shrinks axially. Alternatively, a system is possible where a two pipe drilling riser is needed. The internal pipe in this case would be an inner riser rather than a tubing string.

Abstract: A system comprising a floating host located over a first drilling center in a body of water, the floating host comprising drilling facilities; a floating spar located over a second drilling center; a first fluid transfer conduit between the second drilling center and the spar; and a second fluid transfer conduit between the spar and the floating host.

Abstract: The present invention concerns an apparatus for cutting a tubular part (16) extending down into a sea- or ocean bed. The apparatus includes a carrying body (1) adapted to be led over the tubular part (16) that is to be cut, with a cutting assembly placed in the carrying body (1). The cutting assembly includes a ring adapted to be driven in rotation in the carrying body (1). At least one cutting element (6) with a cutting portion (19), is hinged to the ring. At least one actuator (3) is adapted for leading the cutting element (6) between a retracted position and a cutting position against the tubular part (16) that is to be cut. Furthermore it is described an assembly with a cutting apparatus (A) and a carrying body (1) with a least one jaw (15, 28, 29) for fixing and centring the tubular part (16) in relation to the apparatus (A), and a method for subsea cutting of tubular parts (16).

Abstract: A method for removing a hydrocarbon production platform at sea, the production platform being connected to a hydrocarbon well, and including a support structure and an upper part being supported by the support structure, where the method includes the steps of; temporarily closing the well, removing at least part of the upper part from the support structure, positioning a well abandonment module on the support structure, which well abandonment module is constructed and arranged to perform well abandonment operations, performing abandonment operations from the well abandonment module to abandon the well, removing the well abandonment module from the support structure after the well abandonment operations are completed.

Abstract: The disclosure is directed to a method for retrieving a drilling riser connected to a blow-out-preventer (BOP) located on a sea bed. The method includes the steps of: a) attaching the first end of the retrieval line to a vessel; b) attaching the second end of the retrieval line to a drilling riser; c) disconnecting the riser from the BOP; d) initiating the assent of the disconnected riser from the sea bed; e) maintaining tension on the riser as it ascends to the sea surface by creating a horizontal load that is opposite to a current load on a bottom end of the riser; f) releasing tension on the retrieval line as the riser approaches the bottom of the drilling vessel; and/or g) disconnecting the retrieval line from the riser, whereby the riser is pulled through the bottom opening in the drilling vessel.

Abstract: A system for transferring fluids from a free-standing riser to a surface vessel comprises a first valve assembly including a first valve spool and a first isolation valve configured to control the flow of fluids through the first valve spool. In addition, the system comprises a second valve assembly releasably coupled to the first valve assembly with a hydraulically actuated connector. The second valve assembly includes a second valve spool and a second isolation valve configured to control the flow of fluids through the second valve spool. Further, the system comprises a deployment/retrieval rigging coupled to the first valve assembly and configured to suspend the first valve assembly and the second valve assembly from the surface vessel. Each isolation valve has an open position allowing fluid flow therethrough and a closed position restricting fluid flow therethrough, and each isolation valve is biased to the closed position.

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 tree cap has a wedge type annular metal seal for capping and sealing a subsea tree and associated methods to energize the same. The tree cap includes a cam element having a lower end with a conical profile adapted to be disposed within a respective bore of the subsea tree. The cam element moves along an axis of the bore. The annular metal seal is disposed on an outer diameter of the cam element so that the cam element may compress the annular metal seal against an actuation member to seal the bore of the subsea tree. The tree cap includes a housing adapted to be disposed on and secure to the subsea tree. The housing carries the cam element and exerts an axial force on the cam element to deform the annular metal seal into sealing engagement between the tree cap and the subsea tree.

Abstract: A method and system for producing fluid from a subsea wellbore. An amount of fluid is sampled from fluid being produced and retained for a period of time until constituents in the fluid stratify. A fluid characteristic is sensed at spaced apart vertical locations in the sampled fluid. A water fraction as well as gas content can be ascertained from sensing the sampled fluid. The fluid characteristic is used for calibrating a multi-phase flowmeter that measures flow of the fluid being produced from the wellbore.

Abstract: A riser assembly and method of forming where the riser assembly is made up of tubular members joined together. A metal spray process applies a layer of cladding onto ends of the tubular members and the ends are threaded to form respective box and pin configurations. Grooves are provided onto the surface of the tubular members beneath where the metal spray is applied for enhancing adhesion of the cladding and tubular members. The layer of cladding provides sufficient material so that threads may be selectively formed on the outer or the inner surface of the tubular members.

Abstract: An apparatus for tensioning a marine riser comprising a support for a number of actuators, where the support is connected to a vessel's structure, and where each actuator is connected to the support and to a marine riser, and where elements of the riser tensioner apparatus are enclosed.