Abstract: Power umbilical (1) comprising a plurality of power cables (7) for electric power transmission, elongated filler elements (5), and an outer sheath (3). The elongated filler elements (5) abut against each other at abutment faces (5a), thereby forming a complete ring enclosing the power cables (7). The elongated filler elements (5) comprise cable recesses (5b) within which the power cables (7) are embedded. The power umbilical (1) further comprises one or more friction control profiles (13, 15, 116), wherein the material of the friction control profile (13, 15, 116) is softer than the material of the elongated filler elements (5). The one or more friction control profiles (13, 15) are arranged in a deformed state.

Abstract: A connection device for mating and making up a subsea connection. The connection device includes a first pipeline end which is fixable to an end of a subsea pipeline, a first connection element which is connected to the first pipeline end, and a second connection element which is connected to the first connection element. The first connection element is rotatably connected to the second connection element.

Abstract: An offshore power distribution system includes first cables each having a first dry mate connection at a first end and each connecting to an offshore power generator unit at a second end, a subsea junction box at a sea floor, a second cable extending from the junction box to a subsea transformer station at the sea floor and connecting with the transformer station, and a third cable extending from the transformer station to an onshore receiver. Each first dry mate connection terminates in the junction box. The second cable has a second dry mate connection at an end thereof. The second dry mate connection terminates inside the junction box and is operatively connected to each first dry mate connection. The power distribution system is configured to transmit electric power from the power generator unit, via the first cables, the second cable, and the third cable, to the receiver.

Abstract: A Christmas tree includes a main body, an bulkhead connector, a wet-mate connector, a cable, and a sensor. The main body has a first and a second main body end, and a further passage, and encloses a main passage. The further passage includes a first further passage end at a main body exterior and a second further passage end at the main passage, and extends from the first to the second further passage end. The bulkhead connector is secured to the main body exterior to close the first further passage end, and has a first and a second electrical connection. The wet-mate connector is mounted in the second further passage end to close the second further passage end. The cable transmits an electrical signal and connects the first electrical connection to the wet-mate connector. The sensor is arranged in the further passage and electrically connects to the second electrical connection.

Abstract: An adapter assembly for connecting a flowline which includes an end portion to a subsea tree which includes a fluid line connector. The adapter assembly includes an adapter base, a first connection element which is connected to the adapter base and which connects to the fluid line connector of the subsea tree, and a flowline connector assembly which includes a second connection element which connects to the end portion of the flowline. The flowline connector assembly is attached to the adapter base. The adapter assembly connects to the subsea tree via the first connection element.

Abstract: A method of connecting a tubing hanger mounted in a subsea wellhead to equipment which is external to the tubing hanger. The method includes securing the tubing hanger to an end of a drill string using a tubing hanger running tool assembly, lowering the drill string from a drilling rig so as to land the tubing hanger on or in the wellhead, running an umbilical from the sea surface to the wellhead, and connecting the umbilical to at least one conduit in the tubing hanger via the tubing hanger running tool assembly. The umbilical is unconnected to the drill string other than via the tubing hanger running tool assembly.

Abstract: A method for constructing a floater for a floatable wind energy power plant includes providing a first pre-assembled part with at least one first connection arrangement, providing a second pre-assembled part with at least one second connection arrangement, arranging the at least one first connection arrangement of the first pre-assembled part proximate to the at least one second connection arrangement of the second pre-assembled part so as to form a connection site which includes at least a part of the at least one first connection arrangement and at least a part of the at least one second connection arrangement, sealingly arranging an enclosure about the connection site so as to seal the enclosure against an ingress of water, and connecting the first pre-assembled part and the second pre-assembled part at the connection site. Each of the first pre-assembled part and the second pre-assembled part are floatable.

Abstract: Example embodiments presented herein are directed towards a subsea control system for transmitting subsea related data to and from a topside control system with the use of Subsea Electronic Modules (SEMs) connected in a network in a multidrop configuration.

Abstract: The invention concerns a subsea umbilical comprising an electrical conductor (2) and/or a fluid pipe, and an outer sheath (7) surrounding the electrical conductor (2) and/or the fluid pipe. The umbilical (1, 20, 21, 25, 30, 40, 51, 60) further comprising a plurality of deformable rods (3a, 3b, 15, 23a, 23b, 26a, 27a, 26b) evenly distributed between the electrical conductor (2) and/or the fluid pipe, and the outer sheath (7) for radial load protection of said electrical conductor (2) or fluid pipe.

Abstract: A method of connecting a tubing hanger mounted in a subsea wellhead to equipment which is external to the tubing hanger. The method includes securing the tubing hanger to an end of a drill string using a tubing hanger running tool assembly, lowering the drill string from a drilling rig so as to land the tubing hanger on or in the wellhead, running an umbilical from the sea surface to the wellhead, and connecting the umbilical to at least one conduit in the tubing hanger via the tubing hanger running tool assembly. The umbilical is unconnected to the drill string other than via the tubing hanger running tool assembly.

Abstract: A subsea well equipment landing body (1) includes an indicator assembly to indicate landing of the landing body or to indicate locking of the landing body. The indicator assembly has a stem bore (7), a sliding stem (11) within the stem bore that has a stem head (23) protruding beyond an external face of the landing body. A stem channel (25) in the sliding stem extends between the stem head and a stem channel mouth (27), and is in fluid communication with the outside of the landing body. A hydraulic channel (9) in the landing body is in fluid communication with the stem bore. The stem channel mouth is positionable in a communicating position, in which there is fluid communication between the hydraulic channel and the stem channel, and a non-communicating position, without fluid communication between the hydraulic channel and the stem channel.

Abstract: A flexible deployment system is used to deploy subsea/downhole well equipment or modules from a multi-purpose vessel without requiring a moon pool and a derrick or tower. The deployment system may include the vessel and a deployment frame disposed on the vessel. The deployment frame includes a protruding section extending as a cantilever beyond an external edge of the vessel, and the protruding section includes an aperture formed therein to facilitate construction of the well equipment or modules through the protruding section. The deployment system also includes an actuation assembly coupled to the protruding section to selectively transition the protruding section to a collapsed, split, or retracted orientation out of a deployment path of the well equipment or modules. The system allows for controlled deployment of well equipment or modules including at least a string of downhole tools or tubulars coupled end to end from the side of the vessel in a single trip.

Abstract: A system including a subsea module, a tool hanger, and an in-well tool string coupled to and extending from a lower portion of the tool hanger is provided. The subsea module includes a subsea spool with a main bore formed therethrough, and the main bore includes a tool hanger interface. The subsea module also includes a connector for mounting the subsea module on a subsea component, wherein the connector includes a grip configured to engage the subsea component, and a first seal coupled to the connector and configured to seal the connector against the subsea component. The tool hanger is disposed within the main bore and coupled to the tool hanger interface via at least a second seal configured to seal the tool hanger against the main bore of the subsea spool. The in-well tool string is configured to couple the tool hanger to an in-well tool.

Abstract: A fluid separator unit includes an elongate body having a circular internal cross-section and a longitudinal axis, an inlet which directs a fluid flow into the body in a rotational flow pattern around the longitudinal axis, a first outlet, a second outlet, a first centrifugal separation zone arranged within the body, a second centrifugal separation zone arranged within the body, a first fluid path from a central part of the first centrifugal separation zone to the first outlet, a second fluid path from an outer periphery of the second centrifugal separation zone to the first outlet, and a third fluid path from the second centrifugal separation zone to the second outlet. A diameter of the second centrifugal separation zone is smaller than a diameter of the first centrifugal separation zone.

Abstract: The invention provides an autonomous subsea barrier fluid system for a subsea pressure booster, the subsea pressure booster comprising a process fluid compartment, a motor compartment and a rotor assembly extending from the motor compartment into the process fluid compartment with one or several shaft seals separating the process fluid from the barrier fluid in the motor compartment. The subsea barrier fluid system is distinguished in that it comprises: a subsea barrier fluid pump, a barrier fluid delivery line, arranged between the barrier fluid pump and the motor compartment, a pressure controlled regulator, operatively arranged to at least one of the barrier fluid delivery line and the subsea barrier fluid pump, a subsea barrier fluid storage, and a barrier fluid suction line arranged from the subsea barrier fluid storage to the subsea barrier fluid pump.

Abstract: A process system includes a process module, an upstream pipe, a downstream pipe, an inlet pipe with an inlet isolation valve, an outlet pipe with a discharge isolation valve, a bypass with a bypass isolation valve, and a drainage line with a valve. The process module has an inlet, an outlet, and a drainage outlet. The inlet pipe fluidically connects the inlet of the process module to the upstream pipe. The outlet pipe fluidically connects the outlet of the process module to the downstream pipe. The bypass fluidly connects the upstream pipe and the downstream pipe via the bypass isolation valve. The drainage line fluidly connects the drainage outlet of the process module to the downstream pipe via the valve.

Abstract: An offshore methane hydrate production assembly (1), having a tubing (41) extending into a subsea well (5) that extends down to a methane hydrate formation (7) below the seabed (3). A submersible pump (45) is arranged in the tubing (41). A methane conduit (35,35) extends down from a surface installation (49). A well control package (15) landed on a wellhead (13) is positioned at the upper end of the subsea well (5). Moreover, an emergency disconnection package (25) is arranged between the methane conduit (35,135) and the well control package (15). The tubing (41) is suspended from the well control package (15). Other aspects of the invention are also disclosed.

Abstract: Example embodiments presented herein are directed towards a safety system, for example a subsea workover safety system, for overriding a control module configured to actuate a component of a hydrocarbon production apparatus, particularly an apparatus comprising at least one of a lower riser package and an emergency disconnect package.