An offshore facility evacuation system that includes a submerged-floating pod (SFP) unit adapted to be positioned in a body of water adjacent an offshore facility, and a SFP station of the offshore facility adapted to launch the SFP unit from the facility. The SFP unit including a SFP controller, an SFP escape line to extend between the SFP station and the SFP unit to provide a path for moving persons from the SFP station to the SFP unit while the SFP unit is floating in the body of water, a SFP landing base including an inflatable platform to provide a landing area for persons, a SFP depth control system to regulate submergence of the SFP unit, a SFP location control system to control a location of the SFP unit, and a SFP communication system to provide communication with the SFP unit, and personal evacuation devices (PEDs).

The invention relates to an offshore hydrocarbon production facility arrangement that is to be located on a body of water, which includes a floating hydrocarbon processing unit, a floating renewable electric energy source, and a hydrogen gas source, wherein the floating renewable electric energy source is configured to generate electric energy; the hydrogen gas source is configured to produce hydrogen gas using the electric energy from the floating renewable electric energy source; the floating hydrocarbon processing unit is configured with an electric power generator; the electric power generator is coupled to the hydrogen gas source and is configured for receiving produced hydrogen gas as fuel gas.

A riser system with a primary conduit extends between a surface vessel and a subsea location and an auxiliary conduit that extends adjacent the primary conduit. In one example a composite jumper conduit extends from the surface vessel and is fluidly connected to the auxiliary conduit. The jumper conduit includes a composite material formed of at least a matrix and one or more reinforcing elements embedded within the matrix. In one example a subsea composite jumper conduit extends from subsea infrastructure and is fluidly connected to the auxiliary conduit. The subsea jumper conduit includes a composite material formed of at least a matrix and one or more reinforcing elements embedded within the matrix.

A supporting system for a floating unit in shallow water exerts controlled stresses on the floating unit hull and includes supporting structure for the hull. An extendable supporting device operatively connects to the supporting structure and is suitable to support a predetermined weight of the floating unit and load when entirely supported by the extendable supporting device and when the extendable supporting device rests on a bed of a water body. An actuator device connects to the supporting structure and operatively connects to the extendable supporting device for extension or contraction. A control device operatively connects to the actuator device to control the extraction or contraction movement of the extendable supporting device. The system includes at least one hull stress monitoring device operatively connected to the control device. A device to monitor the stress, or load, on the extendable supporting device operatively connects to the control device.

A vessel adapted to perform subsea wellbore related operations involving a riser string that is assembled from releasably interconnected riser sections and extends between a subsea wellbore and the vessel. The riser string vertical handling system of the vessel includes a controlled motion device that is adapted to displace the riser string lifting tool in at least one horizontal direction relative to the riser spider device at least whilst travelling between the elevated and lowered position thereof loaded by the riser string suspended from the riser string lifting tool, thereby allowing to establish an inclined travel path with selectively variable inclination of the riser string lifting tool relative to an imaginary vertical line through the riser string passage of the riser spider device, e.g. said inclined travel path having an inclination selected to correspond to an actual water current induced inclination of an upper portion of the riser string during the riser string assembly process.

Techniques and systems to store and deploy a lift frame of an offshore vessel. A device may include a member arm comprising a locking feature configured to couple the member arm to a lift frame of the offshore vessel. The device may also include a base configured to be coupled to a drill floor of the offshore vessel, wherein the base comprises a joint configured to allow for rotation of the member arm and the lift frame from a storage position having a first angle between the member arm and the drill floor and a deployment position having a second angle between the member arm and the drill floor.

Techniques and systems to remove a portion of a drill floor from an offshore vessel. The drill floor may include an immovable section comprising a first portion of a surface area of the drill floor. The drill floor may also include a moveable section comprising a second portion of the surface area of the drill floor. Additionally, the drill floor may include an actuator configured to retract the moveable section from a first position to a second position to remove the second portion of the surface area of the drill floor.

A drilling rig includes a drill floor with a well center opening, a derrick having a drilling machine which is suspended above the well center opening, a pipe supply area which is arranged adjacent to the well center opening on the drill floor, and a pipe handling machine. The pipe supply area has at least one pipe rack which horizontally stores pipe sections. The pipe handling machine moves at least one of the pipe sections between a horizontal storage position in the at least one pipe rack and a vertical position or a substantially vertical position above the well center opening.

This invention relates generally to geotechnical rig systems and methods. In one embodiment, a cone penetration testing system includes, but is not limited to, a frame; at least one rotatable reel; at least one movable roller; and at least one sensor, wherein the at least one movable roller is configured to adjust a bend radius of at least one tube coiled about the at least one rotatable reel based at least partly on data received from the at least one sensor.

Systems, devices and methods enable generation and monitoring of support platform structural conditions in a manner that overcomes drawbacks associated with conventional approaches (e.g., load cells) for generating and monitoring similar operating condition information. In preferred embodiments, such systems, devices and methods utilize fiber optic strain gauges (i.e., fiber optic sensors) in place of (e.g., retrofit/data replacement) or in combination with conventional load cells. The fiber optic sensors are strategically placed at a plurality of locations on one or more support bodies of a support platform. In preferred embodiments, the fiber optic strain gauges are placed in positions within a hull and/or one or more pontoons of an offshore platform. Such positions are selected whereby resulting operating condition data generated by the fiber optic strain gauges suitably replaces data received by conventionally constructed and located load cells of an offshore platform (e.g., a TLP).