Systems and methods provide for offloading liquefied gas, e.g. liquefied natural gas (LNG), from a cargo vessel offshore and regasifying the offloaded gas. In example systems, a floating storage unit is moored to the seabed offshore; first tubing offloads liquefied gas from the cargo vessel to the storage unit; a jack-up platform is positioned offshore in proximity to the floating storage unit, the jack-up platform comprising legs which are arranged to be supported on the seabed and a hull which is arranged to be jacked up along the legs to a position above the sea surface; a regasification facility is provided on the jack-up platform; second tubing extends between the storage unit and the regasification facility of the jack-up platform for transferring liquified gas from the cargo vessel to the regasification facility for regasification of the liquified gas; and third tubing communicates regasified gas away from the regasification facility, e.g. to shore.

A catamaran oil production apparatus is disclosed for producing oil in a marine environment. The apparatus includes first and second vessels that are spaced apart during use. A first frame spans between the vessels. A second frame spans between the vessels. The frames are spaced apart and connected to the vessels in a configuration that spaces the vessels apart. The first frame connects to the first vessel with a universal joint and to the second vessel with a hinged connection. The second frame connects to the second vessel with a universal joint and to the first vessel with a hinged or pinned connection. At least one of the frames supports an oil production platform. One or more risers or riser pipes extends from the seabed (e.g., at a wellhead) to the production platform (or platforms). In one embodiment, the production apparatus includes crew quarters.

An offshore spill protection system includes a flare boom configured to connect to an offshore drilling rig. The flare boom is configured to flare at least a portion of hydrocarbons flowed from the offshore drilling rig to the flare boom. A liquid hydrocarbon capture system includes a plate configured to be spatially positioned relative to the flare boom. The plate is sized to collect at least unflared hydrocarbons in a liquid state that flow through the flare boom.

Systems and processes for recovering a condensate from a conduit. In one embodiment, the system can include a floating buoy that can include a fluid swivel assembly coupled thereto. The system can also include a floating conduit, a first gas transfer conduit, and a second gas transfer conduit that can be configured to transfer a gas discharged from a vessel storage tank to a pipeline end manifold located at a subsea location. The system can also include a first condensation conduit, a pump, and a second condensation conduit that can be configured to transfer at least a portion of any condensate that accumulates within an internal volume of the floating conduit at a low point between the vessel storage tank and the first gas transfer conduit into a flow path defined by a first swivel section of the fluid swivel assembly, a storage tank, or a combination thereof.

A slide-in structural interface between a Sea Water Intake Riser (SWIR) and a floating unit hull or sump tank bottom plate permits a pull-in, diver-less installation of the SWIR. Certain embodiments include an integrated, easily maintainable strainer.

Mooring support structures, systems for mooring vessels, and processes for using same. In some embodiments, a system for mooring a vessel can include a mooring support structure than can include a post connected at a first end to a turntable disposed on a base structure. The post can extend out from the turntable and a yoke head connector can be connected to a second end of the post. A distal end of the yoke head connector can provide a disconnection location such that when a yoke head is disconnected from the yoke head connector, the yoke head can fall by gravity from the yoke head connector without contacting the mooring support structure.

This invention provides a means of loading, processing and conditioning raw production gas, production of CGL, storage, transport, and delivery of pipeline quality natural gas or fractionated products to market. The CGL transport vessel utilizes a pipe based containment system to hold more densely packed constituents of natural gas held within a light hydrocarbon solvent than it is possible to attain for natural gas alone under such conditions. The containment system is supported by process systems for loading and transporting the natural gas as a liquid and unloading the CGL from the containment system and then offloading it in the gaseous state. The system can also be utilized for the selective storage and transport of NGLs to provide a total service package for the movement of natural gas and associated gas production. The mode of storage is suited for both marine and land transportation and configured in modular form to suit a particular application and/or scale of operation.

A power generation and distribution arrangement that includes at least three switchgear sections. Each switchgear includes at least one or more power generators and an internal busbar in which the one or more power generators are electrically connected to the internal busbar. The internal busbar of each switchgear has one connecting end that is electrically connected to a common conductive node of the arrangement. The common conductive node includes an external interconnecting busbar between the switchgear sections.

The present invention relates to a spread moored vessel for production and/or storing of hydrocarbons. The vessel comprises a laterally extending main deck, a symmetrical mooring arrangement for mooring the vessel to a seabed when the vessel is floating in a body of water and a longitudinal hull. The longitudinal hull further comprises a bow, a midbody, a stern, and a motion suppressing element protruding out from the longitudinal hull, below the vessel's maximum draught. The ratio between a maximum length (L.sub.wl) and a maximum breadth (B.sub.wl) of the longitudinal hull, at the vessel's maximum draught, is between 1.1 and 1.5. The specific hull shape with the particular length/breadth ratio and the motion suppressing element allows for favorable and uniform motions regarding of wave direction in relation to vessel heading.

A first permissible operating range of the self-elevating vessel is determined based on a first structural analysis of the self-elevating vessel under a first set of conditions. A structural utilization ratio of the self-elevating vessel is determined based on a second structural analysis of the self-elevating vessel under first and second sets of conditions. Safety of lowering the self-elevating vessel from an elevated state to a first hull draft level is determined when the structural utilization ratio is less than a predetermined value. Safety of lowering the self-elevating vessel from the first hull draft level to a second hull draft level is indicated when positional displacement data obtained while the vessel is at the first hull draft level indicates that the positional displacement of the self-elevating vessel while at the first hull draft level is within the first permissible operating range.