A technique facilitates movement of fluids while reducing axial loading on system components such as thrust bearings. The technique utilizes a system, e.g. a compressor, for moving fluid via counter rotating rotors. By way of example, the rotors may utilize impellers for establishing opposed fluid flows along fluid movement sections. The fluid movement sections may be arranged in a back-to-back configuration such that counter rotation of the rotors causes the impellers to move fluid flows in opposed directions, thus reducing axial loading. The opposed fluid flows ultimately are redirected to an outlet.

A technique facilitates movement of fluids while reducing axial loading on system components such as thrust bearings. The technique utilizes a system, e.g. a compressor, for moving fluid via counter rotating rotors. By way of example, the rotors may utilize impellers for establishing opposed fluid flows along fluid movement sections. The fluid movement sections may be arranged in a back-to-back configuration such that counter rotation of the rotors causes the impellers to move fluid flows in opposed directions, thus reducing axial loading. The opposed fluid flows ultimately are redirected to an outlet.

A buoy accomplishes a fluid connection between a vessel on a water surface and a subsea template located on a seabed via at least one riser. A fluid is transported by the fluid connection from the vessel to the subsea template, and the fluid is injected from the subsea template (120) into a subterranean void via a drill hole. At least one valve in the buoy is controllable from an external site in response to commands so as to shut off the fluid connection from the vessel to the at least one riser.

A buoy accomplishes a fluid connection between a vessel on a water surface and a subsea template located on a seabed via at least one riser. A fluid is transported by the fluid connection from the vessel to the subsea template, and the fluid is injected from the subsea template (120) into a subterranean void via a drill hole. At least one valve in the buoy is controllable from an external site in response to commands so as to shut off the fluid connection from the vessel to the at least one riser.

The protection device has a valve and a valve actuator, able to move the valve to a closed position when a pressure upstream of the valve exceeds a predetermined threshold pressure. The valve actuator includes a biaser, to maintain the valve in an open position; an actuation mechanism, to move the valve to the closed position, the actuation mechanism with a fluid sampling passage to fluidly connect the flow line to a fluid actuated surface of the actuation mechanism. At least a rupture element preventing the passage of fluid from the flow line when the pressure upstream of the rupture element is lower than the threshold pressure, the rupture element being able to break at the threshold pressure.

The protection device has a valve and a valve actuator, able to move the valve to a closed position when a pressure upstream of the valve exceeds a predetermined threshold pressure. The valve actuator includes a biaser, to maintain the valve in an open position; an actuation mechanism, to move the valve to the closed position, the actuation mechanism with a fluid sampling passage to fluidly connect the flow line to a fluid actuated surface of the actuation mechanism. At least a rupture element preventing the passage of fluid from the flow line when the pressure upstream of the rupture element is lower than the threshold pressure, the rupture element being able to break at the threshold pressure.

Systems and methods for thermal management of subsea conduits such as jumpers provide the ability to alternate between cooling and heat retention of production fluids within the conduit as needed depending on the phase of operation. Adjustable insulation elements are provided on the conduits so that convective heat transfer between surrounding seawater and the conduit can be allowed or reduced. A control system can activate an alarm indicating the need to adjust the insulation depending on the temperature and/or flow rate of fluids in the conduit. Conventional conduits can be retrofitted by adding adjustable insulation elements to enable thermal management.

Disclosed are systems and methods for thermal management of subsea interconnecting conduit such as jumpers that provide cooling and heat retention of production fluids within the jumpers. In a jumper circuit, parallel sections of jumper are provided having differing amounts of heat transfer between surrounding seawater and production fluids flowing within. Valving is provided to control fluid flow between the parallel sections of jumper, thus controlling the amount of heat transfer between the surrounding seawater and the jumper circuit. A control system can be used to generate an alarm based on fluid temperature and/or fluid flow rate within the jumper circuit indicating the need to adjust the valving to manage the temperature of fluids within the jumper circuit. Changes may be needed particularly depending on the phase of production, e.g., early life, normal operation, shut down and late life operation.

A modular subsea fluid storage unit has a variable-volume inner tank having a rigid top panel and a peripheral wall that is flexible by virtue of concertina formations. The peripheral wall is extensible and retractable vertically while the horizontal width of the tank remains substantially unchanged. A side wall of a lower housing part surrounds and is spaced horizontally from the peripheral wall of the inner tank to define a floodable gap between the peripheral wall and the side wall that surrounds the tank. An upper housing part extends over and is vertically spaced from the top panel of the inner tank and overlaps the side wall to enclose the inner tank. The floodable gap and the upper housing part enhance thermal insulation and trap any fluids that may leak from the inner tank.

An offshore hydrocarbon processing facility (2) comprises an offshore floating structure (8) and a submerged floating riser deck (10). The submerged floating riser deck is operatively connected to a subsea hydrocarbon riser (12). Hydrocarbon processing equipment (26) is disposed on the submerged floating riser deck. The offshore floating structure (8) may be connected to the submerged floating riser deck (10) using a riser (16) that can be disconnected if there is inclement weather.