Exxon Production Research Company

Deep Oil Technology Incorporated

Technip France

Cso Aker Maritime, Inc.

Paul Nelson Stanton

Metin Karayaka

Lyle David Finn

Roger W Huffaker

Wynn P Rickey

David A Hibbs

Clarence Afton Schulte

Michael F Cook

There is provided a buoyancy system for a structure having at least one component being substantially stationary with respect to the bottom of a water covered area. The system comprises a set of buoyancy modules of engineered materials to apply an identified amount of buoyancy. The set of buoyancy modules is attached to the structure at a set of buoyancy load transfer locations. The set of buoyancy modules comprises layers of the engineered materials. The engineered materials comprise a substantially reinforced axial layer, a substantially reinforced hoop layer; and a leak prevention layer.

Engineered material buoyancy system and device

A subsea hydraulic control module that is totally enclosed such that the hydraulic fluid does not contact the seawater. The majority of the power for the module comes from the hydrostatic pressure of the sea itself. Two oil-over-seawater actuators each have an internal piston that separates the oil from the seawater. Each actuator is provided with two solenoid valves that control the flow of seawater. A fluid line and one solenoid valve on the seawater side of each actuator is in fluid communication with a seawater recovery reservoir. These two valves are also in fluid communication with each other through a common fluid line to the seawater reservoir. The remaining solenoid valve on the seawater side of each actuator may be selectively opened or closed to the ambient seawater. A hydraulic line on the oil side of each actuator is in fluid communication with the equipment to be controlled. The hydraulic lines from each actuator enter the equipment to be controlled on opposite sides of the equipment to allow control of the equipment. The solenoid valves are opened and closed in selected combinations to open, close, or maintain the equipment in selected operating positions.

Subsea power module

A riser guide and support mechanism for a floating vessel, and particularly a spar type structure, where the buoyancy can stem extends nearly the entire length of the floating vessel. A riser centralizing element is provided on the riser near the lower end of the buoyancy guide stem. Riser bend limiting elements are positioned on the riser so as to extend above and below the riser centralizing element. Since the buoyancy cans and buoyancy can stem are not required to rotate relative to the stem guides on the floating vessel, the stem guides can be formed from pipe sections that provide a much larger bearing area than is customary.

Riser guide and support mechanism

A system for supporting one end of a riser or other elongate element from a marine structure. In the preferred embodiment, a plurality of gas springs are symmetrically disposed about the upper end of a riser. The axis of compression of each gas spring is parallel to the axis of the riser. One end of each gas spring is secured to the riser and the other end of each gas spring is secured to the marine structure. Relative motion between the riser and marine structure along the riser axis is accommodated by contraction or extension of the gas springs. A gas reservoir can be provided to reduce pressure changes as the gas springs extend and contract. This reduces changes in the loading applied to the riser as the marine structure moves relative to the ocean bottom.

Pneumatic riser tensioner

An apparatus and method is described for introducing and removing TFL tools from a subsea wellhead assembly. The apparatus includes an elongate member adapted to hold at least one TFL tool, docking hubs for aligning the elongate member with the wellhead, a clamping mechanism or the like for engaging the elongate member with the wellhead and a circulation for circulating fluid within the elongate member and the wellhead to transport the TFL tool between the elongate member and the wellhead. In another embodiment, the apparatus includes at least two elongate members and a diverter located between the elongate members and the clamping mechanism. The diverter permits alternate fluid communication between each elongate member and the wellhead assembly. The method comprises the steps of lowering the elongate member containing a TFL tool to the subsea wellhead assembly, positioning the elongate member adjacent the wellhead assembly, engaging the elongate member to the wellhead assembly, the then circulating fluid within the elongate member and the wellhead assembly to transport the TFL tool between the elongate member and the wellhead assembly.

Apparatus for performing subsea through-the-flowline operations

A fluid control system 10 and selector valve 24 for use therein, for controlling a plurality of fluid actuated elements 12, such as valve operators. The fluid actuated elements are controlled from an operating station 52, which is located remotely from the fluid actuated elements 12. Instructions regarding which of the fluid actuated elements 12 it is desired to operate are transmitted by coded signal from the operating station 52 to the selector valve 24, which is positioned proximate the fluid actuated elements 12. The coded signal is transmitted in binary form through a plurality of code input lines 30, each code input line carrying one binary digit of the code. Each of the fluid actuated elements 12 is represented by a corresponding binary code. In response to receiving the binary code corresponding to a given one of the fluid actuated elements 12, the selector valve 24 establishes a fluid circuit serving to introduce fluid pressure to or release pressure from that one of the fluid actuated elements 12, causing it to alter its condition. The present invention is especially well suited for use in the hydraulic control of a satellite well subsea production system.

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Houston, TX, United States of America

Paul Nelson Stanton