Exxonmobil Upstream Research Company

Exxon Production Research Company

Mark E Ehrhardt

Jeffrey William Frederick

Robert E Sandstrom

L Donald Maus

W Brett Wilson

Mark A Danaczko

Lonny R Kelley

Paul W Sibal

William S Mathews

Mukhtiar S Purewal

James P Johnston

Dawn Rymer

Houston G Wood, Iii

Tracy A Fowler

Torney M Van Acker

Jimmie G Galloway

Dawn L Rymer

Robert E Foglesong

Robert D Denton

The present application is directed to methods and systems for transporting or importing LNG via vessels. Under the present techniques, SRTs, which are equipped with regasification equipment, LNG offloading equipment (e.g. marinized mechanical loading arms), LNG storage tanks, and equipment to transfer natural gas to an import terminal are utilized as temporary interchangeable FSRUs (TIFs). Two or more TIFs in conjunction with transport vessels (e.g. LNGCs) are utilized to transfer LNG between an export terminal and an import terminal. A first of the TIFs is utilized at an import terminal to offload LNG from LNGCs, while the second of the TIFs is utilized as a LNGC, carrying LNG between the export terminal and import terminal. The first of the TIFs may be replaced by the second of the TIFs to maintain operations for the import terminal. The use of multiple TIFs in combination with LNGCs provides an alterative LNG delivery approach in comparison to having a permanently moored FSRU located at the import terminal or using a fleet of SRT vessels to transport LNG between an export terminal and an import terminal.

Transporting and managing liquefied natural gas

The current invention includes to systems and methods of transferring cryogenic fluids between two locations. More particularly, some embodiments of the invention are related to systems and methods of using cryogenic risers and rotatable connections for transferring cryogenic fluids, including liquefied natural gas, from an ocean going vessel to a second location. One embodiment of the invention includes a system for transporting a cryogenic fluid between a floating vessel and a second location. The system including a cryogenic riser, a submersible turret connector. The being riser adapted to allow the vertical position of the first end of the riser to be changed, the second end of the first riser located in a body of water and in fluid communication with the second location. The submersible turret connector connected to the first end of the first riser. The first connector adapted for releasably connecting to a first floating vessel located on the body of water so that a cryogenic fluid can be communicated between the first vessel and the first end of the first riser, the first connector being moored to the bottom of the body of water such that the vertical position of the first connector can be changed, and the first connector adapted to allow the first vessel to rotate around the first connector upon the surface of the body of water while the first vessel is connected to the first connector.

Subsea cryogenic fluid transfer system

A method and apparatus for controlling the riser base pressure and detecting well control problems, such as kicks or lost circulation, during drilling of an offshore well using a gas-lifted riser. The pressure control apparatus preferably includes two separate control elements, one to adjust the pressure at the surface (p ) and the mass flow rate out of the top of the riser ({dot over (m)} ) to compensate for changes in riser base pressure (p ) and the other to adjust either or both of the boost mud flow rate (q ) and lift gas flow rate (q ) to maintain a constant or nearly constant mass flow rate entering the base of the riser ({dot over (m)} ). According to the method of the present invention, the well return flow rate (q ) is preferably determined by directly measuring various other parameters and then computing q from the measured parameters. The computed value of q may be compared to the drill string flow rate (q ) to detect well control problems, such as kicks or lost circulation.

Method and apparatus for controlling pressure and detecting well control problems during drilling of an offshore well using a gas-lifted riser

Gas storage is provided for a subsea gas-lifted riser during offshore drilling and/or production operations. One or more gas storage chambers positioned along and about the subsea riser are connected to a gas conduit. Each chamber has at least one valve for controlling passage of gas out of the chamber and into the gas conduit. The valves serve to allow the gas from the storage chambers to be injected as lift gas as needed.

Method and system for storing gas for use in offshore drilling and production operations

A one-pass centrifuge separator for mixtures of two liquids which may also contain gas. The centrifuge uses separation zones on a rotor's inner wall to improve separation efficiency and minimize turbulent mixing. The zones consist of surface and interface vanes, and baffle plates to control flow at the fluid interface. The zones also retain an open concept to facilitate washing by cleaning fluids which are provided by nozzles installed on a stationary feedpipe mounted along the rotational axis of the centrifuge. A fluid accelerator gradually accelerates the fluid from the feedpipe to the inner wall of the rotor.

Flow enhanced one-pass centrifuge separator

A centrifugal method and apparatus capable of separating a fluid stream composed of a plurality of components with differing specific gravities. The stream contemplated for separation is that of a producing oil well with components of oil, water, natural gas, and particulates. The method and apparatus use centrifugal forces to separate the gaseous, solid, and liquid components from each other. After separation is completed, detector and sensor arrangements are used to maintain liquid levels in the separator and to control the removal of the individual separated fluids from the apparatus.

Centrifuge processor and liquid level control system

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Houston, TX, United States of America

Mark E Ehrhardt