Fmc Technologies, Inc.

Fmc Corporation

Harold Brian Skeels

Michael R Williams

Christopher E Cunningham

Eric Randall Smedstad

Thomas L Hergarden

Marcus Alan Smedley

Howard J Hartley

Andrei M Strikovski

John A Fitzgerald

Jimmy D Andrews

John D Dafler, Jr

Christopher D Bartlett

Bashir M Koleilat

Shiva P Singeetham

Vidar Sten-Halvorsen

Russell Eric McBeth

Bill George Louis

Mark Alan Johnson

Randy J Wester

Robert B Baten

Ole Eddie Karlsen

Edmund M Mouret

Michael J Krenek

Timothy R Goggans

Robert S Hamell

Steven A Reinhardt

Andrei Strikovski

Donald M Underwood

Sterling F Lewis

Robert J Writt

Robert R Decker

David MacFarlane

Christopher E Cunninham

Kevin Roy Knight

Luis Felipe De Barros Mendes

Bob Houlgrave

Steve Malone

John D Dafler

John Lawson

An actuation device () includes a plurality of actuation units () disposed about an axis (Ar). Each actuation unit of the plurality of actuation units () includes a shape memory alloy component (-), an auxetic material component (-) operationally coupled to the shape memory alloy component (-), and a power source (-) operationally coupled to the shape memory alloy component (-). Additionally, the actuation device () includes a control system () operationally coupled to the power source (-), the control system () is configured to actuate the shape memory alloy component (-) through the power source (). Further, when actuated, the shape memory alloy component (-) moves in a direction outward from the axis (Ar) to pull the auxetic material component (-), and the auxetic material component expands in a direction perpendicular to the movement direction of the shape memory alloy component (-).

Method and systems for positive displacement of an actuation device

A method includes choosing a well site for Carbon Capture and Sequestration, preparing the well site for Carbon Capture and Sequestration, and hydraulic fracturing a target area in a formation using fracturing fluid containing a reactant proppant to form fractures in the target formation and to trap the reactant proppant in the fractures. The target formation is in communication with a well in the well site. Such methods also include injecting a volume of carbon dioxide into the fractures in the target formation, chemically reacting the volume of carbon dioxide with the reactant proppant, converting the volume of carbon dioxide into a carbonate, and storing the carbonate in the fractures in the target formation.

Method and systems for subsurface carbon capture

A system for forming an upper plug in a well, the system, comprising lower tool segment that is adapted to land within a wellhead housing under open water conditions, a well control package that is adapted to be positioned above the lower segment and coupled to the wellhead housing, the well control package comprising at least one seal ram, an upper tool segment that is adapted to be positioned through the well control package (i.e., after the well control package has been attached to the wellhead) and operatively coupled to the lower tool segment, wherein at least one seal ram of the well control package is adapted to engage an outer surface of the upper tool segment, and at least one cutting means that is coupled to the lower segment and adapted to be actuated to cut at least one opening in at least one section of casing within the well.

Plug and abandonment system for forming an upper plug when abandoning an oil and gas well

Disclosed are various to blockage remediation systems for removing blockages, e.g., hydrate plugs, debris plugs, etc., from subsea flowlines and subsea equipment. In one illustrative embodiment, the system includes, among other things, an ROV () deployed into a body of water from a surface vessel () and a blockage remediation skid () that is operatively coupled to the ROV (), wherein the skid () includes at least a skid fluid inlet (A) and a skid fluid outlet (A). The system also includes a returns downline () and a pressurized lift-gas supply downline () that extends into the body of from the vessel (). The returns downline () is operatively coupled to the skid fluid outlet (A), while the pressurized lift-gas supply downline () is adapted to be operatively and directly coupled to the blockage remediation skid () or operatively and directly coupled to the returns downline (). The system also includes a remediation flow line () that is operatively coupled to the skid fluid inlet (A) and a flowline () or an item of subsea equipment (or).

Systems for removing blockages in subsea flowlines and equipment

Disclosed is flow reversal system () that comprises a single direction flow device () adapted for receiving a fluid and first (), second (), third () and fourth () binary valves. The system is adapted to be configured in a first position wherein the first () and fourth () binary valves are open and the second () and third () binary valves are closed and the fluid flows through the single direction flow device () in a first direction (), be configured from the first position to a neutral position by actuating the second () and third () binary valves from a closed position to an open position wherein, in the neutral position, the first (), second (), third () and fourth () binary valves are open and the fluid flows through the single direction flow device () in the first direction () and be configured from the neutral position to a second position by actuating the first () and fourth () binary valves from an open position to a closed position wherein the first () and fourth () binary valves are closed and the second () and third () binary valves are opened and the fluid flows through the single direction flow device () in the first direction ().

Systems for reversing fluid flow to and from a single-direction fluid flow device

Generally, the present disclosure is directed to systems that may be used to facilitate the retrieval and/or replacement of production and/or processing equipment that may be used for subsea oil and gas operations. In one illustrative embodiment, a method is disclosed that includes, among other things, removing at least a portion of trapped production fluid () from subsea equipment () while the subsea equipment () is connected to a subsea equipment installation () in a subsea environment (), and storing at least the removed portion of the trapped production fluid () in a subsea containment structure () that is positioned in the subsea environment (). Additionally, the disclosed method also includes disconnecting the subsea equipment () from the subsea equipment installation () and retrieving the subsea equipment () from the subsea environment ().

Methods for retrieval and replacement of subsea production and processing equipment

Expandable and contractible buoyancy modules are assembled to the risers of a deepwater exploration spar or other offshore structure to provide an upwardly directed buoyancy force to offset at least a portion of the weight of the riser. The buoyancy modules have a fabricated pressure tight expandable and contractible envelope composed of rubber or rubber-like material which is mounted onto a tubular member having a central passage for receiving the riser to be supported. The tubular member projects beyond the respective upper and lower ends of the envelope and defines upper and lower riser joint connectors and buoyancy module travel stops which secure the buoyancy module to the riser and provide for force transmission from the buoyancy module to selected locations along the length of the riser or to the upper end of the riser. The envelope is provided with at least one access port through which an inflation medium such as a gas or an uncured polymer can be added to control inflation of the envelope and through with liquid ballast is added or removed for ballast control.

Collapsible buoyancy device for risers on offshore structures

A technique for maintaining pressure integrity within a submersible system. The system utilizes a pressure housing with an internal component, such as a valve. The internal component is actuated by an external actuator via an actuator stem. A seal region is positioned to interact with the stem, such that the interior of the pressure housing is sealed and pressure integrity is maintained upon retraction of the stem from engagement with the internal component.

Technique for maintaining pressure integrity in a submersible system

A mudmat foundation for supporting an item of subsea equipment on the sea floor comprises a mudmat on which the item of subsea equipment may be supported and a plurality of legs which are pivotably connected to and depend downwardly from the mudmat. The legs are free to pivot outwardly relative to the mudmat upon insertion of the legs into the sea floor to thereby increase the load bearing capacity of the mudmat.

Mudmat foundation for subsea equipment

A downhole safety valve for a central circulation completion system having concentric inner and outer tubular members defining a production bore therebetween comprises a generally cylindrical body which includes an outer surface which is sealed to the outer tubular member and an axial through bore to which the inner tubular member is secured. In this manner, the downhole safety valve forms a pressure barrier between a first portion of the production bore located below the body and a second portion of the production bore located above the body. The downhole safety valve further comprises at least one flow passage which extends through the body and communicates between the first and second portions of the production bore, and at least one closure member which is disposed across the flow passage to control fluid flow between the first and second portions of the production bore.

Downhole safety valve for central circulation completion system

A wellhead system for petroleum producing wells comprises a &ldquo;stack-down&rdquo; casing hanger configuration. In this stack-down system, the hanger for each successively smaller diameter casing string is landed or &ldquo;nested&rdquo; within the hanger for the next larger casing string. This approach allows the pack-off for each casing hanger to be retrieved independently, thus allowing fluid communication to be established with any of the casing annuli after all of the casing strings and hangers have been installed. Thus the pressure in each annulus may be monitored while the well is in production mode.

Nested stack-down casing hanger system for subsea wellheads

A subsea pig launching apparatus for launching one or more pigs into a flowline which is fluidly connectable to a source of well fluid comprises at least one first hub to which the source of well fluid is connectable and which is in communication with the flowline, a first valve which is positioned between the first hub and the flowline, a second hub which is in communication with the flowline, and a pig launcher which is removably connectable to the second hub and which comprises at least one pig, at least one launch valve which is positioned between a pressure source and the pig, and a launch actuator for selectively opening and closing the launch valve. The launch actuator is controlled by a signal which is communicated through at least one of a number of external control and service lines that are connected to a control and service umbilical for the source of well fluid.

Subsea pig launching apparatus

A subsea system is provided for producing a number of subsea wells which may be arranged in groups. Each of the groups of subsea wellheads is connected to deliver production flow to a subsea manifold and each subsea manifold is connected to deliver production flow to a production riser. A plurality of production risers each being connected to receive production flow from one of said subsea manifolds extend from the subsea manifolds for groups of wells. A deep draft floating spar is located generally above the subsea wellheads with mooring lines and has a production platform located above the sea surface and has buoyancy and ballast chambers to control floatation. The spar structure defines a riser bore receiving the production risers extending from the subsea wellheads to the production platform. The spar is also capable of being shifted laterally by its mooring lines for positioning above a selected well to thus permit well intervention activities as needed. The subsea wells are each provided with wellheads having a removable cap to permit ROV actuated cap removal and replacement as needed to permit well intervention.

Floating spar for supporting production risers

Flying lead hydraulic and electrical umbilical arrangements are disclosed for control of a subsea christmas tree for production and workover operations. Alternative arrangements for deep water ROV arrangements for a conventional christmas tree are illustrated in FIGS. 2A, 2B and in FIGS. 3A, 3B, and 3C. Alternative arrangements for a horizontal christmas tree are illustrated in FIGS. 5, 6, and 7.

Growing community of inventors

Kingwood, TX, United States of America

Harold Brian Skeels