| 序号 | 专利名 | 申请号 | 申请日 | 公开（公告）号 | 公开（公告）日 | 发明人 |
|---|---|---|---|---|---|---|
| 141 | CONNECTOR APPARATUS FOR SUBSEA BLOWOUT PREVENTER | US14095241 | 2013-12-03 | US20140151059A1 | 2014-06-05 | Jerry Keith Rhodes; Kenneth Bean; Paul Horton, JR. |
| According to one aspect, an apparatus is adapted to be operably coupled to a subsea blowout preventer and includes a first tubular member defining an internal passage, and a second tubular member extending within the internal passage. A sealing assembly is disposed radially between the first and second tubular members, and includes a sealing element. The second tubular member covers the sealing element and thus facilitates protecting the sealing element from any fluid flow through the internal passage. According to another aspect, a sealing element of a connector is protected before engaging the connector with a subsea casing. The connector is engaged with the casing while the sealing element is protected so that the sealing element is fluidically isolated from any fluid flow through the connector. The sealing element sealingly engages the casing. | ||||||
| 142 | Flexible riser pipe installation for conveying hydrocarbons | US12524045 | 2008-01-23 | US08733446B2 | 2014-05-27 | Philippe Espinasse; Alain Coutarel; Isabel Teresa Waclawek |
| The invention relates to a riser pipe installation that comprises a flexible duct of the non-bound type, the duct being vertically arranged between a mechanical connection with a submerged buoy at the stub on the one hand, and a mechanical connection with the seabed at the bottom on the other hand, wherein fluid connections are provided at the stub and at the bottom for connecting the riser pipe with surface equipment on the one hand and bottom equipment on the other hand; the bottom of the pipe is located at a depth of at least 1000 m where it is submitted to a computable maximum reverse bottom effect F, while the buoy is oversized in order to generate at the bottom of the riser pipe a reaction tension T higher than at least 50% or even 100% of the computable maximum reverse bottom effect F applied at the bottom of the pipe. | ||||||
| 143 | METHOD FOR THE ASSISTED INSTALLATION OF AN UNDERWATER RISER | US14006836 | 2012-03-15 | US20140037385A1 | 2014-02-06 | Ange Luppi |
| A method for installing an underwater riser between a seabed (52) and a surface (12), and a tubular pipe suspended from a float (24): The float (24) is weighted to be able to submerge it to drive one pipe end (28) toward the seabed (52) for connecting the tubular pipe at the seabed. Unwinding the flexible pipe (20) to extend it catenary fashion between the float (24) and a surface installation (10) so as to weight the float (24) with the unwound flexible pipe (20) and cause the submersion of the float (24), whereby the other pipe end (28) is driven toward the seabed (52). | ||||||
| 144 | CONNECTION APPARATUS AND METHODS | US13994036 | 2011-12-14 | US20140034327A1 | 2014-02-06 | John White; Brian Wells; Colin Bickersteth |
| A vertical connection apparatus for connecting a pipeline to a subsea structure comprises a guide funnel for controlling the position of the pipeline relative to the subsea structure; a moveable barrier and a attachment region for a drive mechanism; the moveable barrier is operable between an open position in which the pipeline can pass through the guide funnel and a closed position in which the barrier prevent the end of the pipeline passing through the end of the guide funnel. A tool with a drive mechanism can be attached between the pipeline and guide funnel to manipulate the pipeline into a connectable position. A clamp connector secures the connection between the pipeline and subsea structure conduit. | ||||||
| 145 | RETRIEVABLE FLOW MODULE UNIT | US14045093 | 2013-10-03 | US20140027125A1 | 2014-01-30 | Edmund McHugh; Finbarr Evans; Tobias Voelkel |
| A retrievable flow module (RFM) apparatus is provided. In one embodiment, the RFM apparatus is a standalone assembly configured to mate with a subsea device, such as a production tree. The RFM apparatus may include a frame within which various flow control and monitoring elements are disposed. The frame may have an alignment system that enables the RFM apparatus to horizontally mate with the tree. Because the RFM apparatus provides for the collocation of flow control and monitoring elements within a standalone assembly, deployment or retrieval of the flow control and monitoring elements may be accomplished in single operation. Additional systems, devices, and methods are also disclosed. | ||||||
| 146 | Subsea Production System Having Arctic Production Tower | US13997609 | 2011-12-20 | US20130292128A1 | 2013-11-07 | Carl R. Brinkmann; Dmitri G. Matskevitch |
| A subsea production system for conducting hydrocarbon recovery operations in a marine environment, including a trussed tower having a first end including a base residing proximate the seabed and a second end having a landing deck configured to receive and releasably attach to a floating drilling unit. The system also includes one or more hydrocarbon fluids storage cells. The storage cells reside at the seabed proximate the base of the trussed frame. The system further includes subsea production operational equipment that resides within the trussed frame near the water surface and is in fluid communication with the hydrocarbon fluids storage cells. A method for installing such components is also provided. | ||||||
| 147 | Modular stress joint and methods for compensating for forces applied to a subsea riser | US13506352 | 2012-04-13 | US20130269946A1 | 2013-10-17 | Mitchell Z. Dziekonski |
| Modular stress joints usable to compensate for forces applied to a subsea riser or other structure include a base member and one or more additional members. Members having desired lengths can be selected such that the sum of the length of the base member and additional members defines a desired total length. Members having desired wall thicknesses can be selected such that a combination of the wall thicknesses of the base member and each additional member defines an overall wall thickness or stiffness. The total length, overall wall thickness, or both correspond to expected forces applied to the subsea riser or structure, such that the stress joint is adapted to compensate for the forces and prevent damage. The number or length of members used and their thickness or other characteristics can be varied to provide multiple lengths and stiffnesses, such that the stress joint is modular and reconfigurable. | ||||||
| 148 | Retrievable flow module unit | US13421254 | 2012-03-15 | US08550170B2 | 2013-10-08 | Edmund McHugh; Finbarr Evans; Tobias Voelkel |
| A retrievable flow module (RFM) apparatus is provided. In one embodiment, the RFM apparatus is a standalone assembly configured to mate with a subsea device, such as a production tree. The RFM apparatus may include a frame within which various flow control and monitoring elements are disposed. The frame may have an alignment system that enables the RFM apparatus to horizontally mate with the tree. Because the RFM apparatus provides for the collocation of flow control and monitoring elements within a standalone assembly, deployment or retrieval of the flow control and monitoring elements may be accomplished in single operation. Additional systems, devices, and methods are also disclosed. | ||||||
| 149 | Plugged hot tap tee | US13121141 | 2009-09-23 | US08511328B2 | 2013-08-20 | Per Lillejordet |
| The invention is directed toward a T-pipe designed for transfer of high pressure fluids through the main run and where the branch run is left in a standby position for possible use in the future. The opening, or outlet, of the branch run is sealed by a material continuous with the main run. An opening and fluid flow in the branch run while the main run is in production and remains under full pressure, is to be provided. The sealing includes a metal membrane which is in contact with the fluid flowing in the main run. The metal membrane is thinner than the wall thickness of the T-pipe and is supported by a plug inserted in the branch run. | ||||||
| 150 | Docking and Drilling Stations for Running Self-Standing Risers and Conducting Drilling, Production and Storage Operations | US13727241 | 2012-12-26 | US20130112131A1 | 2013-05-09 | Keith K. Millheim |
| A sea vessel exploration and production system is provided, wherein the system includes a drilling station formed from at least one section of a first sea vessel hull; and a docking station, which is also formed from at least one section of a second sea vessel hull. A mooring system suitable for connecting the drilling station to the docking station is also provided. Means for anchoring the vessels to the seafloor, and for attaching them to turret buoys, are also considered. Various exploration and production packages, as well as equipment required to deploy and control a self-standing riser system in either deep or shallow waters, are also described. | ||||||
| 151 | Underwater connection installation | US12863228 | 2009-01-23 | US08418766B2 | 2013-04-16 | Ange Luppi |
| An underwater connection installation (26) and a laying method for connecting a riser and a flexible pipe (22) that are intended for carrying hydrocarbons. A post (28) is attached to a float (20) to suspend the riser (12) below the surface. The post (28) supports a gooseneck shape pipe (54) that has a bent-over outlet free end (58) ending in a first coupling (60). A coupling end piece (32) mounted on the flexible pipe (22) includes a second coupling (86). The coupling end piece (32) and the post (28) define mechanical guides including complementary frustoconical rings (64, 84). The driving of the coupling end piece (32) and of the bent-over free end (58) toward each other causes the frustoconical rings (64, 84) to engage one another to bring about coaxial alignment of the couplings (60, 86). | ||||||
| 152 | Interchangeable subsea wellhead devices and methods | US12415190 | 2009-03-31 | US08322429B2 | 2012-12-04 | Robert Arnold Judge; Perrin Rodriguez |
| A method for interchangeably connecting undersea a marine package with first and second pressure control devices. The method includes lowering undersea the marine package toward the first pressure control device such that a first half of a feed-thru component mounted to the marine package contacts a second half of the feed-thru component mounted on the first pressure control device; engaging the first and second halves, wherein the first and second halves of the feed-thru component were not previously engaged while the marine package and the first pressure control device were each assembled above sea; and locking the first half to the second half by using an external pressure such that a functionality of the feed-thru component is achieved. | ||||||
| 153 | Devices and Methods for Transmitting EDS Back-up Signals to Subsea Pods | US12969822 | 2010-12-16 | US20120152554A1 | 2012-06-21 | Eric Lee MILNE |
| Methods and systems for a backup emergency disconnect signal (EDS) transmission in an offshore oil and gas installation are provided. A backup EDS transmission system includes a pressure pulse generator located close to a water surface and configured to generate a predetermined pressure variation pattern including at least one of positive and negative pressure pulses and corresponding to an emergency disconnect signal, the signal being propagated downwards in a mud column. The pressure pulse generator is located at a surface end of the mud column. The backup EDS transmission system also includes a pressure pulse receptor connected to a controller of blowout preventers and configured to measure a pressure in the mud column, at a subsea location. | ||||||
| 154 | METHOD FOR INSTALLING AN OPERATING RIG FOR A FLUID IN A BODY OF WATER WITH A TRACTION UNIT | US13127246 | 2009-11-03 | US20120134755A1 | 2012-05-31 | Jeroen Remery; Romain Vivet; Christophe Defreslon; Ange Luppi |
| This method comprises connecting a downstream point (40) of a pipe (24) to a buoy (26) and completely submerging the buoy (26). It comprises deploying in the body of water (12) an intermediate section (30) of the pipe (24) from the downstream point (40) to at least as far as an upstream point (38), anchoring the upstream point (38), and tensioning the intermediate section (30) to keep it vertical. The connecting step includes activating a traction unit (96) to raise the downstream point (40) on the buoy (26). During the connecting step, the buoy (26) is carried in the body of water (12) virtually exclusively by its own floatability. | ||||||
| 155 | Universal method and apparatus for deploying flying leads | US12535653 | 2009-08-04 | US08186910B2 | 2012-05-29 | Ronald E. Smith |
| In one embodiment, the subsea deployment system may be used to install flying leads with integral buoyancy. In another embodiment, the subsea deployment system may be used to install flying leads with separate buoyancy modules. The installation sling assembly may be used with the subsea deployment system or with other systems to deploy flying leads subsea. The universal removable cartridge may be interchanged for use on a horizontal drive unit and a mud mat. | ||||||
| 156 | MARINE SUBSEA FREE-STANDING RISER SYSTEMS AND METHODS | US13156224 | 2011-06-08 | US20120085544A1 | 2012-04-12 | Roy Shilling; Paul W. Gulgowski, JR.; Philip D. Maule; Kevin Kennelley; Walter Greene; Robert W. Franklin; Vicki Corso; Tony Oldfield; Adam L. Ballard; Graeme Steele; David Wilkinson; Ricky Thethi; Chau Nguyen; Steve Hatton |
| A free-standing riser system connects a subsea source to a surface structure. The system includes a concentric free-standing riser comprising inner and outer risers defining an annulus there between. A lower end of the riser is fluidly coupled to the subsea source through a lower riser assembly (LRA) and one or more subsea flexible conduits. An upper end of the riser is connected to a buoyancy assembly and the surface structure through an upper riser assembly (URA) and one or more upper flexible conduits, the riser also mechanically connected to a buoyancy assembly that applies upward tension to the riser. The riser may be insulated for flow assurance, either by a flow assurance fluid in the annulus, insulation of the outside of the outer riser, or both. The system may include a hydrate inhibition system and/or a subsea dispersant system. The surface structure may be dynamically positioned. | ||||||
| 157 | Loose tube flying lead assembly | US12208448 | 2008-09-11 | US08100182B2 | 2012-01-24 | Ronald E. Smith; John Theobald |
| In combination, the loose tube flying lead includes: a) a pair of improved cobra head assemblies, each being able to receive a variety of different stab-plates with minimal modification; b) a pair of bend limiters, one extending from each cobra head assembly and c) an elongate bundle of non-constrained interior conduits surrounded by an over-hose, the over-hose being connected to each bend limiter. The over-hose may rotate independently of the bend limiters and the cobra head assemblies. | ||||||
| 158 | Docking and Drilling Stations for Running Self-Standing Risers and Conducting Drilling, Production and Storage Operations | US13205119 | 2011-08-08 | US20110286806A1 | 2011-11-24 | Keith K. Millheim |
| A sea vessel exploration and production system is provided, wherein the system includes a drilling station formed from at least one section of a first sea vessel hull; and a docking station, which is also formed from at least one section of a second sea vessel hull. A mooring system suitable for connecting the drilling station to the docking station is also provided. Means for anchoring the vessels to the seafloor, and for attaching them to turret buoys, are also considered. Various exploration and production packages, as well as equipment required to deploy and control a self-standing riser system in either deep or shallow waters, are also described. | ||||||
| 159 | METHOD FOR ASSEMBLING AN OPERATING RIG FOR A FLUID IN A BODY OF WATER AND ASSOCIATED OPERATING RIG | US13127244 | 2009-11-03 | US20110274501A1 | 2011-11-10 | Jeroen Remery; Romain Vivet; Christophe Defreslon; Ange Luppi |
| This method comprises connecting a downstream point (40) of a pipe (24) to a buoy (26) and completely submerging the buoy (26). It comprises deploying in the body of water (12) an intermediate section (30) of the pipe (24) from the downstream point (40) to at least as far as an upstream point (38), anchoring the upstream point (38), and tensioning the intermediate (section (30) to keep it vertical. The height of the buoy (26) is less than 1.5 times its greatest transverse dimension. The method comprises moving the buoy (26) between a remote position and an installed position in line with an anchoring region, keeping the buoy (26) partly submerged on the surface (16) of the body of water. | ||||||
| 160 | STABPLATE CONNECTIONS | US12877214 | 2010-09-08 | US20110088909A1 | 2011-04-21 | Andrew S. Hamblin; Gareth H. Lewis |
| A stabplate connection is provided by: providing a first part (1) comprising a stabplate and carried by an underwater structure; providing a second part (2) comprising a stabplate carried by tooling (4); engaging the tooling with said first part; using the tooling to bring the parts together so the stabplates mate with each other; using the tooling to lock the first and second parts together by engaging a portion (6) carried by the first part with a portion (10) carried by the second part; disengaging the tooling from the first part; and removing the tooling from the stabplate connection. | ||||||
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