| 序号 | 专利名 | 申请号 | 申请日 | 公开（公告）号 | 公开（公告）日 | 发明人 |
|---|---|---|---|---|---|---|
| 101 | Extender jumper system and method | US15280832 | 2016-09-29 | US09784074B1 | 2017-10-10 | John Hellums; David Anthony James; Jesus Manuel Williams Sequera; Ted Mercer; Randy Kimberling; Ken Flakes |
| Extender jumper systems and methods including an extender jumper system having an extender jumper assembly with a flowline and first and second connectors positioned at first and second ends of the flowline, and a support assembly configured to couple the extender jumper assembly to a support structure within a subsea field and to support the second connector to facilitate attachment between the second connector and a corresponding connector of another extender jumper or a jumper. | ||||||
| 102 | Fluid injection system | US15182540 | 2016-06-14 | US09752424B2 | 2017-09-05 | Kevin Minnock; Eddie McHugh |
| A system including a fluid injection system configured to removably couple to a mineral extraction system, wherein the fluid injection system includes a fluid injection system controller, a flow meter system coupled to the fluid injection system controller, wherein the flow meter system is configured to measure a fluid flow of a fluid through the fluid injection system, an adjustable valve configured to control the fluid flow through the fluid injection system, and a non-return valve configured to block reverse flow of the fluid through the fluid injection system, wherein the fluid injection system controller, the flow meter system, the adjustable valve, and the non-return valve are coupled to a common housing. | ||||||
| 103 | Fluid connector assembly with automatic flow shut-off and method usable for establishing a fluid connection | US14087892 | 2013-11-22 | US09732595B2 | 2017-08-15 | David C. Wright |
| Embodiments usable within the scope of the present disclosure relate generally to a connector apparatus and methods usable to securely and repeatedly connect a sub-sea fluid conduit to another fluid conduit or well equipment, such as a manifold, a wellhead, a BOP, or other associated items. The disclosed embodiments further relate to systems and methods usable to remotely disconnect the fluid conduit and automatically shut off fluid flow therethrough. The male connector includes a flow control valve adapted to open upon connection with a female connector and to close upon disconnection from the female connector. The female connector is adapted to actuate the flow control valve of the male connector to the open position. The male connector includes a biasing member that actuates the flow control valve of the male connector to the closed position. | ||||||
| 104 | Subsea chemical injection system | US14739229 | 2015-06-15 | US09695665B2 | 2017-07-04 | David Older; Jay Bullard; Brent Cox |
| A subsea chemical injection system has a subsea structure, a manifold connected by jumper to the subsea structure, a coiled tubing, a disconnect mechanism affixed to the coiled tubing, and a hose extending from the disconnect mechanism to the manifold such that the chemical flowing through the coil tubing can selectively flow through the disconnect mechanism and through the hose to the subsea structure. The disconnect mechanism is adapted to selectively release from the hose. The disconnect mechanism has a connector affixed thereto. A hydraulic fluid supply is connected to the connector so as to selectively release the connector from the hose. Control lines can extend from a surface location to a control module and the disconnect mechanism for selectively delivering for receiving signals from the subsea structure. | ||||||
| 105 | Modular subsea completion | US14339320 | 2014-07-23 | US09631460B2 | 2017-04-25 | David R. June |
| A system for producing well production fluids through a tubing hanger connected with a tubing string, in certain embodiments, includes a subsea tree and a tubing spool. The subsea tree includes a production flow passage, and the tubing spool includes a longitudinal bore configured to receive the tubing hanger and a lateral production flow passage configured to transfer well production fluids to the production flow passage of the subsea tree. The subsea tree and the tubing spool are configured to be run and retrieved independently of one another in any order. | ||||||
| 106 | CONNECTOR APPARATUS FOR SUBSEA BLOWOUT PREVENTER | US15361649 | 2016-11-28 | US20170074064A1 | 2017-03-16 | 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. | ||||||
| 107 | SUBSEA WELL ASSEMBLY AND ASSOICATED METHOD | US15278226 | 2016-09-28 | US20170016302A1 | 2017-01-19 | Robert STUBBEMAN |
| Subsea well assembly having a Xmas tree (107, 207) and wellhead (103). From a tubing hanger (113) a tubing extends into the well. A part of a production flow passage extends vertically from the tubing hanger (113) in a vertical bore (111) of the Xmas tree. A fail close production master valve (PMV) (117) is arranged in the production flow passage. The tubing hanger (113) is arranged below the Xmas tree (107), such as in the wellhead (103). The Xmas tree (107) exhibits a branch (115) that deviates from the vertical bore (111), which branch constitutes part of the production flow passage. The fail close type production master valve (PMV) (117) is arranged in the branch (115). | ||||||
| 108 | FLUID INJECTION SYSTEM | US15182540 | 2016-06-14 | US20160369613A1 | 2016-12-22 | Kevin Minnock; Eddie McHugh |
| A system including a fluid injection system configured to removably couple to a mineral extraction system, wherein the fluid injection system includes a fluid injection system controller, a flow meter system coupled to the fluid injection system controller, wherein the flow meter system is configured to measure a fluid flow of a fluid through the fluid injection system, an adjustable valve configured to control the fluid flow through the fluid injection system, and a non-return valve configured to block reverse flow of the fluid through the fluid injection system, wherein the fluid injection system controller, the flow meter system, the adjustable valve, and the non-return valve are coupled to a common housing. | ||||||
| 109 | SUBSEA CHEMICAL INJECTION SYSTEM | US14739229 | 2015-06-15 | US20160362956A1 | 2016-12-15 | David OLDER; Jeffrey PARTRIDGE; Brent COX |
| A subsea chemical injection system has a subsea structure, a manifold connected by jumper to the subsea structure, a coiled tubing, a disconnect mechanism affixed to the coiled tubing, and a hose extending from the disconnect mechanism to the manifold such that the chemical flowing through the coil tubing can selectively flow through the disconnect mechanism and through the hose to the subsea structure. The disconnect mechanism is adapted to selectively release from the hose. The disconnect mechanism has a connector affixed thereto. A hydraulic fluid supply is connected to the connector so as to selectively release the connector from the hose. Control lines can extend from a surface location to a control module and the disconnect mechanism for selectively delivering for receiving signals from the subsea structure. | ||||||
| 110 | HYDRAULIC CONNECTOR SYSTEM | US14667466 | 2015-03-24 | US20160281473A1 | 2016-09-29 | Alexis Delgado; Ricardo Araujo; Jose Gutierrez |
| A system including a mineral extraction system, including a tubular with a fluid passage, a hydraulic connector system configured to couple to the tubular, the hydraulic connector system, including a hydraulic block configured to couple to one or more fluid lines, and a sleeve coupled to the hydraulic block and configured to move axially with respect to the hydraulic block to couple and uncouple the hydraulic connector system with the tubular. | ||||||
| 111 | Sealable wellsite valve and method of using same | US14252481 | 2014-04-14 | US09394758B2 | 2016-07-19 | James Ray Landrith, II; Matthew Christopher Quattrone |
| A valve, system and method for controlling flow of fluid about a wellsite component of a wellsite are provided. The wellsite component has a flowline to pass the fluid therethrough. The valve includes a valve housing, a cage having holes therethrough positionable in selective fluid communication with the flowline, a valve plate operatively connectable between the valve housing and the cage (the valve plate having a sealing surface thereon), and a spool assembly comprising a spool slidably positionable in the cage. The spool assembly is selectively positionable in sealing engagement with the sealing surface of the valve plate to define a sealing interface therebetween, and is movable between an inlet position defining a fluid intake path and an outlet position defining a fluid outtake path whereby the fluid is selectively diverted through the wellsite component. | ||||||
| 112 | SUBSEA SUPPORT | US14972082 | 2015-12-16 | US20160186517A1 | 2016-06-30 | Hans Paul Hopper; Johnnie Kotrla; John T. Evans |
| A subsea support system comprises: at least one component (501) which is configured to be fixedly connected to a pressure conductor (101) in a seabed; and a subsea support (601) which is configured to compliantly support the at least one component (501); wherein, when the at least one component (501) is fixedly connected to the pressure conductor (101), substantially all of a mechanical load (T) which is applied to the subsea support (601) is transmitted by the subsea support (601) to the seabed while the at least one component (501) is substantially free of the mechanical load and remains fixed relative to the pressure conductor (101). | ||||||
| 113 | JUMPER LINE CONFIGURATIONS FOR HYDRATE INHIBITION | US14895575 | 2014-06-04 | US20160130918A1 | 2016-05-12 | Gaurav BHATNAGAR; Gregory John HATTON |
| A jumper line system comprising: a first subsea device; a second subsea device; and a jumper line providing fluid communication between the first subsea device and the second subsea device, wherein the jumper line does not comprise a valley. | ||||||
| 114 | Guide funnel | US13627299 | 2012-09-26 | US09328572B2 | 2016-05-03 | Andrew David Hughes |
| A guide funnel for guiding a subsea infrastructure for connection with a subsea wellhead or mandrel profile is provided. The guide funnel comprises a plurality of sections, wherein the sections are collapsible such that the guide funnel can be in an extended state or a collapsed state. | ||||||
| 115 | Docking and Drilling Stations for Running Self-Standing Risers and Conducting Drilling, Production and Storage Operations | US14959862 | 2015-12-04 | US20160090156A1 | 2016-03-31 | 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. | ||||||
| 116 | Marine subsea free-standing riser systems and methods | US14591545 | 2015-01-07 | US09297214B2 | 2016-03-29 | 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 E. 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. | ||||||
| 117 | Systems and methods for pulling subsea structures | US14293264 | 2014-06-02 | US09284806B2 | 2016-03-15 | Daniel Gutierrez; Luis J. Gutierrez; Parker Berry |
| A system for pulling a subsea structure includes an adapter configured to be mounted to an upper end of a subsea pile. In addition, the system includes an interface assembly fixably coupled to the adapter. The interface assembly includes a first channel configured to receive a flexible tension member and a first chuck disposed in the first channel. The tension assembly includes a second channel configured to receive the flexible tension member and a second chuck disposed in the second channel. Each chuck is configured to pivot about a horizontal axis between an unlocked position allowing the flexible tension member to move in a first axial direction and a locked position preventing the tension member from moving in a second axial direction that is opposite the first axial direction. | ||||||
| 118 | Subsea production system having arctic production tower | US13997609 | 2011-12-20 | US09260949B2 | 2016-02-16 | 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. | ||||||
| 119 | FLANGE CATCHING, ALIGNING AND CLOSING TOOL | US14763322 | 2013-06-05 | US20160039076A1 | 2016-02-11 | Roy VOSS |
| A flange catching, aligning and closing tool (10) designed to facilitate the tie-in of spools and other similar mechanical assemblies that utilise a bolted flange for installation, for example, in subsea pipelines. The tool (10) has an elongate support member (12) having a locating pin (14) mounted adjacent one end with its longitudinal axis (16) substantially parallel to a longitudinal axis (18) of the support member (12). A slide assembly (20) is slidably mounted on the support member (12) and has a movable drift pin (22) provided in connection therewith. In use, when the locating pin (14) is located in a bolt hole on a first flange, a second flange can be brought into partial alignment with the first flange by engaging with the support member (12), and the drift pin (22) can be inserted in a matching bolt hole in the second flange to bring the two flanges into full alignment. | ||||||
| 120 | Subsea platform transporter (SPT) | US14538141 | 2014-11-11 | US09254893B2 | 2016-02-09 | Amal C. Phadke; George Z. Gu; Scott E. Coblitz; Daniel R. Givan; Derrick Laskowski; Chad A. Petrash |
| A subsea platform transporter includes a plurality of pontoon members, a plurality of column members interconnecting select adjacent ones of the plurality of pontoon members forming a support frame having an inner platform receiving area, a plurality of buoyancy members mechanically linked to at least one of the plurality of pontoon members and the plurality of column members, and a plurality of platform retaining members mounted to one or more of the plurality of pontoon members and the plurality of column members about the inner platform receiving area. The plurality of platform retaining members is configured and disposed to selectively retain and release a platform supported by the subsea platform transporter. | ||||||
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