| 序号 | 专利名 | 申请号 | 申请日 | 公开（公告）号 | 公开（公告）日 | 发明人 |
|---|---|---|---|---|---|---|
| 161 | Drillable Oilfield Tubular Plug | US15259284 | 2016-09-08 | US20180066496A1 | 2018-03-08 | Tyler W. Blair; Bruce W. Cunningham; Timothy R. Shamburger |
| A drillable oilfield tubular plug that employs clutch faces, drilling features, anti-rotation features, and composite materials to facilitate quicker drill-out operations after the plugs have been utilized. | ||||||
| 162 | Method of using a downhole force generating tool | US14830061 | 2015-08-19 | US09903161B2 | 2018-02-27 | Roger Schultz; Brock Watson; Andy Ferguson |
| The disclosure of this application is directed to a downhole tool comprising a central element/member and a sleeve that is rotatably and orbitally disposed around the central element/member. The sleeve rotates and orbits around the central element/member responsive to fluid flowing through the downhole too. The disclosure is also related to a method of advancing the downhole tool in a well by flowing fluid through the tool. | ||||||
| 163 | Louvered Pipe Shroud Assembly | US15627708 | 2017-06-20 | US20180003011A1 | 2018-01-04 | Donald H. Michel; Steven Mark Everritt |
| Embodiments of an apparatus of the present invention generally include a filtration assembly having a louvered shroud circumferentially positioned around a perforated inner pipe, such that at least a substantial portion of the shroud's inner surface contacts and frictionally engages the outer surface of the inner pipe. Embodiments of a method of the present invention generally include spirally wrapping a substantially flat strip of louvered material around the inner pipe, wherein adjoining edges of the louvered material abut and are at least partially welded together, to provide the shrouded pipe. Other method embodiments generally include an inner pipe having a louvered shroud positioned there around being introduced to a device operable to, dynamically or statically, radially compress the shroud such that at least a substantial portion of the shroud's inner surface contacts and frictionally engages at least a substantial portion of the outer surface of the inner pipe. | ||||||
| 164 | Downhole force generating tool | US14828157 | 2015-08-17 | US09840873B2 | 2017-12-12 | Roger Schultz; Brock Watson; Andy Ferguson |
| The disclosure of this application is directed to a downhole tool comprising a central element/member and a sleeve that is rotatably and orbitally disposed around the central element/member. The sleeve rotates and orbits around the central element/member responsive to fluid flowing through the downhole too. The disclosure is also related to a method of advancing the downhole tool in a well by flowing fluid through the tool. | ||||||
| 165 | Method of using a downhole force generating tool | US14813980 | 2015-07-30 | US09840872B2 | 2017-12-12 | Roger Schultz; Brock Watson; Andy Ferguson |
| The disclosure of this application is directed to a downhole tool comprising a central element/member and a sleeve that is rotatably and orbitally disposed around the central element/member. The sleeve rotates and orbits around the central element/member responsive to fluid flowing through the downhole too. The disclosure is also related to a method of advancing the downhole tool in a well by flowing fluid through the tool. | ||||||
| 166 | Helical screw pile | US14833166 | 2015-08-24 | US09598831B2 | 2017-03-21 | Alan Lutenegger; Gary Seider |
| A helical screw pile includes a longitudinal shaft having a top end and a bottom end with a plurality of helical plates arranged on the shaft in increasing diameter from the top to the bottom. The largest diameter helical plate is located toward the bottom of the shaft. A second helical plate having a diameter smaller than that of the first plate is located above the first helical plate. A smaller third helical plate is located above the second helical plate so that the smallest is located toward the top of the shaft. The helical plates can be spaced apart along the shaft or coupled together in an end-to-end manner to form a continuous helix. | ||||||
| 167 | Well Logging With Autonomous Robotic Diver | US14899066 | 2014-11-13 | US20160369620A1 | 2016-12-22 | Michael T. Pelletier; David L. Perkins |
| A logging apparatus for use in a well can include at least one sensor that senses a well parameter, at least one buoyancy control device, and the logging apparatus extending helically between opposite ends of the logging apparatus. A method of logging in a subterranean well can include installing at least one logging apparatus in the well, and the logging apparatus helically displacing in the well as a sensor of the logging apparatus senses a well parameter. A well system can include at least one logging apparatus disposed in a wellbore, the logging apparatus including multiple segments, the segments including at least one buoyancy control device and at least one sensor that senses a well parameter, and the segments being helically arranged in the wellbore. | ||||||
| 168 | Drill string tubular component | US14348510 | 2012-09-07 | US09493998B2 | 2016-11-15 | Krzysztof Machocki |
| A drill string tubular component for use in an oil or gas well, in the form of a tubular having a central bore and a mechanism for mobilizing drill cuttings comprising at least one radial impeller (30) configured to apply radial thrust cuttings passing it, the radial impeller being located between first and second axial impellers (10, 20) configured to apply axial thrust to the fluids in opposite directions. Typically helical components of the first and second axial impellers extend in respective opposite directions, typically toward the radial impeller. Fluids are thus diverted radially away from the outer surface of the tubular component, and thereby enter a more turbulent region of the annulus, there reducing the tendency of the drill cuttings to settle out of suspension. | ||||||
| 169 | Bidirectional stabilizer with impact arrestors | US14981376 | 2015-12-28 | US09470048B1 | 2016-10-18 | Lee Morgan Smith; Betty A. Eastup-Smith |
| A bidirectional stabilizer which reduces impact damage while rotating into and out of a wellbore. The bidirectional stabilizer can be coupled on a first end to a drill string and on a second end to a drill bit. The bidirectional stabilizer can have an annulus configured for maximum wellbore fluid flow. A cutting portion can be formed on a shaft with a plurality of helical blades between the first shaft end and the second shaft end. The plurality of helical blades of the cutting portion can be on a first plane and a plurality of cutting nodes can be on a second plane for smoothing a wellbore. The plurality of cutting nodes can have at least one impact arrestor mounted directly adjacent each cutting node. | ||||||
| 170 | SUPERHYDROPHIC FLOW CONTROL DEVICE | US14398151 | 2013-11-25 | US20160264856A1 | 2016-09-15 | Luke William Holderman; Jean-Marc Lopez; Liang Zhao; Michael L. Fripp |
| A wellbore subassembly is provided that includes a device having a production flow path toward a production tubing. The production flow path can include a superhydrophobic coating for restricting the production of an unwanted fluid towards the production tubing. | ||||||
| 171 | DOWNHOLE HOLE CLEANING JOINTS AND METHOD OF USING SAME | US15031670 | 2014-10-22 | US20160237764A1 | 2016-08-18 | Michael Joseph Jellison; Guillaume Plessis; Andrei Muradov; John Forester Price; Stephen C. Hain |
| A hole cleaning joint for a drill string is deployed into a wellbore penetrating a subterranean formation. The hole cleaning joint includes a tubular body connectable to the drill string and a hole cleaning section positionable about the tubular body. The hole cleaning section has an outer surface engageable with a wall of the well bore. The outer surface has spiral grooves extending therein defining blades therebetween, and an uphole end and a downhole end with a spiral cavity therebetween. The spiral cavity has a width that decreases towards the uphole end of the spiral cavity to define a tapered flow channel to receive cuttings therethrough whereby uphole movement of cuttings is facilitated during drilling. | ||||||
| 172 | DRILL STRING ELEMENT WITH A FLUID ACTIVATION AREA | US14234542 | 2013-06-12 | US20150361729A1 | 2015-12-17 | Christophe ROHART; Thomas DIDRY |
| A tubular element (3) for a drill stem comprising a substantially cylindrical body (12) and two tool joints (4, 5), each tool joint being disposed at one end of the body and provided with a threaded portion (18, 19) which can be joined to a complementary element, at least one of the tool joints having a lifting surface (22) which can cooperate with a lifting tool of the element to connect it into a drill stem, characterized in that the lifting surface has a non-circular cross-section forming an activation zone (24) for a drilling fluid. | ||||||
| 173 | Bidirectional dual eccentric reamer | US14717969 | 2015-05-20 | US09151119B1 | 2015-10-06 | Lee Morgan Smith |
| A bidirectional dual eccentric reamer which can form a larger wellbore than originally drilled and a wellbore larger than the drill bit diameter. The bidirectional dual eccentric reamer can have a shaft with a longitudinal axis supporting a plurality of reamer portions. The reamer portions have a plurality of helical blades of varying thicknesses. The plurality of helical blades can have a plurality of cutting nodes and cutting inserts. The plurality of helical blades can have a center of eccentric rotation which is offset from the longitudinal axis, thereby creating an eccentric rotation. This allows for the formation of a larger wellbore than originally drilled and a wellbore larger than the drill bit diameter. | ||||||
| 174 | Downhole force generating tool | US14551791 | 2014-11-24 | US09140069B2 | 2015-09-22 | Roger Schultz; Brock Watson; Andy Ferguson |
| The disclosure of this application is directed to a downhole tool comprising a central element/member and a sleeve that is rotatably and orbitally disposed around the central element/member. The sleeve rotates and orbits around the central element/member responsive to fluid flowing through the downhole too. The disclosure is also related to a method of advancing the downhole tool in a well by flowing fluid through the tool. | ||||||
| 175 | Grooved drill string components and drilling methods | US13570902 | 2012-08-09 | US08955621B1 | 2015-02-17 | Brandon Barrett Eads; Paul Gregory Kates |
| This specification discloses a drilling string, including drill pipe, drill collar, or sub for use in drilling operations, comprising at least one upset that has an outer surface having a plurality of grooves, wherein at least one of the grooves comprise a curved leading edge that is generally convex, a leading side, a trough having a generally convex curvature, a trailing side that extends in a substantially radial direction, and a trailing edge. The groove configuration results in improved transport of drilling fluids and cuttings and is especially beneficial for use in directional drilling operations. | ||||||
| 176 | DRILL STRING TUBULAR COMPONENT | US14348510 | 2012-09-07 | US20140299380A1 | 2014-10-09 | Krzysztof Machocki |
| A drill string tubular component for use in an oil or gas well, in the form of a tubular having a central bore and a mechanism for mobilising drill cuttings comprising at least one radial impeller (30) configured to apply radial thrust cuttings passing it, the radial impeller being located between first and second axial impellers (10, 20) configured to apply axial thrust to the fluids in opposite directions. Typically helical components of the first and second axial impellers extend in respective opposite directions, typically toward the radial impeller. Fluids are thus diverted radially away from the outer surface of the tubular component, and thereby enter a more turbulent region of the annulus, there reducing the tendency of the drill cuttings to settle out of suspension. | ||||||
| 177 | HELICAL SCREW PILE | US14353974 | 2012-10-24 | US20140286712A1 | 2014-09-25 | Alan Lutenegger; Gary Seider |
| A helical screw pile includes a longitudinal shaft having a top end and a bottom end with a plurality of helical plates arranged on the shaft in increasing diameter from the top to the bottom. The largest diameter helical plate is located toward the bottom of the shaft. A second helical plate having a diameter smaller than that of the first plate is located above the first helical plate. A smaller third helical plate is located above the second helical plate so that the smallest is located toward the top of the shaft. The helical plates can be spaced apart along the shaft or coupled together in an end-to-end manner to form a continuous helix. | ||||||
| 178 | PLUG COUNTER AND DOWNHOLE TOOL | US13910597 | 2013-06-05 | US20130264049A1 | 2013-10-10 | Hector H. Mireles |
| A plug counter including a housing sized to receive and pass plugs. A helix sleeve rotatably positioned relative to the housing. The helix sleeve including a helical track having a plurality of consecutive turns. A key positionable relative to the helical track and responsive to movement of the helix sleeve in a first rotational direction, wherein the key prevents further movement of the helix sleeve in the first rotational direction after a selected number of plugs pass through the plug counter. Also included is a downhole tool including | ||||||
| 179 | AUGER | US13349050 | 2012-01-12 | US20120205161A1 | 2012-08-16 | Andreas STIMPFLE-ZIEGLER |
| The invention relates to an auger having a cutting means for removing ground material and a conveyor flight for conveying the ground material removed by the cutting means, whereby the conveyor flight has several conveyor flight pieces which are arranged along an axial direction of the auger and connected to each other in a detachable manner. Provision is made for a central receiving shaft, on which the cutting means is arranged in a rotationally fixed manner. Furthermore, provision is made for the conveyor flight pieces of the conveyor flight to have a mounting pipe each, which is mounted onto the central receiving shaft, whereby the central receiving shaft projects through the mounting pipe, and for the conveyor flight pieces to be connected in a rotationally fixed manner to the central receiving shaft. | ||||||
| 180 | PLUG COUNTER AND METHOD | US12564539 | 2009-09-22 | US20110067888A1 | 2011-03-24 | Hector H. Mireles |
| A plug counter including a j-slot sleeve; a helix sleeve in operable communication with the j-slot sleeve such that axial movement of the j-slot sleeve causes rotational movement of the helix sleeve; an anti-rotation sleeve disposed about the helix sleeve and having a keyway therein; and a key disposed in the keyway and responsive to movement of the helix sleeve and method. | ||||||
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