| 序号 | 专利名 | 申请号 | 申请日 | 公开（公告）号 | 公开（公告）日 | 发明人 |
|---|---|---|---|---|---|---|
| 261 | CURVED LINKS FOR WIRING CONDUIT | US15737633 | 2015-07-28 | US20180155990A1 | 2018-06-07 | Shao Hwa Lee; Hong Jin Lau |
| A downhole tool is disclosed. The downhole tool may include an actuator having a housing, a shaft extending through at least a portion of the housing, and a nut movably disposed on the shaft. Further, the downhole tool may include a wiring conduit disposed in a helix shape around the shaft, and extending between the nut and a fixed position relative to the shaft. The wiring conduit may include a plurality of curved links. Each of the plurality of curved links may include a first hinge and a second hinge, the first hinge of a first curved link pivotably coupled to the second hinge of a second curved link. The downhole tool may also include a wire routed through the wiring conduit. | ||||||
| 262 | COMPOSITE CENTRALIZER BLADE | US15326770 | 2014-08-18 | US20170204685A1 | 2017-07-20 | Bo Gao; Nicholas Budler |
| In accordance with embodiments of the present disclosure, a centralizer for aligning a tubular in a wellbore includes a stepped centralizer feature. The stepped centralizer feature includes a composite material with a stepped profile. That is, the stepped centralizer feature includes a first layer of the composite material having a convex rounded side for interfacing with the tubular, and a second layer of the composite material extending from the first layer. The first layer is wider than the second layer. The stepped centralizer feature may be a centralizer blade bonded to an outer surface of the tubular, or a stop collar used to hold a centralizer spring in place on the tubular. The stepped centralizer feature helps to distribute stress through the centralizer feature so that the centralizer feature does not crack or de-bond from the tubular in low temperature, high pressure environments. | ||||||
| 263 | SOIL AUGER AND METHOD OF MANUFACTURE | US15303154 | 2015-04-10 | US20170120315A1 | 2017-05-04 | Peter Tucker |
| An auger useable for creating an opening in the ground for a soil sensor housing wherein the sensor housing has a predetermined volume and a tapered outer surface, includes an auger made in accordance with the methods described and defined in this specification. The auger having a shaft having an outer surface of circular cross-section having an larger outer diameter at one end than the other end and a strip material having a helical shape with an inner wall having a larger inner diameter at one end than the other end of the helical shape wherein the helically shaped material is fixed over the outer diameter of the shaft to form a tapered auger with helical flighting. The volume of the opening created by an auger in the ground will provide a matching volume for a sensor housing of a predetermined volume such that substantially the full length of the tapered outer surface of the sensor is adjacent the ground along the full length/depth of the created opening. | ||||||
| 264 | TOP-DOWN FRACTURING SYSTEM | US15224345 | 2016-07-29 | US20170030168A1 | 2017-02-02 | Neil H. AKKERMAN; John A. BARTON |
| A valve for use in a wellbore includes a housing including a housing port, a slidable closure member disposed in a bore of the housing and including a closure member port, and a seal disposed in the housing, wherein the closure member includes a first position in the housing where fluid communication is provided between the closure member port and the housing port, and a second position axially spaced from the first position where fluid communication between the closure member port and the housing port is restricted, wherein, in response to sealing of the bore of the housing by an obturating member sealingly engaging the seal, the closure member is configured to actuate from the first position to the second position. | ||||||
| 265 | Segmented strake concepts | US14293775 | 2014-06-02 | US09523456B1 | 2016-12-20 | Donald Wayne Allen; Julie Ann Dehne |
| Concepts for segmented helical strakes are presented herein. In one embodiment, the segmented helical strake includes a fin segment. The fin segment includes a fin body having an interior surface defining a substantially hollow interior area. The fin segment further includes a receiving member formed along the interior surface, wherein the receiving member is dimensioned to secure the fin body to a fin core positioned around a tubular. A segmented strake according to one embodiment may include a fin segment having an interior surface defining a substantially hollow interior area and a receiving member formed within the interior area. The segmented strake may further include a fin core positioned within the receiving member. | ||||||
| 266 | METHODS, STRINGS AND TOOLS TO ENHANCE WELLBORE FRACTURING | US15027192 | 2014-10-06 | US20160245062A1 | 2016-08-25 | DANIEL JON THEMIG |
| A tubing string external structure forms a pathway in a cemented annulus that extends from a fluid treatment port axially away from the port and along a length of the tubing string. Wellbore treatment fluids can be injected through the tubing string and through the pathway to contact the wellbore wall along a length greater than the axial length of the port. | ||||||
| 267 | Apparatus and method for positioning of a fluidized plugging material in an oil well or gas well | US14003424 | 2012-03-20 | US09416618B2 | 2016-08-16 | Arne Gunnar Larsen; Roy Inge Jensen; Patrick Andersen; Morten Myhre |
| An apparatus and a method are for supplying a fluidized plugging material to a well. The apparatus includes: a carrier body defined by an indefinite side portion extending between a first end portion and a second end portion, the carrier body being arranged to be set in motion by a driving device; and at least one displacement member arranged on the carrier body, the displacement member being defined by the surface of the carrier body and a free end portion facing the inside of the casing, and the driving device being arranged to set the carrier body and the displacement member in motion in the bore of the casing, so that the fluidized plugging material is set in motion within the bore of the casing. | ||||||
| 268 | METHOD AND APPARATUS TO ROTATE SUBSURFACE WELLBORE CASING | US14979105 | 2015-12-22 | US20160177637A1 | 2016-06-23 | William W. Fleckenstein; Alfred W. Eustes |
| Embodiments of the present invention are generally related to a method and apparatus for subterranean wellbores and in particular, to a method and apparatus for rotating a subsurface tubular string, such as a casing section, without rotation at the surface. More specifically, a casing section of a wellbore may be rotated to provide a cement seal with increased strength and reliability. In one embodiment, a downhole tool and rotation assembly is disclosed which imparts a torsional force to a predetermined casing section when a fluid is flowed through the downhole tool and rotation assembly. | ||||||
| 269 | DOWNHOLE FORCE GENERATING TOOL | US14828183 | 2015-08-17 | US20150354281A1 | 2015-12-10 | 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. | ||||||
| 270 | METHOD OF USING A DOWNHOLE FORCE GENERATING TOOL | US14813980 | 2015-07-30 | US20150337602A1 | 2015-11-26 | 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. | ||||||
| 271 | Apparatus and Method for Positioning of a Fluidized Plugging Material in an Oil Well or Gas Well | US14003424 | 2012-03-20 | US20150308219A1 | 2015-10-29 | Arne Gunnar Larsen; Roy Inge Jensen; Patrick Andersen; Morten Myhre |
| An apparatus and a method are for supplying a fluidized plugging material to a well. The apparatus includes: a carrier body defined by an indefinite side portion extending between a first end portion and a second end portion, the carrier body being arranged to be set in motion by a driving device; and at least one displacement member arranged on the carrier body, the displacement member being defined by the surface of the carrier body and a free end portion facing the inside of the casing, and the driving device being arranged to set the carrier body and the displacement member in motion in the bore of the casing, so that the fluidized plugging material is set in motion within the bore of the casing. | ||||||
| 272 | Variable geometry auger coupler | US13604140 | 2012-09-05 | US09127513B2 | 2015-09-08 | Eric Matthias |
| An auger attachment system having a collar combined with an auger and one or more couplers each having a first end and a second end. The coupler first end is adapted to operatively combine with the output drive shaft of an engine suitable for rotating an auger. Each coupler has a different size and/or geometry at their respective first ends to allow each coupler to combine with a drive shaft having the corresponding size and geometry. The coupler second end is adapted to combine with the collar thereby allowing a single auger to be used with multiple drive shafts, each having a different size and/or geometry. | ||||||
| 273 | Helical screw pile | US14353974 | 2012-10-24 | US09115478B2 | 2015-08-25 | 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. | ||||||
| 274 | Fixed swirl inducing blast liner | US12134975 | 2008-06-06 | US08678079B2 | 2014-03-25 | Nicholas J. Clem; Martin P. Coronado |
| Wear is reduced in abrasive slurry service at an outlet into an annular space defined by the wellbore and around the tool. In a gravel packing application with a crossover, the slurry exits a central passage and goes into an internal annulus in the tool. Turning vanes that make at least one full turn and that have a height at least partially the height of the annular space are there to impart a swirl movement to at least a portion of the slurry stream. The swirling motion has beneficial effects of reducing turbulence which allows a velocity reduction for a comparable output volume. | ||||||
| 275 | Drilling cuttings mobilizer and method for use | US12550192 | 2009-08-28 | US08336645B2 | 2012-12-25 | Daniel Robson; Christopher Konschuh; Laurier Comeau; Paul Sibbald |
| A rotating drill string sub redistributes wellbore drill cuttings into the drilling fluid flowstream to improve the efficiency of the drilling operation. Standoff elements are located on each side of an agitator, all configured on a relatively short section of drill pipe. The agitator comprises a plurality of alternating blades standing radially outward from and arranged helically about the axis of the sub, and grooves located between pairs of adjacent blades, each groove comprising a flow channel that is open at both ends of the agitator. The standoff elements contain abutment surfaces having an outer diameter greater than the outer diameter of the agitator, so that the agitator is prevented from contacting the wall of the wellbore and therefore does not experience the forces that the standoff elements experience. | ||||||
| 276 | Rod Guide With Wrapping Vanes | US13111361 | 2011-05-19 | US20120292021A1 | 2012-11-22 | Daryl Kaltwasser |
| A sucker rod guide includes a pair of vanes, offset from one another by 180°, with each vane wrapping approximately 180° around the rod guide. The vanes wrap around the body of the guide, and are neither spiral nor helical because the surfaces of the vanes extending radially outwardly from the body of the rod guide define two dimensional planar surfaces, i.e. flat planes. The vane thickness varies from a maximum at each end of the vane to a minimum at a midway point along the vane. This shape assists in moving fluid up the production tubing when the guide is applied to a rotary system, such as a progressive cavity pump. This shape also enhances the erodable volume of the vanes at the extremities, while providing a less inhibiting path for the flow of fluid in reciprocating applications. | ||||||
| 277 | Tubular Casing Member with Helical Threads | US12893900 | 2010-09-29 | US20120073695A1 | 2012-03-29 | Donald Patrick Muth |
| A drilling device for use in a wellbore may include a tubular casing member having an external surface, and a thread member positioned on the exterior surface of the tubular casing member. The thread member may form a spiral on the exterior surface of the tubular casing member. The thread member may have a pentagonal cross section. The thread member may have a pitched cross section. The thread member may have a triangular cross-section. The thread member may have a convex cross-section. The thread member may have a concave cross-section. The thread member may have a rectangular cross section. | ||||||
| 278 | Olefin production furnace having a furnace coil | US11575730 | 2005-09-21 | US08088345B2 | 2012-01-03 | Colin G. Caro; Philip L. Birch; William Tallis |
| The present invention relates to piping (1) for use in industrial activities, where the piping (1) has a specific geometry. In particular, the piping (1) is formed as a lowamplitude helix, which causes fluid flowing through the piping (1) to swirl. This swirl flow provides a large number of advantages. Particular applications where the piping (1) can be used include petroleum production risers and flowlines, production tubing for downhole use in wells, pipelines for the transportation of fluids, static mixers, bends, junctions or the like, penstocks and draft tubes, reactors for chemical, petrochemical, and pharmaceutical applications, heat exchangers, cold boxes, incinerators and furnaces for waste disposal, static separators, and air intakes. | ||||||
| 279 | PERFORATING GUN ASSEMBLY TO CONTROL WELLBORE FLUID DYNAMICS | US13159946 | 2011-06-14 | US20110284246A1 | 2011-11-24 | William D. Myers; Alphie S. Wright |
| A downhole tool used in the pressure isolation of adjacent subterranean formations. The downhole tool may comprise flow restriction devices along the outer circumference for impeding flow along the length of the tool. The tool may further comprise a perforating gun and an accumulator. Impeding flow along the length of the tool provides a dynamic flow restriction within the wellbore that precludes fluid flowing from one subterranean zone to an adjacent zone. | ||||||
| 280 | DRILLING CUTTINGS MOBILIZER | US12550192 | 2009-08-28 | US20110048803A1 | 2011-03-03 | DANIEL ROBSON; CHRISTOPHER KONSCHUH; LAURIER COMEAU; PAUL SIBBALD |
| A rotating drill string sub redistributes wellbore drill cuttings into the drilling fluid flowstream to improve the efficiency of the drilling operation. Standoff elements are located on each side of an agitator, all configured on a relatively short section of drill pipe. The agitator comprises a plurality of alternating blades standing radially outward from and arranged helically about the axis of the sub, and grooves located between pairs of adjacent blades, each groove comprising a flow channel that is open at both ends of the agitator. The standoff elements contain abutment surfaces having an outer diameter greater than the outer diameter of the agitator, so that the agitator is prevented from contacting the wall of the wellbore and therefore does not experience the forces that the standoff elements experience. | ||||||
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