子分类：
- E21B29/002： .{用沿着管子周围转动的切割器切割管子,例如,研磨}
- E21B29/02： .使用炸药或热力或化学方法(通过爆炸释放粘住的物品入E21B31/002;通过爆炸破坏井眼或井中的物体入E21B31/16)
- E21B29/04： .切割钢丝绳或类似物(E21B29/02优先)
- E21B29/06： .切割窗口,例如,用于造斜器操作的定向窗口切割器(E21B29/005和E21B29/08优先;造斜器入E21B7/061)
- E21B29/08： .切割管道或使管道变形来控制液体流动(剪切型防喷器入E21B33/06)
- E21B29/10： .修复井筒,例如,调直
- E21B29/12： .专门适用于水下安装的(E21B29/08优先)
| 序号 | 专利名 | 申请号 | 申请日 | 公开（公告）号 | 公开（公告）日 | 发明人 |
|---|---|---|---|---|---|---|
| 301 | Rotatable Wireline Tool of Enhanced Hydraulic Drive Consistency | US13316239 | 2011-12-09 | US20120145394A1 | 2012-06-14 | Michael Jensen; Ruben Martinez |
| A rotatable downhole cutting tool configured for enhanced drive consistency in low power circumstances. The tool is equipped with a hydraulic axial drive actuator suitable for use in wireline deployment. The actuator itself includes a reciprocating piston with a ball screw that threadably interfaces a ball nut for dampening the axial drive imparted by the piston. As such, even though hydraulically driven at generally well under about 10 horsepower, bounce in the axial drive is substantially eliminated. This is particularly advantageous where cutting is to be applied to downhole metal based obstructions. | ||||||
| 302 | Method and apparatus for cutting and removing pipe from a well | US13136339 | 2011-07-29 | US20120048535A1 | 2012-03-01 | David J. Ruttley; Charles Larue Bryant, JR. |
| A lifting apparatus for supporting tubular goods that can be used to perform down-hole operations in oil and gas wells. The lifting apparatus has push and pull capability, a minimal footprint, and requires minimal surface area to operate. The support apparatus can be used to jack and remove casing and other pipe, such as during plugging and abandonment operations, and to perform other rig-less downhole well operations. | ||||||
| 303 | WELL ASSEMBLY COUPLING | US12789822 | 2010-05-28 | US20110290476A1 | 2011-12-01 | David Joe Steele; Srinivasa Prasanna Vemuri |
| Assemblies that can be disposed in a subterranean bore and that can facilitate branch wellbore creation are described. An assembly can include threadedly coupled components having inner and outer sealing members in grooves. The sealing member can cooperate with the components to provide a pressure seal. The assembly can also include a venting member for equalizing pressure in a chamber defined by the coupled components. One of the components can be made from aluminum. At least part of that component can be coated with a coating material that is nonconductive. | ||||||
| 304 | CUTTING DART AND METHOD OF USING THE CUTTING DART | US12784311 | 2010-05-20 | US20110284224A1 | 2011-11-24 | John G. Misselbrook; Manfred Sach; Jason M. Skufca |
| The present disclosure is directed to a cutting dart. The cutting dart comprises a dart body including a first pathway. The first pathway is configured to redirect cutting fluid flowing through a coiled tubing so that the cutting fluid flows radially to impinge against an inner surface of the coiled tubing. A seal is positioned around an outer circumference of the dart body. The present disclosure is also directed to an anchor dart. The anchor dart comprises a dart body and a swellable elastomer positioned around an outer circumference of the dart body. Methods of employing the cutting dart and anchor dart are also disclosed. | ||||||
| 305 | Shearing tool and methods of use | US13136035 | 2011-07-21 | US20110278020A1 | 2011-11-17 | James Edward Chambers, II; Gerald Robert Byrd |
| A shearing tool for shearing, trimming, or reducing objects being pulled through a drill string and methods for retrieving retrievable tools with fins from the drill string, where the retrievable tools must pass through restrictions in the drill string having interior diameters less than the outer diameters of the fins. The fins, affixed to the retrievable tools, provide stability to the tools, while within the drill string, and can be made of rubber, plastic, other shearable materials, or combinations thereof. The apparatuses and methods include inserting a shearing tool with a flange into a box end of a section of drill string, where the flange keeps the shearing tool in place. The shearing tool further comprising a cutting surface for cutting materials pulled through the shearing tool. | ||||||
| 306 | Downhole assembly and cutter assembly | US12848921 | 2010-08-02 | US08051928B2 | 2011-11-08 | Daryl Richard Henry Stroud; Robert Donald John Sedgeman; Colin Walker |
| This invention relates to a downhole assembly and to a cutter assembly, and in particular to a downhole assembly including an apparatus for breaking up large-scale material which is present behind a drill bit, and to a cutter assembly for use in such a downhole assembly. The downhole assembly is suitably for use in a drillstring, the downhole assembly comprising a drill bit, a sensitive component, and at least one rotatable set of cutter blades located between the drill bit and the sensitive component. | ||||||
| 307 | METHOD OF TESTING A PIPELINE CUT | US13119212 | 2009-09-25 | US20110209540A1 | 2011-09-01 | Steve Banks; Peter Robinson; Anthony Peyton; David Armitage |
| A method of testing the through cut of a pipeline comprising at least the steps of: (a) transmitting an electromagnetic signal through the pipeline; (b) monitoring any reflected signal(s); and (c) interpreting the or each reflected signal to test for the through cut of the pipeline. In this way, a non-invasive electromagnetic signal can be passed through, along, across or otherwise within the pipeline, and any reflected signal(s) can be interpreted and analysed based on one or more characteristics of the received signal(s) to ascertain the change in the conductivity of the pipeline due to the cutting thereof, in particular when or whether the cutting of the pipeline is complete or has been completed such that there is a through cut. | ||||||
| 308 | METHODS OF DRILLING USING DIFFERING TYPES OF CUTTING ELEMENTS | US13098976 | 2011-05-02 | US20110203850A1 | 2011-08-25 | Eric E. McClain; John C. Thomas; Sarvesh Tyagi; Jack T. Oldham; Lester I. Clark; William Heuser |
| A drill bit includes a bit body having a face on which two different types of cutting elements are disposed, the first type being cutting elements suitable for drilling at least one subterranean formation and the second type being cutting elements suitable for drilling through a casing bit disposed at an end of a casing or liner string and cementing equipment or other components, if such are disposed within the casing or liner string, as well as cement inside as well as exterior to the casing or liner string. The second type of cutting elements exhibits a relatively greater exposure than the first type of cutting elements, so as to engage the interior of the casing bit and, if present, cementing equipment components and cement to drill therethrough, after which the second type of cutting elements quickly wears upon engagement with the subterranean formation material exterior to the casing bit, and the first type of cutting elements continues to drill the subterranean formation. The first type of cutting elements may comprise superabrasive cutting elements and the second type of cutting elements may comprise abrasive or superabrasive cutting elements comprising a plurality of configurations. | ||||||
| 309 | Cutting elements configured for casing component drillout and earth boring drill bits including same | US11524503 | 2006-09-20 | US07954570B2 | 2011-06-07 | Eric E. McClain; John C. Thomas; Sarvesh Tyagi; Jack T. Oldham; Lester I. Clark; William Heuser |
| A drill bit includes a bit body having a face on which two different types of cutting elements are disposed, the first type being cutting elements suitable for drilling at least one subterranean formation and the second type being cutting elements suitable for drilling through a casing bit disposed at an end of a casing or liner string and cementing equipment or other components, if such are disposed within the casing or liner string, as well as cement inside as well as exterior to the casing or liner string. The second type of cutting elements exhibits a relatively greater exposure than the first type of cutting elements, so as to engage the interior of the casing bit and, if present, cementing equipment components and cement to drill therethrough, after which the second type of cutting elements quickly wears upon engagement with the subterranean formation material exterior to the casing bit, and the first type of cutting elements continues to drill the subterranean formation. The first type of cutting elements may comprise superabrasive cutting elements and the second type of cutting elements may comprise abrasive or superabrasive cutting elements comprising a plurality of configurations. | ||||||
| 310 | Method and apparatus for expanding and separating tubulars in a wellbore | US12119216 | 2008-05-12 | US07921925B2 | 2011-04-12 | Patrick G. Maguire; Robert J. Coon; Neil Andrew Abercrombie Simpson |
| Embodiments of the present invention provide an apparatus and method for expanding a tubular. In one aspect, embodiments of the prevent invention provide an expander tool having at least two expansion members radially extendable from the expander tool into contact with a surrounding inside surface of the tubular, the at least two expansion members radially extendable at different times and axially spaced after radially extending. In another aspect, embodiments include a method for isolating a first portion of a wellbore from a second portion of a wellbore comprising locating an expandable tubular within the wellbore between the first and second portions, the expandable tubular having a weakened portion therein, isolating the first portion from the second portion of the wellbore, and expanding the expandable tubular proximate to the weakened portion to sever the expandable tubular. | ||||||
| 311 | Downhole Casing Cutting Tool | US12501788 | 2009-07-13 | US20110005755A1 | 2011-01-13 | Wesley P. Dietz; David J. Steele |
| An oilfield downhole cutting tool is provided. The cutting tool comprises a tool body that comprises a non-cutting stabilizing section. The cutting tool further comprises a plurality of cutters coupled to the tool body forward of the non-cutting stabilizing section, wherein a maximum cutting diameter defined by the cutters is less than 1.1 times a diameter defined by the non-cutting stabilizing section. The cutting tool further comprises a cutting rate limiting component coupled to the tool body. | ||||||
| 312 | Method for adapting a tubular element in a subsiding wellbore | US11792574 | 2005-12-08 | US07861783B2 | 2011-01-04 | Matheus Norbertus Baaijens; Wilhelmus Christianus Maria Lohbeck; Paul Dirk Schilte |
| A method for adapting a tubular element extending into a wellbore formed in an earth formation, where the tubular element is susceptible to damage caused by axially compressive forces acting on the tubular element as a result of compaction of the earth formation surrounding the tubular element. The method comprises the steps of reducing the axial stiffness of at least one section of the tubular element, and allowing each tubular element section of reduced axial stiffness to be axially compressed by the action of said axially compressive forces, thereby accommodating compaction of the earth formation surrounding the tubular element. | ||||||
| 313 | Convertible downhole devices and method of performing downhole operations using convertible downhole devices | US12221746 | 2008-08-06 | US07775286B2 | 2010-08-17 | Darin H. Duphorne |
| A convertible downhole device comprises at least one sacrificial material to provide two or more configurations so that two or more different operations or functions are performable by the downhole device, one in which the sacrificial material is fully intact and another in which the sacrificial material is at least partially removed or disappeared. The sacrificial material may be removable through any suitable method or device, such as by contacting with a fluid, by temperature, by pressure, or by combustion, ignition, or activation of a fusible or energetic material, or crushing or breaking up of a frangible material. Upon removal of the sacrificial material, the downhole device has at least one additional configuration so that at least a second operation can be performed by the downhole device. | ||||||
| 314 | Method of Direct Hot Tapping Into A Multiple Production String Without Removing Outer Layers of Casing | US12276863 | 2008-11-24 | US20100084024A1 | 2010-04-08 | Martin Cenac; Richard J. Robichaux; John William Angers, JR. |
| A method of hot tapping into a multiple string configuration for obtaining access to the production tubing without removing outer layers of casing by providing a multiple casing string that includes at least an outer casing and an inner casing or production string; mounting a clamp assembly around the wall of the outer casing; hot tapping a small opening through the outer casing wall to capture any pressurized fluid through the opening; cutting first and second large openings through the wall of the outer casing to access the inner casing, each opening being approximately 180 degrees from the other opening; through the first opening, drilling a small hole through the wall of the inner casing to capture any pressurized fluid through the opening in the inner casing; and inserting an anvil through the second opening to contact and stabilize the wall of the inner casing to prevent the casing from moving while the casing is drilled. | ||||||
| 315 | METHODS AND APPARATUS FOR REMOVAL AND CONTROL OF MATERIAL IN LASER DRILLING OF A BOREHOLE | US12543968 | 2009-08-19 | US20100044102A1 | 2010-02-25 | Charles C. Rinzler; Mark S. Zediker; Brian O. Faircloth; Joel F. Moxley |
| There is provided a system, apparatus and methods for removal of material for the path of a laser beam during laser drilling of a borehole and for removal of displaced borehole material from the borehole during laser drilling. In particular, there are provided paths, dynamics and parameters of fluid flows, and apparatus for obtaining such, for use in conjunction with a laser bottom hole assembly. | ||||||
| 316 | Borehole Imaging and Orientation of Downhole Tools | US11964145 | 2007-12-26 | US20090166035A1 | 2009-07-02 | James S. Almaguer |
| Methods of generating radial survey images of a borehole and methods of orienting downhole operational tools are disclosed. The disclosed techniques are used to generate a radial survey of the borehole in the form of one or more rose-plots and/or a radial image of the borehole and surrounding area that can be used to properly orient downhole operational tools in the desired direction. The tool string includes, from the top to bottom, a telemetry module, a non-rotating centralizer, a motor module, an imaging sonde used to survey the borehole, a rotating centralizer and a downhole operational tool. The motor module can be used to rotate the imaging sonde to generate the radial survey and then rotate the downhole operational tool to the desired direction based upon a review of the radial survey. | ||||||
| 317 | Methods for expanding tubular strings and isolating subterranean zones | US11865850 | 2007-10-02 | US07543637B2 | 2009-06-09 | Annabel Green; Lev Ring; Colin McHardy; Simon Harrall; Gary Johnston; Neil A. A. Simpson |
| Methods relate to tubulars that may be part of a tubular string for isolating one or more zones within a wellbore. In one embodiment, the tubular string includes a first expandable zone isolation unit disposed on a first side of a zone to be isolated, a second expandable zone isolation unit disposed on a second side of the zone to be isolated, and a perforated tubular disposed in fluid communication with a producing zone. The tubular string may be expanded using an expansion assembly having a first expander for expanding the first and second expandable zone isolation units and a second expander for expanding the at least one perforated tubular. Tags or markers along the tubular string may indicate locations where expansion is desired such that connections or connectors between joints are not expanded. | ||||||
| 318 | METHOD AND APPARATUS FOR EXPANDING AND SEPARATING TUBULARS IN A WELLBORE | US12119216 | 2008-05-12 | US20080202753A1 | 2008-08-28 | Simon John Harrall; Patrick G. Maguire; Robert J. Coon; Neil Andrew Abercrombie Simpson |
| Embodiments of the present invention provide an apparatus and method for expanding a tubular. In one aspect, embodiments of the prevent invention provide an expander tool having at least two expansion members radially extendable from the expander tool into contact with a surrounding inside surface of the tubular, the at least two expansion members radially extendable at different times and axially spaced after radially extending. In another aspect, embodiments include a method for isolating a first portion of a wellbore from a second portion of a wellbore comprising locating an expandable tubular within the wellbore between the first and second portions, the expandable tubular having a weakened portion therein, isolating the first portion from the second portion of the wellbore, and expanding the expandable tubular proximate to the weakened portion to sever the expandable tubular. | ||||||
| 319 | PRODUCTION CASING RIPPER | US11669087 | 2007-01-30 | US20080178721A1 | 2008-07-31 | Shane Schwindt |
| A production casing ripper comprising a swedge; spring housing; coupling; main housing; end piece; blade; and means for connecting the blade to the plunger; wherein the blade is situated inside of the main housing; wherein a plunger is situated inside of the main housing; wherein a primary spring is situated inside of the spring housing; wherein a primary pull rod is connected to the primary spring at one end and to the plunger at the other end; wherein when hydraulic pressure is introduced through the swedge, the plunger moves downward inside of the main housing and causes the blade to extend through an aperture in the main housing; and wherein when the hydraulic pressure is released, the primary spring causes the plunger to return to its original position, thereby causing the blade to retract. | ||||||
| 320 | Wear resistant tubular connection | US11549007 | 2006-10-12 | US20070074868A1 | 2007-04-05 | MAURICE SLACK; Robert Tessari; Per Angman; Tommy Warren |
| A wear resistant casing connection including a wear resistant portion on its exterior surface is taught. A casing connection having a controlled bend angle is also taught. | ||||||
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