序号 | 专利名 | 申请号 | 申请日 | 公开(公告)号 | 公开(公告)日 | 发明人 |
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181 | COMPRESSION ASSEMBLY AND METHOD FOR ACTUATING DOWNHOLE PACKING ELEMENTS | EP09849922.1 | 2009-09-28 | EP2483518A1 | 2012-08-08 | CLEMENS, Jack, Gammill; LUDWIG, Wesley, Neil; RODGERS, John, P.; EATON, Ed; SERRA, Marco |
A compression assembly (500) for actuating packing elements of a through tubing bridge plug in a casing string of a wellbore. The compression assembly (500) includes a support assembly (502) and an anti extrusion assembly (504). The support assembly (502) has a running configuration in which link arm assemblies are substantially longitudinally oriented and an operating configuration in which short arms (514) are pivoted relative to long arms (520) of link arm assemblies such that the short arms (514) form a support platform. The anti extrusion assembly (504) is operably associated with the support assembly (502). The anti extrusion assembly (504) has a running configuration in which petals (536) are substantially perpendicular to a base member (534) and nested relative to one another and an operating configuration in which the petals (536) are radially outwardly disposed substantially filling gaps between the short arms (514). | ||||||
182 | ANCHOR ASSEMBLY AND METHOD FOR ANCHORING A DOWNHOLE TOOL | EP09849920.5 | 2009-09-28 | EP2483517A1 | 2012-08-08 | CLEMENS, Jack, Gammill; LUDWIG, Wesley, Neil; RODGERS, John, P.; EATON, Ed; SERRA, Marco |
An anchor assembly (400) for anchoring a downhole tool in a wellbore tubular. The anchor assembly (400) includes a plurality of slip arm assemblies each having first and second arms (412, 414) hingeably coupled together. The first and second arms (412, 414) each have teeth (418, 426) on one end. A first sleeve (402) is rotatably associated with each of the first arms (412) and a second sleeve (404) is rotatably associated with each of the second arms (414) such that the anchor assembly (400) has a running configuration in which the slip arm assemblies are substantially longitudinally oriented and an operating configuration in which the first and second arms (412, 414) of each slip arm assembly form an acute angle relative to one another such that the teeth (418, 426) of the first and second arms (412, 414) define the radially outermost portion of the anchor assembly (100). | ||||||
183 | REMOTELY CONTROLLED APPARATUS FOR DOWNHOLE APPLICATIONS AND METHODS OF OPERATION | EP10821267.1 | 2010-09-30 | EP2483510A2 | 2012-08-08 | RADFORD, Steven, R.; TRINH, Khoi, Q.; HABERNAL, Jason, R.; GLASGOW, R., Keith; EVANS, John, G.; STAUFFER, Bruce; WITTE, Johannes |
An apparatus for use downhole is disclosed that, in one configuration includes a downhole tool configured to operate in an active position and an inactive position and an actuation device, which may include a control unit. The apparatus includes a telemetry unit that sends a first pattern recognition signal to the control unit to move the tool into the active position and a second pattern recognition signal to move the tool into the inactive position. The apparatus may be used for drilling a subterranean formation and include a tubular body and one or more extendable features, each positionally coupled to a track of the tubular body, and a drilling fluid flow path extending through a bore of the tubular body for conducting drilling fluid therethrough. A push sleeve is disposed within the tubular body and coupled to the one or more features. A valve assembly is disposed within the tubular body and configured to control the flow of the drilling fluid into an annular chamber in communication with the push sleeve; the valve assembly comprising a mechanically operated valve and/or an electronically operated valve. Other embodiments, including methods of operation, are provided. | ||||||
184 | Casing anchor | EP10195570.6 | 2010-12-17 | EP2466064A1 | 2012-06-20 | Hallundbæk, Jørgen |
The present invention relates to a fixation device for securing a tubular in a wellbore, the fixation device comprising a tubular part, a fixation unit and a fluid passage. Furthermore, the invention relates to a downhole fixation system for securing a casing comprising a first end and a second end in a wellbore and to a method of permanently fixating a tubular part in a wellbore. |
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185 | TOOLS AND METHODS FOR USE WITH EXPANDABLE TUBULARS | EP00971612.7 | 2000-10-27 | EP1242714B1 | 2012-06-06 | TRAHAN, Kevin, Otto; HAUGEN, David, Michael |
In one aspect of the invention, tools are actuated or operated within a well by selectively expanding the tool wall. To actuate the tool, the tool wall (225) is urged outward past its elastic limits. The expanding wall physically unlocks a locking ring (280) which then ulocks a piston (260). Thereafter, hydraulic pressure difference are employed to move the piston to operate the downhole tool. In another aspect of the invention, a first piece of casing is joined to a second, larger diameter casing. By expanding the diameter of the first piece of casing into contact with the second piece of casing, the two are joined together. The joint is formed with helical formations in a manner that provides flow paths around the intersection of the two members for the passage of cement or other fluid. | ||||||
186 | A COMPLETION ASSEMBLY AND A METHOD FOR STIMULATING, SEGMENTING AND CONTROLLING ERD WELLS | EP10724097.0 | 2010-06-22 | EP2446107A1 | 2012-05-02 | LUMBYE, Peter |
The invention relates to an assembly to be run with a well tubular having openings provided in the wall and for being arranged in a well bore and thereby forming a space between said tubing and the well bore surface. The assembly comprising: first fluid control means and second fluid control means being provided in another opening in said well tubular. The assembly further having a set of packers for sealing of the space between said tubing and the well bore surface, said set of packers being positioned such that a part the tubular having both first and second fluid control means is located between the set of packers. The first fluid control means is adapted such that it is capable of blocking fluid flow from the interior of said well tubular to said space between said tubing and the well bore surface. The second fluid control means is adapted such that it is capable of blocking fluid flow from said space between said tubing and the well bore surface to the interior of said well tubular. | ||||||
187 | Method and apparatus for retrieving an assembly from a wellbore | EP09251922.2 | 2009-08-03 | EP2149671A3 | 2012-01-11 | Sokol, Jonathan P.; McIntire, Scott; Stulberg, Michael |
A method and apparatus for retrieving an assembly having a whipstock and an anchor from a wellbore. A method of retrieving an assembly having a whipstock coupled to an anchor from a wellbore may comprise the steps of releasing the whipstock from the anchor in the wellbore, re-engaging the whipstock to the anchor, and retrieving the whipstock with the anchor from the wellbore. An apparatus for use in a wellbore may comprise a whipstock, a latch coupled to the whipstock, and an anchor operable to be selectively retrieved from the wellbore using the latch. |
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188 | APPARATUS AND METHOD FOR SETTING A DOWNHOLE ANCHOR AND RELATED TELESCOPIC JOINT | EP10703333.4 | 2010-01-22 | EP2389495A2 | 2011-11-30 | MACLEOD, Iain; ELRICK, Andrew; REID, Stephen |
A lock ring (150) for use as a one way movement restrictor between two telescopingly arranged tubulars (23, 9,16) to permit movement in one direction and prevent movement in the other direction of one tubular (23) relative to the other tubular (9, 16); the lock ring comprising: a profile having one or more formations (147) formed on the outer circumference for engagement with a suitable formation profile formed on the inner circumference of the outer telescopic tubular; and one or more teeth (149) formed on its inner circumference, the teeth (149) being adapted to dig into the outer surface of the inner telescopic member (23); such that the profile having one or more formations (147) on the outer circumference and/or the said one or more teeth (149) permits the lock ring to be pushed along the outer surface of the inner telescopic tubular (23) when pushed by the outer telescopic tubular in one direction;; and is further adapted to dig the teeth (149) into the outer surface of the inner telescopic tubular when the push in said one direction is removed or when it is pushed by the outer telescopic tubular (23) in the other direction in order to prevent the lock ring (150) from moving in the other direction relative to the inner telescopic tubular (23). | ||||||
189 | BRAKING DEVICES AND METHODS FOR USE IN DRILLING OPERATIONS | EP09735209 | 2009-04-22 | EP2271818A4 | 2011-09-14 | DRENTH CHRISTOPHER L |
A braking device for drilling operations in a borehole includes a brake retainer having a plurality of brake connector openings defined therein, a body member having a tapered surface having a first diameter and a second diameter, the second diameter being larger than the first diameter, at least one brake element positioned at least partially between the brake retainer and the body member and in communication with the tapered surface and at least one of the brake connector openings, and a bias member configured to exert a biasing force on the body member to move the body member toward the brake retainer to move the brake element from contact with the first diameter of the tapered surface toward contact with the second diameter. | ||||||
190 | Liner hanger, running tool and method | EP06012127.4 | 2002-05-15 | EP1712729B1 | 2011-07-20 | Yokley, John M.; Reimert, Larry E. |
191 | Liner Hanger, Running Tool and Method | EP08105836.4 | 2002-05-15 | EP2020482A3 | 2011-04-27 | Yokley, John M.; Reimert, Larry E |
A tool for use in a subterranean well to seal with a generally cylindrical interior surface of a tubular or another downhole tool, the tool comprising: |
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192 | Method and apparatus for isolating and treating discrete zones within a wellbore | EP10157828.4 | 2010-03-25 | EP2236738A2 | 2010-10-06 | Murphy, Robert; Ingram, Gary Duron; Harrall, Simon J. |
A method and apparatus for conducting a fracturing operation using a wellbore fracturing assembly. The assembly may be mechanically set and released from a wellbore using a coiled tubing string to conduct a fracturing operation adjacent an area of interest in a formation. The assembly may include an unloader for equalizing pressure between the assembly and the wellbore, a pair of spaced apart packers for straddling the area of interest, an injection port disposed between the packers for injecting fracturing fluid into the area of interest, and an anchor for securing the assembly in the wellbore. After conducting the fracturing operation, the assembly may be relocated to another area of interest to conduct another fracturing operation. |
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193 | System and methods for tubular expansion | EP08150002.7 | 2008-01-02 | EP1942248B1 | 2009-12-23 | Giroux, Richard Lee; Luke, Mike A. |
194 | DOWNHOLE TOOL WITH SLIP RELEASING MECHANISM | EP07870872.4 | 2007-11-15 | EP2089607A2 | 2009-08-19 | REIMERT, Larry E.; YOKLEY, John M. |
A downhole tool includes a lock for maintaining a slip in a reduced diameter position when running the tool in the well, and selectively releases the slip to move radially outward to a set position to suspend an anchored portion of the tool within a downhole tubular. The tool includes a mandrel having a through passage, with a hydraulic port within the mandrel that is closed to mandrel internal pressure as the tool is run in the wellbore. A ball seat covers hydraulic ports in the mandrel. A ball may be dropped to seat and increase pressure to open the ports. A piston moves in response to mandrel internal pressure applied through the hydraulic port to unlock the locking device, such that further movement of the piston releases the slip from the reduced diameter position to the set position. | ||||||
195 | Liner hanger, running tool and method | EP06012130.8 | 2002-05-15 | EP1712732B1 | 2009-07-15 | Yokley, John M.; Reimert, Larry E. |
196 | System and method for drilling lateral boreholes | EP07122050.3 | 2007-11-30 | EP2065553A1 | 2009-06-03 | Hopkins, Chris; Nobuyoshi, Niina; Bonner, Stephen |
A drilling system for drilling a lateral borehole from a mail borehole comprises a tubular conduit through which a fluid can be pumped; and a drilling assembly connected to the tubular conduit so as to receive fluid pumped therethrough, the drilling assembly comprising: a power conversion unit, through which the fluid flows and which operates to provide a downhole power output; a drilling unit including a drilling apparatus powered by the output of the power conversion unit and operable to drill a lateral borehole into the formation surrounding the main borehole, and a liner unit for storing one or more liners for installation into the lateral borehole; and an anchor unit operable to anchor the drilling assembly in the main borehole when the drilling unit operates to drill the lateral borehole. A method of drilling a lateral borehole from a main borehole using such a drilling system comprises positioning the drilling assembly in the main borehole at a location of interest using the tubular conveyance; anchoring the drilling assembly in the main borehole using the anchor unit; operating the drilling unit to drill a lateral borehole from the main borehole; retrieving the drilling unit from the lateral borehole; releasing the anchor unit; and moving the drilling assembly to another location. |
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197 | EXPANDABLE WELLBORE ASSEMBLY | EP04791115.1 | 2004-10-01 | EP1680573B1 | 2008-07-30 | LOHBECK, Wilhelmus Christianus Maria |
An assembly for use in a wellbore formed in an earth formation, comprising an expandable tubular element and an outer structure having first and second portions arranged at a distance from each other, said portions being to the tubular element in a manner that said distance changes as a result of radial expansion of the tubular element, the outer strucure further having a third portion arranged to move radially outward upon said change in distance between the first and second portions, wherein said radially outward movement of the third portion is larger than radially outward movement of the tubular element as a result of radial expansion of the tubular element. | ||||||
198 | Wellbore lining apparatus and method of lining a wellbore | EP05004441.1 | 2000-09-06 | EP1555386B1 | 2008-04-16 | Oosterling, Peter |
199 | SMART SHUTTLES TO COMPLETE OIL AND GAS WELLS | EP00955473.4 | 2000-08-09 | EP1210498B1 | 2007-11-28 | VAIL, William, Banning, III |
Smart shuttles (306) are used to convey into the steel pipe (664) the various smart completion devices (188) necessary to complete the oil and gas well. Smart shuttles (306) may be attached to a wireline (302), a coiled tubing (656), or to a wireline installed within coiled tubing. Of particular interest is a wireline conveyed smart shuttle (306) that possesses an electrically operated internal pump (402) that pumps fluid from below the shuttle (306), to above the shuttle (306), that in turn causes the smart shuttle (306) to "pump itself down" and into a horizontal wellbore. Similar comments apply to coiled tubing conveyed smart shuttles. | ||||||
200 | SONDE DEPLOYMENT | EP05826420.1 | 2005-12-07 | EP1825103A1 | 2007-08-29 | JAQUES, Paul Stephen; JONES, Robert Hughes |
Apparatus is disclosed for securing a sonde to the inner wall of a well casing (3). The sonde (2) comprises a clamp (2) expandable from a contracted position to an expanded position in which the clamp can engage the inner wall. The securing apparatus comprises a member (5,6) for releasably engaging with the clamp (2) to hold the clamp in the contracted position; a spring (7) connected to the member such that when the spring is in a compressed state, the member is constrained into engagement with the clamp to hold the clamp in the contracted position; and a mechanism (8,9,10) for holding the spring (7) in its compressed state during a 10 first mode of operation and, in a second mode of operation, for releasing the spring (7) from its compressed state thus disengaging the member (5,6) from the clamp to permit the clamp to expand into its expanded position, the mechanism including a material (11) which in the first mode of operation, is in a solid state and, in the second mode of operation, is in a liquid state. |