| 序号 | 专利名 | 申请号 | 申请日 | 公开（公告）号 | 公开（公告）日 | 发明人 |
|---|---|---|---|---|---|---|
| 121 | SEALING AND CONTROLLING OF FLUID PRESSURE IN AN ANNULAR FLUID PASSAGEWAY IN A WELLBORE RELATED PROCESS | EP16760825.6 | 2016-08-25 | EP3341559A1 | 2018-07-04 | BAKKER, Thomas Walburgis; VAN OG, Gerardus Godefridus Johannes; ROODENBURG, Joop |
| In a method for sealing and controlling fluid pressure in an annular fluid passageway in a wellbore related process, use is made of an annular fluid passageway sealing device, which includes a chamber delimited by chamber end members each provided with an opening therein so that the drilling tubulars string passes through said chamber and said chamber end members. The lower chamber end member is exposed, at least partially, to wellbore related fluid pressure in the annular fluid passageway. The housing is provided with an inlet and an outlet in communication with said chamber. Use is made of a pump that circulates a high viscosity liquid. The inlet and the outlet are vertically offset from each other and the chamber is provided with one or more narrow annular gap defining members that are arranged between vertically spaced apart feed and discharge zones. The circulation of liquid and the narrow annular gap are such that shear of the high viscosity liquid is induced resulting in a pressure drop between the discharge zones such that high viscosity liquid pressure in the feed zone assists the lower chamber end member in absorbing the wellbore related fluid pressure. | ||||||
| 122 | SOLIDS CONTROL METHODS, APPARATUS, AND SYSTEMS | EP14905404 | 2014-11-05 | EP3215710A4 | 2018-06-06 | ROGERS HENRY EUGENE; MALAVE MICHAEL |
| A weir assembly system comprises an insert dimensioned to be inserted into a section of a wellbore and a plurality of weirs spaced within the insert so as to increase the separation of solids from fluid within the section of the wellbore when the fluid is flowing through the wellbore. The plurality of weirs may be oriented to create a tortuous fluid flow path, such that a flow opening of a first weir causes solids to deposit at a second weir without obstructing a flow opening of the second weir. Additional apparatus, methods, and systems are disclosed. | ||||||
| 123 | A DOWNHOLE FISHING TOOL | EP15753981.8 | 2015-08-14 | EP3126617B1 | 2018-05-16 | CARRAGHER, Paul |
| An oil or gas well fishing tool (60) is provided. The downhole fishing tool (60) has a receptacle (61) that is open at one end. The tool also has deployment tool engaging means (62), located on the opposite end of the receptacle (61) to the one end. The tool further has a layer of an alloy (64) provided on the interior surface of the receptacle (61). The alloy is a eutectic alloy and/or a bismuth alloy. The tool further comprises heating means (65) to heat the alloy (64) so that it melts and can flow over any object received within the receptacle (61). | ||||||
| 124 | REDRESSING METHOD AND REDRESSED COMPLETION SYSTEM | EP16728984.2 | 2016-06-15 | EP3310991A1 | 2018-04-25 | HAZEL, Paul |
| A redressing method for arranging an inner production casing within an existing production casing in order to re-establish production of hydrocarbon-containing fluid in a well, comprises providing the inner production casing to having a substantially constant inner diameter, the inner production casing comprising spaced first and second annular barriers. Each annular barrier has a tubular metal part and an expandable metal sleeve surrounding the tubular metal part. Each barrier has an inner face facing the tubular metal part and an outer face facing an inner wall of the existing production casing. The inner production casing has an outer unexpanded diameter which is smaller than the first inner diameter of the existing production casing. The existing production casing is redressed by introducing the inner production casing into the existing production casing, arranging the first annular barrier on one side of the first inflow section and the second annular barrier on the other side of the inflow section, thereby isolating an inflow of fluid from the first inflow section, encapsulating the first inflow section of the existing production casing by expanding the expandable metal sleeves of the first annular barrier and the second annular barrier, thereby isolating the first inflow section. | ||||||
| 125 | DRILLING DEBRIS SEPARATOR | EP14904165 | 2014-10-14 | EP3177801A4 | 2018-02-28 | MERICAS CHRISTOPHER JAMES; HENRY KEVIN WAYNE; STAIR TODD ANTHONY; DOWNY LUKE CHRISTOPHER |
| In accordance with embodiments of the present disclosure, a debris separator device for use with a casing system may include an impeller having a plurality of blades to generate a vortex of mud in the section of the casing system when the casing system is lowered into a wellbore. The device may also include a baffle disposed in the section of the casing system, the baffle having an annular cup shape that forms an outer circumferential pocket to capture debris from the vortex of mud. The impeller and baffle may enable the debris separator device to separate debris and other debris from a flow of mud through the casing system so that the debris does not clog a float collar of the system. The disclosed debris separator device may be flushable so that the device does not become clogged with debris and can thereby maintain auto-fill through the casing system. | ||||||
| 126 | METHOD FOR RUNNING CONDUIT IN EXTENDED REACH WELLBORES | EP14809133 | 2014-11-25 | EP3087246B1 | 2018-01-10 | VESTAVIK OLA |
| A method for inserting a conduit into a wellbore includes inserting the conduit into the wellbore until an upper end of a predetermined section thereof is disposed proximate a selected position in the wellbore and reducing pressure in the conduit to a predetermined pressure. | ||||||
| 127 | TUBULAR MEMBER ADAPTOR APPARATUS | EP11733444 | 2011-01-14 | EP2524107A4 | 2017-12-13 | SINCLAIR EDWARD; HUSTINX GUY; SIBILLE PATRICK NEIL |
| Apparatuses, systems, and methods in accordance with the present disclosure are disclosed herein. The system includes a gripping tool operatively connected to and suspended from the top drive assembly, in which the gripping tool includes an axis defined therethrough and a gripping member, and an adaptor apparatus having a first end and a second end. The at least one gripping member engages the adaptor apparatus, and the second end includes a connection member to connect with the tubular member. | ||||||
| 128 | TELEMETRY OPERATED SETTING TOOL | EP17173136.7 | 2014-11-04 | EP3241984A1 | 2017-11-08 | TURLEY, Rocky A.; CAMPBELL, Robin L.; HEIDECKE, Karsten; GIVENS, George |
A setting tool for hanging a tubular string includes: a mandrel having an upper portion and a lower portion for extending into the tubular string; a housing connected to the mandrel upper portion; and a bonnet. The bonnet is: for receiving an upper end of the tubular string, disposed along the mandrel, and linked to the housing. The setting tool further includes: an actuator for stroking the bonnet relative to the mandrel and the housing, thereby setting a hanger of the tubular string; an electronics package in communication with the actuator for operating the actuator in response to receiving a command signal; and a latch. The latch is: connected to the mandrel lower portion, operable between an extended position and a retracted position, for being restrained in the retracted position by being disposed in the tubular string, and extendable by being removed from the tubular string.
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| 129 | TIE-BACK SEAL ASSEMBLY | EP14901475 | 2014-09-10 | EP3164567A4 | 2017-10-18 | GHARESI ABDOL REZA; CHUA RAYMOND YIT LONG |
| A tie-back seal system is disclosed. The system includes a tie-back seal assembly including an outer sleeve, an inner sleeve disposed within the outer sleeve, a shear pin extending through the outer and inner sleeves, and a ratch-latch pin coupled to and disposed downhole from the inner sleeve. The system also includes a tie-back liner disposed within the inner sleeve and coupled to the outer and inner sleeves using the shear pin such that the shear pin prevents axial movement of the tie-back liner relative to the outer and inner sleeves. The system further includes a tie-back receptacle configured to engage the ratch-latch pin to prevent axial movement of the inner sleeve and tie-back liner in an uphole direction and including a shoulder that, when in contact with the outer sleeve, prevents axial movement of the outer sleeve in a downhole direction. | ||||||
| 130 | CASING WINDOW ASSEMBLY | EP12873778.0 | 2012-04-04 | EP2834446B1 | 2017-09-27 | STEELE, David, Joe |
| 131 | SOLIDS CONTROL METHODS, APPARATUS, AND SYSTEMS | EP14905404.1 | 2014-11-05 | EP3215710A1 | 2017-09-13 | ROGERS, Henry Eugene; MALAVE, Michael |
| A weir assembly system comprises an insert dimensioned to be inserted into a section of a wellbore and a plurality of weirs spaced within the insert so as to increase the separation of solids from fluid within the section of the wellbore when the fluid is flowing through the wellbore. The plurality of weirs may be oriented to create a tortuous fluid flow path, such that a flow opening of a first weir causes solids to deposit at a second weir without obstructing a flow opening of the second weir. Additional apparatus, methods, and systems are disclosed. | ||||||
| 132 | WELLBORE APPARATUS AND METHOD FOR SAND CONTROL USING GRAVEL RESERVE | EP13849507.2 | 2013-09-18 | EP2912260B1 | 2017-08-16 | YEH, Charles, S.; BARRY, Michael, D.; HECKER, Michael, T.; MOFFETT, Tracy, J. |
| A wellbore completion apparatus (1300) that allows for placement of a gravel reserve, comprising a first sand screen assembly (1360) having one or more sand control segments connected in series, a first joint assembly (1350) and a packer assembly (1320), wherein the first sand screen assembly, the first joint assembly, and the packer assembly are connected in series so that (i) the perforated base pipe of the one or more sand control segments, the non-perforated base pipe of the first joint assembly, and the inner mandrel of the packer assembly are in fluid communication; and (ii) the at least one transport conduit in the one or more sand control segments, the at least one transport conduit in the first joint assembly, and the at least one transport conduit in the packer assembly are in fluid communication. | ||||||
| 133 | DOWNHOLE WELL TOOLS AND METHODS OF USING SUCH | EP15753149.2 | 2015-08-14 | EP3180492A1 | 2017-06-21 | CARRAGHER, Paul |
| An oil or gas well fishing tool (60) is provided. The downhole fishing tool (60) has a receptacle (61) that is open at one end. The tool also has deployment tool engaging means (62), located on the opposite end of the receptacle (61) to the one end. The tool further has a layer of an alloy (64) provided on the interior surface of the receptacle (61). The alloy is a eutectic alloy and/or a bismuth alloy. The tool further comprises heating means (65) to heat the alloy (64) so that it melts and can flow over any object received within the receptacle (61). | ||||||
| 134 | CEMENTING A LINER USING REVERSE CIRCULATION | EP13899132 | 2013-12-11 | EP3044405A4 | 2017-04-26 | STAUTZENBERGER ARTHUR; NOFFKE RICHARD; MATUS DAVID; DAIGLE ODEE; HUMPHREY RYAN; MADDUX STEPHEN |
| A method for reverse circulation cementing of a liner in a wellbore extending through a subterranean formation is presented. A running tool with expansion cone, annular isolation device, and reverse circulation assembly is run-in with a liner. The annular isolation device is set against the casing. A valve, such as a dropped-ball valve, opens reverse circulation ports for the cementing operation. The liner annulus is cemented using reverse circulation. An expandable liner hanger, if present, is expanded into engagement with the casing. The running tool is released and pulled from the hole. | ||||||
| 135 | LINER HANGER | EP10759087 | 2010-03-31 | EP2414626A4 | 2017-04-26 | BRÆKKE KRISTOFFER |
| 136 | RETRIEVABLE CEMENT BUSHING SYSTEM AND METHODOLOGY | EP14889953.7 | 2014-04-24 | EP3134606A1 | 2017-03-01 | JAVED, Asif; HALL, James |
| A technique facilitates pressure containment with a retrievable cement bushing. The retrievable cement bushing includes a body and an engagement lug that cooperates with a sleeve. The engagement lug is mounted on the body and is movable to a radially outward position for engagement with a corresponding portion of a surrounding wall, e.g an internal packer wall. The sleeve is sized to receive a slick joint therethrough and is secured to a radially inward position relative to the engagement lug via a retention member movably mounted on the sleeve, so as to hold the engagement lug in the radially outward position. The sleeve protects the slick joint from inwardly directed loading via the engagement lug when the retrievable cement bushing is subjected to differential pressures. | ||||||
| 137 | A DOWNHOLE FISHING TOOL | EP15753981.8 | 2015-08-14 | EP3126617A1 | 2017-02-08 | CARRAGHER, Paul |
| An oil or gas well fishing tool (60) is provided. The downhole fishing tool (60) has a receptacle (61) that is open at one end. The tool also has deployment tool engaging means (62), located on the opposite end of the receptacle (61) to the one end. The tool further has a layer of an alloy (64) provided on the interior surface of the receptacle (61). The alloy is a eutectic alloy and/or a bismuth alloy. The tool further comprises heating means (65) to heat the alloy (64) so that it melts and can flow over any object received within the receptacle (61). | ||||||
| 138 | MECHANICALLY ACTUATED DEVICE POSITIONED BELOW MECHANICALLY ACTUATED RELEASE ASSEMBLY UTILIZING J- SLOT DEVICE | EP12887023 | 2012-10-26 | EP2900896A4 | 2017-01-11 | STAUTZENBERGER ARTHUR |
| 139 | DOWNHOLE TUBULAR ASSEMBLY OF A WELL TUBULAR STRUCTURE | EP15165785.5 | 2015-04-29 | EP3088655A1 | 2016-11-02 | Hazel, Paul |
The present invention relates to a downhole tubular assembly configured to be mounted as part of a well tubular structure in a borehole of a well having a top. The downhole tubular assembly comprises a well metal tubing configured to be mounted as part of the well tubular structure, the well metal tubing having a longitudinal extension, a tubing length along the longitudinal extension, an inner diameter and an outer diameter defining a wall, and an inner face and an outer face. The downhole tubular assembly further comprises a tubular metal receptacle having an inner receptacle face and an outer receptacle face, a receptacle length and a first part closest to the top of the well, and having an inner receptacle diameter larger than the outer diameter of the well tubing part, and a second part extending from the first part towards the well metal tubing. The tubing length is larger than the receptacle length, and the wall of the well metal tubing extends inside the tubular metal receptacle along the entire length of the tubular metal receptacle, and the second part of the tubular metal receptacle is fastened to the outer face of the well metal tubing, thereby closing the tubular metal receptacle in one end and defining an annular space between the tubular metal receptacle and the well metal tubing. Furthermore, the invention relates to a well tubular structure for being arranged in a borehole in a well and to a downhole system configured to be arranged in a borehole of a well. Finally, the invention relates to a structure replacement method for replacing at least part of the well tubular structure of a downhole system.
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| 140 | METHOD AND SYSTEM FOR PREDICTING DRILLING EVENTS | EP13876731 | 2013-02-27 | EP2932031A4 | 2016-08-31 | SAMUEL ROBELLO; GERMAIN OLIVIER R |
| Calculating wellbore energy. At least some of the illustrative embodiments are methods including: calculating an expected wellbore energy for a planned wellpath, the calculating by a computer system; calculating an expected tortuosity of the planned wellpath; calculating a first value indicative of probability of occurrence of a drilling event for drilling along the planned wellpath, the first value based on the expected wellbore energy and the expected tortuosity; and then drilling a wellbore along at least a first portion of the planned wellpath if the first value indicates the probability of the drilling event is less than a predetermined threshold. | ||||||
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