子分类：
- E21B2021/005： .使用气态流体
- E21B2021/006： .欠平衡技术,即井眼流体压力低于地层压力
- E21B2021/007： .井眼外操作钻井液或者岩屑的装置,例如泥箱
- E21B21/001： .{专门适用于水下钻进的}
- E21B21/002： .{井下钻井液分离系统(包括具有过滤器的收集装置的容器入E21B27/005;亚层土过滤入E21B43/02;井下生产分离装置入E21B43/38)}
- E21B21/003： .{用于停止钻井液漏失的装置(给井壁涂抹灰泥入E21B33/138)}
- E21B21/01： .井眼外处理钻井液或者岩屑的装置,例如泥箱(软管管路内的旋转接头入E21B21/02;处理钻井液的装置入E21B21/06;废物处理系统入E21B41/005)
- E21B21/02： .软管管路内的旋转接头{(一般软管连接入F16L31/00,F16L33/00)}
- E21B21/06： .井眼外处理钻井液的装置(处理步骤本身参见相关的小类)
- E21B21/08： .钻井液压力或流量的控制或监测,例如,自动充注井眼,自动控制井底压力(其阀装置入E21B21/10)
- E21B21/10： .钻井液循环系统的阀装置(一般的阀入F16K)
- E21B21/12： .使用带多个钻井液通路的钻管,例如,闭式循环系统(带多个钻井液通路的管路入E21B17/18)
- E21B21/14： .使用液体和气体,例如泡沫
- E21B21/16： .使用气态流体(E21B21/14优先;井眼外操作钻井液或者岩屑的装置入E21B21/01;用于处理钻井液的设备入E21B21/06)
- E21B21/18： .防止钻进马达的废气吹向工作面
| 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 | HYDRAULIC DIVERSION SYSTEMS TO ENHANCE MATRIX TREATMENTS AND METHODS FOR USING SAME | EP14785224 | 2014-04-21 | EP2986818A4 | 2017-04-26 | VAN PETEGEM RONALD; DUNCAN ANDREW; ZURITA ALFREDO MENDEZ; SMITH KERN L; VIGDERMAN LEONID; SAINI RAJESH K |
| Systems and methods for treating formation intervals including forming a low permeability layer on a surface of the interval and pumping a sand control treating solution through the layer, which diverts the flow into the formation permitting improved treatment uniformity and improved overall internal treatment. | ||||||
| 302 | DRILLING FLUID AND METHOD FOR DRILLING IN COAL-CONTAINING FORMATIONS | EP11819240.0 | 2011-08-26 | EP2609169B1 | 2017-03-15 | SMITH, Carl, Keith |
| A drilling fluid and method for drilling in a coal containing formation with a mixed metal-viscosified drilling fluid including at least 0.05% calcium sulfate. | ||||||
| 303 | Method for changing an aggregation potential | EP10250920.5 | 2010-05-13 | EP2251394B1 | 2016-11-23 | Kakadjian, Sarkis Ranka; Veldman, Raynard; Zamora, Frank; Fitzgerald, Erin; Garza, Tina |
| 304 | PRECIPITATED PARTICLES AND WELLBORE FLUIDS AND METHODS RELATING THERETO | EP14746595 | 2014-01-16 | EP2951264A4 | 2016-10-05 | JAMISON DALE E; LANDIS CHARLES; DEVILLE JAY; MCDANIEL CATO |
| A method of using precipitated particles in a wellbore may comprise circulating a wellbore fluid in a wellbore penetrating a subterranean formation, the wellbore fluid having a density of about 7 ppg to about 50 ppg and comprising a base fluid and a plurality of precipitated particles having a shape selected from the group consisting of ovular, substantially ovular, discus, platelet, flake, toroidal, dendritic, acicular, spiked with a substantially spherical or ovular shape, spiked with a discus or platelet shape, rod-like, fibrous, polygonal, faceted, star shaped, and any hybrid thereof. | ||||||
| 305 | DEVICE RELATING TO A FLUSHING HEAD FOR A ROCK DRILLING MACHINE AND ROCK DRILLING MACHINE | EP13857500 | 2013-10-29 | EP2923026A4 | 2016-08-17 | JONSSON PER |
| A device for a flushing head (3) of a rock drilling machine (1), which includes a machine housing (3) and, inside a cylinder (18), a to and fro moveable percussive piston (17) arranged to exert percussive action against a shank adapter (15), wherein the shank adapter has symmetry axis (19) and a flushing medium channel (22,23) for co-operation with a flushing medium chamber (24) in the flushing head (3) surrounding the shank adapter (15), said flushing head (3) being provided with a connection unit (7) for the connection to a flushing hose (10). The flushing head (3) and the machine housing (2) exhibit co-operating fastening means and fastening elements (6) in line with a force direction of tensile forces (F) being exerted by the flushing medium hose (10) on the connection unit (7) for movability of the flushing head (3) in respect of the machine housing (2) in directions perpendicular to said symmetry axis (19). The device also concerns a rock drilling machine including such a device. | ||||||
| 306 | ALKYLATED POLYETHERAMINES AS CLAY STABILIZING AGENTS | EP13852379 | 2013-11-04 | EP2917301A4 | 2016-07-27 | PAKULSKI MAREK; FORKNER MATTHEW W |
| The present disclosure provides water-based well treatment fluids for use in treating subterranean formations to prevent swelling and/or migration of fines. The water-based well treatment fluid contains an aqueous continuous phase, a clay stabilizing agent consisting of an alkylated polyetheramine and a weighting material. In addition to inhibiting swelling and/or migration, the water-based well treatment fluids are thermally stable, are toxicologically safe, and have exceptional handling properties. | ||||||
| 307 | APPARATUS FOR USE IN TOP FILLING OF TUBULARS AND ASSOCIATED METHODS | EP09785132.3 | 2009-09-18 | EP2326789B1 | 2016-06-01 | CHURCHILL, Andrew, Philip |
| 308 | SYSTEMS AND METHODS FOR REAL TIME MONITORING AND MANAGEMENT OF WELLBORE SERVICING FLUIDS | EP13863564 | 2013-12-12 | EP2901130A4 | 2016-05-11 | JAMISON DALE E; ALMOND STEPHEN W |
| 309 | ENVIRONMENTALLY BENEFICIAL RECYCLING OF BRINES IN THE PROCESS OF REDUCING FRICTION RESULTING FROM TURBULENT FLOW | EP13829751 | 2013-08-16 | EP2885374A4 | 2016-05-04 | PERRY HOUSTON P; MUELLER BRIAN L |
| Processes are provided for reducing the hydrodynamic friction of a turbulent brine stream including, for example, the step of injecting a mixture of a finely divided free flowing friction reducing powder into the turbulent brine stream, wherein the particles of the powder have a primary particle size between 10 and 100 microns in average particle diameter, and the brine stream comprises water with at least 90,000 ppm total dissolved solids, wherein the total dissolved solids includes at least 30,000 ppm sodium cations, 10,000 ppm calcium cations, and 1,000 ppm magnesium cations, and wherein the brine has an electrical conductivity of greater than 100.0 mS/cm at 25° C. For use with a harsher brine, the particles preferably have a primary particle size between 10 and 53 microns in average particle diameter. The friction reducing powder may, for example, be a polyacrylamide polymer. | ||||||
| 310 | Shank adaptor with reinforced flushing slot | EP14168027.2 | 2014-05-13 | EP2944756A1 | 2015-11-18 | Lejon, Susanne; Persson, Magnus; Jansson, Tomas Sh |
A rock drilling shank adaptor comprising an elongate body having an internal flushing bore and an entry hole through the sidewall of the adaptor in fluid communication with the internal bore. The adaptor wall at the region of the entry hole is reinforced such that an internal diameter of the flushing bore at the reinforced region is less than an internal diameter of the bore at a position axially beyond the reinforced region.
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| 311 | USE OF NANOPARTICLES AS A LUBRICITY ADDITIVE IN WELL FLUIDS | EP12867972 | 2012-10-01 | EP2798035A4 | 2015-10-14 | HUSEIN MAEN MOH D; ZAKARIA MOHAMMAD FERDOUS; HARELAND GEIR |
| The present invention is directed to a well fluid, and in particular a drilling fluid having low amounts of nanoparticles which act as fluid loss material for reducing fluid loss in an underground formation. The fluid is a nanoparticle-containing well fluid comprising a base fluid and about 5 wt % or less nanoparticles, for preventing or reducing fluid loss to an underground formation, wherein the well fluid is a drilling fluid, kill fluid, completion fluid, or pre-stimulation fluid. The invention also includes in situ and ex situ methods of forming the nanoparticles. | ||||||
| 312 | Sealing device and method for sealing fractures or leaks in wall or formation surrounding tube-shaped channel | EP12194965.5 | 2012-11-30 | EP2738349B1 | 2015-09-02 | Hansen, Jens Henrik; Skov, Anne Ladegaard |
| The sealing device (1) includes an elongated body (5) adapted to be introduced into a tube-shaped channel (2) and including a sealing fluid placement section (6) arranged between a first and a second annular flow barrier (7, 8). The elongated body further includes a sealing fluid activation section (11) arranged between the second annular flow barrier (8) and a third annular flow barrier (12) and including a sealing fluid activation device (13) adapted to at least initiate or accelerate curing of the sealing fluid (17). In operation, the elongated body may be displaced along the tube-shaped channel until the sealing fluid activation section is placed at a position where sealing fluid has been ejected by the sealing fluid placement section, and the sealing fluid activation device may be activated. Thereby, sealing fluid may be cured at selected locations along the tube-shaped channel after ejection of sealing fluid. | ||||||
| 313 | INVERT EMULSION FLUIDS WITH HIGH INTERNAL PHASE CONCENTRATION | EP10819358.2 | 2010-09-22 | EP2480622B1 | 2015-03-18 | PATEL, Arvind, D.; YOUNG, Steve; BRUTON, Jim |
| An invert emulsion wellbore fluid may include an oleaginous external phase; a non-oleaginous internal phase, wherein a ratio of the oleaginous external phase and non-oleaginous internal phase is less than 50:50; and an emulsifier stabilizing the oleaginous external phase and the non-oleaginous internal phase, wherein an average diameter of the non-oleaginous internal phase ranges from 0.5 to 5 microns. | ||||||
| 314 | Apparatuses and methods for testing wellbore fluids | EP14001799.7 | 2014-05-22 | EP2813666A1 | 2014-12-17 | Barral, Quentin; Chougnet - Siraplan, Alice; Dargaud, Bernard; Bennani, Nora; Zamora, Dominique; Kefi, Slaheddine |
An apparatus may be used to test the ability of a first fluid to remove a second fluid from a surface. The apparatus comprises a reservoir (100) that contains the first fluid and a testing cell (106) that contains the second fluid. The testing cell also contains a rotor (107) within. The first fluid is pumped into the testing cell, thereby displacing the second fluid. The displaced second fluid flows to a collection vessel (109). The apparatus is particularly useful for determining the ability of a chemical wash or a spacer fluid to remove non-aqueous drilling fluids from a metallic surface.
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| 315 | SYSTEMS, METHODS AND DEVICES FOR ANALYZING DRILLING FLUID | EP13702275.2 | 2013-01-07 | EP2807483A1 | 2014-12-03 | JAMISON, Dale E.; MURPHY, Robert J.; BROUSSARD, Shawn; GONZALEZ, Peter |
| System, methods and devices for analyzing drilling fluids are presented herein. A fluid analysis system for determining at least one characteristic of a drilling fluid is disclosed. The system includes a pump and two reversible fluid ports each configured, when in a first state, to intake drilling fluid into the fluid analysis system and, when in a second state, to expel drilling fluid from the fluid analysis system. A valve fluidly couples the reversible fluid ports to the pump. The valve controls the respective states of the reversible fluid ports. At least one measurement module is fluidly coupled to the pump to receive drilling fluid therefrom. The at least one measurement module is configured to determine at least one characteristic of the drilling fluid. Filters can be fluidly coupled with each of the reversible fluid ports. The filters prevent solids of a predetermined size from entering the fluid analysis system. | ||||||
| 316 | USE OF NANOPARTICLES AS A LUBRICITY ADDITIVE IN WELL FLUIDS | EP12867972.7 | 2012-10-01 | EP2798035A1 | 2014-11-05 | HUSEIN, Maen, Moh'd; ZAKARIA, Mohammad, Ferdous; HARELAND, Geir |
| The present invention is directed to a well fluid, and in particular a drilling fluid having low amounts of nanoparticles which act as fluid loss material for reducing fluid loss in an underground formation. The fluid is a nanoparticle-containing well fluid comprising a base fluid and about 5 wt % or less nanoparticles, for preventing or reducing fluid loss to an underground formation, wherein the well fluid is a drilling fluid, kill fluid, completion fluid, or pre-stimulation fluid. The invention also includes in situ and ex situ methods of forming the nanoparticles. | ||||||
| 317 | UNEQUAL LOAD COLLET AND METHOD OF USE | EP11808262.7 | 2011-12-22 | EP2795042A1 | 2014-10-29 | INGLIS, Peter Derek Walter; MILNE, John |
| A downhole actuation system comprises an actuation mechanism comprising an indicator (304); a wellbore tubular (302); and a collet (200) coupled to the wellbore tubular. The collet comprises a collet protrusion (206) disposed on one or more collet springs (204), and the collet protrusion has a position on the one or more collet springs that is configured to provide a first longitudinal force to the indicator in a first direction and a second longitudinal force to the indicator in a second direction. The first longitudinal force is different than the second longitudinal force. | ||||||
| 318 | Methods for increase gas production and load recovery | EP10250909.8 | 2010-05-12 | EP2251395B1 | 2014-07-30 | Zamora, Frank; Kakadjian, Sarkis Ranka; Fitzgerald, Erin; Garza, Tina |
| 319 | DRILL STRING TUBULAR COMPONENT | EP12778367.8 | 2012-09-07 | EP2753780A2 | 2014-07-16 | MACHOCKI, Krzysztof |
| 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 configured to apply radial thrust cuttings passing it, the radial impeller being located between first and second axial impellers 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. | ||||||
| 320 | Methods for increase gas production and load recovery | EP11005345.1 | 2010-05-12 | EP2371924B1 | 2014-07-02 | Zamora, Frank; Kakadjian, Sarkis, Ranka; Fitzgerald, Erin; Garza, Tina |
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