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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121 | Bi-stable expandable device and method for expanding such a device | EP02290106.0 | 2002-01-15 | EP1223305A3 | 2002-11-13 | Hart, Barrie; Johnson, Craig D.; Schetky, L. McD. |
An expandable device comprising a plurality of expandable cells (23). The cells may be bistable cells or other types of cells that are expanded from a contracted position towards an expanded position. Additionally, the cells may be combined with locking mechanisms to hold the structure in an expanded position. |
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122 | Corrosion inhibitors | EP01301638.1 | 2001-02-23 | EP1130214A1 | 2001-09-05 | Nettleship, Christopher; Hopkins, William |
A method of preventing corrosion in pipelines comprising draining pipeline of all residual compounds, blowing through with nitrogen and rinsing with a corrosion inhibiting rinsing agent. |
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123 | Method for treating oil wells | EP94308132.3 | 1994-11-04 | EP0656459B1 | 2001-03-28 | Read, Peter Arne |
124 | Method of controlling fine particulate flowback in subterranean wells | EP97307807.4 | 1997-10-02 | EP0879935A2 | 1998-11-25 | Weaver, Jim D.; Nguyen, Philip D.; Stanford, James R.; Bowles, Bobby K.; Wilson, Steven F.; Parker, Mark A.; Dewprashad, Brahmadeo |
A wellbore penetrating a subterranean formation is treated with a fluid whereby fine particulate flowback is reduced or prevented. The method includes the steps of providing a fluid suspension including a mixture of a particulate coated with a tackifying compound, pumping the suspension into a subterranean formation and depositing the mixture within the formation whereby the tackifying compound retards movement of at least a portion of any fine particulate within the formation upon flow of fluids from the subterranean formation through the wellbore. Alternatively, the tackifying compound may be introduced into a subterranean formation in a diluent containing solution to deposit upon previously introduced particulates to retard movement of such particulates and any fines subject to flow with production of fluids from the subterranean formation. |
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125 | WELL COMPLETION SYSTEM | EP91919844.0 | 1991-11-15 | EP0558534B1 | 1998-08-05 | MOHN, Frank |
A well completion system comprises production tubing (5) extending downhole from wellhead equipment (2) to a plurality of completion systems (7, 8, 9). A well testing facility comprising a test loop (26) with flow metering equipement (27) is included in the wellhead equipment. Each of a plurality of independently adjustable flow control means (57) is operable to stop the flow of fluid from a respective one of the completion assemblies into the production tubing. The downhole completion assemblies (7, 8, 9) are mounted on a common fluid and electrical supply means (4) comprising tubular electrical conductor means (42) and tubing (41, 45, 46) defining fluid paths. | ||||||
126 | OIL WELL TREATMENT | EP95920998.0 | 1995-05-30 | EP0811110A1 | 1997-12-10 | BOURNE, Hugh, Malcolm; READ, Peter, Arne |
Corrosion, scale-formation, or other deleterious processes are inhibited in an oil well by providing within the oil well (10) elements comprising an insoluble porous inorganic material in which is absorbed a well treatment chemical. The material may be in the form of particles or beads, for example porous ceramic spheres impregnated with an inhibitor material. Such particles may be injected as proppant particles into the formation through which the well extends, during a fracturing treatment. Alternatively such particles may be packed as a filter bed (26) in a filter (20) comprising two spaced tubular screens (24) between which the filter bed (26) is located. The inhibitor material gradually dissolves in the well fluids during operation, and may for example inhibit corrosion and/or scale-formation. | ||||||
127 | ABLATING GELATIN PIG AND METHOD FOR USE IN TUBULARS | EP92922769.0 | 1992-04-09 | EP0579788A1 | 1994-01-26 | LOWTHER, Frank, E.; OLSEN, Alden, W. |
Racleur (20), constitué d'une masse de gélatine, destiné au traitement des conduites tubulaires (15). Le racleur remplit son office en cheminant à l'intérieur de la conduite et en déposant, ce faisant, sur la paroi interne de celle-ci une couche de traitement (21). Le racleur peut être moulé hors de la conduite ou bien formé in situ. Le racleur est constitué en mélangeant une gélatine ordinaire (c'est-à-dire à usage industriel) d'un type dérivé du collagène à un liquide chauffé et une solution de traitement (par exemple, inhibiteur de corrosion, réducteur de traînée, etc.). Dans une configuration donnée, des particules magnétiques (13) sont entraînées dans la masse. Cette dernière peut être homogène ou bien être constituée de plusieurs éléments de gélatine. Un bouchon de solution de traitement peut également être acheminé le long de la conduite entre deux racleurs de gélatine. Pour les applications à hautes températures, un durcisseur peut être utilisé afin d'accroître la température de fusion de la gélatine. | ||||||
128 | WELL COMPLETION SYSTEM | EP91919844.0 | 1991-11-15 | EP0558534A1 | 1993-09-08 | MOHN, Frank |
Système de complétion d'un puits de forage comprenant une colonne de production (5) s'étendant vers le bas du puits à partir d'un équipement de tête de puits (2) jusqu'à plusieurs systèmes de complétion (7,8,9). L'équipement de tête de puits comprend une installation d'essai comportant une canalisation parallèle d'essai (26) associée à un système débitmètre (27). Chacun des systèmes de commande de l'écoulement (57) réglables de manière indépendante, peut être mis en oeuvre pour arrêter l'écoulement de fluide provenant respectivement d'un des systèmes de complétion, dans la colonne de production. Les systèmes de complétion (7,8,9) situés dans le bas du puits sont montés sur un système commun d'alimentation en fluide et en électricité (4) comprenant un système électroconducteur tubulaire (42) et une ligne de tubes (41,45,46) définissant des voies pour le fluide. | ||||||
129 | DISPOSITIF DE PROTECTION DES PUITS FACE AUX RISQUES DE CORROSION OU DEPOTS DUS A LA NATURE DU FLUIDE PRODUIT OU EN PLACE DANS LE PUITS | EP91905542.0 | 1991-02-22 | EP0469140A1 | 1992-02-05 | UNGEMACH, Pierre; TURON, Roland |
Dispositif de complétion de puits utilisant un tubage de soutènement (2) en acier associé à une colonne de production ou d'injection (3) en matériaux composites, avec annulaire libre (6). L'invention concerne un dispositif de protection des puits face aux risques de corrosion ou de dépôt dus à la nature du fluide produit ou en place dans le puits. Il est constitué d'un tubage de soutènement (2) en acier, associé à une colonne de production (3) en matériaux composites, avec un annulaire (6) libre permettant notamment l'injection, sans arrêt de l'exploitation, d'inhibiteurs. La colonne (3) est posée sur le tubage (2) par l'intermédiaire d'un dispositif (4) pouvant être descendu en même temps que la colonne (3) et muni d'ouvertures (13) assurant la continuité hydraulique de l'annulaire (6). Le dispositif selon l'invention est particulièrement adapté aux puits véhiculant des fluides de nature agressive vis-à-vis de tubages acier traditionnels. | ||||||
130 | CORROSION INHIBITORS FOR CLEAR, CALCIUM-FREE HIGH DENSITY FLUIDS | EP87906346.9 | 1987-09-08 | EP0290486B1 | 1991-01-16 | DADGAR, Ahmad |
Corrosion inhibitors which can be used with calcium-free drilling, completion and workover fluids in carbonate or sulfate containing wells. More particularly, the invention relates to the use of sodium, ammonium and/or calcium thiocyanate alone, or in combination with specific aldose group antioxidants, as corrosion inhibitors. Aldose group antioxidants include arabinose, ascorbic acid, isoascorbic acid, gluconic acid, alkali metal, and alkaline earth or other metal ascorbates, isoascorbates and gluconates and mixtures thereof. Additionally, ammonium thioglycolate may be incorporated as a further corrosion inhibitor. | ||||||
131 | Corrosion inhibition apparatus for downhole electrical heating | EP90104843.9 | 1990-03-14 | EP0387852A1 | 1990-09-19 | Bridges, Jack E.; Dubiel, George T.; Bajzek, Thomas J. |
Corrosion inhibition apparatus in an electromagnetic heating system for in situ downhole heating in an oil well or other mineral fluid well that includes an A.C. power source for a high amperage, low frequency heating current (e.g. over 50 amperes at 0.01 to 35 Hz) and a D.C. bias source for generating a low amplitude (e.g., less than one ampere) current for corrosion inhibition, both sources connected to a downhole electrode. The bias source includes at least one semiconductor device, connected in the main A.C. heating circuit, in a bias circuit that develops a net D.C. voltage differential of the polarity required for corrosion inhibition in response to the A.C. heating current. |
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132 | Corrosion inhibition method and apparatus for downhole electrical heating in mineral fluid wells | EP90104842.1 | 1990-03-14 | EP0387851A1 | 1990-09-19 | Bridges Jack E. |
Method and apparatus for corrosion inhibition in an electromagnetic heating system for heating a portion of a mineral fluid deposit adjacent an oil well or other mineral fluid well, in situ. The preferred apparatus includes a power source, that develops a high amperage heating current, over 100 amperes, at a heating frequency usually in a range of from 0.01 Hz or lower to 35 Hz, in a heating circuit that includes a main heating electrode downhole of the well and a return electrode. The power source also supplies a very low amplitude, controlled D.C. bias current to those electrodes, maintaining the main electrode at a neutral or negative polarity for corrosion protection. The D.C. bias current is monitored and maintained below a given minimum level, usually about one ampere, to extend the effective life of the return electrode and to minimize corrosion protection costs. |
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133 | Method for monitoring and controlling scale formation in a well | EP89308660.3 | 1989-08-25 | EP0359427A1 | 1990-03-21 | Seidner, David S. |
Formation of scale from radioactive components is monitored with a radiation detector (16). Upon indication of initiation of scale formation in a system, treatment with inhibitor is carried out. |
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134 | Dispositif d'injection d'additifs inhibiteurs de corrosion ou de dépôts dans un puits géothermal d'exhaure | EP88402197.3 | 1988-08-31 | EP0306407A1 | 1989-03-08 | Goyeneche, Olivier; Martin, Gilbert; Longin, Gérard |
La présente invention concerne un dispositif d'injection d'additifs inhibiteurs de corrosion ou de dépôts dans un puits géothermal d'exhaure. Ce dispositif est caractérisé en ce qu'il comprend un tube d'injection (7) en matériau composite, du type verre-résine, suspendu dans le cuvelage (1) du puits en dessous du groupe de pompage d'exhaure (4,5) en étant fixé à un dispositif d'accrochage (8) monté sous le groupe de pompage (4,5), ce tube d'injection (7) débouchant, à son extrémité inférieure, à proximité du fond du puits et étant raccordé, à son extrémité supérieure, à une source d'additif située en surface, par l'intermédiaire d'un tuyau flexible (9) s'étendant dans le puits le long du tube d'exhaure. |
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135 | CORROSION INHIBITOR FOR HIGH DENSITY BRINES. | EP86901204 | 1986-01-28 | EP0211065A4 | 1988-07-29 | DOTY PETER A; LARSON WILLIAM A |
136 | Apparatus for anchoring downhole corrosion coupons | EP87300748.8 | 1987-01-28 | EP0246722A1 | 1987-11-25 | Williams, Mitchel E. |
A corrosion coupon anchoring system (10) for positively positioning at least one corrosion monitoring coupon (20,22) in the production flowpath downhole in a producing well, wherein the preferably cylindrical coupons (20,22) are held firmly within a cylindrical housing (12) suspended out of contact with any other metallic surface. An adaptor (14) threadingly engages the cylindrical housing (12) with a conventional locking mandrel (11) that is locked in place to a nipple (13) positioned in the tubing string. The minimum internal dimension (D2) of the coupon holding section is not less than the minimum internal dimension (D1) of the locking mandrel so as to minimize flow restriction introduced by the anchoring system. |
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137 | Method and apparatus for the servicing and inspection of pipes | EP85307314.6 | 1985-10-11 | EP0178870A2 | 1986-04-23 | Cruickshank, John Smith |
@ A method and apparatus for treating very large pipe sections such as those used for oil or gas wells, in which one or both cyclindrical surfaces of the pipe sections are processed entirely throughout the length and circumference of the pipe, in one cycle of operation. The processing comprises cleaning and one or more of the following treatments: inspection, coating with a corrosion preventative material and forced-air drying and the inspection process will include remote optical/video scanning of the whole circumference of the pipe. The preferred apparatus comprises a bed (1a) on which the pipe section is supported, an external processing unit (9) and a probe (8), both of which are advanced down the pipe section and retracted with a fixed spatial relationship and both of which contain means for treating the respective pipe surfaces. In a second embodiment the probe is used on its own as a means for , cleaning and inspecting down-hole pipe conditions around 360° of the circumference of the pipes. |
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138 | CHEMICAL-INJECTION MANAGEMENT SYSTEM | EP08728735.5 | 2008-01-31 | EP2111496B1 | 2018-07-25 | GREENE, Gregory; GRACE, Andrew; MCHUGH, Edmund |
An apparatus that includes a chemical injection management system. The chemical injection management system may include a tree interface configured to couple the chemical injection management system to a tree and a positive-displacement flow-meter. | ||||||
139 | DOWNHOLE TOOLS HAVING HYDROPHOBIC COATINGS, AND METHODS OF MANUFACTURING SUCH TOOLS | EP15845210 | 2015-09-24 | EP3198104A4 | 2018-06-20 | OVERSTREET JAMES L; SISTA VIVEKANAND; YU BO |
A downhole tool for use in wellbores comprises a layer of hydrophobic material over a body, wherein the layer of hydrophobic material comprises a transition metal boride having a higher hydrophobicity than the body. The downhole tool may comprise a body having a composition and the layer of hydrophobic material comprising a discontinuous phase of the transition metal binder dispersed within a first continuous phase comprising a metal binder. The layer of material may be chemically bonded to the body. An interface between the body and the layer of material may comprise the transition metal boride dispersed within a second continuous phase comprising the metal binder and the composition of the body. Methods of forming downhole tools include forming such a layer of material at a surface of a body of a downhole tool. | ||||||
140 | PROCEDE D'EXPLOITATION D'UNE FORMATION SOUTERRAINE PAR INJECTION D'UN FLUIDE COMPRENANT UN ADDITIF MARQUE PAR UN NANO-CRISTAL SEMI-CONDUCTEUR LUMINESCENT | EP16717662.7 | 2016-04-22 | EP3298100A1 | 2018-03-28 | LECOLIER, Eric; GATEAU, Patrick |
The present invention relates to a method for exploitation of a subterranean formation, into which at least one fluid is injected. According to the invention, the fluid comprises at least one additive, the additive being tagged by at least one luminescent (fluorescent or phosphorescent) semiconductor nanocrystal. In this way, and by optical analysis of the presence of luminescent semiconductor nanocrystal in a fluid recovered from the subterranean formation, it is possible to determine the presence and/or the amount of additive in the fluid recovered. Given that the semiconductor nanocrystal is either phosphorescent or fluorescent, the additive is rendered easily detectable and quantitatively assayable in the fluids recovered from the subterranean formation. |