| 序号 | 专利名 | 申请号 | 申请日 | 公开（公告）号 | 公开（公告）日 | 发明人 |
|---|---|---|---|---|---|---|
| 201 | DRILL STRING CHECK VALVE | EP14710369.1 | 2014-03-11 | EP2971473A2 | 2016-01-20 | CHURCHILL, Andrew Philip |
| Drill string check valve apparatus comprises a tubular body and a flapper valve mounted in the body with a flapper movable between an open position and a closed position. An axially extending valve retainer is also mounted in the body and is translatable from a running position to a drilling position. In the running position the valve retainer extends through the valve to maintain the flapper in the open position. In the drilling position the valve retainer permits the flapper to move to the closed position to prevent flow up through the body. | ||||||
| 202 | TWO PHASE MUD FLOW USAGE WITH DUAL-STRING DRILLING SYSTEM | EP13705078.7 | 2013-02-06 | EP2954148A1 | 2015-12-16 | MANSELL, Arthur G.; HAY, Richard Thomas |
| Systems and methods for controlling fluid contact with a borehole wall during drilling operations include introducing an outer pipe into a borehole and positioning an inner pipe within the outer pipe, wherein the inner pipe may be axially disposed within the outer pipe. The annular isolator may be disposed within an annulus between the outer pipe and the borehole wall. The method may include placing a control fluid in the annulus between the outer pipe and the borehole wall. The method may further include circulating a drilling fluid to a drill bit using the inner pipe and the annulus between the inner pipe and the outer pipe. The drilling fluid may be separated from the control fluid by an annular isolator. | ||||||
| 203 | SPLIT RING SHIFT CONTROL FOR HYDRAULIC PULSE VALVE | EP12863145 | 2012-12-27 | EP2655790A4 | 2015-12-02 | KOLLE JACK J; THEIMER KENNETH J |
| 204 | SELF-REGULATING SURPLUSSING CHECK VALVE | EP13819055.8 | 2013-12-16 | EP2935765A1 | 2015-10-28 | THOMPSON, John; CHUBBOCK, Paul |
| A check valve assembly (100, 200) is provided for subsea applications. The check valve assembly comprises a housing (102, 202), having an inlet port (106, 206) and an outlet port (108, 208) forming an internal fluid passageway through the housing;, a valve member (112, 212), moveable within the internal fluid passageway between a first position, where fluid flow through the internal fluid passageway is prevented, and a second position, where fluid flow through the internal fluid passageway is permitted; a biasing member (110, 210), adapted to urge the valve member into the first position at a predetermined cracking force, and a pressure interface (116, 216). The pressure interface operatively links the valve member and an external fluid of a region exterior of the check valve assembly so as to provide a supplemental force, proportional to the ambient pressure of the external fluid, adapted to urge the valve member towards the first position. | ||||||
| 205 | Downhole deployment valves | EP12183774.4 | 2008-03-31 | EP2535507B1 | 2015-10-14 | Noske, Joe; Iblings, David; Pavel, David; Brunnert, David J.; Smith, Paul L.; Grayson, Michael Brian |
| 206 | DIRECTIONAL CONTROL OF A ROTARY STEERABLE DRILLING ASSEMBLY USING A VARIABLE FLOW FLUID PATHWAY | EP12816577.6 | 2012-12-21 | EP2920399A1 | 2015-09-23 | WINSLOW, Daniel; DEOLALIKAR, Neelesh |
| According to aspects of the present disclosure, systems and methods for controlling the direction of a drilling assembly within a borehole are described herein. An example system may include a housing 201 b (FIG. 2B) and a variable flow fluid pathway 203 (FIG. 2B) within the housing 201b. A fluid-controlled drive mechanism 209 (FIG. 2C) may be in fluid communication with the variable flow fluid pathway 203. Additionally, an offset mandrel 212 may be coupled to an output of the fluid-controlled drive mechanism 209. The offset mandrel 212 may be independently rotatable with respect to the housing 201b. The system may also include a bit shaft 216 pivotably coupled to the housing 201b and coupled to an eccentric receptacle of the offset mandrel 212. | ||||||
| 207 | PUMP THROUGH CIRCULATING AND OR SAFETY CIRCULATING VALVE | EP11749070.6 | 2011-08-22 | EP2609283B1 | 2015-07-29 | RINGGENBERG, Paul, David; CARDER, Charles, Frederick |
| 208 | ARRANGEMENT FOR CONTINUOUS CIRCULATION OF DRILLING FLUID DURING DRILLING OPERATIONS | EP13806771 | 2013-06-13 | EP2861816A4 | 2015-07-22 | SKJÆRSETH ODD B; EILERTSEN BJØRN |
| 209 | PRESSURE CONTROL IN DRILLING OPERATIONS WITH CHOKE POSITION DETERMINED BY CV CURVE | EP12880350.9 | 2012-07-02 | EP2852732A1 | 2015-04-01 | BUTLER, Cody, N.; LOVORN, James, R.; DAVIS, Nancy, S. |
| A method of controlling pressure in a wellbore can include determining a desired position for a choke, the determining being based on a Cv curve for the choke, and adjusting the choke to the desired position, thereby producing a desired backpressure. A wellbore drilling system can include a choke which variably restricts flow of fluid from the wellbore, and a control system which compares actual and desired wellbore pressures and, in response to a difference between the actual and desired wellbore pressures, adjusts the choke to a predetermined position which corresponds to a desired Cv of the choke. A method of controlling pressure in a wellbore can include comparing an actual wellbore pressure to a desired wellbore pressure and, in response to a difference between the actual and desired wellbore pressures, adjusting a choke to a predetermined position, the predetermined position corresponding to a desired Cv of the choke. | ||||||
| 210 | PRESSURE CONTROLLED WELL CONSTRUCTION AND OPERATION SYSTEMS AND METHODS USABLE FOR HYDROCARBON OPERATIONS, STORAGE AND SOLUTION MINING | EP11759817.7 | 2011-03-01 | EP2550422B1 | 2015-02-18 | Tunget, Bruce A. |
| 211 | TOE CIRCULATION SUB | EP13757344.0 | 2013-03-07 | EP2823137A1 | 2015-01-14 | THEMIG, Daniel Jon |
| A toe circulation sub for a wellbore liner, the toe circulation sub comprising: a body including a connection for connecting the body to a wellbore liner to define an inner facing portion open to an inner diameter of the liner and an outer facing portion open to an outer surface of the liner; a bore through the body from the inner facing portion to the outer facing portion; and, a ball seat in the bore formed to stop and seal with a ball to plug flow through the bore to close the toe circulation sub. The toe circulation sub is useful for methods and may be installed in a wellbore liner. | ||||||
| 212 | WELL DRILLING SYSTEMS AND METHODS WITH PUMP DRAWING FLUID FROM ANNULUS | EP12869370.2 | 2012-02-24 | EP2817486A1 | 2014-12-31 | BAKRI, Emad; LOVORN, James, R.; LEWIS, Derrick, W. |
| A well pressure control method can include regulating pressure in a wellbore by operating a suction pump which draws fluid from an annulus formed between a drill string and the wellbore, the fluid entering the suction pump proximate the earth's surface. Another well pressure control method can include regulating pressure in a wellbore by operating a suction pump which applies suction pressure to an annulus formed between a drill string and the wellbore. A well drilling system can include a suction pump positioned proximate the earth's surface. The suction pump can receive fluid which exits an annulus formed between a drill string and a wellbore. | ||||||
| 213 | CONTROLLED FULL FLOW PRESSURE PULSER FOR MEASUREMENT WHILE DRILLING (MWD) DEVICE | EP13769354.5 | 2013-02-08 | EP2815063A1 | 2014-12-24 | MacDonald, Robert; Vecseri, Gabor; Jennings, Benjamin |
| An apparatus, method, and system is described for generating pressure pulses in a drilling fluid utilizing a flow throttling device longitudinally and axially positioned within the center of a main valve actuator assembly which includes a controllable pulser that operates sequentially within a downhole assembly within a drill string of a drill pipe, that enhances operational efficiency in the removal of hydrocarbon deposits, the system includes a drilling fluid, fluid flow, and a fluid drilling pump which when combined creates fluid flow into a bore pipe annulus within said downhole assembly such that a base line bore pipe pressure is created wherein the bore pipe pressure is sensed via a sensor sensing a pressure increase when said the pump is operating such that the sensor sends information to a Digital Signal Processor (DSP) that interprets the information and said the DSP also receives information from an annulus pressure sensor that senses drilling fluid (mud) pressure as it returns to the pump in an annular outside portion of the drill pipe such said the DSP recognizes pressure variation input obtained from the annulus pressure sensor and the bore pipe pressure sensor and detects pressure variation exhibited between pulsing pressures and a pump base line pressure thereby providing signals that are sent as data information to said the DSP such that said DSP determines required action to properly adjust pulser operation settings. | ||||||
| 214 | A DRILL BIT FOR USE IN BORING A WELLBORE AND SUBTERRANEAN FRACTURING | EP12815906.8 | 2012-12-19 | EP2795036A2 | 2014-10-29 | ZHOU, Shaohua |
| A drill bit for use in drilling a wellbore and that can be used for fracturing the subterranean formation surrounding the wellbore. Included on the bit body is a packer for sealing against the wellbore wall during fracturing. A chamber in the drill bit houses a valve assembly for selectively diverting fluid between use in drilling and for use in fracturing. The fluid is delivered through a drill string that attaches to an upper end of the bit. The valve assembly can be shuttled between drilling and fracturing configurations by selectively adjusting an amount and/or pressure of the fluid flowing in the drill string. | ||||||
| 215 | DRILL STRING CHECK VALVE | EP12798808.7 | 2012-11-27 | EP2785956A2 | 2014-10-08 | CHURCHILL, Andrew |
| A drilling method comprising running a drill string (12) part way into a bore (11); then pumping fluid through the drill string; then running the drill string further into the bore; and then reconfiguring a check valve (20) located towards the distal end of the drill string from a running configuration, in which the valve permits flow both up and down the string, to a drilling configuration in which the valve permits flow down through the string but prevents flow up through the string. | ||||||
| 216 | Rotating continuous flow sub | EP14164811.3 | 2011-01-05 | EP2757228A1 | 2014-07-23 | Bailey, Thomas F.; Mitchell, Mark; Pavel, David; Ring, Lev; Bansal, Ram K.; Iblings, David |
A method for drilling a wellbore comprises drilling the wellbore by rotating a tubular string (8) using a top drive (50) and advancing the tubular string longitudinally into the wellbore. An upper portion of the tubular string having a side port (150) is rotationally unlocked from the rest of the tubular string. A tubular joint or stand of joints is added to the upper portion while drilling fluid is injected into the side (150) port and the rest of the tubular string is rotated using a rotary table The upper portion is rotationally locked to the rest of the tubular string after adding the joint or stand. Drilling of the wellbore is resumed after the upper portion is rotationally locked.
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| 217 | METHOD AND APPARATUS FOR CONTROLLING DOWNHOLE ROTATIONAL RATE OF A DRILLING TOOL | EP09763078.4 | 2009-04-17 | EP2279327B1 | 2013-10-23 | PRILL, Jonathan, Ryan; MARCHAND, Nicholas, Ryan; JOHNS, Ralph, William, Graeme |
| A downhole rotational rate control apparatus, adapted for coupling to the lower end of a drill string, includes a progressive cavity (PC) motor, a driveshaft, a mud flow control valve, and an electronics section. Drilling mud flowing downward through the drill string is partially diverted to flow upward through the PC motor and out into the wellbore annulus, with the mud flow rate and, in turn, the PC motor speed being controlled by the mud flow control valve. The control valve is actuated by a control motor in response to inputs from a sensor assembly in the electronics section. The PC motor drives the driveshaft and a controlled downhole device at a specific zero or non-zero rotational rate. By varying the rotational rate of the PC motor relative to the rotational rate of the drill string, the tool face orientation or non-zero rotational speed of the controlled device in either direction can be varied in a controlled manner. | ||||||
| 218 | Downhole deployment valves | EP13172554.1 | 2008-03-31 | EP2650467A1 | 2013-10-16 | Noske, Joe; Iblings, David; Pavel, David; Brunnert, David J.; Smith, Paul, L.; Grayson, Michael Brian |
Methods and apparatus enable reliable and improved isolation between two portions of a bore extending through a casing string disposed in a borehole. A downhole deployment valve (DDV) may provide the isolation utilizing a valve member such as a flapper (102) that is disposed in a housing (106) of the DDV and is designed to close against a seat (110) within the housing. The DDV includes an operating mechanism for opening/closing the DDV. In use, pressure in one portion of a well that is in fluid communication with a well surface may be bled off and open at well surface while maintaining pressure in another portion of the casing string beyond the DDV.
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| 219 | Valve for communication of a measurement while drilling system | EP13162378.7 | 2013-04-04 | EP2647791A2 | 2013-10-09 | Rogers, John Preston; Bonner, Stephen D.; Kirby, Robert Rudolph; Linyaev, Eugene |
A valve for communication of a measurement while drilling system includes a first structure having a central portion and one or more elongate portions radially extending from the central portion, and a second structure having one or more portions which substantially bound a central orifice region and one or more elongate orifice regions radially extending from the central orifice region. At least one of the first structure and the second structure is configured to be rotated about a rotation axis to produce a relative rotation between the first structure and the second structure such that a flow path through which mud can flow varies as the at least one of the first structure and the second structure rotates about the rotation axis. The central portion has a maximum inscribed circle encircling the rotation axis and having a first radius and the central orifice region has a maximum inscribed circle encircling the rotation axis and having a second radius greater than the first radius.
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| 220 | TWO-PORT PERCUSSION MOLE | EP11743581.8 | 2011-07-14 | EP2593628A2 | 2013-05-22 | BRICE, Mark |
| A percussion mole for inserting a ground-loop for a geothermal heat-pump apparatus. The ground-loop includes a first pipe and a second pipe. The mole comprises: a percussive drive mechanism; a first passage connectable to the first pipe, for receiving a driving fluid via the first pipe and delivering it to the drive mechanism, during insertion of the ground-loop; a second passage connectable to the second pipe, for exhausting the driving fluid from the drive mechanism via the second pipe, during insertion of the ground-loop; and a connection connecting the first passage with the second passage. The connection includes a non-return valve arranged to restrict flow of the driving fluid from the first passage to the second passage during insertion of the ground-loop but permit flow in the opposite direction, whereby after insertion, when the heat pump apparatus is in use, the ground-loop comprises the first and second pipes; the first and second passages; and the connection. | ||||||
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