EP1867831B1 - Verfahren und Vorrichtung zum Drahtseilbohren mittels eines gewickelten Rohrstranges - Google Patents

Verfahren und Vorrichtung zum Drahtseilbohren mittels eines gewickelten Rohrstranges Download PDF

Info

Publication number
EP1867831B1
EP1867831B1 EP06291008.8A EP06291008A EP1867831B1 EP 1867831 B1 EP1867831 B1 EP 1867831B1 EP 06291008 A EP06291008 A EP 06291008A EP 1867831 B1 EP1867831 B1 EP 1867831B1
Authority
EP
European Patent Office
Prior art keywords
drilling
fluid
flow
annulus
tubular conveyance
Prior art date
Legal status (The legal status is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the status listed.)
Not-in-force
Application number
EP06291008.8A
Other languages
English (en)
French (fr)
Other versions
EP1867831A1 (de
Inventor
Iain Cooper
Spyro Kotsonis
Warren Zemlak
Current Assignee (The listed assignees may be inaccurate. Google has not performed a legal analysis and makes no representation or warranty as to the accuracy of the list.)
Services Petroliers Schlumberger SA
Gemalto Terminals Ltd
Prad Research and Development NV
Schlumberger Technology BV
Schlumberger Holdings Ltd
Original Assignee
Services Petroliers Schlumberger SA
Gemalto Terminals Ltd
Prad Research and Development NV
Schlumberger Technology BV
Schlumberger Holdings Ltd
Priority date (The priority date is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the date listed.)
Filing date
Publication date
Priority to EP06291008.8A priority Critical patent/EP1867831B1/de
Application filed by Services Petroliers Schlumberger SA, Gemalto Terminals Ltd, Prad Research and Development NV, Schlumberger Technology BV, Schlumberger Holdings Ltd filed Critical Services Petroliers Schlumberger SA
Priority to GB0823035A priority patent/GB2454373A/en
Priority to US12/304,946 priority patent/US20090321141A1/en
Priority to PCT/EP2007/005206 priority patent/WO2007144157A1/en
Priority to CA002655245A priority patent/CA2655245A1/en
Priority to MX2008016052A priority patent/MX2008016052A/es
Priority to RU2009101029/03A priority patent/RU2436929C2/ru
Publication of EP1867831A1 publication Critical patent/EP1867831A1/de
Application granted granted Critical
Publication of EP1867831B1 publication Critical patent/EP1867831B1/de
Not-in-force legal-status Critical Current
Anticipated expiration legal-status Critical

Links

Images

Classifications

    • E—FIXED CONSTRUCTIONS
    • E21—EARTH OR ROCK DRILLING; MINING
    • E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B4/00—Drives for drilling, used in the borehole
    • E21B4/04—Electric drives
    • E—FIXED CONSTRUCTIONS
    • E21—EARTH OR ROCK DRILLING; MINING
    • E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B17/00—Drilling rods or pipes; Flexible drill strings; Kellies; Drill collars; Sucker rods; Cables; Casings; Tubings
    • E21B17/20—Flexible or articulated drilling pipes, e.g. flexible or articulated rods, pipes or cables
    • E—FIXED CONSTRUCTIONS
    • E21—EARTH OR ROCK DRILLING; MINING
    • E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B21/00—Methods or apparatus for flushing boreholes, e.g. by use of exhaust air from motor
    • E21B21/10—Valve arrangements in drilling-fluid circulation systems
    • E21B21/103—Down-hole by-pass valve arrangements, i.e. between the inside of the drill string and the annulus
    • E—FIXED CONSTRUCTIONS
    • E21—EARTH OR ROCK DRILLING; MINING
    • E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B4/00—Drives for drilling, used in the borehole
    • E21B4/18—Anchoring or feeding in the borehole

Definitions

  • This invention relates to methods and apparatus for drilling boreholes that is particularly applicable to drilling with wireline drilling apparatus carried on coiled tubing.
  • CT Current conventional coiled tubing drilling
  • PDM drilling positive displacement motor
  • US 2 548 616 describes a method of drilling a well with a conduit to surface through which a fluid is pumped (today's CTD).
  • the option of a cable in the CT with an electric motor at the bottom-hole assembly driving the bit is also described but the conduit still provides the axial thrust for drilling.
  • EP 0 110 182 describes an apparatus with a hydraulic tractor/crawler (with anchors and a stroker), an umbilical from surface for communications and powering of an electric pump that powers the hydraulic tractor, and methods of steering.
  • the means of rotating the bit are described as purely hydraulic (either from the hydraulic distribution system, or from a hydraulic line from the surface.) CT is also described.
  • US 6 629 570 describes a high-power electric motor capable of drilling on CT. In use drilling fluid flows through the motor to return to the surface through the bit and annulus (conventional circulation).
  • US20040134662 describes a drilling system connected to a composite umbilical. Drilling fluid is pumped down from the surface outside the umbilical and diverted into the drilling system to be delivered to the drill bit to return to the surface through the umbilical (reverse circulation).
  • US4630691 describes a drilling system for under balanced drilling. A flushing fluid is pumped down the drill string to the bit. Bypass means discharge upward flowing fluid into the wellbore annulus above the drilling tool to return to the surface.
  • WO 2004 011766 describes a wireline powered drilling system in which produced fluid from the borehole is circulated as drilling fluid.
  • a downhole pump is used to perform conventional or reverse circulation through the downhole drilling tool. Flow to the surface is through production tubing around the cable.
  • the object of the invention is to provide a drilling apparatus that does not need large capacity CT due to reduced hydraulic power requirements yet which still provides effective hole cleaning in the drilling region to avoid sticking.
  • the invention achieves this object by providing electric power to the drilling system via a cable and by providing a flow diverter to allow downward drilling fluid flow around the outside of the drilling assembly while using normal annulus flow above the drilling system for good cuttings transport.
  • One aspect of the invention comprises apparatus for drilling an underground borehole, comprising:
  • the use of the flow diverter makes it possible to provide reverse circulation (circulation of fluid from the annulus into the BHA) where drilling is taking place, so improving hole cleaning in small diameter boreholes and reducing the risk of sticking.
  • the drilling system has separate axial and rotary drive mechanisms. It is particularly preferred that the axial drive mechanism comprises a crawler system.
  • the drilling motor can comprise an electric motor powered through the electric cable.
  • the drilling system typically comprises an electric pump but can comprise a jet pump instead of the electrically powered pump.
  • the tubular conveyance system comprises coiled tubing. This can be a single coiled tube or can comprise several sections joined end o end. Because the drilling action is handled by the drilling system, it is not necessary that the tubular conveyance system provide the torque four a rotary drilling action nor high axial stiffness to transfer the weight on the bit necessary for drilling.
  • the flow diverter forms part of the connector.
  • the flow diverter is positioned in the tubular conveyance above the connector.
  • the flow diverter directs part of the drilling fluid down around the outside of the drilling system and the remainder of the fluid back to the surface around the outside of the tubular conveyance.
  • the reverse circulation around the drilling system changes to conventional circulation around the tubular conveyance which allows improved cuttings transport in the main part of the borehole.
  • the flow diverter can be arranged to divert flow from the inside of the drilling system to the annulus above the point at which it diverts flow from the tubular conveyance system into the annulus.
  • One embodiment of the apparatus further comprises a jetting system including one or more flow nozzles arranged to direct jets of fluid inside the borehole to remove accumulated deposits.
  • the flow nozzles are adjustable so as to change the direction of flow of fluid therefrom.
  • the flow diverter can direct fluid into the flow nozzles for jetting and further comprises a valve adjustable to vary the amount of fluid directed through the flow nozzles and the amount of fluid directed into the annulus.
  • the apparatus can further comprise a rotatable crown driven by the motor for use in back reaming.
  • a turbine driven by fluid flow from the tubular conveyance system can be connected to drive the crown via a gear train.
  • An electric generator can be connected to the turbine and an electric motor connected to the crown via the gear train, the output of the generator being used to power the electric motor and drive the crown.
  • Another aspect of the invention comprises a method of drilling an underground borehole using an apparatus comprising a tubular conveyance system including an electric cable and a supply of drilling fluid; a drilling system comprising an electrically powered pump and a drilling motor; a connector connecting the drilling system to the tubular conveyance system, through which the pump and drilling motor are connected to the electric cable; and a flow diverter; the method comprising:
  • method further comprises directing jets of fluid from one or more nozzles of a jetting system inside the borehole to remove accumulated deposits.
  • the flow nozzles can be adjusted so as to change the direction of flow of fluid therefrom.
  • Fluid can be diverted into the flow nozzles for jetting using the flow diverter and adjusting a valve to vary the amounts of fluid directed through the flow nozzles and the amount of fluid directed into the annulus.
  • the method can further comprise back reaming the borehole using the drilling system.
  • the back reaming can be performed using a rotating crown driven by the drilling motor and/or a hydraulic system.
  • the drilling operation shown in Figure 1 is conducted using a conventional CT unit 10 and injector/pressure control setup 12 at the surface of the well 14 and is being used to drill a lateral well 16 extending away from the main well 14.
  • the lateral well has been started in the usual manner by milling a window in the casing and drilling laterally using a whipstock to provide deviation in drilling direction.
  • the drilling apparatus comprises a CT conveyance system 18 carrying a drilling assembly 20 at its lower end.
  • the conveyance system 18 comprises a CT having an electric cable running inside from the surface.
  • the weight of the tool is carried by the CT 18, so the electric cable only needs to be able to support its weight.
  • a drilling fluid supply forms part of the CT unit 10 at the surface and pumps drilling fluid down the inside of the CT.
  • the drilling assembly comprises a motor section 22 including an electric motor providing rotary drive to a drill bit 24.
  • a crawler unit 26 comprising an open hole tractor for providing axial drive to the drill bit 24. Acting together, the electric motor and the crawler unit 26 provide the drive to the drill bit 24 to allow drilling to proceed.
  • the crawler unit 26 can also be operated in reverse to pull the motor section and bit from the borehole.
  • a pump section 28 is mounted above the crawler unit 26 and has an electric pump mounted therein.
  • a channel extends from the drill bit up through the motor section 22 and crawler section 26 to the pump so that in normal use, the pump can draw fluid and drilled cuttings up through the drill bit 24 and inside the drilling assembly 20.
  • the drilling assembly 20 is connected to the end of the CT by means of a connection unit 30.
  • the connection unit 30 provides a mechanical connection between the CT and the drilling assembly 20 and an electrical connection between the electric cable and the electrical components of the drilling assembly 20.
  • connection unit 30 also comprised a flow diverter as is shown in more detail in Figure 2 .
  • the flow diverter is formed by flow channels 32, 34 in the connection unit 30.
  • Flow channel 32 is connected to the interior of the CT so that fluid flowing down the CT is vented into the annulus surrounding the CT and drilling assembly via lower ports 36 in the lower part of the connector 30. Fluid exiting these lower ports 36 flows mainly back to the surface in the annulus but a portion of this fluid also flows down the annulus around the drilling assembly 20 to be drawn up through the bit 24 by the action of the pump.
  • Flow channel 34 connects to the channel running through the inside of the drilling assembly 20 and is vented into the annulus via upper ports 38 in the upper part of the connector 30 above the lower ports 36.
  • the connector shown in Figure 2 also has a back reaming device comprising a rotatable crown 40 mounted at the top of the connector 30.
  • the crown 40 is driven by a turbine and gear train (not shown), the turbine being driven by the flow of fluid along the tool.
  • the turbine can drive an electrical generator (alternator) for powering an electric motor for driving the crown 40.
  • a still further version can take electric power from the cable.
  • the crown 40 can be operated when the drilling assembly 20 is pulled out of hole and allows any lips or ledges that have formed to be smoothed and allow easy passage of the drilling assembly 20 from the well with less likelihood of sticking.
  • FIG 3 shows a further embodiment of the invention in which the flow diverter is positioned in the main well 14 in order to reduce the issues relating to transport of cuttings in the lateral borehole 16 and possible contamination of the reservoir with cuttings infiltration through the borehole wall.
  • the CT is split during deployment, as described in European patent application no. EP 1780372 and the flow diverter 42 is inserted at this point.
  • the combination with a CT connector 44 between the CT and the drilling assembly 20 allows the drilled cuttings to be returned to the main well 14 (preferably a cased section) by ejecting the cuttings from the flow diverter 42 into the annulus.
  • the conventional drilling fluid circulation at this point is used to transport the cuttings to the surface. This approach eliminates cuttings transport in the open-hole annulus section of the lateral well 16, and therefore decreases the possibility of accumulation of cuttings beds. This in turn reduces the sticking risks when pulling the drilling assembly 20 out of hole.
  • the drilling assembly 20 can include sensors to assess the condition of the borehole for the risk of solids build-up that can potentially impede the movement of the BHA and/or CT in the well.
  • the sensors included in the tool to detect such conditions include calliper, azimuthal density neutron, and internal and annular pressure sensors.
  • the fluid jetting can be provided by nozzles, preferably in or near the connector 30 but potentially in other parts of the drilling assembly 20 or elsewhere in the CT.
  • nozzles 46 are configured to provide a jetting flow with a helical swirl as it exits a nozzle. Such nozzles are known in other well cleaning applications and can be applied mutatis mutandis to this application.
  • the jetting arrangement can include a mechanism using hydraulic or electric signals such that allows the direction of the flow from the nozzle to be adjusted in the vicinity of the cuttings, to further mobilize the cuttings, or to give some directional jetting focus as necessary. Dictation of the outward and rear jetting flow ratio will give further control on the cleaning efficiency for the specific conditions.
  • measurements incorporated in the tool e.g. internal and annular pressures
  • ECD equivalent circulating density
  • Hydraulic signalling can include methods such as flow rate changes and modulation from the surface unit pump, and ball drops.
  • Electric signals can include solenoid activation, or use of bi-stable valves (to decrease the need for high power consumption during extended periods of time as is the case with traditional solenoids). Such bi-stable valves are described by EP113578 .
  • CT flow To power a turbine whose axis turns the reamer crown via a gear train.
  • CT flow Another involves using the CT flow to power a turbine connected to an alternator to create electrical power that can then run an electric motor that turns the reamer crown through a gear train.
  • a downhole valve can also be included to dictate the proportion of flow split between exit ports 36 and jetting nozzles 46. Apart from being able to change between jetting and simply circulating, this valve can also produce pressure pulses to remove harder ledges in a similar manner to that described in US5944123 and US6062311 .
  • the valve can either be electrically activated using surface commands, or hydraulically commanded using flow variation schemes (e.g. switches to jetting above a specific flow rate and pressure drop.)
  • An additional advantage of power available in the fluid in the CT is the ability to power a jet pump in the pump section 28.
  • This jet pump can replace the electric motor driving the pump.
  • the use of a jet pump will create a small increase in surface power needs but has the advantage that the tool length can be substantially reduced (pump, transmission, gear box, motor, oil compensation, motor control and drive electronics), while increasing the reliability.
  • a dual pump system can be employed to circulate around the drilling assembly and in the lateral borehole 16, and to act as a booster in the well 14 to circulate cuttings to the surface.

Landscapes

  • Engineering & Computer Science (AREA)
  • Life Sciences & Earth Sciences (AREA)
  • Geology (AREA)
  • Mining & Mineral Resources (AREA)
  • Mechanical Engineering (AREA)
  • Physics & Mathematics (AREA)
  • Environmental & Geological Engineering (AREA)
  • Fluid Mechanics (AREA)
  • General Life Sciences & Earth Sciences (AREA)
  • Geochemistry & Mineralogy (AREA)
  • Earth Drilling (AREA)

Claims (23)

  1. Vorrichtung zum Bohren eines unterirdischen Bohrlochs, die umfasst:
    - ein rohrförmiges Fördersystem (18), das ein elektrisches Kabel und eine Versorgung für Bohrfluid enthält, wobei die Versorgung für Bohrfluid im Gebrauch dafür ausgelegt ist, Fluid von der Oberfläche nach unten in den Innenraum der rohrförmigen Förderung zu pumpen, damit es durch den Ringraum zwischen der Außenseite der rohrförmigen Förderung und dem Bohrloch zur Oberfläche zurückkehrt;
    - ein Bohrsystem (20), das einen elektrisch angetriebenen Bohrmotor (22) und eine Pumpe (28), die dafür ausgelegt ist, Fluid von dem Bohrloch außerhalb des Bohrsystems durch den Innenraum des Bohrsystems (20) nach oben zu pumpen;
    - einen Verbinder (30), um das Bohrsystem (20) mit dem rohrförmigen Fördersystem (18) und mit dem elektrischen Kabel zu verbinden, und
    - einen Strömungsumlenker (32, 34), bei dem eine Strömung nach unten innerhalb des rohrförmigen Fördersystems (18) in den Ringraum umgelenkt wird und die Strömung nach oben innerhalb des Bohrsystems (20) in den Ringraum umgelenkt wird, wobei im Gebrauch der Strömungsumlenker (32, 34) einen Teil des Bohrfluids nach unten um die Außenseite des Bohrsystems (20) und den Rest des Fluids zurück zu der Oberfläche um die Außenseite der rohrförmigen Förderung (18) lenkt.
  2. Vorrichtung nach Anspruch 1, wobei das Bohrsystem (20) getrennte axiale und rotatorische Antriebsmechanismen besitzt.
  3. Vorrichtung nach Anspruch 2, wobei der axiale Antriebsmechanismus ein Raupensystem (26) umfasst.
  4. Vorrichtung nach Anspruch 1, 2 oder 3, wobei der Bohrmotor (22) einen Elektromotor umfasst, der durch das elektrische Kabel mit Leistung versorgt wird.
  5. Vorrichtung nach Anspruch 1, 2 oder 3, wobei das Bohrsystem (20) eine Strahlpumpe umfasst, um Fluid durch das Bohrsystem (20) zu pumpen.
  6. Vorrichtung nach einem vorhergehenden Anspruch, wobei das rohrförmige Fördersystem (18) eine Rohrschlange umfasst.
  7. Vorrichtung nach einem vorhergehenden Anspruch, wobei der Strömungsumlenker einen Teil des Verbinders (30) bildet.
  8. Vorrichtung nach einem der Ansprüche 1-6, wobei der Strömungsumlenker in der rohrförmigen Förderung (18) über dem Verbinder (30) positioniert ist.
  9. Vorrichtung nach einem vorhergehenden Anspruch, wobei der Strömungsumlenker dafür ausgelegt ist, Strömung von innerhalb des Bohrsystems (20) in den Ringraum oberhalb des Punkts, an dem er Strömung von dem rohrförmigen Fördersystem (18) in den Ringraum umlenkt, umzulenken.
  10. Vorrichtung nach einem vorhergehenden Anspruch, die ferner ein Strahlbildungssystem umfasst, das eine oder mehrere Strömungsdüsen (46) enthält, die dafür ausgelegt sind, Fluidstrahlen in dem Bohrloch zu lenken, um angesammelte Ablagerungen zu entfernen.
  11. Vorrichtung nach Anspruch 10, wobei die Strömungsdüsen (46) einstellbar sind, um die Richtung der Fluidströmung hiervon zu ändern.
  12. Vorrichtung nach Anspruch 10 oder 11, wobei der Strömungsumlenker Fluid in die Strömungsdüsen (46) für die Strahlbildung lenkt und ferner ein Ventil umfasst, das einstellbar ist, um die durch die Strömungsdüsen (46) gelenkte Fluidmenge und die in den Ringraum gelenkte Fluidmenge zu variieren.
  13. Vorrichtung nach einem vorhergehenden Anspruch, die ferner eine drehbare Krone (40) umfasst, die durch einen Motor angetrieben wird, der für die Verwendung beim Rückwärtsräumen mit Leistung versorgt wird.
  14. Vorrichtung nach Anspruch 13, wobei der Motor ein Elektromotor ist, der durch das elektrische Kabel mit Leistung versorgt wird.
  15. Vorrichtung nach Anspruch 13, die ferner eine Turbine umfasst, die durch Fluid angetrieben wird, das von dem rohrförmigen Fördersystem (18) strömt, und angeschlossen ist, um die Krone (40) über einen Getriebezug anzutreiben.
  16. Vorrichtung nach Anspruch 15, die ferner einen elektrischen Generator, der mit der Turbine verbunden ist, und einen Elektromotor, der mit der Krone (40) über den Getriebezug verbunden ist, umfasst, wobei der Ausgang des Generators verwendet wird, um den Elektromotor mit Leistung zu versorgen und die Krone (40) anzutreiben.
  17. Verfahren zum Bohren eines unterirdischen Bohrlochs unter Verwendung einer Vorrichtung, die ein rohrförmiges Fördersystem (18), das ein elektrisches Kabel und eine Versorgung für Bohrfluid enthält; ein Bohrsystem (20), das eine mit elektrischer Leistung versorgte Pumpe (28) und einen Bohrmotor (22) enthält; einen Verbinder (30), um das Bohrsystem (20) mit dem rohrförmigen Fördersystem (18) zu verbinden, durch den die Pumpe (28) und der Bohrmotor (22) mit dem elektrischen Kabel verbunden sind; und einen Strömungsumlenker umfasst, wobei das Verfahren umfasst:
    - Pumpen von Fluid von der Oberfläche nach unten innerhalb der rohrförmigen Förderung (18), damit es durch den Ringraum zwischen der Außenseite der rohrförmigen Förderung und dem Bohrloch zu der Oberfläche zurückkehrt; und
    - Verwenden der mit elektrischer Leistung versorgten Pumpe (28) des Bohrsystems (20), um Fluid von dem Bohrloch außerhalb des Bohrsystems (20) nach oben durch den Innenraum des Bohrsystems (20) zu pumpen;
    - Umlenken einer Fluidströmung (32) nach unten innerhalb des rohrförmigen Fördersystems (18) in den Ringraum (36, 38), wobei ein Teil des Fluids nach unten um die Außenseite des Bohrsystems (20) und der Rest des Fluids zurück um die Außenseite der rohrförmigen Förderung (18) zu der Oberfläche umgelenkt wird, und Umlenken der Strömung (34) nach oben in dem Bohrsystem (20) in den Ringraum unter Verwendung des Strömungsumlenkers; und
    - Verwenden des Bohrmotors (22), um das Bohrloch unter Verwendung des Bohrsystems (20) zu bohren.
  18. Verfahren nach Anspruch 17, das ferner das Lenken von Fluidstrahlen von einer oder von mehreren Düsen (46) eines Strahlbildungssystems in das Bohrloch umfasst, um angesammelte Ablagerungen zu entfernen.
  19. Verfahren nach Anspruch 18, das ferner das Einstellen der Strömungsdüsen (46) umfasst, um die Richtung der Fluidströmung hiervon zu ändern.
  20. Verfahren nach Anspruch 17, 18 oder 19, das das Lenken von Fluid in die Strömungsdüsen (46) für die Strahlbildung unter Verwendung des Strömungsumlenkers und das Einstellen eines Ventils, um die durch die Strömungsdüsen (46) gelenkte Fluidmenge und die in den Ringraum gelenkte Fluidmenge zu variieren, umfasst.
  21. Verfahren nach einem der Ansprüche 17-20, das ferner das Rückräumen des Bohrlochs unter Verwendung eines zusätzlichen Elektromotors in dem Bohrsystem (20) umfasst.
  22. Verfahren nach Anspruch 17-20, das das Rückräumen unter Verwendung einer rotierenden Krone (40), die durch den Bohrmotor (22) angetrieben wird, umfasst.
  23. Verfahren nach Anspruch 21 oder 22, das das Rückräumen unter Verwendung eines Strahlbildungssystems umfasst.
EP06291008.8A 2006-06-15 2006-06-15 Verfahren und Vorrichtung zum Drahtseilbohren mittels eines gewickelten Rohrstranges Not-in-force EP1867831B1 (de)

Priority Applications (7)

Application Number Priority Date Filing Date Title
EP06291008.8A EP1867831B1 (de) 2006-06-15 2006-06-15 Verfahren und Vorrichtung zum Drahtseilbohren mittels eines gewickelten Rohrstranges
US12/304,946 US20090321141A1 (en) 2006-06-15 2007-06-12 Methods and Apparatus for Wireline Drilling On Coiled Tubing
PCT/EP2007/005206 WO2007144157A1 (en) 2006-06-15 2007-06-12 Methods and apparatus for wireline drilling on coiled tubing
CA002655245A CA2655245A1 (en) 2006-06-15 2007-06-12 Methods and apparatus for wireline drilling on coiled tubing
GB0823035A GB2454373A (en) 2006-06-15 2007-06-12 Methods and apparatus for wireline drilling on coiled tubing
MX2008016052A MX2008016052A (es) 2006-06-15 2007-06-12 Metodo y aparato para la perforacion alambrica en tuberia enrollada.
RU2009101029/03A RU2436929C2 (ru) 2006-06-15 2007-06-12 Способы и установки для бурения на гибкой трубе

Applications Claiming Priority (1)

Application Number Priority Date Filing Date Title
EP06291008.8A EP1867831B1 (de) 2006-06-15 2006-06-15 Verfahren und Vorrichtung zum Drahtseilbohren mittels eines gewickelten Rohrstranges

Publications (2)

Publication Number Publication Date
EP1867831A1 EP1867831A1 (de) 2007-12-19
EP1867831B1 true EP1867831B1 (de) 2013-07-24

Family

ID=37400909

Family Applications (1)

Application Number Title Priority Date Filing Date
EP06291008.8A Not-in-force EP1867831B1 (de) 2006-06-15 2006-06-15 Verfahren und Vorrichtung zum Drahtseilbohren mittels eines gewickelten Rohrstranges

Country Status (7)

Country Link
US (1) US20090321141A1 (de)
EP (1) EP1867831B1 (de)
CA (1) CA2655245A1 (de)
GB (1) GB2454373A (de)
MX (1) MX2008016052A (de)
RU (1) RU2436929C2 (de)
WO (1) WO2007144157A1 (de)

Cited By (2)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
CN106703684A (zh) * 2017-02-22 2017-05-24 武汉科技大学 一种地下钻进机器人
CN109899061A (zh) * 2019-03-29 2019-06-18 浙江大学 一种用于原位海底地层实时测量的钻推式机器人

Families Citing this family (21)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US6464003B2 (en) 2000-05-18 2002-10-15 Western Well Tool, Inc. Gripper assembly for downhole tractors
US8245796B2 (en) 2000-12-01 2012-08-21 Wwt International, Inc. Tractor with improved valve system
US7392859B2 (en) 2004-03-17 2008-07-01 Western Well Tool, Inc. Roller link toggle gripper and downhole tractor
US7624808B2 (en) 2006-03-13 2009-12-01 Western Well Tool, Inc. Expandable ramp gripper
WO2008061100A1 (en) 2006-11-14 2008-05-22 Rudolph Ernst Krueger Variable linkage assisted gripper
GB2454702A (en) * 2007-11-15 2009-05-20 Schlumberger Holdings Cutting removal with a wireline lateral drilling tool
GB2454895B (en) * 2007-11-22 2012-01-11 Schlumberger Holdings Flow diverter for drilling
US8485278B2 (en) 2009-09-29 2013-07-16 Wwt International, Inc. Methods and apparatuses for inhibiting rotational misalignment of assemblies in expandable well tools
US9175515B2 (en) * 2010-12-23 2015-11-03 Schlumberger Technology Corporation Wired mud motor components, methods of fabricating the same, and downhole motors incorporating the same
GB2486777B (en) * 2010-12-23 2017-04-05 Schlumberger Holdings Wired mud motor components, methods of fabricating the same, and downhole motors incorporating the same
US9447648B2 (en) 2011-10-28 2016-09-20 Wwt North America Holdings, Inc High expansion or dual link gripper
EA201490942A1 (ru) * 2011-11-08 2014-08-29 Шеврон Ю.Эс.Эй. Инк. Устройство и способ бурения скважин в подземном пласте
WO2013119586A1 (en) * 2012-02-06 2013-08-15 Wwt International Inc. Motor saver sub for down hole drilling assemblies
US9157278B2 (en) 2012-03-01 2015-10-13 Baker Hughes Incorporated Apparatus including load driven by a motor coupled to an alternator
US9359862B2 (en) * 2012-06-04 2016-06-07 Schlumberger Technology Corporation Wellbore isolation while placing valves on production
WO2014031098A1 (en) * 2012-08-20 2014-02-27 Halliburton Energy Services, Inc. Slow drilling assembly and method
US9488020B2 (en) 2014-01-27 2016-11-08 Wwt North America Holdings, Inc. Eccentric linkage gripper
US10697245B2 (en) 2015-03-24 2020-06-30 Cameron International Corporation Seabed drilling system
CN104948134B (zh) * 2015-06-30 2018-04-06 安东柏林石油科技（北京）有限公司 存储式精密定量油气井井下工作剂注入系统及注入方法
US10491004B2 (en) * 2016-10-19 2019-11-26 Caterpillar Inc. Systems and methods for controlling power output to a load by multiple gensets based on load operation modes
WO2023183577A1 (en) * 2022-03-25 2023-09-28 Schlumberger Technology Corporation Method and system for simultaneous wireline milling and debris collection

Family Cites Families (13)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US2548616A (en) 1948-02-02 1951-04-10 Priestman George Dawson Well drilling
US4463814A (en) 1982-11-26 1984-08-07 Advanced Drilling Corporation Down-hole drilling apparatus
US4630691A (en) 1983-05-19 1986-12-23 Hooper David W Annulus bypass peripheral nozzle jet pump pressure differential drilling tool and method for well drilling
US4844182A (en) * 1988-06-07 1989-07-04 Mobil Oil Corporation Method for improving drill cuttings transport from a wellbore
GB9810321D0 (en) 1998-05-15 1998-07-15 Head Philip Method of downhole drilling and apparatus therefore
MXPA01012424A (es) * 1999-06-03 2002-07-30 Shell Int Research Metodo para crear una perforacion de pozo.
US7032658B2 (en) 2002-01-31 2006-04-25 Smart Drilling And Completion, Inc. High power umbilicals for electric flowline immersion heating of produced hydrocarbons
US6877571B2 (en) * 2001-09-04 2005-04-12 Sunstone Corporation Down hole drilling assembly with independent jet pump
AU2003251337A1 (en) 2002-07-25 2004-02-16 Etudes & Productions Schlumberger Drilling method
US7036611B2 (en) * 2002-07-30 2006-05-02 Baker Hughes Incorporated Expandable reamer apparatus for enlarging boreholes while drilling and methods of use
US7114582B2 (en) * 2002-10-04 2006-10-03 Halliburton Energy Services, Inc. Method and apparatus for removing cuttings from a deviated wellbore
US20060054354A1 (en) 2003-02-11 2006-03-16 Jacques Orban Downhole tool
DE602004001328T2 (de) 2004-01-27 2007-05-10 Schlumberger Technology B.V. Unterirdisches Bohren einer Lateralbohrung

Cited By (2)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
CN106703684A (zh) * 2017-02-22 2017-05-24 武汉科技大学 一种地下钻进机器人
CN109899061A (zh) * 2019-03-29 2019-06-18 浙江大学 一种用于原位海底地层实时测量的钻推式机器人

Also Published As

Publication number Publication date
RU2009101029A (ru) 2010-07-20
GB2454373A (en) 2009-05-06
MX2008016052A (es) 2009-02-06
RU2436929C2 (ru) 2011-12-20
US20090321141A1 (en) 2009-12-31
CA2655245A1 (en) 2007-12-21
GB0823035D0 (en) 2009-01-28
EP1867831A1 (de) 2007-12-19
WO2007144157A1 (en) 2007-12-21

Similar Documents

Publication Publication Date Title
EP1867831B1 (de) Verfahren und Vorrichtung zum Drahtseilbohren mittels eines gewickelten Rohrstranges
WO2022083601A1 (zh) 短半径钻井工具、高稳定性可控轨迹柔性钻井工具及方法
US7055627B2 (en) Wellbore fluid circulation system and method
EP2225438B1 (de) Verfahren zur entfernung eines hydratsteckers aus einer flussleitung
US6305469B1 (en) Method of creating a wellbore
US7743849B2 (en) Dual tractor drilling system
CN112267830A (zh) 短半径可控轨迹钻井工具
US20100314174A1 (en) Flow diverter for drilling
US8708066B2 (en) Dual BHA drilling system
NO325928B1 (no) Anordning og fremgangsmate for rotering av en del av en borestreng
CN101824966A (zh) 一种高压水力喷射超短半径水平井眼的装置
GB2454900A (en) Self circulating drill bit
AU2006321380A1 (en) Method and apparatus for installing deflecting conductor pipe
US20150337598A1 (en) Pressure Booster for Rotary Steerable System Tool
EP1696101A1 (de) Vorrichtung und Verfahren geeignet für Bohrlochreinigung während des Bohrens
US20080053663A1 (en) Downhole tool with turbine-powered motor
US8925652B2 (en) Lateral well drilling apparatus and method
WO2009065536A1 (en) Downhole drilling system
US20080053703A1 (en) Downhole tool with turbine-powered pump
US20180320459A1 (en) Drill String Applications Tool
CA3131963A1 (en) Drill string applications tool
WO2016028160A1 (en) Complementing drilling system and method

Legal Events

Date Code Title Description
PUAI Public reference made under article 153(3) epc to a published international application that has entered the european phase

Free format text: ORIGINAL CODE: 0009012

AK Designated contracting states

Kind code of ref document: A1

Designated state(s): AT BE BG CH CY CZ DE DK EE ES FI FR GB GR HU IE IS IT LI LT LU LV MC NL PL PT RO SE SI SK TR

AX Request for extension of the european patent

Extension state: AL BA HR MK YU

17P Request for examination filed

Effective date: 20080515

17Q First examination report despatched

Effective date: 20080718

AKX Designation fees paid

Designated state(s): AT BE BG CH CY CZ DE DK EE ES FI FR GB GR HU IE IS IT LI LT LU LV MC NL PL PT RO SE SI SK TR

GRAP Despatch of communication of intention to grant a patent

Free format text: ORIGINAL CODE: EPIDOSNIGR1

GRAS Grant fee paid

Free format text: ORIGINAL CODE: EPIDOSNIGR3

GRAA (expected) grant

Free format text: ORIGINAL CODE: 0009210

AK Designated contracting states

Kind code of ref document: B1

Designated state(s): AT BE BG CH CY CZ DE DK EE ES FI FR GB GR HU IE IS IT LI LT LU LV MC NL PL PT RO SE SI SK TR

REG Reference to a national code

Ref country code: GB

Ref legal event code: FG4D

REG Reference to a national code

Ref country code: CH

Ref legal event code: EP

REG Reference to a national code

Ref country code: AT

Ref legal event code: REF

Ref document number: 623588

Country of ref document: AT

Kind code of ref document: T

Effective date: 20130815

REG Reference to a national code

Ref country code: IE

Ref legal event code: FG4D

REG Reference to a national code

Ref country code: DE

Ref legal event code: R096

Ref document number: 602006037479

Country of ref document: DE

Effective date: 20130919

REG Reference to a national code

Ref country code: AT

Ref legal event code: MK05

Ref document number: 623588

Country of ref document: AT

Kind code of ref document: T

Effective date: 20130724

REG Reference to a national code

Ref country code: NL

Ref legal event code: VDEP

Effective date: 20130724

REG Reference to a national code

Ref country code: LT

Ref legal event code: MG4D

PG25 Lapsed in a contracting state [announced via postgrant information from national office to epo]

Ref country code: SE

Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT

Effective date: 20130724

Ref country code: PT

Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT

Effective date: 20131125

Ref country code: AT

Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT

Effective date: 20130724

Ref country code: IS

Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT

Effective date: 20131124

Ref country code: CY

Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT

Effective date: 20130703

Ref country code: LT

Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT

Effective date: 20130724

Ref country code: BE

Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT

Effective date: 20130724

PG25 Lapsed in a contracting state [announced via postgrant information from national office to epo]

Ref country code: LV

Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT

Effective date: 20130724

Ref country code: SI

Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT

Effective date: 20130724

Ref country code: PL

Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT

Effective date: 20130724

Ref country code: GR

Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT

Effective date: 20131025

Ref country code: NL

Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT

Effective date: 20130724

Ref country code: FI

Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT

Effective date: 20130724

PG25 Lapsed in a contracting state [announced via postgrant information from national office to epo]

Ref country code: CY

Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT

Effective date: 20130724

PG25 Lapsed in a contracting state [announced via postgrant information from national office to epo]

Ref country code: EE

Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT

Effective date: 20130724

Ref country code: CZ

Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT

Effective date: 20130724

Ref country code: RO

Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT

Effective date: 20130724

Ref country code: SK

Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT

Effective date: 20130724

Ref country code: DK

Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT

Effective date: 20130724

PG25 Lapsed in a contracting state [announced via postgrant information from national office to epo]

Ref country code: IT

Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT

Effective date: 20130724

Ref country code: ES

Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT

Effective date: 20130724

PLBE No opposition filed within time limit

Free format text: ORIGINAL CODE: 0009261

STAA Information on the status of an ep patent application or granted ep patent

Free format text: STATUS: NO OPPOSITION FILED WITHIN TIME LIMIT

26N No opposition filed

Effective date: 20140425

REG Reference to a national code

Ref country code: DE

Ref legal event code: R097

Ref document number: 602006037479

Country of ref document: DE

Effective date: 20140425

REG Reference to a national code

Ref country code: DE

Ref legal event code: R119

Ref document number: 602006037479

Country of ref document: DE

PG25 Lapsed in a contracting state [announced via postgrant information from national office to epo]

Ref country code: MC

Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT

Effective date: 20130724

Ref country code: LU

Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT

Effective date: 20140615

REG Reference to a national code

Ref country code: CH

Ref legal event code: PL

REG Reference to a national code

Ref country code: IE

Ref legal event code: MM4A

REG Reference to a national code

Ref country code: FR

Ref legal event code: ST

Effective date: 20150227

REG Reference to a national code

Ref country code: DE

Ref legal event code: R119

Ref document number: 602006037479

Country of ref document: DE

Effective date: 20150101

PG25 Lapsed in a contracting state [announced via postgrant information from national office to epo]

Ref country code: LI

Free format text: LAPSE BECAUSE OF NON-PAYMENT OF DUE FEES

Effective date: 20140630

Ref country code: CH

Free format text: LAPSE BECAUSE OF NON-PAYMENT OF DUE FEES

Effective date: 20140630

Ref country code: IE

Free format text: LAPSE BECAUSE OF NON-PAYMENT OF DUE FEES

Effective date: 20140615

Ref country code: DE

Free format text: LAPSE BECAUSE OF NON-PAYMENT OF DUE FEES

Effective date: 20150101

PG25 Lapsed in a contracting state [announced via postgrant information from national office to epo]

Ref country code: FR

Free format text: LAPSE BECAUSE OF NON-PAYMENT OF DUE FEES

Effective date: 20140630

PG25 Lapsed in a contracting state [announced via postgrant information from national office to epo]

Ref country code: BG

Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT

Effective date: 20130724

PG25 Lapsed in a contracting state [announced via postgrant information from national office to epo]

Ref country code: TR

Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT

Effective date: 20130724

Ref country code: HU

Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT; INVALID AB INITIO

Effective date: 20060615

PGFP Annual fee paid to national office [announced via postgrant information from national office to epo]

Ref country code: GB

Payment date: 20160615

Year of fee payment: 11

GBPC Gb: european patent ceased through non-payment of renewal fee

Effective date: 20170615

PG25 Lapsed in a contracting state [announced via postgrant information from national office to epo]

Ref country code: GB

Free format text: LAPSE BECAUSE OF NON-PAYMENT OF DUE FEES

Effective date: 20170615