WO2007144157A1 - Procédés et appareil pour le forage au fil métallique pour des tubes enroulés - Google Patents

Procédés et appareil pour le forage au fil métallique pour des tubes enroulés Download PDF

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Publication number
WO2007144157A1
WO2007144157A1 PCT/EP2007/005206 EP2007005206W WO2007144157A1 WO 2007144157 A1 WO2007144157 A1 WO 2007144157A1 EP 2007005206 W EP2007005206 W EP 2007005206W WO 2007144157 A1 WO2007144157 A1 WO 2007144157A1
Authority
WO
WIPO (PCT)
Prior art keywords
drilling
fluid
flow
annulus
tubular conveyance
Prior art date
Application number
PCT/EP2007/005206
Other languages
English (en)
Inventor
Spyro Kotsonis
Warren Zemlak
Iain Cooper
Original Assignee
Services Petroliers Schlumberger
Schlumberger Technology B.V.
Schlumberger Holdings Limited
Schlumberger Canada Limited
Prad Research And Development Nv
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
Application filed by Services Petroliers Schlumberger, Schlumberger Technology B.V., Schlumberger Holdings Limited, Schlumberger Canada Limited, Prad Research And Development Nv filed Critical Services Petroliers Schlumberger
Priority to US12/304,946 priority Critical patent/US20090321141A1/en
Priority to GB0823035A priority patent/GB2454373A/en
Priority to MX2008016052A priority patent/MX2008016052A/es
Priority to CA002655245A priority patent/CA2655245A1/fr
Publication of WO2007144157A1 publication Critical patent/WO2007144157A1/fr

Links

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.
  • CTD 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).
  • 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:
  • tubular conveyance system including an electric cable and a supply of drilling fluid, the supply of drilling fluid being arranged in use to pump fluid from the surface down the inside of the tubular conveyance so as to return to the surface via the annulus between the outside of the tubular conveyance and the borehole;
  • a drilling system comprising an electrically powered drilling motor and a pump arranged in use to pump fluid from the borehole outside the drilling system up through the inside of the drilling system;
  • 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 for 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 can direct 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 motor are connected to the electric cable; and a flow diverter; the method comprising:
  • the method comprises diverting 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.
  • 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.
  • Figure 1 shows a drilling operation using apparatus according to a first embodiment of the invention
  • Figure 2 shows details of the connection and flow diverter of Figure 1;
  • Figure 3 shows a drilling operation using apparatus according to a second embodiment of the invention.
  • Figure 4 shows detail of jetting nozzles and the ensuing swirling flow pattern in a third embodiment of the invention.
  • 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. 05291698.8 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 drilling assembly 20 As the drilling assembly 20 is pulled back, it can drag with it cuttings left in the borehole and these can eventually accumulate sufficiently to create a barrier through which it cannot be pulled by use of the CT alone.
  • One solution for such a case is to jet fluid backwards in the annulus while POOH to mobilize cuttings and transport them in the annulus, so that they do not accumulate to cause a potential sticking problem.
  • 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.
  • One preferred form of jetting arrangement is shown in Figure 4.
  • the 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 EPl 13578.
  • 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.

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  • 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)

Abstract

Appareil pour forer un trou souterrain, comprenant: - un système de transport tubulaire (18) comprenant un câble électrique et une alimentation de fluide de forage, l'alimentation de fluide de forage étant conçue pour, une fois en service, pomper un fluide à partir de la surface jusqu'à l'intérieur du transport tubulaire (18) de manière à retourner à la surface par l'intermédiaire de l'espace annulaire formé entre l'extérieur du transport tubulaire (18) et le trou; - un système de forage (20) comprenant une pompe électrique (28) et un moteur de forage (22), la pompe (28) étant conçue pour, une fois en service, pomper un fluide à partir de le trou à l'extérieur du système de forage (20) jusqu'à l'intérieur du système de forage (20); - un connecteur (30) pour relier le système de forage (20) au système de transport tubulaire (18), par l'intermédiaire duquel la pompe (28) et le moteur (22) sont connectés au câble électrique, et - un déviateur d'écoulement auquel l'écoulement descendant en provenance de l'intérieur du système de transport tubulaire (18) est dévié dans l'espace annulaire, et où l'écoulement ascendant jusqu'à l'intérieur du système de forage (20) est dévié dans l'espace annulaire.
PCT/EP2007/005206 2006-06-15 2007-06-12 Procédés et appareil pour le forage au fil métallique pour des tubes enroulés WO2007144157A1 (fr)

Priority Applications (4)

Application Number Priority Date Filing Date Title
US12/304,946 US20090321141A1 (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.
CA002655245A CA2655245A1 (fr) 2006-06-15 2007-06-12 Procedes et appareil pour le forage au fil metallique pour des tubes enroules

Applications Claiming Priority (2)

Application Number Priority Date Filing Date Title
EP06291008.8 2006-06-15
EP06291008.8A EP1867831B1 (fr) 2006-06-15 2006-06-15 Procédé et dispositif pour le forage au cable parmi tubage enroulé

Publications (1)

Publication Number Publication Date
WO2007144157A1 true WO2007144157A1 (fr) 2007-12-21

Family

ID=37400909

Family Applications (1)

Application Number Title Priority Date Filing Date
PCT/EP2007/005206 WO2007144157A1 (fr) 2006-06-15 2007-06-12 Procédés et appareil pour le forage au fil métallique pour des tubes enroulés

Country Status (7)

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

Cited By (2)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
WO2017000622A1 (fr) * 2015-06-30 2017-01-05 安东柏林石油科技（北京）有限公司 Système d'injection quantitatif précis de type pour stockage pour injection d'agent de service de puits de pétrole ou de gaz souterrain et procédé d'injection associé
WO2023183577A1 (fr) * 2022-03-25 2023-09-28 Schlumberger Technology Corporation Procédé et système de fraisage au câble et de collecte de débris simultanés

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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
WO2005090739A1 (fr) 2004-03-17 2005-09-29 Western Well Tool, Inc. Pince a genouillere pour chaines a rouleaux pour tracteur de fond de puits
US7624808B2 (en) 2006-03-13 2009-12-01 Western Well Tool, Inc. Expandable ramp gripper
US7748476B2 (en) 2006-11-14 2010-07-06 Wwt International, Inc. 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
EP2776656A4 (fr) * 2011-11-08 2016-04-13 Chevron Usa Inc Appareil et procédé pour forer un trou de forage dans une formation souterraine
WO2013119586A1 (fr) * 2012-02-06 2013-08-15 Wwt International Inc. Raccord d'usure de moteur pour systèmes de forage de fond de puits
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 (fr) * 2012-08-20 2014-02-27 Halliburton Energy Services, Inc. Ensemble et procédé de forage lent
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
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
CN106703684B (zh) * 2017-02-22 2018-08-10 武汉科技大学 一种地下钻进机器人
CN109899061B (zh) * 2019-03-29 2020-09-25 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

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US4844182A (en) * 1988-06-07 1989-07-04 Mobil Oil Corporation Method for improving drill cuttings transport from a wellbore
EP1181432B1 (fr) * 1999-06-03 2004-05-06 Shell Internationale Researchmaatschappij B.V. Procede de creation d'un trou de forage
US20040134662A1 (en) * 2002-01-31 2004-07-15 Chitwood James E. High power umbilicals for electric flowline immersion heating of produced hydrocarbons

Cited By (2)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
WO2017000622A1 (fr) * 2015-06-30 2017-01-05 安东柏林石油科技（北京）有限公司 Système d'injection quantitatif précis de type pour stockage pour injection d'agent de service de puits de pétrole ou de gaz souterrain et procédé d'injection associé
WO2023183577A1 (fr) * 2022-03-25 2023-09-28 Schlumberger Technology Corporation Procédé et système de fraisage au câble et de collecte de débris simultanés

Also Published As

Publication number Publication date
GB0823035D0 (en) 2009-01-28
EP1867831B1 (fr) 2013-07-24
EP1867831A1 (fr) 2007-12-19
RU2009101029A (ru) 2010-07-20
GB2454373A (en) 2009-05-06
US20090321141A1 (en) 2009-12-31
RU2436929C2 (ru) 2011-12-20
CA2655245A1 (fr) 2007-12-21
MX2008016052A (es) 2009-02-06

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