+

WO2009065581A1 - Dispositif de déviation de flux pour forage - Google Patents

Dispositif de déviation de flux pour forage Download PDF

Info

Publication number
WO2009065581A1
WO2009065581A1 PCT/EP2008/009809 EP2008009809W WO2009065581A1 WO 2009065581 A1 WO2009065581 A1 WO 2009065581A1 EP 2008009809 W EP2008009809 W EP 2008009809W WO 2009065581 A1 WO2009065581 A1 WO 2009065581A1
Authority
WO
WIPO (PCT)
Prior art keywords
diverter
flow
drilling
conveyance system
fluid
Prior art date
Application number
PCT/EP2008/009809
Other languages
English (en)
Inventor
Henri Denoix
Charles Deible
Original Assignee
Services Petroliers Schlumberger
Schlumberger Technology B.V.
Schlumberger Holdings Limited
Schlumberger Canada Limited
Prad Research And Development Limited
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 Limited filed Critical Services Petroliers Schlumberger
Priority to US12/744,091 priority Critical patent/US20100314174A1/en
Publication of WO2009065581A1 publication Critical patent/WO2009065581A1/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
    • 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
    • E21B17/203—Flexible or articulated drilling pipes, e.g. flexible or articulated rods, pipes or cables with plural fluid passages
    • 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
    • E21B21/00—Methods or apparatus for flushing boreholes, e.g. by use of exhaust air from motor
    • E21B21/12—Methods or apparatus for flushing boreholes, e.g. by use of exhaust air from motor using drilling pipes with plural fluid passages, e.g. closed circulation systems
    • 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
    • E21B34/00—Valve arrangements for boreholes or wells
    • 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
    • E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
    • E21B43/12—Methods or apparatus for controlling the flow of the obtained fluid to or in wells
    • E21B43/121—Lifting well fluids
    • E21B43/122—Gas lift
    • E21B43/123—Gas lift valves
    • 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
    • E21B7/00—Special methods or apparatus for drilling
    • E21B7/04—Directional drilling
    • E21B7/06—Deflecting the direction of boreholes
    • E21B7/068—Deflecting the direction of boreholes drilled by a down-hole drilling motor

Definitions

  • This invention relates to methods and apparatus for drilling boreholes, in particular to drilling with a coiled tubing system.
  • Coiled tubing drilling comprises drilling with a continuous pipe coiled onto a reel with a downhole drilling motor typically providing rotation to the drill bit.
  • the tubing is conveyed into a borehole with a special injector system mounted on the surface.
  • Coiled tubing drilling shows many advantages compared to conventional drilling with jointed pipes, including: ability to operate in pressurized wells, fast tripping speed, continuous circulation while tripping and drilling, ability to be used in slimhole and through-tubing applications, and rig-less operations.
  • EP 1780372 describes an apparatus having a drilling system comprising a drilling drive mechanism that can apply both rotation an axial force to the drill bit and can use coiled tubing having a smaller diameter than that is used in conventional CTD systems.
  • a first aspect of the invention comprises an apparatus for drilling a borehole in a well comprising a tubular conveyance system; a drilling system connected to one end of the tubular conveyance system and comprising a drilling assembly; and a flow diverter positioned in the tubular conveyance system and comprising a first flow channel configured to receive fluid from inside the conveyance system and at least two side flow channels configured to direct fluid from the first flow channel out of the tubular conveyance system; wherein fluid flow between the first flow channel and each side flow channel is controlled by a valve which is operable to divert fluid out of the tubular conveyance system or to maintain the fluid in the tubular conveyance system.
  • the flow diverter can be located in the tubular conveyance system such that in use the flow diverter is positioned in the main well. This allows fluid to be released into a cased section of the well, when the diverter is configured to release fluid into the annulus
  • the side flow channels of the flow diverter can be arranged to divert flow that has come from inside the drilling system to the annulus above the point at which the side channels divert flow from the surface into the annulus. This allows crossflow so that the flow of the drilling fluid pumped from the surface will lift the flow of the fluid from the drilling system to the surface.
  • the side channels of the flow diverter can be arranged to divert flow that has come from the surface to the annulus above the point at which the side channels divert flow that has come from inside the drilling system to the annulus. This allows a fluid such as a gas to be pumped into the conveyance system and discharged into the annulus to adjust the density of the fluid column to achieve the desired well parameters.
  • valves are controlled by an electrical line from the surface.
  • the electric line can run down the tubular conveyance system, along with lines that may power the drilling system.
  • the valves can have a default position such that when a valve actuation signal is lost the valves are configured to return to their position.
  • the diverter is spoolable.
  • the diameter of the diverter can be larger than the diameter of the tubular conveyance system.
  • the diameter of the diverter is the same as the diameter of the tubular conveyance system.
  • the diameter of the diverter relative to the tubular conveyance system can be adjusted to the application according to the well conditions.
  • the diverter can pass through the tubular conveyance deployment system and into the well.
  • tubular conveyance system is coiled tubing.
  • the apparatus can further comprise an electric line controlled from the surface running through the diverter and tubular conveyance system to the drilling assembly.
  • the electric line can provide power to the drilling assembly or transmit telemetry to and/or from the assembly.
  • the apparatus can also comprise a second flow diverter.
  • the second flow diverter can form part of the bottom hole assembly or may be positioned adjacent the bottom hole assembly.
  • a second embodiment of the invention comprises a method for drilling a borehole in an underground formation comprising; deploying the apparatus as described above down a borehole; pumping a fluid through the tubular conveyance system; and using the drilling assembly to drill the borehole.
  • the method also comprises positioning the apparatus such that the flow diverter is positioned in the main well.
  • the method can comprise pumping drilling fluid from the surface through the tubular conveyance system.
  • the method can comprise injecting gas from the surface through the tubular conveyance system into the annulus or comprising injecting a fluid gas mixture from the surface through the tubular conveyance system to the diverter.
  • the method can comprise adjusting the valves of the diverter to direct the received flow from the tubular conveyance system into the annulus.
  • the method can comprise adjusting the valves of the diverter to maintain the received flow within the conveyance system.
  • the method can comprise pumping produced well fluids with cuttings from the drilling assembly to the surface through the diverter or from the drilling assembly to the diverter and into the annulus such that they can then be lifted to surface.
  • Drilling fluids laden with cuttings can be pumped from the drilling assembly to surface through the diverter or from the drilling assembly to the diverter and into the annulus such that they can then be lifted to the surface.
  • Figure 1 shows a drilling operation using standard circulation
  • Figure 2 shows a drilling operation using reverse circulation
  • Figure 3 shows a drilling operation using a gas lift system
  • Figure 4 shows a drilling operation using a mud lift system
  • FIG. 5 shows details of a flow diverter for use in the drilling apparatus of Figure
  • Figure 6 shows the flow diverter of Figure 5 in a gas lift configuration
  • Figure 7 shows details of a flow diverter for use in the drilling apparatus of Figure
  • Figure 8 shows the flow diverter of Figure 7 in mud lift configuration. Mode(s) for carrying out the invention
  • a drilling operation is conducted using a conventional coiled tubing 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 drilling apparatus comprises a coiled tubing conveyance system 18, a diverter 20 and a drilling system 22.
  • the diverter 20 is adjustable to control the path through which the fluid can flow through the coiled tubing depending on the drilling conditions.
  • the diverter 20 is positioned in the main well 14, such that when the diverter 20 is configured to direct fluid into the annulus the fluid will be released into a cased portion of the well.
  • the coiled tubing conveyance system 18 can carry fluid from the surface to the section of the well being drilled.
  • the fluid passes directly through the diverter 20 from the upper region of the CT conveyance system 18 above the diverter 20 to the lower region of the CT conveyance system 18 below the diverter 20 and then into the drilling system 22 connected to the CT conveyance system. Whereby the fluid is discharged from the drilling assembly into the well and can return to the surface via the annulus around the coiled tubing.
  • the apparatus can also be used in a reverse circulation application as shown in Figure 2.
  • the fluid is pumped down the annulus around the drilling system and drill bit and then the fluid is returned to the surface by being pumped up inside the drilling system 22, through the lower region of the coiled tubing conveyance system 18, directly through the diverter 20 into the upper region of the conveyance system and to the surface.
  • the coiled tubing conveyance system 18 comprises a coiled tubing having an electrical cable running inside from the surface to the drilling system.
  • a drilling fluid supply forms part of the coiled tubing unit at the surface and can pump fluid down the inside of the coiled tubing.
  • the drilling system comprises a bottomhole drilling assembly and includes the drill bit and drill driving mechansim, for example as described in
  • the system can also include other features such as a crawler system to provide axial drive to the drill bit, and a pump, such as electric or jet pump to draw fluid and drill cuttings up through the drill bit and inside the bottomhole drilling assembly.
  • a crawler system to provide axial drive to the drill bit
  • a pump such as electric or jet pump to draw fluid and drill cuttings up through the drill bit and inside the bottomhole drilling assembly.
  • valves of the flow diverter will be configured so that the fluid can flow directly through the diverter from the upper region of the coiled tubing to the lower region of the coiled tubing ( Figure 1) and from the lower region of the coiled tubing through the diverter to the upper region of the coiled tubing ( Figure 2).
  • Using a reverse circulation application to carry cuttings away from the drill bit avoids the risks associated with using standard circulation to transport cuttings in open hole regions of boreholes with low fluid flow.
  • the fluid carrying cuttings are transported inside the coiled tubing in the open hole region of the drainhole being drilled, into the casing section of the main bore.
  • the flow diverter Once the fluid flow has reached the flow diverter which is positioned in the coiled tubing conveyance system in the casing section of the main borehole, the flow diverter can divert the cuttings from the coiled tubing into the annulus between the coiled tubing and the casing.
  • the fluids with cuttings are then carried away to the surface up the annulus.
  • the cuttings can be carried away by a number of methods. If the natural fluid flow from the well is sufficient the flow from the well can carry the cuttings to the surface and then to the production facilities or a fluid treatment system. If the natural flow is not sufficient the pressure in the well bore can be decreased by decreasing the weight of the fluid in the main well bore. As shown in Figure 3 this can be achieved by using a gas lift system. Gas is injected into the coiled tubing 18 from the surface and the valves of the diverter are adjusted so that the gas injected from the surface into the coiled tubing 18 is diverted into the annulus once it reaches the flow diverter 20. Fluid flowing up the coiled tubing 18 below the flow diverter 20 from the drilling system 22 will also be diverted into the annulus.
  • a mud lift system can also be used to help carry the cuttings to surface as shown in Figure 4. Fluid is circulated down the coiled tubing 18 from surface to the diverter 20 and out into the annulus. Fluid carrying cuttings are transported in the lower region of the coiled tubing conveyance system 18 from the bottom hole and directed into the annulus at the diverter 20.
  • the flow of the drilling fluid around the diverter is such that it will mix with the cuttings carrying fluid, from the drilling system, in the annulus around the diverter and carry the cuttings back to surface.
  • the fluid can be treated, cuttings removed and the fluid subsequently reinjected into the conveyance system.
  • the configuration of the flow diverter used will depend on the drilling conditions.
  • the flow diverter 20 is formed by flow channels as shown in more detail in Figures 5 to 8.
  • a first flow channel is 24 connected at both ends to the interior of the coiled tubing 18 so that fluid flowing in the coiled tubing can flow into and out of the diverter.
  • Side flow channels 26 extend from the first flow channel 24 to the outside the coiled tubing to direct fluid into the annulus between the casing and coiled tubing.
  • a series of valves 28, 30 are used to control the pathway of the fluid flow through the flow diverter.
  • the fluid can be maintained in the first flow channel 24 for the fluid to flow through the conveyance system 18 or the fluid can be directed into the side flow channels 26 into the annulus.
  • the valves can be standard ball valves or they may be sleeve valves or seat valves or a combination of these types.
  • the valves can be actuated electrically through an a electrical line running from the surface through the conveyance system, or may be actuated manually or with the effect of pressure or pressure pulses. This enables the configuration of the diverter to be controlled from the surface such that the valves can be adjusted during an operation depending on the drilling conditions encountered.
  • valves in the diverter will have a preset default position. In the event the acutation signal is lost the valves will automatically return to this postion to allow safe retrieval from the well.
  • valves 28, 30 are positioned so that the fluid will be maintained in the first flow channel 24. Fluid in the upper region of the coiled tubing 18 is transported to the flow diverter 20 where it is maintained in the first flow channel 24 and flows directly through the flow diverter 20 and into the lower region of the coiled tubing conveyance system 18 positioned below the diverter 20 and then will continue down to the drilling assembly. The fluid will be released into the wellbore from the drill bit where it carries the drilling cuttings from around the drill bit and transports them to the surface via the wellbore annulus. Alternatively the fluid circulation can be done in reverse circulation mode.
  • drill cuttings are transported through the uncased portion of the lateral borehole.
  • the diverter can be configured such that artificial lift means can be used.
  • the valves of the the diverter are positioned so fluid entering the flow diverter from the surface is directed into the annulus while fluid entering the diverter from the drilling assembly is also directed into the annulus.
  • Figure 6 shows one configuration of the flow diverter 20 when a gas lift system is used to facilitate the transport of the fluid to the surface.
  • Gas is injected from the surface into the coiled tubing system 18 and is transported down to the flow diverter 20.
  • the valves 28 of the diverter are positioned so that the gas is diverted from the first flow channel 24 into a side flow channel 26 and out into the annulus. Fluid is also transported up the lower region of the coiled tubing system 18 from the drilling system to the diverter 20.
  • Valves 30 of the diverter are positioned to divert the fluid from the first flow channel 24 to a side flow channel 26 and out into the annulus. The introduction of the gas into annulus adjusts the density of the fluid column such that the well begins to flow at the desired rate.
  • the produced fluids then carry the cutttings to surface.
  • the amount of gas injected controls the well's bottom hole and surface pressures as well as the its production rate.
  • the amount of injected gas required is specific to the well being drilled and can be continuously adjusted at surface to adjust to changing drilling or well conditions. For example as the diverter moves down in the main well, during the drilling prcess, injecting gas at the same sustained rate will result in a continual decrease of the bottom hole pressure. Thus it is necessary to adjustt the rate from surface depending on the conditions required.
  • Figure 8 shows a configuration of the flow diverter 20 when a mud lift system is used to transport fluid with cuttings to the surface. Fluid is pumped from the surface into the coiled tubing system 18 and into the flow diverter 20. The valves 28 of the diverter are positioned so that the fluid is diverted from the first flow channel 24 to a side flow channel 26 out into the annulus. Fluid is also transported up from the lower region of the coiled tubing system 18 from the drilling system to the flow diverter 20. Valves 30 of the diverter 20 are positioned to divert fluid from the first flow channel 24 to a side flow channel 26 and out into the annulus.
  • the side flow channel openings 32 through which fluid from the surface via the upper region of the coiled tubing system is released into the annulus are positioned below the the side flow channel openings 34 through which the cuttings carrying fluid is released into the annulus, such that there is crossflow of the two fluids. This enables the flow from the surface fluid to help lift the cuttings to the surface.
  • the diameter of the diverter can be made larger than the size of the coiled tubing used. In this situation where the diverter is larger in diameter than the coiled tubing, the apparatus is required to be assembled and deployed using a lubricator at the wellhead.
  • the diverter can be also be used to inject a fluid-gas slurry or foam into the annulus below the exit point of the cuttings-laden fluid from the drilling assembly.
  • a gas slurry or foam can be used in wells that cannot produce enough fluids to carry cuttings back to surface or when doing so may damage the formation or jepordize the drilling process. It may also be desirable to use a foam or fluid-gas slurry to help control bottom hole pressure.
  • Using a flow diverter that is adjustable depending on the drilling conditions allows the flow of fluids to be optimised in the wellbore without the use of conventional well intervention methods and allows drilling with smaller coiled tubing with better performance and effiiciency.
  • the same drilling apparatus can be used as different drilling conditions are encountered by configuring the flow diverter.
  • the apparatus may further comprise a second diverter.
  • This second diverter can be positioned just above the bottom hole assembly, such that in use it is placed in an uncased section of the well .
  • the second diverter can form part of the bottom hole assembly.
  • the second flow diverter may be a diverter that can be configured to alter the pathway of the fluid flow, as for the main flow diverter described above.
  • the flow diverter may be a simple non-configurable diverter for example as described in EP1780372. Having a second diverter positioned just above the bottom hole assembly is desirable for well control, pumping pills, controlling losses or when trying to free a stuck tool. Other changes within the scope of the invention will be apparent.

Landscapes

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

Abstract

Appareil de forage d'un trou de forage dans un puits, comprenant un système de transport tubulaire ; un système de forage relié à une extrémité du système de transport tubulaire et comprenant un ensemble de forage de fond de trou ; et un dispositif de déviation de flux positionné dans le système de transport tubulaire. Ledit dispositif comprend un premier canal d'écoulement configuré pour recevoir un fluide depuis l'intérieur du système de transport et au moins deux canaux d'écoulement latéraux configurés pour diriger le fluide provenant du premier canal d'écoulement à l'extérieur du système de transport tubulaire. L'écoulement de fluide entre le premier canal d'écoulement et chaque canal d'écoulement latéral est commandé par une vanne qui est actionnable pour faire dévier le fluide vers l'extérieur du système de transport tubulaire ou pour maintenir le fluide dans le système de transport tubulaire.
PCT/EP2008/009809 2007-11-22 2008-11-19 Dispositif de déviation de flux pour forage WO2009065581A1 (fr)

Priority Applications (1)

Application Number Priority Date Filing Date Title
US12/744,091 US20100314174A1 (en) 2007-11-22 2008-11-19 Flow diverter for drilling

Applications Claiming Priority (2)

Application Number Priority Date Filing Date Title
GB0722882.8 2007-11-22
GB0722882.8A GB2454895B (en) 2007-11-22 2007-11-22 Flow diverter for drilling

Publications (1)

Publication Number Publication Date
WO2009065581A1 true WO2009065581A1 (fr) 2009-05-28

Family

ID=38925862

Family Applications (1)

Application Number Title Priority Date Filing Date
PCT/EP2008/009809 WO2009065581A1 (fr) 2007-11-22 2008-11-19 Dispositif de déviation de flux pour forage

Country Status (3)

Country Link
US (1) US20100314174A1 (fr)
GB (1) GB2454895B (fr)
WO (1) WO2009065581A1 (fr)

Families Citing this family (12)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
GB2471385B (en) * 2009-06-23 2011-10-19 Bruce Arnold Tunget Apparatus and methods for forming and using subterranean salt cavern
AU2011341592B2 (en) 2010-12-16 2016-05-05 Exxonmobil Upstream Research Company Communications module for alternate path gravel packing, and method for completing a wellbore
US8925652B2 (en) * 2011-02-28 2015-01-06 Baker Hughes Incorporated Lateral well drilling apparatus and method
EP2562346B1 (fr) * 2011-08-23 2019-03-13 BAUER Maschinen GmbH Agencement de forage sous-marin et procédé d'exécution d'un forage
US9291018B2 (en) 2011-12-20 2016-03-22 Exxonmobil Upstream Research Company Systems and methods to inhibit packoff events during downhole assembly motion within a wellbore
US9157277B2 (en) * 2012-02-06 2015-10-13 Wwt North America Holdings, Inc. Motor saver sub for down hole drilling assemblies
WO2013184100A1 (fr) * 2012-06-05 2013-12-12 Halliburton Energy Services, Inc. Procédés et systèmes de performance d'opérations souterraines à l'aide de tuyaux à train double
GB2536441A (en) * 2015-03-17 2016-09-21 Helix Drilling Tools Ltd A downhole tool and actuation element
GB2550864B (en) * 2016-05-26 2020-02-19 Metrol Tech Ltd Well
US11421529B2 (en) * 2018-01-08 2022-08-23 Halliburton Energy Services, Inc. Activation and control of downhole tools including a non-rotating power section option
GB2576739B (en) * 2018-08-29 2022-12-07 Paradigm Flow Services Ltd Coiled Tubing System
GB2576740A (en) * 2018-08-29 2020-03-04 Paradigm Flow Services Ltd Coiled tubing system

Citations (10)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
GB2302895A (en) * 1995-07-05 1997-02-05 Phoenix P A Ltd Downhole flow control tool
WO1998037300A1 (fr) * 1997-02-20 1998-08-27 Bj Services Company, U.S.A. Ensemble de fond
GB2355275A (en) * 1999-10-08 2001-04-18 Halliburton Energy Serv Inc Adjustable gauge for downhole drilling assembly
US20030155156A1 (en) * 2002-01-22 2003-08-21 Livingstone James I. Two string drilling system using coil tubing
WO2004033842A2 (fr) * 2002-10-04 2004-04-22 Halliburton Energy Services, Inc. Procede et appareil pour enlever des deblais d'un forage devie
US20040195007A1 (en) * 2003-04-02 2004-10-07 Halliburton Energy Services, Inc. Method and apparatus for increasing drilling capacity and removing cuttings when drilling with coiled tubing
EP1669541A1 (fr) * 2001-10-12 2006-06-14 Halliburton Energy Services, Inc. Localisation de joints pour application dans des dispositifs comprenant un tubage enroulé
WO2006138565A1 (fr) * 2005-06-17 2006-12-28 Baker Hughes Incorporated Systeme et procede de controle actif de la pression fond de trou au moyen d'un systeme a circulation continue
EP1780372A1 (fr) * 2005-08-08 2007-05-02 Services Pétroliers Schlumberger Système de forage
EP1867831A1 (fr) * 2006-06-15 2007-12-19 Services Pétroliers Schlumberger Procédé et dispositif pour le forage au cable parmi tubage enroulé

Family Cites Families (1)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US4645006A (en) * 1984-12-07 1987-02-24 Tinsley Paul J Annulus access valve system

Patent Citations (10)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
GB2302895A (en) * 1995-07-05 1997-02-05 Phoenix P A Ltd Downhole flow control tool
WO1998037300A1 (fr) * 1997-02-20 1998-08-27 Bj Services Company, U.S.A. Ensemble de fond
GB2355275A (en) * 1999-10-08 2001-04-18 Halliburton Energy Serv Inc Adjustable gauge for downhole drilling assembly
EP1669541A1 (fr) * 2001-10-12 2006-06-14 Halliburton Energy Services, Inc. Localisation de joints pour application dans des dispositifs comprenant un tubage enroulé
US20030155156A1 (en) * 2002-01-22 2003-08-21 Livingstone James I. Two string drilling system using coil tubing
WO2004033842A2 (fr) * 2002-10-04 2004-04-22 Halliburton Energy Services, Inc. Procede et appareil pour enlever des deblais d'un forage devie
US20040195007A1 (en) * 2003-04-02 2004-10-07 Halliburton Energy Services, Inc. Method and apparatus for increasing drilling capacity and removing cuttings when drilling with coiled tubing
WO2006138565A1 (fr) * 2005-06-17 2006-12-28 Baker Hughes Incorporated Systeme et procede de controle actif de la pression fond de trou au moyen d'un systeme a circulation continue
EP1780372A1 (fr) * 2005-08-08 2007-05-02 Services Pétroliers Schlumberger Système de forage
EP1867831A1 (fr) * 2006-06-15 2007-12-19 Services Pétroliers Schlumberger Procédé et dispositif pour le forage au cable parmi tubage enroulé

Also Published As

Publication number Publication date
GB2454895B (en) 2012-01-11
GB0722882D0 (en) 2008-01-02
US20100314174A1 (en) 2010-12-16
GB2454895A (en) 2009-05-27

Similar Documents

Publication Publication Date Title
US20100314174A1 (en) Flow diverter for drilling
AU2019200877B2 (en) Steerable hydraulic jetting nozzle, and guidance system for downhole boring device
EP1867831B1 (fr) Procédé et dispositif pour le forage au cable parmi tubage enroulé
CA2919649C (fr) Mecanisme de lancage de jets hydrauliques en fond de trou
RU2320840C2 (ru) Способ бурения
CA2506917C (fr) Systeme et procede de circulation d'une boue de forage
AU2004230693B2 (en) Method and apparatus for increasing drilling capacity and removing cuttings when drilling with coiled tubing
CA2919665C (fr) Mecanisme de tracteur interne destine a un corps tubulaire de fond de trou
US12203343B2 (en) Wellbore milling and cleanout system and methods of use
US10060210B2 (en) Flow control downhole tool
US20150337598A1 (en) Pressure Booster for Rotary Steerable System Tool
US20050098351A1 (en) Downhole valve device
CA2965252A1 (fr) Appareil et procedes permettant de forer un puits utilisant un cuvelage
EP1847679A1 (fr) Méthode de forage en sous-pression dans une formation de gaz
US8925652B2 (en) Lateral well drilling apparatus and method
US10907421B2 (en) Drill string applications tool
WO2006021750A1 (fr) Procede de forage equilibre ou sous-equilibre d’un puits a l’aide d’une pompe electrique submersible
WO2019168896A1 (fr) Outil d'applications de train de tiges

Legal Events

Date Code Title Description
121 Ep: the epo has been informed by wipo that ep was designated in this application

Ref document number: 08851386

Country of ref document: EP

Kind code of ref document: A1

NENP Non-entry into the national phase

Ref country code: DE

WWE Wipo information: entry into national phase

Ref document number: 12744091

Country of ref document: US

122 Ep: pct application non-entry in european phase

Ref document number: 08851386

Country of ref document: EP

Kind code of ref document: A1

点击 这是indexloc提供的php浏览器服务，不要输入任何密码和下载