EP2108780A1 - Procédé de forage hybride - Google Patents

Procédé de forage hybride Download PDF

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Publication number
EP2108780A1
EP2108780A1 EP08007083A EP08007083A EP2108780A1 EP 2108780 A1 EP2108780 A1 EP 2108780A1 EP 08007083 A EP08007083 A EP 08007083A EP 08007083 A EP08007083 A EP 08007083A EP 2108780 A1 EP2108780 A1 EP 2108780A1
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EP
European Patent Office
Prior art keywords
coiled tubing
cross
assembly
over
hole
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.)
Withdrawn
Application number
EP08007083A
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German (de)
English (en)
Inventor
Robert Graham
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Individual
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Individual
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Publication date
Application filed by Individual filed Critical Individual
Priority to EP08007083A priority Critical patent/EP2108780A1/fr
Publication of EP2108780A1 publication Critical patent/EP2108780A1/fr
Withdrawn legal-status Critical Current

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    • 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
    • E21B19/00—Handling rods, casings, tubes or the like outside the borehole, e.g. in the derrick; Apparatus for feeding the rods or cables
    • E21B19/22—Handling reeled pipe or rod units, e.g. flexible drilling pipes
    • 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
    • E21B17/02—Couplings; joints
    • E21B17/04—Couplings; joints between rod or the like and bit or between rod and rod or the like
    • E21B17/041—Couplings; joints between rod or the like and bit or between rod and rod or the like specially adapted for coiled tubing
    • 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

Definitions

  • the present application relates to drilling methods in which coiled tubing and jointed pipe are used in combination.
  • New innovations in drilling technology are typically aimed at improving drilling efficiency (cost driver), safety, environmental protection, or a combination of the three.
  • a few of the latest trends in drilling technology development have been underbalanced drilling - typically aimed at the growing number of depleted reservoirs, managed pressure drilling - aimed at reducing drilling problems, and coiled tubing drilling - typically aimed at through tubing re-entry drilling, managed pressure drilling and underbalanced drilling candidates.
  • Coiled tubing technology has been around for a long time and is primarily viewed as a live-well intervention tool. Due to the absence of connections and the use of a coiled tubing injector, well intervention can be undertaken with full pipe control at all times, since the coiled tubing system inherently provides full snubbing capabilities. It is for this reason that coiled tubing was an obvious choice for underbalanced drilling.
  • coiled tubing also has the distinct disadvantage of not being capable of pipe rotation, thus restricting horizontal reach and has problems associated with stick-slip friction in the axial direction. It also has a limitation in terms of cycle-fatigue life, which is exponentially proportional to internal pressure when being plastically deformed (i.e., when going over the gooseneck or reel, through the coiled tubing injector or through a pipe-straightener).
  • Rotary drilling technology with jointed drill pipe is seen as a more robust system, with expanded capabilities due to the ability to rotate the pipe and thus, reduce friction.
  • the challenges with rotary drilling include the labour-intensive requirement to make and break connections between the jointed pipes and more costly and complicated snubbing operations in live-well environments.
  • the drill pipe connections are also a weak-spot and changes in moment of inertia cause stress concentration areas when the drill pipe is in compression or subjected to cyclic stress loads.
  • Coiled tubing is seen as a very efficient tripping and snubbing technology and jointed drill pipe is seen as the most efficient and flexible system for drilling - particularly in horizontal wellbores, where long horizontal displacement is desired.
  • This object is achieved by providing a method for drilling with coiled tubing in conjunction with jointed drill pipe comprising tripping into the hole to a pre-determined depth with coiled tubing using a coiled tubing injector, then disconnecting the coiled tubing at a spoolable connector in the coiled tubing or by severing the coiled tubing, then crossing-over to jointed drill pipe, then drilling conventionally in open hole, then tripping out of hole to shoe, then re-connecting coiled tubing with a spoolable connector, and then tripping out of hole with coiled tubing.
  • This method provides for one low-pressure fatigue cycle per trip (or more depending on configuration or use of pipe-straightener), high-speed tripping and snubbing, less swabbing/surging pressure while tripping, reduced or no requirement for drill collars or heavy-weight drill pipe (coiled tubing more suitable for being run in compression), facilitates use of higher-speed telemetry with capability of running wireline or fiber optics inside coil and requiring a reduced length of expensive wired drill pipe. Further, this method reduces wear and damage to jointed pipe typically run in compression in the lower part of hole. Since no connections are required during the potential "pipe light" tripping operations, the method provides enhanced safety and less manual intervention.
  • the method offers potential to use larger diameter coiled tubing due to lack of tool joints. This leads to the possibility to optimize size to provide better weight on bit and potentially longer reach. Further, the method provides for enhanced overpull capability due to lack of tool joints (higher strength-to-weight ratio).
  • the method may further comprise lubricating out bottomhole assembly after the step of tripping out of hole with coiled tubing.
  • the coiled tubing is disconnected just above the wellhead
  • the method may further comprise racking back the coiled tubing injector after disconnecting the coiled tubing and before crossing-over to jointed drill pipe.
  • the method may further comprise picking-up coiled tubing injector after tripping out of hole to shoe and before re-connecting coiled tubing with a spoolable connector.
  • tripping out of hole to shoe or pre-determined depth is performed by conventional tripping with jointed drill pipe.
  • This object is achieved by providing an assembly for releasably connecting coiled tubing to conventional tubing or to bottom-hole-assembly, said assembly comprising a cross-over to coiled tubing and a cross-over to conventional pin or box connection, said cross-over to coiled tubing being connectable to said cross-over to Pin or Box connection without relative rotation between the cross-overs.
  • the assembly may further comprise a swivel suitable to be inserted between the cross-over to coiled tubing and the cross-over to conventional tubing for allowing rotation of the cross-overs relative to one another.
  • connection between the cross-overs may be a splined connection or a pressure activated connection or some other connection not requiring rotation of the coiled tubing relative to the conventional tubing.
  • Fig. 1 illustrates a drilling operation on a drilling platform or rig with coiled tubing and jointed pipe.
  • the drilling platform or rig is provided with a coiled tubing injector 1 (which may also be considered as an integral part of the snubbing unit) and is provided with a coiled tubing high-pressure stripper.
  • the coiled tubing injector 1 includes a pair of tracks for engaging the coiled tubing and providing force to push or pull tubing into or out of the hole respectively.
  • the coiled tubing 2 may be of a conventional type and stored on a coiled tubing reel 3 and guided from the reel 3 via a gooseneck 4 to the coiled tubing injector 1.
  • the coiled tubing injector 1 may in an embodiment be provided with a pipe straightener (not shown).
  • a coiled tubing spoolable connector 5 is provided at the free extremity of the coiled tubing. The spoolable connector 5 allows strands of coiled tubing to be connected and disconnected.
  • Various parts 6 of a downhole assembly are stored on the platform or drilling rig and can be received inside a high-pressure lubricator 7 (when required to be deployed under pressure).
  • the lowest part 6 of the bottomhole assembly is already inserted into the wellhead assembly or can be deployed with or without the requirement for pressure deployment.
  • a coiled tubing to jointed pipe crossover 8 is also present on the platform.
  • the cross-over is designed for rotary drilling torque values.
  • This jointed pipe crossover 8 in one embodiment may in an embodiment also include a rotational swivel to allow makeup to drill string assembly components using conventional threaded connections.
  • the example wellhead assembly includes in this embodiment slips 9, a rotating control device 10 slip rams 11, an annular preventer 12, the primary flow spool 13, blind/shear rams 14, pipe rams 15, a kill spool 16, operational blind rams 17, operational valve 16 and wellhead 18, all disposed on top of the casing 19.
  • This wellhead assembly configuration is only provided as an example embodiment to illustrate an application of the invention but may also exist in other configurations as required to provide well control and pipe control.
  • the platform or rig is provided with storage for the jointed drill pipe 20 and in this embodiment with a hydraulic top drive 21 that is connected to a standpipe 23.
  • a rotary table and Kelly and other means of handling the drill pipe, such as drill pipe elevators or tuggers, etc.
  • a coiled tubing spoolable connector is provided at the free end of the coiled tubing and a high-pressure lubricator 7 is ready to be used.
  • a high-pressure lubricator is connected to the coiled tubing injector 1 and lifted up.
  • the coiled tubing injector 1 is moved above the wellhead and the part 6 of the bottomhole assembly in the high-pressure lubricator 7 is lowered onto and connected to the part 6 of the bottomhole assembly that is already in the wellhead.
  • the slips 9 are removed prior to connecting the lubricator and equalizing pressure.
  • the wellhead 18 and operational valve 17 are also opened after equalizing pressure between figures 5 and 6 .
  • slip rams 11, annular preventer 12 and pipe rams 15 are activated to provide pipe control and two pressure barriers.
  • the coiled tubing to jointed pipe crossover 8 is disconnected from the part 6 of the bottomhole assembly in the wellhead, the coiled tubing 2 is racked back, the coiled tubing injector 1 is raised and moved above the next part 6 of the bottomhole assembly, the coiled tubing 2 is lowered again to connect the coiled tubing to jointed pipe crossover 8 to the next part 6 of the bottomhole assembly and the coiled tubing 2 is reeled back again to raise the next part 6 of the bottomhole assembly into the high-pressure lubricator 7.
  • next part 6 of the bottomhole assembly is moved above the wellhead and lowered onto and connected to the parts 6 of the bottomhole assembly that are already in the wellhead.
  • the tripping operation for lowering bottomhole assembly commences by the operation of the coiled tubing injector 1.
  • the tripping operation is preferably performed whilst the coiled tubing 2 is not pressurized. However, if desired, the operation could be performed pressurized, thereby sacrificing some fatigue life of the coiled tubing.
  • the string of coiled tubing 2 may include further spoolable connectors 5.
  • the coiled tubing 2 is reeled down until the bottomhole assembly 6 reaches the shoe 29 or some pre-determined depth.
  • the coiled tubing is severed (preferably at a spoolable connector 5) and a jointed pipe to coiled tubing crossover 25 is connected to the extremity of the coiled tubing 2 that protrudes from the wellhead.
  • the other portion of the coiled tubing is reeled back with the free extremity with the spoolable connector 5 withdrawn into the high-pressure lubricator 7.
  • the hydraulic top drive 21 is an example of a means to pick-up the jointed pipe sections 20 and connects the lower end of the picked the jointed pipe section 20 to the jointed pipe to coiled tubing crossover 25. Then, rotary drilling operations may commence.
  • Rotary drilling operations continue as long as necessary whilst more and more pipe sections 20 are added to the drill string, as shown in figure 17 .
  • the jointed pipe sections 20 are one by one (or stand by stand) tripped out of hole to shoe (or some pre-determined depth).
  • the coiled tubing injector 1 is picked up and the coiled tubing 2 is re-connected with a spoolable connector 5 to the portion of the coiled tubing 2 that is still in the hole, followed by tripping out of hole with coiled tubing by the action of the coiled tubing injector 1. Thereafter, the process may continue by lubricating out the bottomhole assembly.
  • Figs. 18 to 20 illustrate an assembly for releasably connecting coiled tubing 2 to the bottom-hole-assembly 6.
  • Fig. 18 shows the assembly in a disconnected state and Fig. 19 shows the assembly in a connected state.
  • the assembly includes a cross-over to coiled tubing 30, a cross-over to conventional pin connection 33 and, if required, also a swivel 35.
  • the crossover to coiled tubing 30 includes the male part 32 of a splined connection and a locking ring 31.
  • the male part 32 has around its circumference external spline elements.
  • the locking ring 31 can freely rotate relative to the main body of the crossover 30 and the locking ring is provided with internal thread (not shown) that engages external thread (not shown) on the counterpart of the connection.
  • the crossover to Pin connection 33 is provided with the female part of the splined connection that includes internal spline grooves for spline engagement with the external spline elements of the male part of the spline connection.
  • the crossover to Pin connection 33 is also provided with external thread (not shown) to engage a locking ring of a counterpart.
  • the splined connection provides for transmission of the rotational forces acting on the connection and the locking rings provide for transmission of the axial (tension or compression) forces acting on the connection.
  • the swivel 35 if required, is provided with the female part 35 of the splined connection at one end and with the male part 37 of the splined connection at the other end.
  • the swivel 35 is also provided with a locking ring 36.
  • the swivel 35 allows the male part 37 and the female part to be rotated and can still transmit tension.
  • the swivel 35 is suitable to be inserted between the cross-over to coiled tubing and the cross-over to conventional tubing for allowing rotation of the cross-overs relative to one another.
  • connection assembly including the swivel 25, is used for snubbing bottom-hole assembly components.
  • the cross-over to coiled tubing 30 can be connected to the cross-over to Pin connection 33 without relative rotation between the cross-overs, as shown in Fig. 20 .
  • the connection assembly without the swivel is used for lower drilling where the coiled tubing is directly connected to the bottom-hole-assembly 6.
  • Figs. 21 to 23 illustrate an assembly for releasably connecting jointed drill pipe 20 to coiled tubing 2.
  • Fig. 21 shows the assembly in a disconnected state
  • Fig. 22 shows the assembly in a partially assembled state
  • Fig. 23 shows the assembly in a connected state.
  • the assembly includes a cross-over to conventional Box connection 40 and a cross-over to coiled tubing 30.
  • the cross-over to conventional Box connection 40 is provided at one of its ends with an internally threaded recess 41 for receiving the externally threaded end portion 38 of jointed drill pipe 20.
  • the other end of the cross-over to conventional Box connection 40 is provided with the female part 40 of a splined connection.
  • the cross-over to conventional Box connection 40 is also provided with an external thread to engage the internal thread of a locking ring of a counterpart.
  • the female part 40 is suitable for receiving the male part 32 of the cross-over to jointed pipe 30.
  • the splined connection provides for transmission of the rotational forces acting on the connection and the locking rings provide for transmission of the axial (tension or compression) forces acting on the connection.
  • connection assembly shown in Figs. 21-23 is used for rotary drilling with jointed drill pipe 20 with the lower part of the drill string above the bottom-hole-assembly being coiled tubing 2.
  • the teaching of this application has numerous advantages. Different embodiments or implementations may yield one or more of the following advantages. It should be noted that this is not an exhaustive list and there may be other advantages which are not described herein.
  • One advantage of the teaching of this application is that it provides for the use of conventional coiled tubing combined with conventional jointed pipe at the same time.
  • Another advantage of the teaching of this application is that it provides for a cross-over from coiled tubing to jointed pipe that is designed for rotary drilling torque values and thereby provides for a potential for use of a more robust connector than a flush spoolable connector for running in hole.
  • Yet another advantage of the teaching of this application is that it provides for rotation of coiled tubing by conventional means.
  • a further advantage of this teaching is that it provides for maximization of coiled tubing cycle fatigue life due to the absence of internal pressure during tripping and the absence of plastic deformation during the drilling phase and open-hole tripping operations.
  • a further advantage of this teaching is that it facilitates the use of larger OD and heavier-walled tubing with minimal economic impact.
  • a further advantage of this teaching is that it provides for use of coiled tubing to provide high-speed snubbing when pipe-light.
  • a further advantage of this teaching is that it enhances safety at higher tripping speed than conventional jointed pipe tripping due to the absence of connections and reduced manual intervention.
  • a further advantage of this teaching is the potential for higher tensile and torsional yield in drill string due to lack of tool joints in lower part of drill string (coiled tubing).
  • a further advantage of this teaching is that there is no requirement for heavy-weight drill pipe due to ability to use coiled tubing in compression with no adverse effects.
  • a further advantage of this teaching is that it facilitates safer injection of natural gas in coiled tubing due to no requirement for plastic deformation of drill string while injecting natural gas. This mitigates against the risk of pinholes in coiled tubing when injecting natural gas, as entire coil length is below well control equipment.
  • a further advantage of this teaching is that it can use a larger OD drill string than comparable jointed pipe due to lack of tool joints - enhanced hole cleaning in horizontal and high angle segments of lower wellbore.
  • a further advantage of this teaching is that it can use additional segments of coiled tubing on subsequent trips.
  • a further advantage of this teaching is that PWD (pressure while drilling) or other data acquisition sensors can be added in coiled tubing connectors.
  • the coiled tubing can be used to run in and set a packer in casing to facilitate running of liner without requiring a subsurface deployment valve.
  • a further advantage of this teaching is that higher wellhead pressures can be maintained while tripping (snubbing) out of the hole with coiled tubing due to the absence of tool joints and the higher pressure rating of a coiled tubing stripper versus a rotating control device.

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  • 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)
EP08007083A 2008-04-10 2008-04-10 Procédé de forage hybride Withdrawn EP2108780A1 (fr)

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EP08007083A EP2108780A1 (fr) 2008-04-10 2008-04-10 Procédé de forage hybride

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Cited By (11)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
WO2011076847A1 (fr) 2009-12-23 2011-06-30 Shell Internationale Research Maatschappij B.V. Procédé de forage d'un trou de forage et train de tiges de forage hybride
WO2011104516A3 (fr) * 2010-02-26 2012-05-10 Haliburton Energy Services, Inc. Vanne actionnée par la pression pour une rame hybride d'outils comprenant des tubes spiralés et des tubes à rallonge
CN102536224A (zh) * 2012-02-22 2012-07-04 上海艾都能源科技有限公司 一种轻便取样钻机
WO2013022449A1 (fr) * 2011-08-11 2013-02-14 Halliburton Energy Services, Inc. Systèmes et procédés de verrouillage de joints tournant lors de l'exécution d'opérations sous-marines
WO2013130977A3 (fr) * 2012-03-01 2014-04-17 Saudi Arabian Oil Company Système de forage rotatif continu et procédé d'utilisation
US8733449B2 (en) 2011-04-15 2014-05-27 Hilliburton Energy Services, Inc. Selectively activatable and deactivatable wellbore pressure isolation device
WO2015010412A1 (fr) * 2013-07-23 2015-01-29 四川宏华石油设备有限公司 Dispositif d'agencement de tube pour tubulure enroulée
RU2588082C2 (ru) * 2011-08-11 2016-06-27 Хэллибертон Энерджи Сервисиз, Инк. Системы и способы застопоривания вертлюжных соединений при выполнении подземных работ
CN105735891A (zh) * 2016-04-15 2016-07-06 南昌工程学院 一种适用于陡峻山地的可取样深孔轻便钻机
US9470063B2 (en) 2013-01-18 2016-10-18 Halliburton Energy Services, Inc. Well intervention pressure control valve
CN110211443A (zh) * 2019-04-11 2019-09-06 西南石油大学 连续油管钻磨桥塞高精密模拟方法

Citations (2)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US4515220A (en) * 1983-12-12 1985-05-07 Otis Engineering Corporation Apparatus and method for rotating coil tubing in a well
US6158516A (en) * 1998-12-02 2000-12-12 Cudd Pressure Control, Inc. Combined drilling apparatus and method

Patent Citations (2)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US4515220A (en) * 1983-12-12 1985-05-07 Otis Engineering Corporation Apparatus and method for rotating coil tubing in a well
US6158516A (en) * 1998-12-02 2000-12-12 Cudd Pressure Control, Inc. Combined drilling apparatus and method

Cited By (20)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
CN102667048B (zh) * 2009-12-23 2014-11-05 国际壳牌研究有限公司 钻井眼的方法和混合型钻柱
CN102667048A (zh) * 2009-12-23 2012-09-12 国际壳牌研究有限公司 钻井眼的方法和混合型钻柱
WO2011076847A1 (fr) 2009-12-23 2011-06-30 Shell Internationale Research Maatschappij B.V. Procédé de forage d'un trou de forage et train de tiges de forage hybride
WO2011104516A3 (fr) * 2010-02-26 2012-05-10 Haliburton Energy Services, Inc. Vanne actionnée par la pression pour une rame hybride d'outils comprenant des tubes spiralés et des tubes à rallonge
US8276676B2 (en) 2010-02-26 2012-10-02 Halliburton Energy Services Inc. Pressure-activated valve for hybrid coiled tubing jointed tubing tool string
AU2011219582B2 (en) * 2010-02-26 2014-07-24 Halliburton Energy Services, Inc. Pressure-activated valve for hybrid coiled tubing jointed tubing tool string
US8733449B2 (en) 2011-04-15 2014-05-27 Hilliburton Energy Services, Inc. Selectively activatable and deactivatable wellbore pressure isolation device
WO2013022449A1 (fr) * 2011-08-11 2013-02-14 Halliburton Energy Services, Inc. Systèmes et procédés de verrouillage de joints tournant lors de l'exécution d'opérations sous-marines
CN103748312A (zh) * 2011-08-11 2014-04-23 哈利伯顿能源服务公司 用于在执行地下操作时锁定回转接头的系统和方法
RU2588082C2 (ru) * 2011-08-11 2016-06-27 Хэллибертон Энерджи Сервисиз, Инк. Системы и способы застопоривания вертлюжных соединений при выполнении подземных работ
CN102536224A (zh) * 2012-02-22 2012-07-04 上海艾都能源科技有限公司 一种轻便取样钻机
WO2013130977A3 (fr) * 2012-03-01 2014-04-17 Saudi Arabian Oil Company Système de forage rotatif continu et procédé d'utilisation
CN104350230A (zh) * 2012-03-01 2015-02-11 沙特阿拉伯石油公司 连续旋转式钻井系统和使用方法
US9546517B2 (en) 2012-03-01 2017-01-17 Saudi Arabian Oil Company Continuous rotary drilling system and method of use
CN104350230B (zh) * 2012-03-01 2017-02-22 沙特阿拉伯石油公司 连续旋转式钻井系统和使用方法
US9470063B2 (en) 2013-01-18 2016-10-18 Halliburton Energy Services, Inc. Well intervention pressure control valve
WO2015010412A1 (fr) * 2013-07-23 2015-01-29 四川宏华石油设备有限公司 Dispositif d'agencement de tube pour tubulure enroulée
CN105735891A (zh) * 2016-04-15 2016-07-06 南昌工程学院 一种适用于陡峻山地的可取样深孔轻便钻机
CN110211443A (zh) * 2019-04-11 2019-09-06 西南石油大学 连续油管钻磨桥塞高精密模拟方法
CN110211443B (zh) * 2019-04-11 2021-04-23 西南石油大学 连续油管钻磨桥塞高精密模拟方法

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