WO2007125359A1 - Appareil et procede de pose de tubes - Google Patents

Appareil et procede de pose de tubes Download PDF

Info

Publication number
WO2007125359A1
WO2007125359A1 PCT/GB2007/050192 GB2007050192W WO2007125359A1 WO 2007125359 A1 WO2007125359 A1 WO 2007125359A1 GB 2007050192 W GB2007050192 W GB 2007050192W WO 2007125359 A1 WO2007125359 A1 WO 2007125359A1
Authority
WO
WIPO (PCT)
Prior art keywords
tubular
running tool
running
handling
arm
Prior art date
Application number
PCT/GB2007/050192
Other languages
English (en)
Inventor
David Brian Mason
Pieter Dekker
Rene Mulder
Antonius Dimphena Maria Krijnen
Original Assignee
National Oilwell Varco, L.P.
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 National Oilwell Varco, L.P. filed Critical National Oilwell Varco, L.P.
Priority to CN200780014588.4A priority Critical patent/CN101427001B/zh
Priority to EP07733614A priority patent/EP2013442A1/fr
Priority to CA2646014A priority patent/CA2646014C/fr
Publication of WO2007125359A1 publication Critical patent/WO2007125359A1/fr
Priority to US12/595,724 priority patent/US8356674B2/en
Priority to GB1112643.0A priority patent/GB2480396B/en
Priority to GB0917691A priority patent/GB2463380B/en
Priority to PCT/US2008/005404 priority patent/WO2008127740A2/fr
Priority to NO20083844A priority patent/NO20083844L/no

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
    • E21B19/00—Handling rods, casings, tubes or the like outside the borehole, e.g. in the derrick; Apparatus for feeding the rods or cables
    • E21B19/08—Apparatus for feeding the rods or cables; Apparatus for increasing or decreasing the pressure on the drilling tool; Apparatus for counterbalancing the weight of the rods
    • E21B19/087—Apparatus for feeding the rods or cables; Apparatus for increasing or decreasing the pressure on the drilling tool; Apparatus for counterbalancing the weight of the rods by means of a swinging arm
    • 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
    • E21B19/02—Rod or cable suspensions
    • E21B19/06—Elevators, i.e. rod- or tube-gripping devices
    • 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
    • E21B19/16—Connecting or disconnecting pipe couplings or joints
    • E21B19/165—Control or monitoring arrangements therefor
    • 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
    • E21B3/00—Rotary drilling
    • E21B3/02—Surface drives for rotary drilling
    • E21B3/022—Top drives

Definitions

  • the present invention relates to an apparatus and method for running tubulars and particularly, but not exclusively, running casing in the construction, maintenance and repair of an oil or gas well .
  • a top drive system for drilling wellbores is one of two common types of system, the other being a rotary table system.
  • a top drive system generally comprises a main body which houses a motor for rotating a sub which has a rotor connected to a sub connectable to a single , stand or string of tubulars .
  • the tubulars may be any of: drill pipe, casing, liner, premium tubular or any other such tubular used in the construction, maintenance and repair of wellbores, such as oil and gas wells .
  • a top drive system is generally arranged on a substantially vertical track on a derrick of a rig.
  • the top drive system is lifted and lowered on the track with a line over a crown block on a travelling block connected to the top drive system.
  • the line is reeled in and let out using a winch commonly known as a drawworks .
  • the top drive system can thus be used to trip tubulars in and out of the wellbore; turn the drill string to facilitate drilling the wellbore; and turn a single or stand of tubulars in relation to a string of tubulars hung in the wellbore to threadly connect or disconnect tubulars from a string of tubulars in the drill string to length or shorten the string of tubulars .
  • An elevator generally depends on links attached to the top drive to facilitate handling of tubulars and alignment with the sub for connection and disconnection therewith.
  • a top drive system may also be used in conjunction with a passive or active spider and/or with rotary tongs to facilitate connection and disconnection of tubulars from the string of tubulars .
  • a casing running tool can be used to allow a top drive to connect a joint of casing to a string of casing held in a spider in the floor of a drilling rig.
  • the casing running tool may have external slips or internal slips to allow the joint of casing to be gripped and rotated by the top drive relative to the static casing string held in the spider.
  • the casing running tool may comprise a fluid connection so that circulation of drilling mud can continue whilst the joint of casing, once connected to the string, can be lowered into the well .
  • the casing running tool may also comprise a blow out preventer for inhibiting a blow out during tripping of the casing string.
  • a compensation device can form part of the casing running tool to allow a degree of movement between the top drive and the connection when the pin end of the joint of casing approaches and is stabbed into the box end of the casing of the string held in the spider. This can be controlled pneumatically to give a little "bounce" as is well known in the art and can allow a degree of vertical movement so that a thread can be made up and broken such that the once the connection is broken, the tubular will be pulled away under a spring force induced by the pneumatic system from the string without fear of damage to the threads by hitting each other .
  • Certain prior tubular running systems and methods using them require controlled manipulation of a tubular through a rig V-door area using rope(s) and/or a tailing arm; stabbing board operations and other necessary manual handling of tubulars; the use of power tongs for certain functions; a relatively large number of personnel with associated expenses and stand-by costs; and a separate single joint elevator to be mated with a running tool system.
  • an apparatus for running tubulars comprising a running tool for running wellbore tubulars and a handling apparatus for handling tubulars , characterised in that the handling apparatus is connected to the running tool, the handling apparatus comprising at least one extensible arm extendable in length and movable toward and away from the running tool .
  • the running tool is one of: a casing running tool for running casing; a pipe running tool for running drill pipe or tool strings and a liner running tool for running liner.
  • Liner is used to case wells and is hung from the bottom of a cased well. Liner may be perforate .
  • the handling apparatus comprises two spaced-apart extensible arms extendable in length and movable toward and away from the running tool .
  • the apparatus further comprises a cross- member extending between said two spaced-apart extensible arms. Preferebaly, such that the cross-member is shaped - A -
  • the cross-member abuts the running tool, aligning the tubular held in the handling apparatus with the running tool .
  • the handling tool is rotatable with respect to rotation of the running tool.
  • the running tool can rotate the tubular, whilst the handling tool stays stationary with respect top the rig.
  • the handling tool is rotatable with the running tool and most preferably, the handling tool is selectably fixed in rotatable relation with the running tool or rotatable with respect to the running tool .
  • the running tool comprises a pipe gripping apparatus , such that, in use , rotation can be imparted to the tubular.
  • the running tool which may be in a fixed rotational relation to the rotor (sub) of the top drive, the tubular will rotate therewith.
  • the pipe gripping apparatus comprises at least one slip.
  • the pipe gripping apparatus comprises several slips, preferably actuatable to be moved closer to the tubular to be gripped.
  • the pipe gripping apparatus grips the external face of the tubular and/or the internal face of the tubular.
  • the at least one extendible arm is telescopic.
  • the arm comprises two sections of hollow box section material , advantageously steel , carbon fibre, aluminium or any other suitable material.
  • one of the two sections is of smaller box section than the other and telescopically slideable therein.
  • a piston and cylinder is arranged in the two sections to facilitate extending and contracting the extendible arm.
  • the arms are moved toward and away from the running tool by mechanical apparatus, for example,, but not limited to, by a rotary actuator .
  • mechanical apparatus for example,, but not limited to, by a rotary actuator .
  • one , two, or more cylinder apparatus connected at one end to the extensible arms and at the other end to the running tool or to a mount body move(s) the arms toward and away from the running tool .
  • the tubular is a joint of casing.
  • the running tool may be a casing running tool , used for running casing for casing wellbores .
  • the apparatus further comprises an elevator connected to the at least one arm for releasably engaging a tubular to be moved with respect to the running tool.
  • the elevator comprises a shoulder on to which an upstand of a tubular may sit. The elevator is placed about the tubular and pulled along the tubular until the shoulder in the elevator abuts the upstand, upon which the elevator lifts the tubular against the upstand.
  • the elevator comprises a surface engaging means such as slips to bite into the tubular. This is useful when the tubular does not have an upstand.
  • the elevator is preferably pivotable about the point at which it is connected to the at least one extendible arm to facilitate connection with the tubular, which may be lying at an angle on a conveyor in the V-door of a derrick.
  • the running tool has a mouth into which the tubular is movable, said elevator movable with respect to the running tool to abut said mouth.
  • the upstand enters the mouth and is positioned for the running tool to grip the upstand so that rotation may be imparted to the tubular.
  • the elevator grips the tubular at a small distance from the top end of the tubular and as the elevator is drawn towards the mouth of the running tool , the top of the tubular enters the mouth of the running tool , so that the tubular can be gripped by the gripping apparatus .
  • the handling apparatus is a single joint handling apparatus.
  • a single joint handling system can handle a single joint of casing, or a stand of two or three tubulars.
  • Tubulars may be any of casing, drill pipe, premium tubular, smooth walled tubulars etc..
  • a single joint elevator can not lift an entire string of tubulars , which may be in excess of tens of tonnes and may be in excess of five hundred tonnes.
  • the running tool includes engagement apparatus connected to the two arms for selectively engaging a tubular.
  • the engagement apparatus comprises a shoulder on an elevator on which an upstand on a tubular can sit, preferably, the shoulder is sloped, advantageously sloped inwardly and downwardly towards the centre of the elevator.
  • the engagement apparatus comprises an elevator comprising slips for gripping the external face of a tubular.
  • the two arms are sufficiently extensible and movable to move the tubular up to the running tool .
  • the apparatus further comprises a body positioned above the running tool, the at least one arm pivotably connected to the body.
  • the apparatus further comprises a shaft on which said at least one arm is pivotably connected.
  • the apparatus further comprises an actuator for moving the at least one arm.
  • the actuator is an extendible arm such as a hydraulic or pneumatic piston.
  • the actuator is connected at one end to said at least one arm and at the other to said body.
  • the connections allow rotational movement between the actuator and the body and the actuator and the at least one arm.
  • the handling apparatus may thus be located between a running tool and a top drive.
  • the apparatus further comprises a drive system connected to and above the running tool for rotating the tubular.
  • the drive system is a top drive for wellbore operations.
  • the drive system may be provided by a rotary drive system or a power swivel system.
  • the present invention also provides a method for running tubulars, the method comprising the steps of using a handling apparatus to pick up a tubular, the handling apparatus comprising at least one extendible arm, contracting the extendible arm to draw the tubular close or into to the running tool, such that a gripping apparatus of the running tool can be activated to grip the tubular.
  • the method further comprises the step of activating said pipe gripping apparatus to grip the tubular.
  • the at least one extendible arm is connected to the running tool on a movement joint, the method comprising the step of swinging the at least one arm on said movement joint towards the tubular to be picked up.
  • away from vertical alignment with well centre Preferably, the step of swinging is facilitated by activating an actuator arranged between the running tool and the at least one extendible arm.
  • the actuator is a piston and cylinder.
  • the tubular to be picked up lies in the V-door of a derrick of a drilling rig.
  • the handling apparatus comprises a cross member, the method further comprising the step of the cross member abutting the running tool to align the tubular with the mouth of the running tool .
  • the handling apparatus further comprises an elevator, the method further comprising the step of attaching the elevator to the tubular to be picked up.
  • the at least one extendible arm is extendible using a piston and cylinder.
  • the running tool is connected to a top drive, the method further comprising the step of rotating the running tool .
  • the handling apparatus moves the tubular into the running tool so that the upstand of the tubular is gripped by the gripping apparatus.
  • the running tool is then lowered and rotated to connect the tubular with a string of tubulars in the well.
  • the gripping apparatus may then be retracted and the runnig tool further lowered such that the gripping apparatus grips the tubular beneath the upstand.
  • the spider in the rig floor can then be released to allow the running tool to carry the full weight of the string of tubulars and then lowers the string into the well.
  • the spider is then activated to hold the pipe string and the gipping apparatus in the running tool is then released and raised in preparation for another tubular to be added to the string.
  • Certain prior art running tool systems employ a relatively long lower stabbing guide to assist in the acquisition and positioning of a tubular.
  • Certain of such guides use a relatively wide, relatively long skirt section for guiding a tubular with respect to the running tool.
  • the single joint handling system pulls a tubular coupling up to or into a running tool so that a relatively short, smaller stabbing section or bell can be used which results in a shorter overall system length.
  • a compensator associated with the running tool can be used to facilitate the introduction (“soft stab) of a pin/male tubular end into a box/female tubular end.
  • the travelling equipment is raised until the tubular stand is in a vertical position under the running tool.
  • the extendible arms are then extended to lower and "soft stab" the tubular stand into a tubular coupling of the tubular string, for example, a string held in the slips at a rig floor rotary table.
  • Figure IA is a front view of a tubular running apparatus in accordance with the present invention.
  • Figure IB is a side view of part of the tubular running apparatus shown in Figure LA;
  • Figure 1C is a side view of part of the tubular running apparatus shown in Figure LA;
  • Figure ID is a perspective view of the tubular running apparatus shown in Figure LA;
  • Figure IE is a perspective view of part of a single joint handling apparatus of the running apparatus shown in Figure IA with parts moved and rotated;
  • Figure IF is a side view of part of a tubular running apparatus in accordance with the present invention;
  • Figure 2A is a schematic view showing a first step in a method in accordance with the present invention using a tubular running apparatus as shown in Figure LA;
  • Figure 2B is a schematic view of a second step in a method in accordance with the present invention using a tubular running apparatus as shown in Figure LA;
  • Figure 2C is a schematic view a third step in a method in accordance with the present invention using a tubular running apparatus as shown in Figure LA;
  • Figure 2D is a schematic view of a fourth step in a method in accordance with the present invention using a tubular running apparatus as shown in Figure IA; and Figure 2E is a schematic view a fifth step in a method in accordance with the present invention using a tubular running apparatus as shown in Figure IA.
  • Figures IA to ID show a tubular running apparatus 10 in accordance with the present invention which includes a casing running tool 20 connected to a drive system 30 (shown schematically, Figures IA, ID; for example, but not limited to, a top drive system) ; and a single joint handling apparatus 50.
  • the casing running tool 20 may be any suitable known casing running tool such as a Model CRT 14 as is commercially available from National Oilwe11 Varco.
  • the CRT 14 casing running tool comprises slips for gripping a joint of casing to allow the top drive to rotate the slips and thus the joint to threadly mate the joint of casing into a threaded joint of casing in a casing string ST.
  • the casing running tool 20 may also have a mechanism to link the top of the joint of casing with a circulating head, such that circulation of drilling mud can continue through the joint of casing whilst the joint of casing is lowered into the well.
  • the drive system 30 can be any suitable known top drive system or power swivel system that can rotate tubulars which is connectible to a derrick D .
  • a drive system is used with an upper Internal Blow Out Preventer (IBOP) U and a lower IBOP L.
  • IBOP Internal Blow Out Preventer
  • the drive system is a National Oilwe11 Varco TDS 11 500 ton system.
  • the single joint handling apparatus 50 has a base 53 with two spaced-apart beams 51, 52 connected by a crossmember 59. Each beam 51, 52 is pivotably connected to a corresponding shaft 53 , 54 (which may be a single unitary shaft through the mount body) projecting from a mount body 55. Arms 61 , 62 are extensibly mounted on the beams 51, 52, respectively. Cylinder/piston apparatuses 56 (shown schematically) within the beams and arms (and connected thereto) move the arms 61 , 62 with respect to the beams 51 , 52. Hoses 57 , 58 provide power fluid to the cylinder/piston apparatuses 56 (for example, from a typical power fluid source on a rig) .
  • a single joint elevator 60 is pivotably connected to ends 71, 72 of the arms 61, 62.
  • Any suitable known elevator may be used.
  • the elevator is a Model SJH commercially available from National Oilwe11 Varco.
  • such an elevator is modified to be remotely-operable with a closed feedback system.
  • a tilt system 70 provides selective controlled tilting of the elevator 60.
  • the tilt system 70 has a piston-cylinder apparatus 73 interconnected between the arm 61 and a body 65 of the elevator 60.
  • a line 66 connects the system 70 to a control system CS (shown schematically, Figure IE) , for example, , a rig control system, a TRS (trademark) system, a top drive control system (for example,, but not limited to, a known National Oilwe11 Varco Driller's Control Station, or a stand alone driller's control system and station that is temporarily or permanently installed on, with, or into an existing rig control system.
  • a control system CS shown schematically, Figure IE
  • a rig control system for example, a rig control system, a TRS (trademark) system, a top drive control system (for example,, but not limited to, a known National Oilwe11 Varco Driller's Control Station, or a stand alone driller's control system and station that is temporarily or permanently installed on, with, or into an existing rig control system.
  • pivot cylinder apparatuses 81, 82 are connected between the mount body 55 and the beams 51, 52.
  • Hoses 57, 58 provide power fluid (for example, from a rig power source PS, shown schematically, Figure ID) to the cylinder apparatuses 56 and 81, 82.
  • Each cylinder apparatus 81, 82 has one end connected to a shaft 91, 92, respectively, projecting from the mount body 55 and an end of a piston 83, 84, respectively, connected to one of the beams 51 , 52.
  • Extension and retraction of the pistons 83, 84 results in movement of the arms 61, 62 with respect to the casing running tool 20.
  • the pivot cylinder apparatuses 81, 82 are connected to the casing running tool 20 or to structure above the casing running tool 20.
  • only one pivot cylinder apparatus is used.
  • a pin 95 projecting form the mount body 55 projects into a fixture 32 of the pipe handler 34, for example, a torque tube of a pipe handler 34 to react torque generated by the casing running tool 20 into the fixture 32 (and to structure interconnected therewith) and to prevent rotation of the single joint handling apparatus 50 with the running apparatus 20.
  • a pin 96 extend from the mount body 55 into a stabbing bell 39 of the drive system 30 which prevent the system 50 from rotating with the casing running tool 20.
  • the single joint handling apparatus 50 in accordance with the present invention falls within a width envelope of a top drive system above it.
  • Figure 1 F shows another embodiment of an apparatus 10a, like the tubular running apparatus 10, and like numerals indicate like parts.
  • the tubular running apparatus 10a has no pivot cylinder apparatuses 81, 82.
  • the beams 51, 52 (one shown in Figure IF; as in Figure IA) ; connected arms (not shown; as in Figure IA) ; and elevator (not shown; as in Figure IA) are moved toward and away from the tubular running apparatus 10a by a mechanical apparatus 74 that rotates the shaft 53a a single shaft extending through the mount body 55 to which both beams are connected.
  • the mechanical apparatus 74 is a rotary actuator apparatus with parts 74a, 74b interconnected with the shaft 53a (or two rotary actuator apparatuses if each beam is mounted to a separate shaft, for example, shafts 53, 54) .
  • FIGS 2A to 2E illustrate one method in accordance with the present invention using an apparatus 10 to move casing on a rig R (for example, a typical drilling rig system) above a wellbore W.
  • a rig R for example, a typical drilling rig system
  • the drive system 30 has been lowered, lowering the casing string ST into the well .
  • the arms 61 , 62 have been extended toward a piece or joint of casing C in the V- door area V of the rig R having a rig floor FR.
  • the elevator 60 is latched onto the piece or joint of casing C below a coupling CG of the casing C.
  • Such a step is used in adding a joint of casing to a casing string either during the typical casing of an already-drilled bore or in a casing-drilling operations.
  • Sensors SR Sensors SR
  • the joint of casing C has been hoisted upwardly by raising the apparatus 10 in the derrick.
  • tailing rope(s) and/or tailing arms(s) are used to support the joint of casing C during this movement.
  • no such rope(s) or arm(s) are used and the system 50 supports the joint of casing C.
  • the joint of casing C has been moved over the wellbore W in line with the string ST of casing.
  • the coupling CG has been pulled up within the casing running tool 20 by the single joint handling apparatus 50 by retracting the arms 61 , 62.
  • Figure 2D illustrates lowering of the joint of casing C down to the top joint of the casing string ST for threaded mating and connection therewith.
  • the tubular running apparatus 10 is then lowered so that the coupling CG is located within the casing running tool 20 so that holding slips 29 within the casing running tool 20 can be set on the body of the casing joint C and not on the coupling (see Figure 2E, coupling CG and slips 29 in dotted lines) .
  • the present invention therefore, provides in some, but not in necessarily all, embodiments a tubular running system including: a running tool system for running wellbore tubulars; a tubular handling system connected to the running tool system; the tubular handling system having two arms comprising two spaced-apart extensible arms extendable in length and movable toward and away from the running tool system.
  • Such a method may have one or some, in any possible combination, of the following: an elevator connected to the arms for releasably engaging a tubular to be moved with respect to the running tool system;
  • the tubular handling system is a single joint handling system; a tubular to be handled by the tubular handling system is connected to at least one additional tubular; the tubular to be handled is connected to two additional tubulars;
  • the tubular running system including engagement apparatus connected to the two arms for selectively engaging a tubular; wherein the two arms are sufficiently extensible and movable to move the tubular up to the running tool; wherein the wellbore tubulars are casing; a body positioned above the running tool system, and the two arms pivotably connected to the body; pivoting apparatus connected to the two arms for moving the two arms with respect to the running tool; wherein the two arms are connected to movable shaft apparatus on the body, the tubular running system further including the pivoting apparatus including rotation apparatus for rotating the movable shaft apparatus to move the two arms toward and away from the running
  • the present invention therefore, provides in some, but not in necessarily all, embodiments a method for running tubulars , the method including engaging a tubular with a joint engagement apparatus of a tubular running system as any disclosed herein with a running tool system in accordance with the present invention; and moving the tubular to the running tool system with the joint handling system.
  • Such a method may have one or some, in any possible combination, of the following: wherein the arms of the tubular running system are sufficiently extendable and movable to move the joint into the running tool system, and moving the joint into the running tool system; wherein the joint engagement apparatus is an elevator; wherein the tubular running system includes a body positioned above the running tool system, the two arms pivotably connected to the body, and pivoting the arms with respect to the running tool system; wherein the tubular running system further comprises a drive system connected to and above the running tool system; and/or wherein the drive system is a top drive system for wellbore operations .
  • a single joint elevator with teeth or other such anti-slip means is used to grip the pipe wall.

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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

L'invention concerne un appareil de pose de tubes, en particulier mais non pas exclusivement, pour le forage d'un puits de pétrole ou de gaz, l'appareil comportant un outil de pose (20) pour poser des tubes de puits de forage et un appareil de manipulation (50) pour manipuler des tubes, caractérisé en ce que l'appareil de manipulation (50) est connecté à l'outil de pose (20), l'appareil de manipulation (50) comportant au moins un bras déployable (61, 62) pouvant se déployer en longueur et mobile en direction et en provenance de l'outil de pose (20).
PCT/GB2007/050192 2006-04-28 2007-04-13 Appareil et procede de pose de tubes WO2007125359A1 (fr)

Priority Applications (8)

Application Number Priority Date Filing Date Title
CN200780014588.4A CN101427001B (zh) 2006-04-28 2007-04-13 下入管件的方法和装置
EP07733614A EP2013442A1 (fr) 2006-04-28 2007-04-13 Appareil et procede de pose de tubes
CA2646014A CA2646014C (fr) 2006-04-28 2007-04-13 Appareil et procede de pose de tubes
US12/595,724 US8356674B2 (en) 2007-04-13 2008-04-26 Tubular running tool and methods of use
GB1112643.0A GB2480396B (en) 2007-04-13 2008-04-26 Tubular running tool and methods of use
GB0917691A GB2463380B (en) 2007-04-13 2008-04-26 Tubular running tool and methods of use
PCT/US2008/005404 WO2008127740A2 (fr) 2007-04-13 2008-04-26 Outil de pose tubulaire et procédés d'utilisation
NO20083844A NO20083844L (no) 2006-04-28 2008-09-05 Apparatus and method for running tubulars

Applications Claiming Priority (2)

Application Number Priority Date Filing Date Title
US11/414,511 2006-04-28
US11/414,511 US20070251700A1 (en) 2006-04-28 2006-04-28 Tubular running system

Publications (1)

Publication Number Publication Date
WO2007125359A1 true WO2007125359A1 (fr) 2007-11-08

Family

ID=38164261

Family Applications (1)

Application Number Title Priority Date Filing Date
PCT/GB2007/050192 WO2007125359A1 (fr) 2006-04-28 2007-04-13 Appareil et procede de pose de tubes

Country Status (6)

Country Link
US (2) US20070251700A1 (fr)
EP (1) EP2013442A1 (fr)
CN (1) CN101427001B (fr)
CA (1) CA2646014C (fr)
NO (1) NO20083844L (fr)
WO (1) WO2007125359A1 (fr)

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GB2464601A (en) * 2008-10-22 2010-04-28 Titan Torque Services Ltd Drill bit support apparatus and method

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US8356674B2 (en) * 2007-04-13 2013-01-22 National Oilwell Varco, L.P. Tubular running tool and methods of use
US8074711B2 (en) * 2008-06-26 2011-12-13 Canrig Drilling Technology Ltd. Tubular handling device and methods
US8720541B2 (en) 2008-06-26 2014-05-13 Canrig Drilling Technology Ltd. Tubular handling device and methods
DE102009039022A1 (de) 2009-08-28 2011-03-03 Bentec Gmbh Drilling & Oilfield Systems Handhabungsgerät für Bohrgestänge, insbesondere so genannter Pipehandler oder so genannter Topdrive mit Pipehandler, und Betriebsverfahren dafür
CN101737016B (zh) * 2009-12-29 2012-05-30 中国石油天然气集团公司 一种可承扭钻杆吊卡装置
US20110214919A1 (en) * 2010-03-05 2011-09-08 Mcclung Iii Guy L Dual top drive systems and methods
US8240372B2 (en) * 2010-04-15 2012-08-14 Premiere, Inc. Fluid power conducting swivel
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US20090101361A1 (en) 2009-04-23
US20070251700A1 (en) 2007-11-01
CA2646014A1 (fr) 2007-11-08
CA2646014C (fr) 2012-07-17
CN101427001B (zh) 2013-04-24
CN101427001A (zh) 2009-05-06
EP2013442A1 (fr) 2009-01-14
NO20083844L (no) 2009-01-19

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