WO2009025832A1 - Appareil de descente d'éléments tubulaires - Google Patents

Appareil de descente d'éléments tubulaires Download PDF

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Publication number
WO2009025832A1
WO2009025832A1 PCT/US2008/009935 US2008009935W WO2009025832A1 WO 2009025832 A1 WO2009025832 A1 WO 2009025832A1 US 2008009935 W US2008009935 W US 2008009935W WO 2009025832 A1 WO2009025832 A1 WO 2009025832A1
Authority
WO
WIPO (PCT)
Prior art keywords
assembly
tubular octg
make
tubular
octg
Prior art date
Application number
PCT/US2008/009935
Other languages
English (en)
Inventor
Richard Mcintosh
Original Assignee
Richard Mcintosh
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 Richard Mcintosh filed Critical Richard Mcintosh
Publication of WO2009025832A1 publication Critical patent/WO2009025832A1/fr

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Classifications

    • E—FIXED CONSTRUCTIONS
    • E21—EARTH DRILLING; MINING
    • E21B—EARTH DRILLING, e.g. DEEP 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

Definitions

  • the present invention relates to a method and apparatus for facilitating the connection of tubulars used in the oil and gas exploration and extraction industries using a top drive. More specifically, the invention relates to an apparatus for running tubulars into a well bore.
  • a string of steel pipes with threaded connectors commonly known as tubulars or tubing or generically as oil country tubular goods ("OCTG").
  • OCTG oil country tubular goods
  • tubular OCTG steel pipes
  • individual sections of tubular OCTG are typically progressively added to the string as it is lowered into a well from a drilling rig or platform.
  • the section to be added is restrained from falling into the well by some tubular engagement means, typically a spider or the like, and is lowered into the well to position the threaded pin of the tubular OCTG section adjacent to the threaded box of the tubular OCTG in the well bore.
  • the sections are then joined by relative rotation of the sections until such time as the desired total length has been achieved.
  • a power tong to torque the connection to a predetermined torque in order to connect the sections of tubular OCTG.
  • This traditional method and equipment types have been used extensively around the world for a period in excess of fifty years. While this method is in daily use it normally requires a large team of specialist personnel along with a plethora of equipment to successfully undertake this task. It is also a very dangerous task with personnel having to be located on a small platform suspended up to 50 feet above the rotary table and the power tong tethered to a steel cable under high loads.
  • a top drive may be used; that is, a top driven rotational system used for drilling purposes.
  • a top drive system is used to make the connection
  • the use of a slip type elevator to restrain the section of tubular OCTG to be added may be problematic, due to the configuration of the top drive apparatus on the drilling platform.
  • an apparatus connected to the top drive which can be inserted into the section of tubular OCTG to be added, and engaged therewith to hold the section in place.
  • Such apparatus may comprise one or more toothed grapples, which may be hydraulically operated to engage an inner surface of the tubular.
  • the intention of the present invention is to offer a much-improved method of running tubular OCTG into a borehole without the shortfalls in the tools available today.
  • An apparatus has been invented for handling tubular OCTG.
  • the apparatus is connectable to a top drive and can be used to grip the tubular OCTG from the inside.
  • the system comprises a top drive, a tubular OCTG make-up assembly, elevator links and transfer elevators.
  • the operator can remotely manipulate the elevator links to extend or retract the transfer elevators to pick up and position a tubular OCTG above the tubular OCTG already secured in the rotary table on the drill floor.
  • the operator can then engage a probe and activate a hydraulic or pneumatic actuator causing a gripper assembly to grip the tubular OCTG, and then use the rotational capability of the top drive to remotely couple the two joints of tubular OCTG together.
  • a make-up assembly for running tubular OCTG into and/or out of the well bore, the make-up assembly comprising a probe engageable within the tubular OCTG, wherein the probe comprises an inner mandrel having an outer surface, a plurality of inclined ramps, a ball cage surrounding the mandrel and having a plurality of balls or rollers captively located in apertures in the ball cage and aligned with the inclined ramps of the mandrel, being relatively movable to cause the balls or rollers to climb and descend the inclined ramps thus, respectively to protrude from and retract within said apertures and, when protruding, to bear upon the inner surface of the tubular OCTG to lock the probe and receiving tubular OCTG in engagement.
  • the probe further comprises an upper hydraulic actuator having an inner sliding sleeve that, when activated, will cause the ball cage to travel relative to the movement of the inner mandrel, thus providing a means of controlling the placement of the balls or rollers relative to the ball cage, therein locking the probe in place prior to applying a rotational force, lifting action or lowering action upon the tubular OCTG.
  • the make-up assembly can include further means for moving the balls or rollers radially with respect to the inner mandrel.
  • an elevator assembly for facilitating the transfer of a tubular OCTG from the V-door of a drilling rig to the vertical position and thereby allowing the tubular OCTG to be stabbed into a similar tubular OCTG located in the slip assembly located in or on the drill floor for the running or pulling of tubular OCTG into and/or out of the well bore.
  • the elevator assembly comprises a set of telescoping transfer elevator links attached to the make-up assembly of the present invention connected to the top drive system or drilling hook on a non-top-drive fitted rig, whereby the telescoping transfer elevator links can be extended to facilitate engagement of the tubular OCTG at the V-door and then retracted to bring the tubular OCTG into a position to be raised to a position ready for stabbing of the tubular OCTG into a similar tubular OCTG located in the slip assembly located in or on the drill floor.
  • the elevator assembly may also have an elevator link tilt assembly comprising two or more hydraulic actuators, wherein the link tilt assembly is coupled to the telescoping transfer elevator links such that the extension or retraction of the hydraulic actuators can pivot the telescoping transfer elevator links about a point located on a vertical axis; providing a secondary means of positioning the transfer elevators to facilitate transfer of the tubular OCTG into the stabbing position for make-up.
  • the make-up assembly may further be provided with positive locking means to maintain the balls or rollers in engagement with a tubular OCTG should the make-up assembly otherwise fail.
  • the positive locking means may be provided in conjunction with axially angled faces, and/or in conjunction with circumferentially angled faces.
  • the positive locking means may comprise, for example, a spring or hydraulic safety interlock system.
  • the make-up assembly In addition to gripping, rotating, lifting and lowering the tubular OCTG, another function of the make-up assembly is to transmit the circulation of drilling fluid or mud through the tubular OCTG. In order to pump drilling fluids or mud, a seal must be established between the tubular OCTG and the make-up assembly of the present invention, hi use, the make-up assembly will be connected to a top drive via a threaded connection at its upper end, or to a non-top-drive rig via a pup joint latched into an elevator. Both systems have available a means of connecting to a circulating system that will permit the tubular being handled to be filled or circulated at any time during the running operation.
  • the mandrel of the make-up assembly is equipped with a through bore to permit tubular fill-up and circulation to take place at any time.
  • a packer cup with a sealing element preferably comprising an elastomer element or layer over a steel body.
  • the sealing element of the packer cup is self energized to establish an initial seal and further energized by the pressure inside the tubular OCTG, which forces the sealing element against the walls of the tubular OCTG, thereby forming a seal to allow mud or drilling fluid to be pumped though the tubular OCTG assembly.
  • the present invention further comprises a control system that is able to manipulate the telescoping transfer elevator links, link tilts, and other elements of all aspects of the present invention.
  • the control system of the present invention is able to open and close the transfer elevators, retract and extend the telescoping transfer elevator links, the secondary link tilt, control and measure the application of torque and turns and stop the rotation of the make-up assembly of the present invention at a pre-determined torque point utilizing either a wireless communication system or a system of hydraulic or pneumatic control line umbilical.
  • the wireless communication system can also be used in other applications to measure and control torque, applied loads and or have the ability to dump torque or applied load at a predetermined point.
  • the system may also be coupled conventionally using a series of cables should the use of wireless communication be restricted.
  • the control system is also able to set and unset the hydraulic actuator used to hydraulically manipulate the outer cage of the make-up assembly causing the balls or rollers to contact the tubular OCTG to facilitate make-up or breakout of the tubular OCTG threaded connection.
  • the control system is also able to monitor feedback loops that include sensors or monitors on the elements of the present invention. For example, sensors of the control system of the present invention monitor the open and close status of the transfer elevators, the status of the hydraulic actuator and thereby the position of the balls or rollers.
  • the control system is designed or rated for use in a hazardous working environment. Communication with the processor of the control system is accomplished through a wireless communications link.
  • the make-up assembly may further comprise a lower mandrel as a tapered guide shoe or a bull-nose centralizer with a tapered high density urethane or polymer coated section sized to suit the tubular OCTG being run, to facilitate easy stabbing of the apparatus into the tubular OCTG, attached to the bottom of the inner mandrel to further protect the thread and sealing areas of the tubular OCTG to be coupled together.
  • the lower mandrel further comprises an inner sleeve assembly fitted with a two-way acting valve to prevent mud discharge onto the drill floor when the apparatus is removed from the tubular OCTG.
  • the same principal used for internal gripping may also be modified to suit external gripping applications. It is further intended that the balls or rollers and their respective ramped surfaces may be disposed randomly about the make-up assembly or in longitudinally spaced rows where the balls or rollers of each row are offset laterally with respect to those of the next succeeding row.
  • the inventive make-up assembly may also be connected to a power swivel suspended under a traditional Kelly in the event that the drilling rig does not have a top drive installed and or on a hydraulic work-over rig or snubbing unit.
  • the power swivel may be installed into a hydraulic or pneumatically controlled frame to lift and lower the power swivel and make-up assembly of the present invention into and out of the tubular OCTG and thereby the well bore.
  • the make-up assembly comprise an upper hydraulic actuator having an inner sliding sleeve that when energized will cause the cage to travel relative to the movement of the inner sliding sleeve, thus providing a means of controlling the placement of the balls and rollers relative to the inner mandrel therein locking the probe in place prior to applying a rotational force, lifting or lowering action upon the tubular OCTG.
  • the make-up assembly be provided with a through bore to allow the transmission of drilling fluids or mud for the purposes of filling or circulation of the tubular OCTG while running into the well bore and further comprise a lower packer cup on the lower mandrel section of the make-up assembly which is self energizing by pressure inside the tubular OCTG thereby forming a seal to allow drilling fluid or mud to be pumped into the tubular OCTG and/ or well bore.
  • the make-up assembly further comprise an elevator assembly with elevator links and transfer elevators which can be remotely manipulated to extend or retract the transfer elevators to pick up and position a tubular OCTG above the tubular OCTG already secured in the rotary table on the drill floor wherein the operator can then engage the make-up assembly to energize the ball or roller mechanism and use the rotational capability of the top drive to remotely couple the two tubular OCTG together.
  • the elevator assembly comprise a set of links used to position the tubular OCTG from the vertical position to the horizontal position wherein said links each contain a single and/ or multi stage hydraulic or pneumatic cylinder contained within the body of the links or mounted externally allowing the operator to extend the links into the correct position to accept the tubular OCTG in the transfer & lifting elevators.
  • the hydraulic or pneumatic cylinders be coupled to a weight compensation control system whereby the activation of the weight compensation system will provide for the tubular OCTG to be lowered in a controlled fashion into the tubular OCTG already secured in the rotary table on the drill floor and utilizing the weight compensation system will effectively give the tubular OCTG zero weight in gravity and protect the threads of the tubular OCTG during stabbing operations, for make-up or breakout operations.
  • Figure 1 shows an axial view of a make-up assembly in accordance with one embodiment of the present invention with a plurality of balls and or rollers and their respective apertures radially mounted thereon.
  • Figure 2 shows an axial view of a make-up assembly in accordance with one embodiment of the present invention with a plurality of balls and or rollers and their respective apertures randomly mounted thereon.
  • Figure 3 shows an axial view of a make-up assembly in accordance with one embodiment of the present invention with a plurality of balls and or rollers and their respective apertures diagonally mounted thereon.
  • Figure 4 shows an axial sectional view of a make-up assembly in accordance with one embodiment of the present invention showing the relationship between the inner mandrel, cage, thru bore, balls and rollers thereon.
  • Figure 5 shows a sectional view through the mandrel of the make-up assembly in Figure
  • Figure 6 shows a sectional view through the mandrel of the make-up assembly in Figure 2
  • Figure 7 shows the tapered guide shoe - lower mandrel of the make-up assembly which may be urethane coated or of nylon drift material to protect the tubular OCTG threads during stab-in operations.
  • Figure 8 shows an axial sectional view of a make-up assembly according to the invention displaying the ball or ramp profile, used to energize the balls or rollers against the inner wall of the tubular OCTG.
  • Figure 9 shows an axial view of a make-up assembly in accordance with one embodiment of the present invention shown in Figure 1 with a plurality of balls and or rollers radially mounted thereon installed inside a tubular joint OCTG.
  • Figure 10 shows a sectional view through the elevator links of the elevator assembly in accordance with one embodiment of the present invention showing the multi-stage hydraulic ram installed inside the link along with the adjustment holes used to further extend the length of the links for varying rig applications.
  • Figure 11 shows a side view of the make-up assembly and elevator assembly in accordance with one embodiment of the present invention showing how it would be rigged up for connection to a top-drive assembly.
  • Figure 12 shows a pictorial view of a top drive assembly defining how the make-up assembly and elevator assembly of the present invention may be installed too. It should be noted that manufacturers of top drive systems are many and each may have their own technical differences in configuration of moving parts. However it is generally found that they are all capable of executing the same tasks of providing a means for connection to a drilling string or cross-over sub; providing a means for rotation in both forward and reverse directions and the ability to apply torque in varying degrees of power.
  • Figure 13 shows a side view of a make-up assembly in accordance with one embodiment of the present invention showing how it would be rigged up to a power swivel and hydraulic or pneumatically controlled torque frame.
  • FIG. 1 to 4 hi Figures 1 to 4 is shown a make-up assembly comprising a probe that can be inserted into a tubular OCTG 10 as shown in Figures 9 and 10, for the purpose of making up or breaking out a threaded connection on a tubular OCTG 10 such as tubular OCTG used in the construction of a well bore, in accordance with an embodiment of the present invention.
  • the make-up assembly comprises an inner tubular mandrel 7 having a plurality of ramped surfaces 8 spaced apart thereon, a second elongate member 3 superimposed with respect to the ramped surfaces 8 of the inner mandrel 7, a plurality of rolling members 9 captively retained within apertures 9 of the cage 3 so as to reside respectively on the ramped surfaces 8 of the inner mandrel 7.
  • Energizing a hydraulic or pneumatic actuator 2 will cause relative movement of the cage 3 to cause the rolling members 9 to descend the ramped surface 8 of the inner mandrel 7 thereby protruding partially from the apertures 4 contained in various styles about or around the cage 3, causing the rolling members 9 to contact the tubular OCTG 10 and thereafter a rotational movement can be applied by the top drive engaging the threaded portion of the tubular OCTG 10 to connect it to its respective partner located in the rotary table.
  • the inner mandrel 7 has a through bore 20 formed through its long axis for the purpose of allowing conveyance of drilling fluids or mud.
  • the inner mandrel 7 may be of circular cross section having the cage 3 concentrically disposed around it.
  • the inner mandrel 7 and the cage 3 may be arranged for longitudinal movement one with respect to the other.
  • the cage 3 may be a ball 9 or roller cage having an array of apertures 4, through which the respective balls or rollers 9 may partially protrude.
  • Figure 1 shows the make-up assembly with a series of longitudinally displaced rows of apertures 4, a lower packer cup 5, a guide shoe 6 to facilitate stabbing of the make-up assembly into a tubular OCTG 10 and a hydraulic or pneumatic actuator 2 for energizing the cage 3 in respect to the inner mandrel 7.
  • the size and quantity of the balls or rollers 9 can be increased or decreased to suit varying applications, types of tubular OCTG or total string weight or length of the connected tubular OCTG 10 when installed in the well bore.
  • Figure 2 shows the make-up assembly with a series of diagonally displaced rows of apertures 4, a lower packer cup 5, a guide shoe 6 to facilitate stabbing of the make-up assembly into a tubular OCTG 10 and a hydraulic or pneumatic actuator 2 for energizing the cage 3 in respect to the inner mandrel 7.
  • the size and quantity of the balls or rollers 9 can be increased or decreased to suit varying applications, types of tubular OCTG or total string weight or length of the connected tubular OCTG 10 when installed in the well bore.
  • Figure 3 shows the make-up assembly with a series of randomly displaced rows of apertures 4, a lower packer cup 5, a guide shoe 6 to facilitate stabbing of the make-up assembly into a tubular OCTG 10 and a hydraulic or pneumatic actuator 2 for energizing the cage 3 in respect to the inner mandrel 7.
  • the size and quantity of the balls or rollers 9 can be increased or decreased to suit varying applications, types of tubular OCTG or total string weight or length of the connected tubular OCTG 10 when installed in the well bore.
  • Figure 4 shows a cross sectional view of the make-up assembly showing the inner mandrel 7 with the thru bore 20, the ramped surfaces 8 for the ball or rollers 9 to ascend and or descend and the lower guide shoe 6.
  • Figure 5 shows a schematic representation of an end view of the make-up assembly showing the inner mandrel 7, cage 3 and the ball or roller 9 showing the longitudinal alignment of the ball or rollers 9 in adjacent rows.
  • Figure 6 shows a schematic representation of an end view of the make-up assembly as detailed in figures 2 & 3 showing the inner mandrel 7, the cage 3 and the ball or roller 9 showing that either diagonal or random placement of the ball or roller 9 leaves no continuous longitudinal spaces between the columns of balls or rollers 9 as is the case in figure 1.
  • This non-uniform arrangement of the balls or rollers 9 results in a more uniform grip being induced into the inner wall of the tubular OCTG 10 once the make-up assembly is energized.
  • Figure 7 shows the arrangement of the tapered guide shoe 6 used to facilitate stabbing the make-up assembly into a tubular OCTG 10.
  • Figure 8 shows a detailed close-up view of the ramped surfaces 8 of the inner mandrel 7 that the balls or rollers 9 ascend and descend. The view also shows the apertures 4 through which the balls or rollers 9 can partially protrude through and engage the inner surface of the tubular OCTG 10.
  • Figure 9 shows an embodiment of the present invention installed inside a tubular OCTG 10 prior to the balls or rollers 9 being energized. It can be clearly seen that the hydraulic or pneumatic actuator 2 or the drill pipe crossover joint 1 which connects the make-up assembly to the top drive or hook assembly does not engage the tubular OCTG 10.
  • Figure 10 shows a sectional cross view of the main elevator link body 16 showing the inner hydraulic or pneumatic multi- stage cylinder 14 used to extend or retract the lower link body 18 in relation to the corresponding link body 16. It also displays the adjustable mounting points 13 contained in the link body 16 such that the total length of the link body 16 may be set prior to extension or retraction. This will allow for a greater flexibility of total length, which will compensate for the variable distances between well centers and V-doors on drilling rigs. The figure also show the mounting point 15 for the link tilt mounted on the outside of the link main body 16. There are mounted on the upper section of the main link body 16 attachment points 11 to facilitate mounting the main link bodies 16 onto the hydraulic actuator 2. In order to provide a secondary means of retention the mounting points 11 include two threaded holes 12 for bolting a link retaining plate 27 and the transfer elevator attachment points 19.
  • Figure 11 shows a vertical view of the make-up assembly and elevator assembly detailing one configuration for attachment to a top drive assembly via the drill pipe crossover 1, the hydraulic actuator 2, the cage 3, the ball or roller apertures 4, packer cup 5, lower guide shoe 6, link lower body 18, attachment points 11, retaining plate 27 and the transfer elevator attachment points 19.
  • Figure 12 shows a pictorial view of a top drive assembly defining how the make-up assembly and elevator assembly of the present invention may be installed too.
  • a top drive 30 on a frame 29 rides on a track 33, being raised or lowered by a block 32.
  • a typical toothed grapple apparatus 31 is shown attached to the top drive 30.
  • Figure 13 shows a sectional view of make-up assembly installed into a frame 23 installed onto a base plate 21 with telescoping members 24 allowing the make-up assembly to be raised and lowered. In this arrangement the make-up assembly would be typically be installed onto a wellhead assembly where no rig, derrick or top drive assembly was present.
  • the frame 24 is variable in height and contains multi-stage hydraulic or pneumatic cylinders 28 to raise and lower the apparatus.

Abstract

L'invention concerne un procédé et un appareil permettant de descendre des éléments tubulaires dans un puits de forage pour une utilisation avec un entraînement supérieur ou une tête d'injection comprenant un ensemble de réalisation ayant des mandrins intérieur et extérieur dont un a un réseau de surfaces inclinées alors que l'autre est une cage avec des billes ou des rouleaux ayant des billes ou des rouleaux et des ouvertures, un mouvement relatif des mandrins repoussant les billes ou les rouleaux pour qu'ils fassent saillie radialement à travers les ouvertures pour venir en contact sur l'intérieur ou l'extérieur d'un élément tubulaire. L'invention concerne également un ensemble élévateur ayant des bielles d'élévateur et des élévateurs de remontée pour positionner des éléments tubulaires pour qu'ils viennent en prise avec l'ensemble de réalisation.
PCT/US2008/009935 2007-08-22 2008-08-21 Appareil de descente d'éléments tubulaires WO2009025832A1 (fr)

Applications Claiming Priority (2)

Application Number Priority Date Filing Date Title
US96569707P 2007-08-22 2007-08-22
US60/965,697 2007-08-22

Publications (1)

Publication Number Publication Date
WO2009025832A1 true WO2009025832A1 (fr) 2009-02-26

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Application Number Title Priority Date Filing Date
PCT/US2008/009935 WO2009025832A1 (fr) 2007-08-22 2008-08-21 Appareil de descente d'éléments tubulaires

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Cited By (7)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US8074711B2 (en) 2008-06-26 2011-12-13 Canrig Drilling Technology Ltd. Tubular handling device and methods
WO2012100019A1 (fr) * 2011-01-21 2012-07-26 2M-Tek, Inc. Dispositif et procédé pour descendre des tubulaires
WO2012076874A3 (fr) * 2010-12-06 2013-06-13 Balltec Limited Appareil pour manipuler des éléments tubulaires
WO2013186549A2 (fr) * 2012-06-11 2013-12-19 Balltec Limited Coin de retenue
US9303472B2 (en) 2008-06-26 2016-04-05 Canrig Drilling Technology Ltd. Tubular handling methods
GB2536075A (en) * 2015-02-13 2016-09-07 First Subsea Ltd Mounting device for an elongate flexible member
WO2019027647A1 (fr) * 2017-08-03 2019-02-07 Forum Us, Inc. Système d'élévateur et procédé à bras d'élévateur possédant des lignes de commande intégrées

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Publication number Priority date Publication date Assignee Title
GB2155577A (en) * 1984-03-13 1985-09-25 Owen Walmsley Pipe clamps/connectors
US6581698B1 (en) * 1998-08-19 2003-06-24 Bentec Gmbh Drilling & Oilfield Systems Drilling device and method for drilling a well
US20050000684A1 (en) * 2000-03-22 2005-01-06 Slack Maurice William Apparatus for handling tubular goods

Patent Citations (3)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
GB2155577A (en) * 1984-03-13 1985-09-25 Owen Walmsley Pipe clamps/connectors
US6581698B1 (en) * 1998-08-19 2003-06-24 Bentec Gmbh Drilling & Oilfield Systems Drilling device and method for drilling a well
US20050000684A1 (en) * 2000-03-22 2005-01-06 Slack Maurice William Apparatus for handling tubular goods

Cited By (17)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US8074711B2 (en) 2008-06-26 2011-12-13 Canrig Drilling Technology Ltd. Tubular handling device and methods
US10309167B2 (en) 2008-06-26 2019-06-04 Nabors Drilling Technologies Usa, Inc. Tubular handling device and methods
US8851164B2 (en) 2008-06-26 2014-10-07 Canrig Drilling Technology Ltd. Tubular handling device and methods
US9303472B2 (en) 2008-06-26 2016-04-05 Canrig Drilling Technology Ltd. Tubular handling methods
US9903168B2 (en) 2008-06-26 2018-02-27 First Subsea Limited Tubular handling methods
US9598918B2 (en) 2010-03-24 2017-03-21 2M-Tek, Inc. Tubular handling system
WO2012076874A3 (fr) * 2010-12-06 2013-06-13 Balltec Limited Appareil pour manipuler des éléments tubulaires
GB2500531A (en) * 2010-12-06 2013-09-25 Balltec Ltd Apparatus for handling tubular members
WO2012100019A1 (fr) * 2011-01-21 2012-07-26 2M-Tek, Inc. Dispositif et procédé pour descendre des tubulaires
US9273523B2 (en) 2011-01-21 2016-03-01 2M-Tek, Inc. Tubular running device and method
WO2013186549A2 (fr) * 2012-06-11 2013-12-19 Balltec Limited Coin de retenue
US9322229B2 (en) 2012-06-11 2016-04-26 Balltec Limited Slip
WO2013186549A3 (fr) * 2012-06-11 2014-08-07 Balltec Limited Coin de retenue
GB2536075A (en) * 2015-02-13 2016-09-07 First Subsea Ltd Mounting device for an elongate flexible member
GB2536075B (en) * 2015-02-13 2017-09-27 First Subsea Ltd Mounting device for an elongate flexible member
WO2019027647A1 (fr) * 2017-08-03 2019-02-07 Forum Us, Inc. Système d'élévateur et procédé à bras d'élévateur possédant des lignes de commande intégrées
US10479644B2 (en) 2017-08-03 2019-11-19 Forum Us, Inc. Elevator system and method with elevator link having integrated control lines

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