WO2020176485A1 - Aide de raccords de tige pour aide-foreur mécanique - Google Patents

Aide de raccords de tige pour aide-foreur mécanique Download PDF

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Publication number
WO2020176485A1
WO2020176485A1 PCT/US2020/019676 US2020019676W WO2020176485A1 WO 2020176485 A1 WO2020176485 A1 WO 2020176485A1 US 2020019676 W US2020019676 W US 2020019676W WO 2020176485 A1 WO2020176485 A1 WO 2020176485A1
Authority
WO
WIPO (PCT)
Prior art keywords
tubulars
relative
height
height indicator
tool joint
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.)
Ceased
Application number
PCT/US2020/019676
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English (en)
Inventor
Lars Smeland
Current Assignee (The listed assignees may be inaccurate. Google has not performed a legal analysis and makes no representation or warranty as to the accuracy of the list.)
Cameron Technologies Ltd
Cameron International Corp
Original Assignee
Cameron Technologies Ltd
Cameron International Corp
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 Cameron Technologies Ltd, Cameron International Corp filed Critical Cameron Technologies Ltd
Publication of WO2020176485A1 publication Critical patent/WO2020176485A1/fr
Anticipated expiration legal-status Critical
Ceased legal-status Critical Current

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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
    • E21B19/16—Connecting or disconnecting pipe couplings or joints
    • E21B19/165—Control or monitoring arrangements therefor

Definitions

  • the present disclosure relates to pipe handling and drilling operations via onshore and offshore drilling rigs, for drilling wells for the exploration and production of hydrocarbons.
  • the invention relates to systems and methods for determining the position of an iron roughneck relative to a tool joint on a drillpipe connection, to make sure the automated iron roughneck gets a correctly positioned grip on the drillpipe when making/breaking a tubular connection.
  • drill string is run into a well bore and is made up of a series of connected drill pipes. As the drill string is tripped into the wellbore, additional pipes are added to the top of the drill string to lengthen the string. The drill string is lowered in the wellbore until only an uppermost portion of the drill string sticks up above the drill floor. The distance the upper end of the drill string extends above the drill floor is called the“stick-up height.” When the drill string is positioned at an appropriate“stick-up height” for making up a new section of drill pipe to the drill string, pipe handling equipment position the new section of drill pipe in axial alignment with the drill string immediately above the string.
  • the new section of drill pipe is lowered until the pin end of the new section stings into the box end of the drill string.
  • the new section of drill pipe is then rotated relative to the drill string so as to engage the threads of the pin and box ends to form a pipe joint.
  • An iron roughneck is then positioned at the pipe joint to apply sufficient torque to make up the joint.
  • the threads are engaged by a low-torque pipe spinner and the joint is made up by mechanical tongs of an iron roughneck, which apply high -torque to the joint to ensure a complete and durable connection where the shoulders of the box and pin fully engage.
  • the“stick-up height” varies each time a new pipe joint is to be made up in the drill string.
  • Variable“stick-up height” presents a problem as the low-torque pipe spinner and the iron rough neck must be properly positioned relative to the joint.
  • the low-torque pipe spinner must be positioned to engage the new pipe section, and the iron roughneck must be positioned so that its upper jaws engage the pin end of the new pipe section and its lower jaws engage the box end of the uppermost section of the drill string.
  • U.S. 9,464,492 discloses a system for determining the position of a downhole drill pipe relative to a pipe handling device.
  • the system comprises: an imaging means arranged to capture an image of the drill pipe in a region of the pipe for engagement by the device; and a processor operable to analyze said captured image and to determine therefrom the position of the drill pipe relative to said device.
  • a processor is operable to analyze captured images and to provide control signals to a control means of the position of the wrench.
  • U.S. 9,657,539 discloses an automated roughneck including a backup tong and a makeup tong.
  • the makeup tong and backup tong may be selectively movable relative to one another.
  • the makeup tong and backup tong may include spinner and gripper assemblies respectively adapted to make up and break out threaded connections.
  • a positioning sensor may be positioned on an upper surface of makeup tong, wherein the positioning sensor may scan drill string to detect tool joint as makeup tong and backup tong are moved vertically.
  • the positioning sensor may instead be located at any other location on automated roughneck or any other surrounding structure.
  • the positioning sensor may be any sensor capable of detecting the location of tool joint in order to position makeup tong and backup tong.
  • the positioning sensor may be, for example, an optical sensor such as a camera, infrared range finder, or sound based sensor such as an ultrasonic sensor. Multiple positioning sensors may be utilized.
  • WO 2016/106294 discloses a system and method for positioning oilfield tubulars on a drilling floor (2), having an automated tubular handling system, to permit alignment and automated make up and break out of threading operations between a stationary tubular and a moving tubular, utilizing image information from radially offset cameras, processing the image information to recognize the tubulars within the image and develop position information for said tubulars, combining the position information from the two camera systems to develop three dimensional information for each of the tubulars, developing instructions for the automated tubular handling system to bring the stationary and moving tubulars into vertical alignment and lowering the moving tubular into threaded contact, and engaging an automated hydraulic torque wrench to make up the threaded connection.
  • a tool joint assist system for making and breaking pipe joints of tubulars in a drill string relative to a drilling rig
  • the tool joint assist system comprising: a height indicator that is observable by an operator relative to the tubulars; a height adjustment input device operable by the operator; a mover of the height indicator; and a computer comprising a processor, a non-transitory storage medium, a transmitter/receiver, and a set of computer readable instructions stored in the non-transitory storage medium and when executed by the processor: (i) receive an input from the height adjustment input device to move the vertical position of the height indicator relative to the tubulars; (ii) and transmit a command to the mover of the height indicator to move the height indicator to the instructed vertical position.
  • a further aspect of the invention provides a tool joint assist method for making and breaking pipe joints of tubulars in a drill string relative to a drilling rig, the tool joint assist method comprising: displaying to an operator a height indicator relative to the tubulars; receiving an input of the operator to move the height indicator relative to the tubulars; and moving the height indicator relative to the tubulars in response to the input of the operator.
  • a tool joint assist system for joining tubulars in a drill string relative to a drilling rig
  • the tool joint assist system comprising: a pipe handling device; a roughneck with upper and lower tongs; a height indicator that is observable by an operator relative to the tubulars; a height adjustment input device operable by the operator; a mover of the height indicator; and a computer comprising a processor, a non- transitory storage medium, a transmitter/receiver, and a set of computer readable instructions stored in the non-transitory storage medium and when executed by the processor: (i) receive an input from the height adjustment input device to move the vertical position of the height indicator relative to the tubulars; (ii) transmit a command to the mover of the height indicator to move the height indicator to the instructed vertical position; and (iii) transmit a command to move the roughneck to a vertical position relative to the tubulars corresponding to the instructed vertical position.
  • FIG. 1 is a perspective view of a line-laser in a line-laser housing for shining a laser beam on the tubulars of a drill string.
  • FIG. 2 is a perspective view of tubulars of a drill string at a well center of a drill rig, wherein a laser beam is shining on the elevator upset of a tubular.
  • FIG. 3 is a perspective view of an iron roughneck positioned on a drill rig floor relative to a drill string at the well center, wherein a laser beam is shining on the elevator upset of a tubular.
  • FIG. 4 is a perspective view of a line-laser in a line-laser housing shining a laser beam on the tubulars of a drill string at the well center of a drill rig floor, and an iron roughneck is also shown.
  • FIG. 5 is a flow chart of an algorithm for making and breaking pipe joints of tubulars in a drill string relative to a drilling rig.
  • FIGS. 1-5 Preferred embodiments are best understood by reference to FIGS. 1-5 below in view of the following general discussion.
  • the present disclosure may be more easily understood in the context of a high level description of certain embodiments.
  • FIG. 1 illustrates an embodiment of the invention comprising a tool joint laser (TJL).
  • a line-laser 110 is positioned within a line-laser housing 111.
  • the purpose of the TJL is to indicate the height from the drillfloor to the elevator-upset in the tool string.
  • the TJL uses this information to correct the height of the automated iron roughneck, to make sure the automated iron roughneck correctly grips the drilling tubulars.
  • the TJL system has a line-laser 110 with an optical lens that is located on drillfloor, wherein the laser is mounted inside a protecting casing or line-laser housing 111.
  • the optical lens of the line-laser 110 points out of the line- laser housing 111.
  • FIG. 2 shows a flat laser beam points at the drillpipe that is in the well-center.
  • the laser beam can be moved vertically by an electrical actuator mounted inside the line-laser housing 111. (See FIG. 1).
  • Line-laser 110 can be moved by an electrical actuator up/down (vertically) within a vertical position range 112.
  • the position sensor measures the height on the line-laser 110 relative to the line-laser housing.
  • the distance 113 is between a fixed position at the drillfloor to the lowest position of the line-laser 110. As shown in FIG. 2, the distance 116 is from the elevator upset to the top of the tool joint box.
  • the driller may insert the distance of the elevator-upset at the tool -joint to the top of the tool joint box.
  • Drillpipe Stickup height 118 Fixed position from drill floor to the lowest position of the line-laser 113 + Distance up to elevator upset within range vertical position 112 + Distance from elevator-upset to top of tool joint box 116. (See FIGS. 5 and 6).
  • the TJL system may comprise components and functions.
  • Line laser 110 may have a replaceable lens to make sure that the laser-line is not more than 36" at well-center.
  • the type of lens may be selected according to the distance between the laser and the well-center.
  • Electrical actuators may adjust the vertical position of the laser.
  • a position sensor may measure the vertical position, and send the position to the drilling control system.
  • a casing or line-laser housing 111 may be provided where the laser, actuator and the position sensor are mounted therein.
  • the casing may have an adjustable cover that will prevent mud and dust to enter the casing.
  • the drilling control system for the iron roughneck may be updated to receive the vertical position from the laser.
  • the drilling control system for the iron roughneck may also control when the laser will be turned on or off.
  • a new function icon or button for selecting a TJL Mode from the operator's panels or screens may be provided.
  • a selection switch or input box (HMI) on the drilling control system for the iron roughneck to set the distance from elevator-upset to top of tool joint box may also be provided.
  • the control of the TJL height may be controlled by the joystick movement at the driller’s chair. This joystick normally controls the iron roughneck up and down. But when the TJL system is activated, the drillpipe stickup height may be sent to the iron roughneck control system, and the iron roughneck will then follow the height on the TJL. To make sure that the upper and lower clamp on the iron roughneck are clamping correctly on the drillpipe, the TJL ensures that the centerline 119 between the upper and lower clamps is at the same height as the split 120 between the two drill-pipes. (See FIG. 3).
  • the TJL line-laser may include a safety feature wherein it will only be activated when the iron roughneck is turned on. This safety feature ensures that there are no people on the drillfloor that can be hit by the line-laser beam. (See FIG. 4).
  • the TJL system may assist in stand building operations at the well center and the mousehole.
  • the pipe handling machine may lower the drillipe until the line-laser is at the elevator-upset and then set the slips.
  • the vertical position may then be verified by the driller and the TJL position can be adjusted, if necessary.
  • the pipe handling machine or top-drive may lower the upper joint into the lower joint.
  • the driller may activate the auto make-up sequence for the iron roughneck.
  • the height on the TJL may be set to a correct height that fits the length of drillpipe in the mouse hole.
  • the vertical position may be verified by the driller and the TJL position may be adjusted if necessary.
  • the pipe handling machine or top-drive lowers the upper joint into the lower joint and the driller activates the auto make-up sequence for the iron roughneck.
  • the TJL system may increase the stand building speed by providing a reference point on the pipe to which the iron roughneck may go directly.
  • the TJL system may be set to an acceptable height and the top-drive may lower the drillpipe until the line-laser is at the elevator-upset and then set the slips.
  • the pipe handling machine may then lower the upper stand into the lower joint. And then activate the auto make up sequence for the iron roughneck.
  • the TJL system may be set to an acceptable height and the top-drive may pull out the drill-string until the line-laser is at the elevator-upset and then set the slips. The driller may then activate the auto make-up sequence for the iron roughneck. This may save time because the iron roughneck will go directly to the correct position on the drill string.
  • the Tool Joint Laser system may provide several advantages and savings.
  • the TJL may increase safety by avoiding a need for people to be on the drill floor to verifying the tool -joint height.
  • the trip in/out speed may increase because the driller will have a reference point to use for setting the height on the stand before he closes the power slips.
  • the drill pipe stick-up height may always be set and verified before the iron roughneck starts the auto sequence.
  • the position from the TJL system may be used for the vertical pipe handling system, to increase the speed on tripping in Auto-mode, because it will get the correct drill pipe stick- up height.
  • the TJL may be used even if the drill-pipes are full of mud.
  • the drill pipe stick-up height may be verified by the driller so as to avoid gripping on a wrong location on the drill pipe.
  • FIG. 5 illustrates a flow chart for a process algorithm for an embodiment of the invention.
  • the process begins with the pipe handling machine positioning 168 drill string tubulars for make-up or brake-out relative to a drill string.
  • the driller turns on the tool joint laser and observes 170 the line-laser beam shining on the drill string tubular.
  • the driller determines 172 whether the line-laser beam is shining on the elevator upset. If not, the driller raises or lowers 178 the line-laser until the line-laser beam is shining on the elevator upset. If the he line-laser beam is shining on the elevator upset, then the TJL calculates 174 the drill pipe stickup height based on the vertical position of the line-laser.
  • the driller then commands 176 the auto sequence for the iron roughneck to perform an operation on the drill string tubulars at the stickup height. If the operator must adjust the vertical position will the Iron-Roughneck in auto-mode, automatically adjust the vertical position on the Iron-Roughneck as it moves forward to well-center. That means that there might be a time saving for tripping, since the Iron-Roughneck will always have the correct vertical position when it reaches the well-center.
  • Tool joint assist systems and methods of the present invention have many industrial applications including but not limited to drilling well bores for the oil and gas industry.

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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 système d'aide de raccords de tige pour fabriquer et séparer des raccords de tige d'éléments tubulaires dans un train de tiges de forage par rapport à un appareil de forage sur terre ou en mer, le système d'aide de raccords de tige comprenant un indicateur de hauteur qui est observable par un opérateur par rapport aux éléments tubulaires ; un dispositif d'entrée de réglage de hauteur actionnable par l'opérateur ; un dispositif de déplacement de l'indicateur de hauteur ; et un ordinateur comprenant un processeur, un support d'informations non transitoire, un émetteur/récepteur, et un ensemble d'instructions lisibles par ordinateur mémorisées dans le support d'informations non transitoire et qui, lorsqu'elles sont exécutées par le processeur : (I) reçoivent une entrée provenant du dispositif d'entrée de réglage de hauteur pour déplacer la position verticale de l'indicateur de hauteur par rapport aux éléments tubulaires ; (ii) et émettent une instruction à destination du dispositif de déplacement de l'indicateur de hauteur en vue de déplacer l'indicateur de hauteur vers la position verticale faisant l'objet de l'instruction.
PCT/US2020/019676 2019-02-26 2020-02-25 Aide de raccords de tige pour aide-foreur mécanique Ceased WO2020176485A1 (fr)

Applications Claiming Priority (2)

Application Number Priority Date Filing Date Title
US201962810874P 2019-02-26 2019-02-26
US62/810,874 2019-02-26

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WO2020176485A1 true WO2020176485A1 (fr) 2020-09-03

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Cited By (1)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
CN112709541A (zh) * 2020-12-24 2021-04-27 四川宏华石油设备有限公司 铁钻工升降机构

Citations (5)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US20050050726A1 (en) * 2002-07-17 2005-03-10 Anderson Mark Wilson Joining expandable tubulars
US20080282847A1 (en) * 2005-11-25 2008-11-20 Helge-Ruben Halse Method and Device for Positioning a Power Tong at a Pipe Joint
US20130275100A1 (en) * 2012-04-16 2013-10-17 Canrig Drilling Technology Ltd. Wellsite control employing three-dimensional imaging
US20170306710A1 (en) * 2014-11-14 2017-10-26 National Oilwell Varco Norway As A method for placing and removing pipe from a finger rack
WO2019013644A1 (fr) * 2017-07-13 2019-01-17 Pipe Pilot As Procédé, appareil et système d'alignement coaxial de tuyaux

Patent Citations (5)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US20050050726A1 (en) * 2002-07-17 2005-03-10 Anderson Mark Wilson Joining expandable tubulars
US20080282847A1 (en) * 2005-11-25 2008-11-20 Helge-Ruben Halse Method and Device for Positioning a Power Tong at a Pipe Joint
US20130275100A1 (en) * 2012-04-16 2013-10-17 Canrig Drilling Technology Ltd. Wellsite control employing three-dimensional imaging
US20170306710A1 (en) * 2014-11-14 2017-10-26 National Oilwell Varco Norway As A method for placing and removing pipe from a finger rack
WO2019013644A1 (fr) * 2017-07-13 2019-01-17 Pipe Pilot As Procédé, appareil et système d'alignement coaxial de tuyaux

Cited By (1)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
CN112709541A (zh) * 2020-12-24 2021-04-27 四川宏华石油设备有限公司 铁钻工升降机构

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