WO2007026111A1 - Method and apparatus for measuring velocity of tubulars - Google Patents

Method and apparatus for measuring velocity of tubulars Download PDF

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Publication number
WO2007026111A1
WO2007026111A1 PCT/GB2006/002906 GB2006002906W WO2007026111A1 WO 2007026111 A1 WO2007026111 A1 WO 2007026111A1 GB 2006002906 W GB2006002906 W GB 2006002906W WO 2007026111 A1 WO2007026111 A1 WO 2007026111A1
Authority
WO
WIPO (PCT)
Prior art keywords
housing
tubular
electromagnetic radiation
velocity
wellbore
Prior art date
Application number
PCT/GB2006/002906
Other languages
French (fr)
Inventor
John William Foubister
Original Assignee
Psl Energy Services Limited
Priority date (The priority date is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the date listed.)
Filing date
Publication date
Application filed by Psl Energy Services Limited filed Critical Psl Energy Services Limited
Publication of WO2007026111A1 publication Critical patent/WO2007026111A1/en

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Classifications

    • G—PHYSICS
    • G01—MEASURING; TESTING
    • G01P—MEASURING LINEAR OR ANGULAR SPEED, ACCELERATION, DECELERATION, OR SHOCK; INDICATING PRESENCE, ABSENCE, OR DIRECTION, OF MOVEMENT
    • G01P3/00—Measuring linear or angular speed; Measuring differences of linear or angular speeds
    • G01P3/36—Devices characterised by the use of optical means, e.g. using infrared, visible, or ultraviolet light
    • G01P3/366—Devices characterised by the use of optical means, e.g. using infrared, visible, or ultraviolet light by using diffraction of light
    • 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
    • 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
    • E21B45/00—Measuring the drilling time or rate of penetration
    • 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
    • E21B47/00—Survey of boreholes or wells
    • G—PHYSICS
    • G01—MEASURING; TESTING
    • G01S—RADIO DIRECTION-FINDING; RADIO NAVIGATION; DETERMINING DISTANCE OR VELOCITY BY USE OF RADIO WAVES; LOCATING OR PRESENCE-DETECTING BY USE OF THE REFLECTION OR RERADIATION OF RADIO WAVES; ANALOGOUS ARRANGEMENTS USING OTHER WAVES
    • G01S17/00—Systems using the reflection or reradiation of electromagnetic waves other than radio waves, e.g. lidar systems
    • G01S17/88—Lidar systems specially adapted for specific applications

Definitions

  • This invention relates to a method and apparatus for measuring the velocity and calculating the length of tubulars deployed in wells in the oil and gas industry.
  • the method and apparatus enable calculation of the length of tubulars such as workstrings deployed during well intervention, well servicing and drilling of wellbores.
  • Oil and gas drilling and production operations involve the deployment of workstrings down a wellbore for a variety of purposes.
  • Workstrings and tubulars can be used in the wellbore to transport fluids downhole, including drilling mud, treatment fluids, pressurized water, and to recover hydrocarbons.
  • Workstrings are frequently also used to deploy downhole apparatus such as drill bits within the well.
  • Conventional workstrings traditionally comprise drillpipe strings, comprising a plurality of conjoined rigid straight steel tubing segments that are connected at the rig floor as the string is lowered down the wellbore.
  • Coiled tubing is becoming an increasingly common replacement for drillpipe strings.
  • Coiled tubing workstrings typically comprises a single continuous length of tubing that is spooled off one or more drums or spools for injection into the wellbore.
  • a method for measuring the velocity of tubulars deployed in or retrieved from a wellbore comprising the steps of; deploying or retrieving the tubular into or from the wellbore; emitting electromagnetic radiation from an electromagnetic source in the direction of the tubular; arranging a receiver to receive electromagnetic radiation reflected from the tubular; and determining the velocity of tubular deployed in or retrieved from the wellbore using the reflected electromagnetic radiation data.
  • the method can include measuring the change in wavelength of the reflected electromagnetic radiation to ascertain the velocity of the tubular.
  • the length of the tubular deployed in or retrieved from the wellbore can be calculated from the velocity measurement.
  • the method can also include coupling the receiver to a processing means to enable real time measurements of the velocity and length of the tubular to be obtained.
  • the receiver can receive the reflected electromagnetic radiation information and convert the information into electrical signals.
  • the electrical signals can be processed by the processing means to allow determination of the velocity of the tubular.
  • the method can include integrating the velocity once with respect to time using the processing means to obtain the length of the tubular.
  • the method can include directing laser light towards the tubular.
  • the method can further include housing the electromagnetic source to substantially contain electromagnetic radiation within the housing.
  • the housing can be an explosion proof housing.
  • the housing can be made form stainless steel, aluminium or plastic.
  • the method can include deploying or retrieving the tubular through the housing.
  • the method can further include sealing the housing in the region of the openings where the tubular passes through the housing, in such a way that the electromagnetic radiation is contained within the housing.
  • the seals can be silicone gaskets.
  • the method can include purging the housing with inert gas.
  • the method can further include raising the pressure within the housing relative to ambient pressure.
  • the method can include automatically preventing the electromagnetic source from emitting electromagnetic radiation in the event that the housing is not sealed.
  • a sensor means can be provided to detect any gap or unsealed opening in the housing and can automatically prevent any electromagnetic radiation from being emitted.
  • the housing is typically sufficient to contain the electromagnetic emissions in such a way that the laser is designated Class IA.
  • the method may include suspending and/or supporting the housing using energy absorbing means such that movement and/or vibration of components indirectly coupled thereto is substantially absorbed by the energy absorbing means and the housing remains substantially stationary.
  • the energy absorbing means can be a spring means and a damper means.
  • the spring means can include one or more coil springs and the damper can be a hydraulic twin-tube design.
  • apparatus for measuring the velocity of tubulars being deployed in a wellbore comprising an electromagnetic radiation source capable of directing electromagnetic radiation towards the tubular member and a receiver arranged to receive electromagnetic radiation reflected from the tubular, enabling determination of the velocity of the tubular.
  • the apparatus can also determine the length of the tubular.
  • the receiver can convert data regarding the reflected electromagnetic radiation into electric signals.
  • the receiver can be integral with the electromagnetic radiation source.
  • a processing means can be coupled to the receiver.
  • the processing means can calculate the velocity of the moving tubular using the principle of the Doppler effect.
  • the reflected electromagnetic radiation contains information on the change in wavelength which is a function of the tubulars' relative velocity.
  • the velocity can be integrated with respect to time to obtain the length of the tubular.
  • a visual display can be provided for reading of the velocity and/or length data.
  • the electromagnetic radiation source can emit laser light.
  • a suitable electromagnetic source is a laser speed gauge such as the BETA LaserMike LS4000 series of gauges.
  • a housing can be provided to house the electromagnetic source and contain the electromagnetic radiation.
  • the housing can be explosion proof.
  • the housing can be arranged such that the tubular passes through the housing.
  • the housing can contain a passageway extending therethrough which passageway can accommodate a tubular.
  • Seal means can be provided at the openings of the passageway such that substantially all electromagnetic radiation is contained within the housing.
  • the seal means can be silicone gaskets.
  • the housing can be provided with an automatic switching system so that when the housing is opened and is not a sealed unit, the electromagnetic source is prevented from emitting electromagnetic radiation.
  • a sensor means can be provided to detect whether the housing is sealed.
  • the sensor means can be coupled to an automatic switching means that can prevent the electromagnetic source from emitting electromagnetic radiation when the sensor means detect that the housing is not a sealed unit.
  • the apparatus can be mounted on an injector head assembly.
  • the apparatus can be supported or suspended from the injector head assembly by energy absorbing means such that the apparatus is substantially isolated from movement of the injector head.
  • the tubular can be coiled tubing.
  • Fig. 1 is a partial cut away view of an injector head; and Fig. 2 is a perspective view of an apparatus according to the invention.
  • An injector head is shown generally at 10 in Fig. 1 used to insert a coiled tubing string 12 into a well. Before deployment of the string 12, the base of the injector head 10 is secured to a wellhead (not shown). The injector head 10 incorporates profiled chain assemblies 13 to grip the coiled tubing string 12. The injector head 10 also includes a hydraulic drive system that is actuable to run and retrieve the coiled tubing string 12 from the wellbore.
  • a gooseneck 14 is mounted above the injector head 10 to feed and guide the coiled tubing string 12 from a reel (not shown) into the injector head 10.
  • Apparatus 20 is located within the injector head 10 at position P.
  • the apparatus 20 can be supported by struts (not shown) having a shock absorber mounted inside a coil spring, so that the device is isolated from vibrations applied to the injector head 10.
  • Fig. 2 shows an enlarged view of the apparatus 20.
  • the apparatus 20 has a housing comprising two portions 21 , 22.
  • the first portion 21 houses a laser measuring device 24.
  • the second portion 22 can accommodate the coiled tubing string 12 in use.
  • the housing portions 21 , 22 form a substantially rectilinear shape and are separated by a window (not shown) at their internal shared wall.
  • the portion of housing 21 that contains the laser measuring device 24 has an access hatch 30.
  • a suitable laser measuring device is similar to the Beta LaserMike LaserSpeed LS4000-1 length and speed measurement gauge, Part No 92664, the disclosure of which is incorporated herein by reference.
  • the window separating the first housing portion 21 from the second housing portion 22 allows the beam from the laser measuring device 24 to be focussed on the coiled tubing string 12.
  • the laser measuring device 24 is provided with an inbuilt receiver (not shown) that is interfaced with a computer in a manner which enables acquisition and display of data in real time.
  • the housing portion 22 comprises two hinged parts 22a, 22b that are substantially symmetrical and adapted to close around a length of tubing 12.
  • Each hinged part 22a, 22b has a mating edge which abuts the mating edge of the adjacent hinged part 22b, 22a in the closed position.
  • Two semicircular cut-outs are provided on opposing mating edges of each hinged part.
  • the axis of the passageway 27 is substantially perpendicular to the direction of the laser beam emitted by the laser measuring device 24 in use, so that the laser measuring device 24 is held generally perpendicular to the tubing 12 as it passes the device 24.
  • the passageway 27 should be of a size sufficient to accommodate different sizes of the coiled tubing string 12.
  • Each opening is provided with a loose fitting seal 28 that substantially prevents laser light from escaping from the housing portion 22 when the tubing 12 is disposed in the passageway 27.
  • Each loose fitting seal 28 can be a silicone gasket.
  • the diameter of the coiled tubing string 12 typically ranges from 0.75 inches (1.9cm) to 5 inches (12.7cm).
  • seals 28 can be provided to be removably attached to the opening of the passageway 27 to cater for the variation in the diameter of different coil tubing strings 12.
  • the seals 28 can be resilient to allow a close fit between the seals and the different sizes of tubing.
  • the coiled tubing string 12 can be made from steel having a yield strength ranging between 55,000 psi (379 MPa) and 120,000 psi (827 MPa).
  • the coiled tubing string 12 length can be approximately 30,000 ft (9.14 km).
  • the gooseneck 14 mounted on the injector head 10 guides the coiled tubing string 12 through an arc from the reel and into vertical alignment with the chains 13 of the injector-head 10 and the wellbore.
  • the radius of the guide arc is typically as large as practicable since plastic deformation created in the coiled tubing string 12 could induce material fatigue.
  • the coiled tubing string 12 is substantially straightened prior to being inserted into the wellbore.
  • the coiled tubing string 12 passes through the loose fitting seals 28 at the openings of the passageway 27.
  • the laser measuring device 24 emits laser light split into two overlapping beams of the same intensity. The beams pass through the window provided between the two housing portions 21 , 22. The area in which the beams overlap is the measurement region through which the coiled tubing string 12 passes.
  • Laser light is scattered when the coiled tubing string 12 passes through the measurement region. Velocity of the coiled tubing string 12 can be interpreted from the scattered light. The change in wavelength of the reflected radiation is a function of the coiled tubing string's 12 relative velocity through the housing.
  • the scattered laser light is collected by the receiver provided on the laser measuring device 24 and is converted to electrical signals that are fed to a computer.
  • the electrical signals contain information with regard to the velocity of the coiled tubing string 12.
  • the computer integrates the velocity once with respect to time to calculate the distance that the coiled tubing string 12 has travelled.
  • the housing portions 21 , 22 can be purged with an inert gas or mixture thereof, such as nitrogen or air.
  • the inert gas should provide a non-corrosive atmosphere within the housing portions 21 , 22.
  • the pressure within the housing portions 21 , 22 can be raised to ensure that any gas leakage is outward from the housing portions 21 , 22 to the environment surrounding the housing.
  • the struts used for mounting the apparatus optionally have coil springs which compress and expand to absorb the vibrations of the injector head 10 in which the apparatus 20 is mounted in use as well as shock absorbers of a twin-tube design.
  • the shock absorbers reduce the magnitude of the vibrations by turning the kinetic energy of the coil spring movement into heat that can be dissipated through hydraulic fluid contained within.
  • the struts provide structural support to maintain the housing in position and also provide a dampening function. Thus the accuracy of the measurements is ensured by isolating the laser measuring device 24 from vibration and harsh working conditions commonly experienced in oil and gas applications as well as reducing alignment problems.
  • the laser is typically classed as a Class INB, moderate power laser.
  • a series of sensors (not shown) within the housing 21 , 22 can detect when the housing is not sealed and automatically prevent the laser measuring device 24 from emitting laser light in this situation.
  • the design of the housing 21 , 22 effectively ensures that the apparatus 20 falls within the Class IA, not intended for viewing category.
  • the apparatus containing the laser measuring device 24 can be mounted in any location and is not limited to attachment to an injector head 10.
  • the tubular can be any type of downhole tubular used in the oil and gas industry since the method of the invention relies on a reflected beam and is thus not limited to coiled tubing string 12.

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Abstract

The invention provides an apparatus (20) and a method for measuring the velocity of tubulars (12) deployed in or retrieved from a wellbore. The method comprises the steps of: deploying or retrieving the tubular (12) into or from the wellbore; emitting electromagnetic radiation from an electromagnetic source (24) in the direction of the tubular (12); arranging a receiver to receive electromagnetic radiation reflected from the tubular (12); and determining the velocity of tubular (12) deployed in or retrieved from the wellbore using the reflected electromagnetic radiation data. Preferably, the electromagnetic radiation directed towards the tubular (12) is laser light. The method can include measuring the change in wavelength of the reflected electromagnetic radiation to ascertain the velocity of the tubular (12). The method can also include calculating the length of the tubular (12) using the velocity measurement. The method can further include housing the electromagnetic source to substantially contain the electromagnetic radiation within a housing (21, 22) and deploying or retrieving the tubular (12) through the housing (21, 22).

Description

METHOD AND APPARATUS FOR MEASURING VELOCITY OF TUBULARS
This invention relates to a method and apparatus for measuring the velocity and calculating the length of tubulars deployed in wells in the oil and gas industry. In particular, the method and apparatus enable calculation of the length of tubulars such as workstrings deployed during well intervention, well servicing and drilling of wellbores.
Oil and gas drilling and production operations involve the deployment of workstrings down a wellbore for a variety of purposes. Workstrings and tubulars can be used in the wellbore to transport fluids downhole, including drilling mud, treatment fluids, pressurized water, and to recover hydrocarbons. Workstrings are frequently also used to deploy downhole apparatus such as drill bits within the well. Conventional workstrings traditionally comprise drillpipe strings, comprising a plurality of conjoined rigid straight steel tubing segments that are connected at the rig floor as the string is lowered down the wellbore. Coiled tubing is becoming an increasingly common replacement for drillpipe strings. Coiled tubing workstrings typically comprises a single continuous length of tubing that is spooled off one or more drums or spools for injection into the wellbore.
It is often a requirement that the position of a tubing that has been deployed in the wellbore is accurately known; for example, an operator might wish to know the precise position of a drill bit or under-reamer deployed on the end of a length of coiled tubing. Current systems employed to measure the depth and length of tubing deployed in the wellbore include contact tachometers counting the number of revolutions of a wheel that is held in contact with the string as it is paid out. The speed of the wheel is used for velocity measurement and the number of revolutions are used to determine length or distance run. There are problems associated with this method since slippage can occur between the wheel and the string. Assembly and disassembly of these systems often involve manual handling of heavy equipment. The systems are also vulnerable to external damage and dirt accumulation, which can vary the wheel diameter and render the measurement inaccurate.
According to a first aspect of the invention, there is provided a method for measuring the velocity of tubulars deployed in or retrieved from a wellbore, the method comprising the steps of; deploying or retrieving the tubular into or from the wellbore; emitting electromagnetic radiation from an electromagnetic source in the direction of the tubular; arranging a receiver to receive electromagnetic radiation reflected from the tubular; and determining the velocity of tubular deployed in or retrieved from the wellbore using the reflected electromagnetic radiation data.
The method can include measuring the change in wavelength of the reflected electromagnetic radiation to ascertain the velocity of the tubular. The length of the tubular deployed in or retrieved from the wellbore can be calculated from the velocity measurement.
The method can also include coupling the receiver to a processing means to enable real time measurements of the velocity and length of the tubular to be obtained. The receiver can receive the reflected electromagnetic radiation information and convert the information into electrical signals. The electrical signals can be processed by the processing means to allow determination of the velocity of the tubular. The method can include integrating the velocity once with respect to time using the processing means to obtain the length of the tubular. Thus, the invention provides a non-contact method of measuring the velocity and calculating the length of the tubular deployed into and retrieved out of the wellbore.
The method can include directing laser light towards the tubular.
The method can further include housing the electromagnetic source to substantially contain electromagnetic radiation within the housing. The housing can be an explosion proof housing. The housing can be made form stainless steel, aluminium or plastic. The method can include deploying or retrieving the tubular through the housing. The method can further include sealing the housing in the region of the openings where the tubular passes through the housing, in such a way that the electromagnetic radiation is contained within the housing. The seals can be silicone gaskets.
The method can include purging the housing with inert gas. The method can further include raising the pressure within the housing relative to ambient pressure.
The method can include automatically preventing the electromagnetic source from emitting electromagnetic radiation in the event that the housing is not sealed. A sensor means can be provided to detect any gap or unsealed opening in the housing and can automatically prevent any electromagnetic radiation from being emitted. The housing is typically sufficient to contain the electromagnetic emissions in such a way that the laser is designated Class IA. The method may include suspending and/or supporting the housing using energy absorbing means such that movement and/or vibration of components indirectly coupled thereto is substantially absorbed by the energy absorbing means and the housing remains substantially stationary. The energy absorbing means can be a spring means and a damper means. The spring means can include one or more coil springs and the damper can be a hydraulic twin-tube design.
According to a second aspect of the invention there is provided apparatus for measuring the velocity of tubulars being deployed in a wellbore, the apparatus comprising an electromagnetic radiation source capable of directing electromagnetic radiation towards the tubular member and a receiver arranged to receive electromagnetic radiation reflected from the tubular, enabling determination of the velocity of the tubular.
The apparatus can also determine the length of the tubular.
The receiver can convert data regarding the reflected electromagnetic radiation into electric signals. The receiver can be integral with the electromagnetic radiation source.
A processing means can be coupled to the receiver. The processing means can calculate the velocity of the moving tubular using the principle of the Doppler effect. Preferably the reflected electromagnetic radiation contains information on the change in wavelength which is a function of the tubulars' relative velocity. The velocity can be integrated with respect to time to obtain the length of the tubular. A visual display can be provided for reading of the velocity and/or length data. The electromagnetic radiation source can emit laser light. A suitable electromagnetic source is a laser speed gauge such as the BETA LaserMike LS4000 series of gauges.
A housing can be provided to house the electromagnetic source and contain the electromagnetic radiation. The housing can be explosion proof. The housing can be arranged such that the tubular passes through the housing. The housing can contain a passageway extending therethrough which passageway can accommodate a tubular.
Seal means can be provided at the openings of the passageway such that substantially all electromagnetic radiation is contained within the housing. The seal means can be silicone gaskets.
The housing can be provided with an automatic switching system so that when the housing is opened and is not a sealed unit, the electromagnetic source is prevented from emitting electromagnetic radiation. A sensor means can be provided to detect whether the housing is sealed. The sensor means can be coupled to an automatic switching means that can prevent the electromagnetic source from emitting electromagnetic radiation when the sensor means detect that the housing is not a sealed unit.
The apparatus can be mounted on an injector head assembly. The apparatus can be supported or suspended from the injector head assembly by energy absorbing means such that the apparatus is substantially isolated from movement of the injector head. The tubular can be coiled tubing. One embodiment of the present embodiment will now be described with reference to the accompanying drawings in which:-
Fig. 1 is a partial cut away view of an injector head; and Fig. 2 is a perspective view of an apparatus according to the invention.
An injector head is shown generally at 10 in Fig. 1 used to insert a coiled tubing string 12 into a well. Before deployment of the string 12, the base of the injector head 10 is secured to a wellhead (not shown). The injector head 10 incorporates profiled chain assemblies 13 to grip the coiled tubing string 12. The injector head 10 also includes a hydraulic drive system that is actuable to run and retrieve the coiled tubing string 12 from the wellbore.
A gooseneck 14 is mounted above the injector head 10 to feed and guide the coiled tubing string 12 from a reel (not shown) into the injector head 10.
Apparatus 20 according to the invention is located within the injector head 10 at position P. The apparatus 20 can be supported by struts (not shown) having a shock absorber mounted inside a coil spring, so that the device is isolated from vibrations applied to the injector head 10.
Fig. 2 shows an enlarged view of the apparatus 20. The apparatus 20 has a housing comprising two portions 21 , 22. The first portion 21 , houses a laser measuring device 24. The second portion 22 can accommodate the coiled tubing string 12 in use. The housing portions 21 , 22 form a substantially rectilinear shape and are separated by a window (not shown) at their internal shared wall. The portion of housing 21 that contains the laser measuring device 24 has an access hatch 30. A suitable laser measuring device is similar to the Beta LaserMike LaserSpeed LS4000-1 length and speed measurement gauge, Part No 92664, the disclosure of which is incorporated herein by reference. The window separating the first housing portion 21 from the second housing portion 22 allows the beam from the laser measuring device 24 to be focussed on the coiled tubing string 12. The laser measuring device 24 is provided with an inbuilt receiver (not shown) that is interfaced with a computer in a manner which enables acquisition and display of data in real time.
The housing portion 22 comprises two hinged parts 22a, 22b that are substantially symmetrical and adapted to close around a length of tubing 12. Each hinged part 22a, 22b has a mating edge which abuts the mating edge of the adjacent hinged part 22b, 22a in the closed position. Two semicircular cut-outs are provided on opposing mating edges of each hinged part. When the hinged parts 22a, 22b are in the closed position corresponding cut outs on each hinged part 22a, 22b form circular openings to provide a passageway 27 through which the tubing 12 can pass. The axis of the passageway 27 is substantially perpendicular to the direction of the laser beam emitted by the laser measuring device 24 in use, so that the laser measuring device 24 is held generally perpendicular to the tubing 12 as it passes the device 24. The passageway 27 should be of a size sufficient to accommodate different sizes of the coiled tubing string 12. Each opening is provided with a loose fitting seal 28 that substantially prevents laser light from escaping from the housing portion 22 when the tubing 12 is disposed in the passageway 27. Each loose fitting seal 28 can be a silicone gasket. The diameter of the coiled tubing string 12 typically ranges from 0.75 inches (1.9cm) to 5 inches (12.7cm). Thus, a number of different seals 28 can be provided to be removably attached to the opening of the passageway 27 to cater for the variation in the diameter of different coil tubing strings 12. Alternatively, or additionally, the seals 28 can be resilient to allow a close fit between the seals and the different sizes of tubing.
In the present embodiment, the coiled tubing string 12 can be made from steel having a yield strength ranging between 55,000 psi (379 MPa) and 120,000 psi (827 MPa). The coiled tubing string 12 length can be approximately 30,000 ft (9.14 km).
In operation, the gooseneck 14 mounted on the injector head 10 guides the coiled tubing string 12 through an arc from the reel and into vertical alignment with the chains 13 of the injector-head 10 and the wellbore. The radius of the guide arc is typically as large as practicable since plastic deformation created in the coiled tubing string 12 could induce material fatigue. Thus the coiled tubing string 12 is substantially straightened prior to being inserted into the wellbore.
As the injector head 10 guides the coiled tubing string 12 towards the wellbore, the coiled tubing string 12 passes through the loose fitting seals 28 at the openings of the passageway 27. The laser measuring device 24 emits laser light split into two overlapping beams of the same intensity. The beams pass through the window provided between the two housing portions 21 , 22. The area in which the beams overlap is the measurement region through which the coiled tubing string 12 passes.
Laser light is scattered when the coiled tubing string 12 passes through the measurement region. Velocity of the coiled tubing string 12 can be interpreted from the scattered light. The change in wavelength of the reflected radiation is a function of the coiled tubing string's 12 relative velocity through the housing. The scattered laser light is collected by the receiver provided on the laser measuring device 24 and is converted to electrical signals that are fed to a computer. The electrical signals contain information with regard to the velocity of the coiled tubing string 12. The computer integrates the velocity once with respect to time to calculate the distance that the coiled tubing string 12 has travelled.
As the measurements are being taken, the housing portions 21 , 22 can be purged with an inert gas or mixture thereof, such as nitrogen or air. The inert gas should provide a non-corrosive atmosphere within the housing portions 21 , 22. The pressure within the housing portions 21 , 22 can be raised to ensure that any gas leakage is outward from the housing portions 21 , 22 to the environment surrounding the housing.
The struts used for mounting the apparatus optionally have coil springs which compress and expand to absorb the vibrations of the injector head 10 in which the apparatus 20 is mounted in use as well as shock absorbers of a twin-tube design. The shock absorbers reduce the magnitude of the vibrations by turning the kinetic energy of the coil spring movement into heat that can be dissipated through hydraulic fluid contained within. The struts provide structural support to maintain the housing in position and also provide a dampening function. Thus the accuracy of the measurements is ensured by isolating the laser measuring device 24 from vibration and harsh working conditions commonly experienced in oil and gas applications as well as reducing alignment problems. The laser is typically classed as a Class INB, moderate power laser. However, a series of sensors (not shown) within the housing 21 , 22 can detect when the housing is not sealed and automatically prevent the laser measuring device 24 from emitting laser light in this situation. Thus the design of the housing 21 , 22 effectively ensures that the apparatus 20 falls within the Class IA, not intended for viewing category.
Modifications and improvements can be made without departing from the scope of the invention. For example, the apparatus containing the laser measuring device 24 can be mounted in any location and is not limited to attachment to an injector head 10. The tubular can be any type of downhole tubular used in the oil and gas industry since the method of the invention relies on a reflected beam and is thus not limited to coiled tubing string 12.

Claims

1. A method for measuring the velocity of tubulars deployed in or retrieved from a wellbore, the method comprising the steps of: deploying or retrieving the tubular into or from the wellbore; emitting electromagnetic radiation from an electromagnetic source in the direction of the tubular; arranging a receiver to receive electromagnetic radiation reflected from the tubular; and determining the velocity of tubular deployed in or retrieved from the wellbore using the reflected electromagnetic radiation data.
2. A method as claimed in claim 1 , including measuring the change in wavelength of the reflected electromagnetic radiation to ascertain the velocity of the tubular and calculating the length of the tubular using the velocity measurement.
3. A method as claimed in claim 1 or claim 2, including coupling the receiver to a processing means and obtaining real time measurements of the velocity and/or the length of the tubular.
4. A method as claimed in any preceding claim, including directing laser light towards the tubular.
5. A method as claimed in any preceding claim, including housing the electromagnetic source to substantially contain the electromagnetic radiation within the housing and deploying or retrieving the tubular through the housing.
6. A method as claimed in claim 5, including sealing the housing in the region where the tubular passes through the housing and purging the housing with inert gas.
7. A method as claimed in claim 5 or claim 6, including maintaining a higher pressure within the housing relative to an ambient pressure.
8. A method as claimed in any of claims 5 to 7, including providing sensors within the housing and automatically preventing the electromagnetic source from emitting electromagnetic radiation when the sensors detect that the housing is not sealed.
9. A method as claimed in any of claims 5 to 8, including mounting the housing to a structure and disposing an energy absorbing means between the mounting and the housing such that movement of the structure is substantially absorbed by the energy absorbing means and the housing is substantially isolated from the movement of the structure.
10. Apparatus for measuring the velocity of tubulars being deployed in or retrieved from a wellbore, the apparatus comprising an electromagnetic radiation source capable of directing electromagnetic radiation towards the tubular and a receiver arranged to receive electromagnetic radiation reflected from the tubular, enabling determination of the velocity of the tubular.
11. Apparatus as claimed in claim 10, wherein the receiver is coupled to a processing means for calculating the velocity of the tubular and wherein the processing means is capable of integrating the velocity of the tubular once with respect to time to obtain the length of the tubular.
12. Apparatus as claimed in claim 10 or claim 11 , wherein the electromagnetic radiation source emits laser light.
13. Apparatus as claimed in any of claims 10 to 12, comprising a housing to house the electromagnetic radiation source and contain the electromagnetic radiation.
14. Apparatus as claimed in claim 13, wherein the housing is an explosion proof housing.
15. Apparatus as claimed in claim 13 or claim 14, wherein the housing is provided with a passageway extending therethrough, which passageway can accommodate a tubular and wherein a seal means is provided at each opening of the passageway such that substantially all electromagnetic radiation is contained within the housing.
16. Apparatus as claimed in any of claims 13 to 15, wherein a sensor means is provided for detecting whether the housing is sealed and wherein the sensor means is coupled to an automatic switching means for preventing the electromagnetic source from emitting electromagnetic radiation when the sensor means detect that the housing is not sealed.
17. Apparatus as claimed in any of claims 13 to 16, wherein the apparatus further comprises a mounting means having an energy absorbing means disposed between the housing and the mounting means such that the apparatus is mountable on a structure to substantially isolate the apparatus from movement of the structure.
18. Apparatus as claimed in claim 17, wherein the energy absorbing means comprises a spring means and a damper means.
PCT/GB2006/002906 2005-08-27 2006-08-04 Method and apparatus for measuring velocity of tubulars WO2007026111A1 (en)

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GB0517531A GB0517531D0 (en) 2005-08-27 2005-08-27 Method and apparatus

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EP2356612A1 (en) * 2008-10-21 2011-08-17 National Oilwell Varco, L.P. Non-contact measurement systems for wireline and coiled tubing
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GB2485517B (en) * 2009-08-10 2013-09-18 Nat Oilwell Varco Lp Methods and apparatus for determination of parameters related to a coiled tubing string
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EP3693534A1 (en) * 2019-02-11 2020-08-12 Sandvik Mining and Construction Oy Determining a length of a drill hole drilled by a continuous rod

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