CN116096980A

CN116096980A - Dual telemetry system with coiled tubing enabled

Info

Publication number: CN116096980A
Application number: CN202180056688.3A
Authority: CN
Inventors: 西尔维乌·利维斯库; B·J·林赛; B·布隆奎斯特
Original assignee: Baker Hughes Holdings LLC
Current assignee: Baker Hughes Holdings LLC
Priority date: 2020-08-27
Filing date: 2021-08-23
Publication date: 2023-05-09
Also published as: EP4204665A1; WO2022046573A1; EP4204665A4; BR112023002901A2

Abstract

A telemetry system is provided for coiled tubing-based workstring and includes electrical transmission of power and data between sensors and a controller in a bottom hole assembly. One or more optical fibers are used to provide distributed temperature or acoustic sensing along the length of the workstring.

Description

Dual telemetry system with coiled tubing enabled

Background

1. Technical field

The present invention relates generally to apparatus and methods for transmitting power and data through a coiled tubing string and to systems and methods for collecting dual sources for downhole telemetry.

2. Description of related Art

Coiled tubing is commonly used as a run in string for a variety of downhole tools. Coiled tubing is known in the art and consists of a length of metal tubing that can be wound onto a coil while on the surface and unwound from the coil for injection into a wellbore.

Sometimes for transmitting power and data through coiled tubing. Telecoil is a coiled tubing that includes a tubing within a coiled tubing. A umbilical is a tube containing insulated electrical cables for providing power and/or data to or transmitting data from a Bottom Hole Assembly (BHA) to the surface. Umbilical is commercially available from manufacturers such as Canada Tech Corporation (calgari, canada).

Disclosure of Invention

The present invention provides systems and methods for transmitting power and/or signals and optical signals within a coiled tubing and along a wellbore. A coiled tubing system is described that includes a coiled tubing string defining a central flowbore along its length. The present invention provides a coiled tubing-based telemetry system comprising a hybrid cable including at least one cable and at least one optical fiber that allows bi-directional communication and bi-directional power transfer.

The system and method of the present invention may be used for communication and control of various bottom hole assemblies. The hybrid cable may provide real-time information to surface operators when interconnected with various wellbore sensors. In the described embodiments, the cable transmits signals to the surface in real time and provides power to downhole sensors and/or tools. In accordance with the described embodiments, the system and method of the present invention provide dual wellbore telemetry to the surface in real time during downhole operations. The first set of telemetry is provided via sensors within the bottom hole assembly. The sensor is preferably a single-point sensor. The second set of telemetry is provided via fiber optic sensing technology, such as Distributed Temperature Sensing (DTS).

In the described embodiments, connectors are used to interconnect coiled tubing and cables with the bottom hole assembly. An exemplary connector is described that includes a housing having a threaded connection at each axial end. The connector includes a terminal for trimming the fiber over the bottom hole assembly while the cable passes through the connector to the bottom hole assembly below it.

In the described embodiments, the telemetry system includes a bus system that allows the bottom hole assembly to be made up of a plurality of interchangeable modules. The bus system allows power and data to be transferred between modules of the bottom hole assembly. This feature allows custom construction of the bottom hole assembly with the desired combination of sensors and/or tools.

Drawings

For a thorough understanding of the present invention, reference is made to the following detailed description of the preferred embodiments, taken in conjunction with the accompanying drawings, in which like reference numerals identify the same or similar elements in the several figures, and in which:

FIG. 1 is a cross-sectional side view of an exemplary wellbore incorporating a bottom hole assembly and a coiled tubing telemetry system constructed in accordance with the present invention.

Fig. 2 is an axial cross-section of an exemplary hybrid cable according to the present invention.

Fig. 3 is a cross-sectional side view of an exemplary connector according to the present invention.

Fig. 4 is a detail view showing the termination of an exemplary optical fiber within a connector.

Fig. 5 is a cross-sectional side view of an exemplary bottom hole assembly according to the present invention.

Detailed Description

The invention features a telemetry system for a wellbore work string having a run-in string and a bottom hole assembly secured to the run-in string by a connector. The telemetry system includes an optical sensing system that monitors wellbore parameters along the length of the run-in string using at least one optical fiber that extends along the flowbore of the run-in string and terminates within the connector. The telemetry system also includes an electrical telemetry system including at least one sensor located within the bottom hole assembly and an electrical conductor that transmits data from the sensor to the controller.

Fig. 1 shows an exemplary wellbore 10 that has been drilled through earth 14 from the surface 12. While the wellbore 10 is shown as being vertically oriented within the earth 14, it should be understood that the wellbore or portions thereof may be slanted or horizontal.

A coiled tubing injector (not shown) of a type known in the art is located at the surface 12 and is used to inject coiled tubing into the wellbore 10. The controller 16 is also located on the ground 12. The controller 16 is preferably a programmable device, such as a computer, capable of receiving data in the form of electrical signals from the downhole sensor device for display to a user and/or storage. In addition, the power source 18 is located at the ground 12 and may be in the form of a generator or a battery. The power source 18 should be adapted to transmit power downhole to the sensor or tool. An Optical Time Domain Reflectometer (OTDR) 20 is also located at the surface 12.

A coiled tubing-based workstring 22 is shown being injected into the wellbore 10. The work string includes a run in string 24 comprised of coiled tubing of the type known in the art and defining a central flowbore 26 along its length. In general, the work string 22 may be used to perform one or more of several types of downhole operations within the wellbore 10, as determined by the type of bottom hole assembly installed on the work string 22. A connector 28 and a Bottom Hole Assembly (BHA) 30 are located at the distal end of the run-in string 24. The bottom hole assembly 30 may be a salvaging BHA, acidizing/fracturing BHA, or cleaning BHA. Alternatively, the bottom hole assembly 30 may be any power tool, such as an electric submersible pump, a tool for opening and closing a sliding sleeve, or a drilling/milling device. The connector 28 connects the bottom hole assembly 30 to the run in string 24.

The hybrid cable 32 extends along the flowbore 26 of the run-in string 24 to the connector 28. At the surface 12, the elements of the hybrid cable 32 are operatively associated with the controller 16, the power source 18, and the OTDR 20. Fig. 2 illustrates an exemplary hybrid cable 32 that allows for bi-directional data communication and bi-directional power supply over electrical conductors. The cable 32 includes a plurality of electrical conductors or wires 34 surrounded by an insulating layer 36. A plurality of optical fibers 38 are located radially outward of the insulating layer 36. An outer metal tubing 40 surrounds the optical fiber 38. An electrical conductor or wire 34 is associated with the power source 18 at the surface 12 to provide power to one or more sensors, such as the sensor 42 or other tools of the bottom hole assembly 30. The electrical conductors or wires 34 are also interconnected with the controller 16 and may transmit data from the sensor 42 or other tool to the controller 16 such that a first operating parameter or set of parameters is provided to the controller 16. The sensor 42 is preferably a single point sensor that is capable of detecting wellbore parameters associated with the bottom hole assembly 30 and its nearby locations. These parameters may include temperature, pressure, gamma, casing collar position, azimuth, tension, compression, and torque.

The optical fiber 38 is interconnected with the OTDR 20 at the surface 12. Each optical fiber 38 will typically include a transparent central core with an outer cladding having a refractive index lower than that of the core. As is known in the art, one or more optical fibers 38 will include a plurality of bragg gratings along their length. According to a preferred embodiment, bragg gratings are formed within the core of the optical fiber 38 at intervals along the length of the optical fiber 38. The OTDR 20 is used to generate pulses of light into the optical fiber 38 and to receive backscattered light from the optical fiber 38.

During operation of the workstring 22, the optical fiber 38 provides optical telemetry to the OTDR 20 that is indicative of at least one second operating parameter within the wellbore 10. In certain embodiments, the optical fiber 38 and the OTDR 20 are configured to perform Distributed Temperature Sensing (DTS) or Distributed Acoustic Sensing (DAS) and provide telemetry to the OTDR 20. The optical fiber 38 and the OTDR 20 may provide information about the sensed temperature or acoustics along the length of the optical fiber 38.

An exemplary connector 28 is shown in fig. 3, in addition to other components of the workstring 22. In a preferred embodiment, the connector 28 includes a housing 44 having axial ends 46 and 48 that are threaded for attaching the bottom hole assembly 30 and the run-in string 24. It should be noted that while threads are shown, the connector 28 may also be a dimple or rolled connector sub-assembly. Connector 28 defines a flow aperture 50 along its length. Connector 28 also preferably includes a termination channel 52 for each optical fiber 38. Each optical fiber 38 is terminated within the connector 28 by disposing the distal end of the optical fiber 38 within a termination channel 52 that contains a gel 54 that is cured to secure the end within the channel. See fig. 4. Electrical conductors 34 and insulation 36 extend down through connector 28 to bottom hole assembly 30.

In a preferred embodiment, the bottom hole assembly 30 includes a buss system and electrical connectors that allow individual sub-components to be assembled within the bottom hole assembly in a modular fashion. The bus is preferably a multi-conductor line with ground, +24VDC and +7.5VDC and two communication lines: signal a and signal B. The communication architecture may be based on the RS-485 standard with a speed of 9600 bits/second. The sub-components may be interchanged or added to allow the bottom hole assembly 30 to be constructed with the desired combination of sensors and/or tools. Fig. 5 illustrates an exemplary bottom hole assembly 30 that is made up of a plurality of

interconnected sub-components

56, 58, 60, 62 and that may be used for performing downhole coiled tubing operations. In the illustrated embodiment, the bottom hole assembly 30 may be used to perform coiled tubing fishing operations. However, it should be understood that this is by way of example only, and that the bottom hole assembly 30 may be used to perform any and all types of coiled tubing operations. Flow through passage 64 is defined along the length of bottom hole assembly 30. The electrical conductors 34 extend along the length of the passage 64 of the bottom hole assembly 30. The sub-assembly 56 includes a fishing tool 66 of a type known in the art for removing stuck tools or objects within the wellbore 10. The sub 58 contains the sensors 42 for detecting tool and annulus pressure and temperature. The sub-assembly 60 contains sensors for detecting gamma. The electrical conductors 34 are preferably provided with detachable connection points 68 that allow the sub-components 56, 58, 60, 62 to be electrically interconnected in a reversible manner. The connection point 68 may include a USB type connector or similar connector that allows for the transfer of power and data. The electrical conductor 34 includes a modem 70 for uphole transmission of data to the controller 16. Each sensor 42 communicates with a modem 70 that packages and transmits uphole data provided from the sensor 42 to the controller 16.

Each of the sub-components 56, 58, 60, 62 includes an electronics package, generally indicated at 72, which may include sensors such as sensor 42, and other wellbore electronics such as those driving or operating valve actuators or other actuators, as well as a processor, logic controller or digitizer, and data storage device, if desired. Electronics packages for various sensor and tool functions may be implemented using printed circuit boards or other methods known in the art.

Modules in the form of additional sensors and/or tool sub-components may be added or interchanged with

sub-components

56, 58, 60, 62 as needed to provide the bottom hole assembly 30 with a desired combination of functions. For example, sub-assembly 60 may be replaced with a sub-assembly having sensors for detecting tension, compression, and torque. In this manner, the bottom hole assembly 30 may be customized to have a desired combination of sub-components with corresponding combinations of functions. When the modules are disassembled from each other, the connection points 68 are broken and these connection points are reassembled when the modules are reassembled.

In operation, the workstring 22 is injected into the wellbore 10 until the bottom hole assembly 30 is at or near a location 56 within the wellbore 10 where downhole operations are desired. Downhole operations may include fishing to remove stuck tools or objects (not shown), fracturing or acidizing, cleaning a portion of a wellbore, or other well known operations. While downhole operations are performed, the controller 16 receives data representing first downhole operating parameters (i.e., temperature, pressure, gamma) from the sensor 42 at location 56 via the electrical conductor 34. At the same time, temperature and/or acoustic data is collected from the optical fiber 38 along the length of the flowbore 26 of the workstring via the OTDR 20.

Claims

1. A workstring for downhole operations within a wellbore, the workstring comprising:

a run in string defining a flowbore;

a bottom hole assembly having at least one electrically powered sensor or tool;

a hybrid cable positioned within the flowbore, the hybrid cable comprising at least one electrical conductor and at least one optical fiber;

a connector interconnecting the bottom hole assembly with a coiled tubing run string;

wherein the electrical conductor passes through the connector and is interconnected with the electrically powered sensor or tool located within the bottom hole assembly; and is also provided with

The optical fiber is terminated within the connector.

2. The workstring of claim 1, wherein:

the at least one electrical conductor transmitting power from a surface-based power source to the power sensor or tool; and is also provided with

The at least one electrical conductor transmits data from the power sensor or tool to a surface-based controller.

3. The workstring of claim 1, wherein:

the at least one optical fiber is interconnected with the OTDR at the ground; and is also provided with

The at least one optical fiber and the OTDR are operated for distributed temperature sensing or distributed acoustic sensing.

4. The workstring of claim 1, wherein the electrical conductor comprises at least one detachable connection point located within the bottom hole assembly.

5. The workstring of claim 1, wherein:

the optical fiber is terminated within the connector by disposing a distal end of the optical fiber within a termination channel formed within the connector.

6. The workstring of claim 1, wherein:

the running pipe column is a coiled tubing running pipe column.

7. The workstring of claim 1, wherein:

the hybrid cable allows bi-directional data communication and bi-directional power supply through the electrical conductors.

8. A telemetry system for a wellbore work string having a run-in string and a bottom hole assembly secured to the run-in string by a connector, the system comprising:

an optical sensing system that monitors wellbore parameters along a length of the run-in string, the optical sensing system comprising an optical fiber that extends along a flowbore of the run-in string and terminates within the connector;

an electrical telemetry system including at least one sensor located within the bottom hole assembly and an electrical conductor that transmits data from the sensor to a controller.

9. The telemetry system of claim 8, wherein:

the electrical telemetry system includes at least one detachable connection point within the bottom hole assembly.

10. The telemetry system of claim 8, wherein the optical fiber and electrical conductor are combined within a hybrid cable disposed within the run in string.

11. The telemetry system of claim 8, wherein:

the at least one sensor of the electrical telemetry system detects one or more of a wellbore parameter selected from the group consisting of temperature, pressure, gamma, casing collar position, azimuth, tension, compression, and torque.

12. The telemetry system of claim 8, wherein:

the optical sensing system detects distributed temperature or distributed acoustic data along the flowbore.

13. The telemetry system of claim 10, wherein:

14. A telemetry system for a wellbore work string having a run-in string and a bottom hole assembly secured to the run-in string by a connector, the system comprising:

an optical sensing system that monitors wellbore parameters along a length of the run-in string, the optical sensing system comprising an optical fiber that extends along a flowbore of the run-in string and terminates within the connector; and

an electrical telemetry system including at least one sensor located within the bottom hole assembly and an electrical conductor allowing bi-directional data communication between a controller and the bottom hole assembly.

15. The telemetry system of claim 14, wherein:

16. The telemetry system of claim 14, wherein:

17. The telemetry system of claim 14, wherein:

the optical fiber and the electrical conductor are combined in a hybrid cable disposed in the run-in string.

18. The telemetry system of claim 17, wherein:

the electrical conductor is held within an insulating layer; and is also provided with

The optical fiber is located radially outward of the insulating layer.

19. The telemetry system of claim 18, wherein:

an outer metal tubing radially surrounds the electrical conductor, insulation and optical fiber.