COMMUNICATING SIGNALS THROUGH A TUBING HANGER

DOCKET NO.: IS 14.9206- WO-PCT

INVENTORS: Scott Johnston

Emmanuel Balster

CROSS-REFERENCE TO RELATED APPLICATIONS

[0001] The present document is based on and claims priority to U.S. Provisional

Application Serial No.: 62/045,187 filed September 3, 2014, which is incorporated herein by reference in its entirety.

BACKGROUND

[0002] Hydrocarbon fluids such as oil and natural gas are obtained from a subterranean geologic formation, referred to as a reservoir, by drilling a well that penetrates the hydrocarbon-bearing formation. Once a wellbore is drilled, various forms of well completion components may be installed to control and enhance the efficiency of producing the various fluids from the reservoir. The well completion components may comprise a variety of sensors and other equipment for monitoring parameters related to the environment and/or production of well fluid. However, difficulties may arise in communicating signals to the surface from the downhole sensors and other equipment. For example, difficulties arise in communicating signals to the surface during a tubing hanger installation operation. SUMMARY

[0003] In general, a methodology and system are provided to facilitate transfer of signals during a tubing hanger deployment operation. A tubing hanger is provided with a coupling region for engagement with a corresponding tubing hanger running tool.

Additionally, the tubing hanger comprises a communication coupling portion which is configured for engagement with a corresponding communication portion of the tubing hanger running tool. A communication line is routed from the communication coupling portion downhole to, for example, a sensor or other device. The communication coupling portion enables communication of signals across the tubing hanger and the tubing hanger running tool.

[0004] However, many modifications are possible without materially departing from the teachings of this disclosure. Accordingly, such modifications are intended to be included within the scope of this disclosure as defined in the claims.

BRIEF DESCRIPTION OF THE DRAWINGS

[0005] Certain embodiments of the disclosure will hereafter be described with reference to the accompanying drawings, wherein like reference numerals denote like elements. It should be understood, however, that the accompanying figures illustrate the various implementations described herein and are not meant to limit the scope of various technologies described herein, and:

[0006] Figure 1 is a schematic illustration of a well system comprising a tubing and tubing hanger deployed in a wellbore via a tubing hanger running tool, according to an embodiment of the disclosure; [0007] Figure 2 is an illustration of an example of a tubing hanger coupled with a tubing hanger running tool and having a 360° communication coupling, according to an embodiment of the disclosure;

[0008] Figure 3 is an illustration of an example of a tubing hanger coupled with a tubing hanger running tool and having another type of communication coupling, according to an embodiment of the disclosure; and

[0009] Figure 4 is an illustration of an example of a tubing hanger coupled with a tubing hanger running tool and having another type of communication coupling, according to an embodiment of the disclosure; and

[0010] Figure 5 is an illustration of an example of a tubing hanger coupled with a tubing hanger running tool and having another type of communication coupling, according to an embodiment of the disclosure.

DETAILED DESCRIPTION

[0011] In the following description, numerous details are set forth to provide an understanding of some embodiments of the present disclosure. However, it will be understood by those of ordinary skill in the art that the system and/or methodology may be practiced without these details and that numerous variations or modifications from the described embodiments may be possible.

[0012] The present disclosure generally relates to a methodology and system to facilitate transfer of signals along a wellbore. In embodiments described herein, the methodology and system facilitate the transfer of signals between a tubing hanger and a tubing hanger running tool. As a result, the ability to communicate during, for example, a tubing hanger deployment operation is enhanced. [0013] According to an embodiment, a tubing hanger is provided with a coupling region for engagement with a corresponding tubing hanger running tool. Additionally, a communication coupling is provided to enable communication of signals between the tubing hanger and the tubing hanger running tool. In at least some applications, the communication coupling is a 360° communication coupling in the sense that signals may be communicated between the tubing hanger and the tubing hanger running tool regardless of the angular orientation of the tubing hanger with respect to the tubing hanger running tool. A communication line is routed from the communication coupling downhole to, for example, a sensor or other device. The communication coupling thus enables communication of signals from the downhole device/sensor to the tubing hanger and then from the tubing hanger to the tubing hanger running tool for transfer to a surface controller or other desired location. As described below, a communication line may be routed from the communication coupling uphole to the surface, however a wireless telemetry system also can be used to transfer signals between the communication coupling and the surface.

[0014] In some embodiments, the communication line is in the form of a cable running from the downhole device, e.g. downhole gauge. By way of example, the cable may be fed through the tubing hanger and connected to a 360° electrical contact. The 360° electrical contact is engaged with a matching contact on the tubing hanger running tool when the tubing hanger is engaged with the tubing hanger running tool. An upper portion of the cable is fed through the tubing hanger running tool and routed to the surface to allow data to be sent to the surface (or to be sent downhole).

[0015] Referring generally to Figure 1, an example of a well system 20 is illustrated as deployed in a wellbore 22 having a portion lined with a casing 24 or other suitable liner. The well system 20 may be used in a wide variety of wells having, for example, generally vertical wellbores 22 or wellbores 22 formed with vertical sections and deviated sections. In the embodiment illustrated, the well system 20 comprises a tubing hanger 26 coupled with a tubing 28. The tubing 28 and tubing hanger 26 may be deployed downhole into wellbore 22 via a tubing hanger running tool 30 which is conveyed downhole on a suitable conveyance 32, e.g. coiled tubing, slick line, wireline, or other suitable conveyance.

[0016] As illustrated, a communication coupling 34 is positioned to enable communication of signals between the tubing hanger 26 and the tubing hanger running tool 30 when the tubing hanger running tool 30 is engaged with the tubing hanger 26. In some applications, the communication coupling 34 is in the form of a 360° coupling which enables communication of signals between the tubing hanger 26 and the tubing hanger running tool 30 regardless of the rotational angle of the tubing hanger running tool 30 with respect to the tubing hanger 26. Depending on the application, the signals communicated across the tubing hanger 26 and tubing hanger running tool 30 via communication coupling 34 may comprise data and/or power signals. In some applications, the communication coupling 34 is constructed to convey electrical signals, although the communication coupling 34 may be constructed to convey other types of signals, e.g. optical signals, or combinations of different signal types, e.g. electrical and optical.

[0017] In some embodiments, a downhole device 36 is located in wellbore 22 beneath or downhole from tubing hanger 26. Depending on the application, the downhole device 36 may be constructed to send and/or receive signals. For example, a communication line 38 may be routed along tubing 28 and coupled between downhole device 36 and communication coupling 34. A corresponding communication line 40, e.g. a communication line routed along running tool 30 and conveyance 32, may be used to convey signals along the portion of wellbore 22 above or uphole from the tubing hanger 26. The communication lines 38, 40 form an overall communication line for

communicating signals between one or more of the downhole devices 36 and a suitable control system 42, e.g. a processor-based control system located at the surface.

[0018] The conveyance of signals via communication coupling 34 from and/or to the downhole device or devices 36 may be used in a variety of applications. For example, downhole device 36 may be in the form of a sensor gauge positioned to collect temperature data, pressure data, and/or other data which is transmitted up to the control system 42 for analysis. In many applications, the downhole device/sensor 36 may be positioned along tubing 28. However, the device/sensor 36 also may be positioned in other equipment or at other locations along wellbore 22.

[0019] Referring generally to Figure 2, an embodiment of the communication coupling 34 is illustrated as positioned to convey signals between the tubing hanger 26 and tubing hanger running tool 30. In this example, the tubing hanger 26 is received in and engaged by the tubing hanger running tool 30 and the communication coupling 34 is an electrical communication coupling. The communication coupling 34 comprises a tubing hanger electrical contact 44 which is received by a corresponding electrical contact 46 of tubing hanger running tool 30.

[0020] By way of example, electrical contact 44 and corresponding electrical contact 46 may be in the form of electrical contact rings 48, such as concentric contact rings. In this latter example, the inner electrical contact ring 48 of tubing hanger 26 may be slidably received within the outer electrical contact ring 48 of tubing hanger running tool 30 to form electrical contact. The contact rings 48 may be used to provide for electrical contact and signal communication capability through 360° of relative rotation between the tubing hanger 26 and the tubing hanger running tool 30. The 360° communication coupling capability facilitates ease of engagement between the tubing hanger 26 and the running tool 30. As illustrated, the communication line 38 is coupled with tubing hanger electrical contact 44 and the corresponding communication line 40 is coupled with the corresponding electrical contact 46 to enable transfer of signals along the wellbore 22.

[0021] Depending on the application, the tubing hanger 26 may be constructed in a variety of suitable configurations. For example, the tubing hanger 26 may comprise various mechanical latches or other types of gripping or holding mechanisms to releasably secure the tubing hanger 26 to the tubing hanger running tool 30 as with conventional systems. Additionally, the tubing hanger 26 may be telescopic with a lower portion 50 and an upper portion 52 slidably received at a telescopic joint 54. In this type of embodiment, the communication line 38, e.g. cable, may include a coiled portion 56 located at the telescopic joint 54 to provide sufficient cable length during relative movement between lower portion 50 and upper portion 52. Additionally, other types of communication couplings 34 may be used for the communication of signals between the tubing hanger 26 and the tubing hanger running tool 30.

[0022] In the embodiment illustrated in Figure 3, for example, the communication coupling 34 is in the form of an induction coupling. In this embodiment, an induction coil 58 is mounted on tubing hanger 26 and a corresponding induction coil 60 is mounted in tubing hanger running tool 30. By way of example, the inner induction coil 58 of tubing hanger 26 may be received within the outer induction coil 60 of tubing hanger running tool 30 to enable inductive transfer of signals when tubing hanger 26 and running tool 30 are engaged. As illustrated, the communication line 38 is coupled with inner induction coil 58 and the corresponding communication line 40 is coupled with the corresponding induction coil 60 to enable transfer of signals between tubing hanger 26 and tubing hanger running tool 30. For example, data on pressure, temperature, and/or other parameters may be transferred from the downhole device or devices 36, through tubing hanger 26 and tubing hanger running tool 30, and to control system 42.

[0023] In another embodiment illustrated in Figure 4, the communication coupling 34 is in the form of a wireless communication system. In this embodiment, signals may be communicated wirelessly between tubing hanger 26 and tubing hanger running tool 30. According to a specific example, a Wi-Fi transceiver 62 is mounted on tubing hanger 26 and a corresponding Wi-Fi transceiver 64 is mounted in tubing hanger running tool 30. When the tubing hanger 26 is engaged with tubing hanger running tool 30, the inner Wi-Fi transceiver 62 of tubing hanger 26 is positioned sufficiently close to the outer Wi-Fi transceiver 64 of tubing hanger running tool 30 to enable wireless transfer of signals. In some embodiments, the Wi-Fi transceivers 62, 64 may be battery- powered via a battery or batteries disposed downhole with communication coupling 34. [0024] As illustrated, the communication line 38 is coupled with inner Wi-Fi transceiver 62 and the corresponding communication line 40 is coupled with the corresponding Wi-Fi transceiver 64 to enable wireless transfer of signals between tubing hanger 26 and tubing hanger running tool 30. As with other embodiments, data on pressure, temperature, and/or other parameters may be transferred from the downhole device or devices 36, through tubing hanger 26 and tubing hanger running tool 30, and to control system 42.

[0025] In another embodiment illustrated in Figure 5, the communication coupling 34 is in the form of an optical communication system. In this type of system, communication lines 38, 40 may be in the form of optical fibers or optical fiber cables for carrying optical signals. The communication coupling 34 is thus constructed facilitate the transfer of optical signals, e.g. optical data signals, between tubing hanger 26 and tubing hanger running tool 30.

[0026] In the embodiment illustrated in Figure 5, signals may be communicated optically, e.g. as light pulses, along the wellbore 22 via optical communication lines 38, 40 and across tubing hanger 26 and tubing hanger running tool 30. According to a specific example, an optical fiber coupling 66 (or couplings) is mounted on tubing hanger 26 and a corresponding optical fiber coupling 68 (or couplings) is mounted in tubing hanger running tool 30. When the tubing hanger 26 is engaged with tubing hanger running tool 30, the inner optical fiber coupling 66 of tubing hanger 26 is received by the outer optical fiber coupling 68 of tubing hanger running tool 30 to enable transfer of optical signals. By way of example, the optical fiber couplings 66, 68 may be slidably engaged when tubing hanger 26 is coupled with tubing hanger running tool 30.

[0027] As illustrated, the communication line 38 is coupled with inner optical fiber coupling 66 and the corresponding communication line 40 is coupled with the corresponding optical fiber coupling 68 to enable transfer of signals between tubing hanger 26 and tubing hanger running tool 30. As with other embodiments, data on pressure, temperature, and/or other parameters may be transferred from the downhole device or devices 36, through tubing hanger 26 and tubing hanger running tool 30, and to control system 42. It should be noted that the embodiments described herein also may be used to transfer signals downhole to one or more downhole devices 36. In many applications, data signals are transferred uphole and/or downhole, but some applications enable transfer of power signals, e.g. transfer of power signals downhole to power the device(s) 36.

[0028] The well system 20 may be used in a variety of applications and environments. Depending on characteristics of the application and environment, the well system 20 may comprise many types of tubing strings deployed in vertical and/or deviated e.g. horizontal, wells. The well system 20 may comprise a variety of casings, liners, well completions, production components, injection components, and/or other components. Additionally, the tubing may comprise a variety of flow control devices, sensors, coupling mechanisms, and/or other equipment selected according to the parameters of a given application.

[0029] Similarly, the configuration of the tubing hanger 26 and the tubing hanger running tool 30 may vary according to the parameters of a given application. The size and the components of the communication coupling 34 can be selected according to the structures of the tubing hanger 26 and/or running tool 30. Additionally, the configuration and type of components selected for the communication coupling 34 may be adjusted according to the characteristics of a given application and/or environment in which the tubing 28 is deployed. For embodiments described herein, the communication coupling 34 may be constructed to transfer signals at a plurality of relative angular positions between the tubing hanger 26 and the tubing hanger running tool 30. In some applications, the communication coupling 34 may provide for the transfer of signals through a full 360 degrees of relative rotation. Additionally, a device 36 or a plurality of devices 36 may be similar or dissimilar and may be used for monitoring various parameters and/or for performing other desired tasks downhole. [0030] Although a few embodiments of the disclosure have been described in detail above, those of ordinary skill in the art will readily appreciate that many modifications are possible without materially departing from the teachings of this disclosure. Accordingly, such modifications are intended to be included within the scope of this disclosure as defined in the claims.