Hanger running tool and method for installing a hanger in a well

Abstract

The present disclosure relates to a hanger running tool (10) for installing a hanger (14) in a well. The hanger running tool includes a central bore (30) and a hanger engagement device (26) configurable between an engaged position in which the engagement device is coupled to the hanger and a disengaged position in which the engagement device is uncoupled from the hanger. The tool also includes a pressure-controlled anchoring actuator (42) for actuating an anchoring device and including an actuation surface (42a). The hanger engagement device (26) is configurable to the engaged position in response to an increase in pressure at a first pressure source and is configurable to the disengaged position in response to an increase in pressure inside the central bore. The anchoring actuator (42) is actuated in response to an increase in pressure on the actuation surface (e.g., an increase in pressure outside the pipe hanger running tool under a smooth joint, such as an increase in pressure in a BOP) such that the anchoring device anchors the hanger to an anchoring point (e.g., the anchoring point can be located on a wellhead, a Christmas tree, a BOP, etc.).

Description

Technical Field

[0001] This disclosure relates to a hanger delivery tool for installing a hanger in a wellbore and a method for installing a hanger in a well. Background Technology

[0002] In the field of subsea oil and gas wells, the installation of hangers (such as pipe hangers or casing hangers) is common. Hangers are used during well completion and are used to suspend pipes or casing from the wellhead.

[0003] Typically, the installation or retraction of the suspension system is performed using the tubular riser inside the marine riser and blowout preventer (BOP). Installation and retraction are performed using a suspension system feeder tool, which connects to the suspension system to allow for installation or retraction.

[0004] Control of the HRT (Hole-Receiving Tool) and associated downhole functions is currently achieved via a hanger umbilical cable clamped to tubular components such as subsea risers, control risers, etc. This setup requires a significant investment to establish and incurs substantial drilling space and operating costs. Furthermore, several activities and processes are necessary during installation, such as handling the umbilical cable and periodically clamping it to the riser.

[0005] With the necessary equipment in place, the HRT then needs to be located and controlled in the seabed environment. Using currently available technology, the HRT is operated by supplying operating fluid via a top-mounted HPU and umbilical cable or via a subsea control module. Both the top-mounted HPU and umbilical cable or the subsea control module require dedicated power supplies to provide the hydraulic fluid required for operation. Besides being expensive and complex for installation and operation (e.g., due to the equipment involved, and / or the need for a separate high-pressure source to generate the hydraulic fluid), there are always risks of hydraulic lines rupture and leakage of hydraulic fluid into the seabed environment, or failure of other components. Current systems may cause environmental problems, and additional measures may be needed to prevent this.

[0006] Therefore, there is a need for a method to control the installation of suspension devices in the seabed environment that is less costly, requires less complex and precise equipment, and is more environmentally friendly compared to known methods. Summary of the Invention

[0007] The purpose of this disclosure is to mitigate, alleviate, or eliminate one or more of the aforementioned defects and disadvantages in the prior art and to at least solve the aforementioned problems. According to a first aspect, a hanger delivery tool for installing a hanger in a well is provided, the hanger delivery tool comprising: a central bore; a hanger engagement device configured between an engaged position and a disengaged position, in which the engagement device is connected to the hanger and in the disengaged position, the engagement device is disconnected from the hanger; a pressure-controlled anchoring actuator for actuating the anchoring device and including an actuating surface; the hanger engagement device being configured to the engaged position in response to an increase in pressure at a first pressure source, and to the disengaged position in response to an increase in pressure inside the central bore; and the anchoring actuator being actuated in response to an increase in pressure on the actuating surface (e.g., an increase in pressure outside the pipe hanger delivery tool below a smooth joint, such as an increase in pressure in a BOP), such that the anchoring device anchors the hanger to an anchor point (e.g., the anchor point may be located at the wellhead, Christmas tree, BOP, etc.).

[0008] The hanger insertion tool can be an insertion tool for any type of hanger, such as an insertion tool for a pipe hanger or a insertion tool for a sleeve hanger.

[0009] The first pressure source can be the pressure inside the central borehole, or it can be an external pressure source located at the sea surface. If the pressure source is located at the sea surface, the pressure increase can be applied by the external pressure source when the hanger delivery tool is also located at the sea surface. According to the second example, the hanger delivery tool can be configured to be located inside at least one of the BOP, subsea tree, and wellbore, and the anchoring actuator can be configured to be actuated in response to a pressure increase inside the BOP, subsea tree, or wellbore, thereby causing a pressure increase on the actuating surface. The anchoring actuator can be located on the outer surface of the tool.

[0010] According to the third example, the first pressure source can be generated by a pump or a compressor. The first pressure source can be generated when the tool is at the sea surface position, and the first pressure source can be connected to the suspension-feeding tool when the suspension-feeding tool is at the sea surface position. The first pressure source can be located at the sea surface position.

[0011] According to the fourth example, the hanger engagement device can be configured to disconnect from the first pressure source before the hanger insertion tool is positioned in the well.

[0012] According to the fifth example, the hanger engagement device and the anchoring actuator can be positioned outside the central hole and around the periphery of the central hole.

[0013] According to the sixth example, the tool may include a pressure sealing device configured to be positioned in a central bore to enable an increase in pressure above the sealing object within the central bore. The pressure sealing device may be, for example, a sleeve and an actuating body or plug.

[0014] According to the seventh example, the sealing object can provide a first pressure zone and a second pressure zone in the central hole.

[0015] According to the eighth example, the tool may include a valve having a valve seat located in a central orifice, the valve being capable of closing to increase the pressure into the tool by sending the hanger inside.

[0016] According to Example 9, the valve may be at least one of a ball valve or a valve actuated by an actuating object.

[0017] According to Example 10, the valve can be removed from the hanger by a tool. In some examples, the valve seat can be removed from the hanger by a tool.

[0018] According to the eleventh example, the suspension engagement device may include an actuator that can be configured to be in pressure communication with a first pressure source and to be in pressure communication with a central orifice.

[0019] According to the twelfth example, the suspension engagement device may include an actuator having a first pressure inlet and a second pressure inlet, the first pressure inlet being in communication with a first pressure source via a first pressure conduit, and the second pressure inlet being in communication with pressure in a central bore via a channel.

[0020] According to Example 13, the suspension engagement device may include an actuator comprising a piston housed in a hydraulic chamber assembly divided into an upper hydraulic chamber and a lower hydraulic chamber, both of which are in pressure communication with the hydraulic chambers of the hydraulic chamber assembly, including a first pressure source and a central bore.

[0021] According to the fourteenth example, the first pressure source can be in pressure communication with the upper hydraulic chamber located at the upper end of the hydraulic chamber device, and the central orifice can be in pressure communication with the lower hydraulic chamber located at the lower end of the hydraulic chamber device, such that an increase in pressure from the first pressure source can be used to move the piston in a first direction, and an increase in pressure from the central orifice can be used to move the piston in a second direction.

[0022] According to Example Fifteen, the anchoring actuator can be in the form of a ring piston.

[0023] According to the sixteenth example, the tool may include an anchoring device that includes an anchoring engagement profile, and the anchoring actuator is configurable to operate the anchoring device to engage the wellbore.

[0024] According to the seventeenth example, the tool may include a locking device configured to lock the hanger engagement device in an engaged position.

[0025] According to Example 18, the tool can be configured to retrieve the hanger from the well.

[0026] According to the nineteenth example, the tool may include a removable retraction module for engaging the tool with a hanger for retraction, the removable retraction module including a retraction profile for engaging the hanger for retraction.

[0027] According to the twentieth example, the central hole can be configured to allow a retractable plug to be inserted through the central hole.

[0028] The second aspect relates to a method for installing a hanger in a well, the method comprising the following steps:

[0029] A hanger delivery tool is provided, which includes a central hole, a hanger engagement device, and an anchoring actuator for actuating the anchoring device;

[0030] By providing an increase in pressure at the first pressure source to configure the suspension engagement device into an engagement configuration, the suspension delivery tool is engaged with the suspension. The pressure increase is provided when both the suspension delivery tool and the first pressure source are at the sea surface position.

[0031] Position the hanger and hanger insertion tool at the desired location in the well;

[0032] The anchor actuator is actuated by providing an increase in pressure in the well to engage the anchoring device with the anchoring point, thereby engaging the hanger with the anchoring point.

[0033] By increasing the pressure in the central bore to configure the hanger engagement device to a disengaged configuration, the hanger is fed into a tool to disengage from the hanger; and

[0034] The hanger is sent into the tool and retrieved from the well.

[0035] According to the second example of the second aspect, the desired location in the well can be at least one of the desired location inside the BOP, the desired location inside the subsea tree, and the desired location inside the wellbore.

[0036] According to a third example of the second aspect, the method may include providing a valve seat in a central orifice and positioning an actuating object (e.g., a ball or dart) in the valve seat to restrict fluid flow through the valve seat and provide a pressure increase in the central orifice.

[0037] According to a fourth example of the second aspect, the method may include increasing the pressure in the well to move the anchoring actuator from a first position to a second position, thereby engaging the anchoring device with the anchoring point.

[0038] According to the fifth example of the second aspect, the method may include attaching a removable retrieval module to the tool and retrieving the hanger from the well by connecting the removable retrieval module to the hanger.

[0039] According to the sixth example of the second aspect, the method may include installing the retractable plug in the well by inserting it through the central hole of the tool.

[0040] According to the seventh example of the second aspect, the method may include performing well cleaning operations before installing the retractable plug.

[0041] This disclosure will become apparent from the detailed description given below. The detailed description and specific examples disclose preferred embodiments of this disclosure by way of illustration only. Those skilled in the art will understand from the guidance of the detailed description that changes and modifications can be made within the scope of this disclosure.

[0042] Therefore, it should be understood that the disclosure herein is not limited to specific components of the described apparatus or steps of the described method, as such apparatus and methods can vary. It should also be understood that the terminology used herein is for the purpose of describing particular embodiments only and is not intended to be limiting. It should be noted that, as used in the specification and appended claims, unless the context clearly indicates otherwise, the articles “a,” “an,” “the,” and “described” are intended to mean the presence of one or more of these elements. Thus, for example, references to “unit” or “the unit” can include several devices, etc. Furthermore, the words “comprising,” “including,” “containing,” and similar terms do not exclude other elements or steps. Attached Figure Description

[0043] The above-mentioned objects, as well as other objects, features, and advantages of this disclosure, will be more fully understood through the following illustrative and non-limiting detailed description of exemplary embodiments of this disclosure, taken in conjunction with the accompanying drawings.

[0044] Figure 1 A cross-sectional view of an example of a hanger feed tool in an installation configuration is shown.

[0045] Figure 2 Details A of the hanger feed tool are shown in more detail.

[0046] Figure 3 The illustration shows a suspension feeder in a retractable configuration, which is equipped with a retraction module.

[0047] Figure 4 Details B of the hanger feed tool are shown in more detail. Detailed Implementation

[0048] This specification provides an improved hanger delivery tool for installing a hanger in a wellbore and a method for installing a hanger in a well. According to one example, a hanger delivery tool for installing a hanger in a well is provided, the hanger delivery tool comprising: a central bore; a hanger engagement device configured between an engaged position and a disengaged position, in which the engagement device is connected to the hanger, and in a disengaged position, the engagement device is disconnected from the hanger; a pressure-controlled anchoring actuator for actuating the anchoring device and including an actuating surface; the hanger engagement device being configured to the engaged position in response to an increase in pressure at a first pressure source, and to the disengaged position in response to an increase in pressure inside the central bore, and the anchoring actuator being actuated in response to an increase in pressure on the actuating surface (e.g., an increase in pressure outside the pipe hanger delivery tool below a smooth joint, such as an increase in pressure in a BOP), such that the anchoring device anchors the hanger to an anchor point (e.g., the anchor point may be located at the wellhead, Christmas tree, BOP, etc.).

[0049] In use, the hanger delivery tool can (e.g., at the surface location) connect, engage, and be delivered to a location at the wellhead, subsea tree, borehole, etc., and can be positioned, for example, via a blowout preventer (BOP) and subsea riser. Once in the desired position, the pressure inside the BOP, subsea riser, and / or borehole can be increased to actuate the hanger delivery tool and provide engagement between the hanger and components such as the casing hanger seat or wellhead. The pressure inside the central bore of the hanger delivery tool can then be increased to configure the hanger engagement device to disengage the hanger from the hanger delivery tool, thereby allowing the hanger delivery tool to be retracted from the wellhead, BOP, borehole, etc., and leaving the hanger in place. This setup allows users to install the hanger in the desired location without the need for a hydraulic connection between the hanger delivery tool and the surface location or subsea control subunit / unit, thereby saving time and costs associated with providing and delivering any necessary auxiliary equipment from the surface location. In addition, the described system is simpler to function than known systems and provides environmental benefits, such as eliminating the risk of hydraulic fluid leakage into the surrounding environment.

[0050] exist Figure 1The figure shows a cross-sectional view of the hanger insertion tool 10, revealing some internal details. The hanger insertion tool 10 is connected at one end to a tubular member 12 and at the other end to a hanger 14. In this case, the hanger 14 is a pipe hanger; however, it should be understood that the hanger insertion tool 10 can be used for any other type of hanger, such as a sleeve hanger. Although in Figure 1 Not shown in the figure, but the hanger delivery tool 10 can be delivered, for example, via the marine riser and blowout preventer (BOP) to the wellhead (e.g., the seat in the casing hanger connected to the wellhead), or to the subsea tree or wellbore.

[0051] In this example, the tubular member 12 can be connected to the hanger feed tool 10 by any suitable means, such as via flange and bolt connection, via threaded connection, etc. Here, the tubular member 12 includes a smooth joint 16, which can be sealed with a pressure head or BOP ring (not shown), and when the pressure head makes sealing contact with the smooth joint, it can increase the pressure below the smooth joint 16 (e.g., pressure in the wellbore, BOP, Christmas tree, etc.).

[0052] As will be described in more detail below, the hanger 14 is coupled to the hanger feed tool 10, and... Figure 1 In the figure, pipe hanger 14 is shown as the lower part near the bottom. The pipe (in...) Figure 1 (Not shown and located below the pipe hanger 14) For example, a production pipe can be suspended from the pipe hanger 14, and the pipe hanger 14 and the attached pipe can be driven into the desired location in the well using the hanger delivery tool 10. The pipe hanger 14 includes a main body 20 for suspending the pipe and an actuating sleeve 22. In this example, the actuating sleeve 22 includes an anchoring engagement profile 24, allowing the pipe hanger 14 to engage with an anchor point. This anchor point can be located, for example, on a component such as a Christmas tree, wellhead, or seat in a casing hanger or pipe hanger (not shown).

[0053] The hanger delivery tool 10, located between the tubular member 12 and the pipe hanger 14, engages with the pipe hanger 14 and the attached pipe, allowing the pipe hanger 14 to be delivered relative to the well to a desired location, such as at the wellhead or on the wellhead tree. The user can deliver the hanger delivery tool 10 into the well via a marine riser and a BOP. The hanger delivery tool 10 is connected to the tubular member 12 via a base component 28, which also defines a central bore 30 within the hanger delivery tool 10.

[0054] To attach the pipe hanger 14 to the hanger insertion tool 10, the hanger insertion tool 10 includes a hanger engagement device 26. The hanger engagement device 26 includes several components, which will be described in more detail in the following paragraphs, and is mounted on a base component 28. The hanger engagement device 26 is in pressure communication with a first pressure source via a first pressure port 32. In this example, the first pressure port 32 is located in the base component 28, which includes a channel that allows pressure communication between the first pressure port 32 and the hanger engagement device 26 by connecting the first pressure port 32. In this example, the first pressure port 32 is coupled to a first pressure conduit 34, and access to the first pressure port 32 is possible by connecting the first pressure port 32 and the first pressure conduit 34. Access to the first pressure port 32 via the first pressure conduit provides the user with a degree of flexibility in setting the pressure at the first pressure port 32, because the first pressure conduit 34 can be routed as needed to provide easy access via the pressure source. Therefore, the first pressure conduit 34 allows communication between the first pressure source (not shown) and the hanger engagement device 26 via the first pressure port 32. The first pressure conduit 34 can be attached to the first pressure source, for example, at a sea surface location, to configure the hanger engagement device 26 for engagement with the pipe hanger. The first pressure source can then be disconnected from the first pressure conduit 34 before the hanger delivery tool 10 is delivered downhole.

[0055] As can be seen in this example, the first pressure conduit 34 extends from the pressure port 32 on the base member 28 and passes through the smooth connector 16, thereby positioning one end above the smooth connector 16. Therefore, connecting the first pressure conduit 34 to the pressure port 32 ensures that the first pressure port 32 is not affected by an increase in pressure below the smooth connector. The first pressure conduit 34 may have a valve or closure at its open end, thereby providing selective pressure communication with the first pressure port 32. Figure 1 In the example, the first pressure conduit 34 includes a valve 34a (e.g., a pilot valve) positioned along its length. As will be described in more detail in the following paragraphs, the valve 34a can be used to achieve selective discharge of the chamber inside the hanger engagement device 26.

[0056] For example, the discharge through the first pressure conduit 34 can enter the wellbore or the BOP.

[0057] Despite the first pressure conduit 34 in Figure 1 The image shows a single conduit extending through the smooth connector 16, but the first pressure conduit 34 may be partially defined by the tubular member 12 and the smooth connector 16, as shown. Figure 1As illustrated, the portion of the first pressure conduit 34 that directly contacts the first pressure port 32 is defined by a channel in the tubular member 12 (particularly the flange connection of the tubular member 12). The first pressure conduit 34 may be entirely defined by the channel in the tubular member 12, and this channel need not contain any conduit. The conduit is then defined by a first segment between the channel defined in the tubular member 12 and the smooth connector 16. The smooth connector 16 also includes a channel therein that partially defines the first pressure conduit 34, and in this example, a second segment connects to the channel in the smooth connector 16 to further define the first pressure conduit 34.

[0058] The first pressure source can be located at the sea surface, such as on the top side of a ship or on a drilling rig. The sea surface location can be anywhere outside the well. In some examples, the first pressure source can be a pump or compressor that can be attached (e.g., temporarily attached) to the first pressure conduit 34 to provide a pressure increase at the first pressure port 32, and thus increase the pressure at the location inside the hanger engagement 26. The first pressure source can be attached to the first pressure conduit 34 when the hanger insertion tool 10 is at the sea surface location, and then disconnected to allow the hanger insertion tool 10 to be inserted into the desired location (e.g., disconnected before inserting the hanger tool 10 into the desired location).

[0059] In addition to the first pressure conduit 34, a second discharge conduit 36 ​​is also illustrated in this example. The second discharge conduit 36 ​​connects to a second pressure port 38, which is also located on the outer surface of the base member 28 (similar to the case of the first pressure port 32). Similarly, the base member 28 includes a channel providing pressure communication between the hanger engagement 26 and the second pressure port 38. The second discharge conduit 36 ​​is coupled to the second pressure port 38 and extends from the second pressure port 38 to a position above the smooth connector 16, thus meaning that the second pressure port 38 is unaffected by pressure changes occurring below the smooth connector. The second pressure port 38 can be used to allow fluid to be discharged from inside the anchor actuator 42. In particular, the second pressure port 38 can allow fluid to be discharged from inside the actuation chamber 40 of the anchor actuator 42. As with the first pressure conduit 34, the second discharge conduit includes a valve 36a (e.g., a pilot valve) that can facilitate the discharge of fluid from inside the hanger engagement 26.

[0060] Similar to the first pressure conduit 34, the second discharge conduit 36 ​​may be partially defined by multiple pipe segments, partially by the smooth connector 16, and partially by the tubular member 12. For the sake of brevity, detailed descriptions will not be repeated.

[0061] exist Figure 1The example illustrates a first auxiliary port 32a and a second auxiliary port 38a. Unlike the first pressure port 32, the first auxiliary port 32a does not include a conduit connected to or communicating with it. In use, the first auxiliary port 32a can be used only as a test port, for example, to perform a pressure test when the hanger insertion tool 10 is in a surface position. Once in a downhole position, the first auxiliary port 32a can be sealed or blocked and may no longer function. The second auxiliary port 38a is similar; it can also be used only as a test port and can also be sealed, blocked, or plugged during normal operation, rendering it inoperable.

[0062] In some cases, a valve device or removable plug may be provided in or near either or both of the first auxiliary port 32a and the second auxiliary port 38a to allow rapid access to ports 32a, 38a when needed. This access component (e.g., a valve or removable plug, or a device comprising either or both of multiple valves or removable plugs) may be located in or between the associated fluid ports 32a, 38a and associated conduits 34, 36.

[0063] Figure 1 The diagram also illustrates an anchor actuator 42 for pressure control of an actuated anchoring device. (As shown in...) Figure 1 As can be seen, the pressure-controlled anchoring actuator 42 is located on the outer surface of the hanger insertion tool 10, around the central bore 30, and is therefore open to pressure outside the hanger insertion tool 10. The pressure outside the hanger insertion tool 10 can be the borehole pressure, where the hanger insertion tool 10 is located in or near the borehole and / or wellhead, or the pressure outside the hanger insertion tool 10 can be the pressure inside the BOP. By providing a seal at the smooth joint 16, the user can increase the pressure outside the hanger insertion tool 10 located below the smooth joint 16 to actuate the pressure-controlled anchoring actuator 42. In this example, the anchoring device can be considered to include at least the anchoring actuator 42, the actuating sleeve 22, and the engagement profile 24.

[0064] To increase the pressure below the smooth connector 16, the user can increase the pressure through a conduit such as a flow-blocking line / kill line, although not shown, which can bypass the smooth connector 16 and allow the pressure below the smooth connector 16 to increase for actuating the anchoring actuator 42.

[0065] In this example, the pressure-controlled anchoring actuator 42 has the shape of an annular piston and includes a laterally extending shoulder defining an actuation surface 42a. When the pressure in the borehole, BOP, etc., increases, the radially and axially extending shoulder, as well as the defined actuation surface 42a, can be used to provide an axial force on the pressure-controlled anchoring actuator 42. Figure 1 As illustrated in the figure, in this example, the axial force acts in a downward direction toward the pipe hanger 14. The pressure-controlled anchoring actuator 42 extends outside one axial end of the hanger feed tool 10 and along a portion of the length of the hanger feed tool, and together with the actuation sleeve 22 of the pipe hanger 14, can be used to provide a housing for the hanger feed tool 10.

[0066] like Figure 1 As illustrated, the anchor engagement profile 24 is in the disengaged engagement position, wherein the anchor engagement profile 24 is radially retracted away from adjacent anchoring points, such as wellheads, BOPs, Christmas trees, etc., and these anchoring points may include the anchor engagement profile to help provide an anchoring connection with the anchor engagement profile 24. To move the anchor engagement profile 24 to the engagement position, the actuating sleeve 22 of the pipe hanger 14 can be moved axially. In this example, as the actuating sleeve 22 moves toward the body 20 of the pipe hanger 14, a portion of the actuating sleeve 22 can be pressed under the anchor engagement profile 24 (e.g., radially inward relative to the anchor engagement profile 24), thereby pushing the anchor engagement profile 24 radially outward and pushing it into engagement contact with the anchoring point, thereby holding the pipe hanger 14 in place in the wellhead, BOP, Christmas tree, etc. To facilitate this movement, the actuating sleeve 22 may include a mating profile, such as a wedge-shaped portion, located near the anchoring engagement profile 24, such that axial movement of the actuating sleeve 22 provides a force acting on the anchoring engagement profile 24, the force having a radially outward force component. Additionally or alternatively, the anchoring engagement profile 24 may include a mating profile, such as a corresponding wedge-shaped portion, which similarly contributes to providing a radially outward force on the anchoring engagement profile 24. When both the actuating sleeve 22 and the anchoring engagement profile 24 include wedge-shaped profiles, the profiles may be functional, for example, they may be used to ensure that the actuating sleeve 22 can apply a radially outward force component on the engagement profile 24, thereby moving the engagement profile 24 to a radially outward position.

[0067] The anchoring engagement profile 24 and / or sleeve 22 may include surfaces configured to maximize the clamping level between the anchoring engagement profile 24 and the anchoring point. For example, the anchoring engagement profile 24 may be rough or include protrusions such as ribs, recesses, teeth, etc.

[0068] like Figure 1As illustrated, the actuating sleeve 22 may contact, be contacted by, or be coupled to the pressure-controlled anchoring actuator 42. In this case, an increase in external pressure (e.g., borehole or BOP pressure) around the hanger feed tool 10 may have the effect of moving the actuator 42 in an axially downward direction, as shown in the illustrated orientation, thereby also moving the actuating sleeve 22 of the pipe hanger 14 and configuring the anchor engagement profile 24 from a disengaged position to an engaged position. In some examples, the actuating sleeve 22 (or at least a portion of the actuating sleeve 22) may form part of the hanger feed tool 10, while the anchor engagement profile 24 forms part of the pipe hanger 14.

[0069] Although not illustrated, the hanger feed tool may include sensors or sensor devices for identifying whether the piston, actuating sleeve, engagement profile, etc., have performed the desired movement. The sensor may be a pressure sensor, strain gauge, optical sensor, or any other type of sensor suitable for identifying piston movement. The sensor or sensor device may be connected to a control unit (e.g., via a wire extending between the sensor and the control unit, or via a wireless connection). The control unit may be located at the surface, on the drill string, or downhole, and may be connected to a display to alert the user to the movement status of (or each) piston in the hanger feed tool 10.

[0070] In this example, a sleeve 44 is illustrated within the central bore 30. The sleeve 44 includes a valve seat 46. In this example, the sleeve 44 is partially located within the hanger feed tool 10 and partially within the hanger 14. The sleeve 44 can be fed into the borehole together with the hanger feed tool 10, or, for example, before or after the hanger feed tool 10 has been installed in the desired position, the sleeve 44 can be positioned independently within the hanger feed tool 10. For example, the sleeve 44 can be fed in via a cable and can be retrieved or replaced if needed. In some examples, the sleeve may have different... Figure 1 The profile illustrated in the figure may differ from that of a pre-installed sleeve, for example, when the sleeve is fed into tool 10 via a cable. Furthermore, or alternatively, a hanger plug may be fed into the pipe hanger 14 by allowing the user to simply insert such a plug through the central bore 30 of the hanger feed tool 10, to, for example, limit or prevent pressure fluctuations from below the pipe hanger 14. In some examples, the plug may be pre-installed in the pipe hanger 14 when it is fed downhole, eliminating the need to install the plug after the hanger is in place at the BOP or wellhead.

[0071] The illustrated sleeve 44 (which may be a retractable sleeve), or hanger plug, or other sealing member or assembly of members, can be considered a pressure sealing device. A pressure sealing device (e.g., sleeve 44 or hanger plug, or pressure sealing object) can facilitate the use of the hanger insertion tool 10. In the case of sleeve 44, by providing a valve seat 46, sleeve 44 can provide a seal in the central bore 30 of the hanger insertion tool 10, for example, by inserting a ball into the hanger insertion tool 10. In the case of hanger plug (e.g., a removable hanger plug) or another sealing member or plurality of sealing members that can be positioned in the central bore 30 to provide a pressure seal therein, the hanger plug can be lowered into and positioned in the central bore 30, and subsequently optionally removed. In some cases, the pressure sealing device can be fully or partially positioned in the central bore 30 defined by the pipe hanger 14. When providing a pressure sealing device, the user can provide a first and a second region with different pressures located above and below the pressure sealing device. For example, by increasing the pressure of the central bore 30 at its sea surface location, the user can increase the pressure in the first region to the actuation pressure required to actuate the actuator 55, while the second (e.g., lower) region remains at a different (e.g., lower) pressure, allowing the user to actuate the actuator 55 without pressurizing the entire conduit. Thus, the user can increase the pressure within the central bore 30 of the hanger feed tool 10 above the valve seat in the direction toward the surface. This pressure increase can be provided by increasing the pressure inside the tubular component 12 (e.g., marine riser, tubular riser, subsea riser, control riser, etc.) connected to the hanger feed tool 10 and the conduit hanger 14. It should be noted that although a pressure sealing device can help pressurize the central bore 30 of the hanger feed tool 10 to the actuation pressure, actuation of the actuator 55 can be achieved without the need for a pressure sealing device. For example, without a pressure sealing device, simply increasing the pressure from, for example, the connected riser to the wellbore can have the same effect as actuating the actuator.

[0072] In addition, sleeve 44 can be used to plug and seal the production ports (not shown) in pipe hanger 14, thereby ensuring that the operation of hanger feed tool 10 is not affected by unsealed ports in pipe hanger 14 if these ports are not already in use.

[0073] Figure 2 The diagram shows Figure 1 Detail A shows a portion of the internal details of the suspension engagement device 26 in more detail.

[0074] As in Figure 1 and Figure 2As can be seen, the channel extends from the first pressure port 32 and passes through the base component 28 of the hanger feed tool 10 to reach the position inside the hanger feed tool 10 (see also...). Figure 1 Inside the hanger feed tool 10, a hydraulic chamber assembly 48 is formed between the base member 28, the lower annular ring 58, and the upper annular engagement ring 50. The hydraulic chamber assembly 48 may include an abutment surface 52 for engaging and / or positioning the hanger feed tool 10 relative to the pipe hanger 14. An annular piston 54 is positioned inside the hydraulic chamber assembly 48, including a thicker end 54a and a thinner end 54b, which define two separate (upper and lower) hydraulic chambers 48a, 48b within the hydraulic chamber assembly 48. The annular piston 54 within the hydraulic chamber assembly 48 may together form an actuator 55 (e.g., a pressure-actuated actuator). In this example, the thicker end 54a of the hydraulic piston 54 is positioned above the thinner end 54b, such that the thicker end 54a is located in the upper hydraulic chamber 48a, while the thinner end is located in the lower hydraulic chamber 48b. Although the annular piston 54 in this example includes a thicker end 54a and a thinner end 54b, in some examples it may be preferable that the annular piston 54 is a balanced piston, wherein the thicker end 54a has the same radial width as the thinner end 54b, and, for example, the annular piston 54 has a constant radial width along its length.

[0075] Actuator 55 includes two pressure ports (a first pressure port and a second pressure port), which can be considered as pressure inlets (a first pressure inlet and a second pressure inlet). The first pressure inlet 49a allows pressure communication with the upper hydraulic chamber 48a, and in this example, the first pressure inlet 49a is connected to a first pressure conduit leading to a location above the smooth connector 16. Optionally, the first pressure inlet 49a may be connected to the first pressure conduit 34 via a channel in the base member 28, or the first pressure conduit 34 may be directly connected to the first pressure inlet 49a. As previously described, the first pressure conduit may be connected to a first pressure source to expose the upper hydraulic chamber 48a to the pressure of the first pressure source. The second pressure inlet 49b allows pressure communication with the lower hydraulic chamber 48b, and in this example, the second pressure inlet 49b is connected to channel 62, allowing the lower hydraulic chamber 48b to be in pressure communication with the central bore 30. Therefore, the actuation pressure used to actuate the actuator from the engaged position (e.g., move) to the disengaged position so as to disengage the suspension engagement member 56 depends on the pressure inside the upper hydraulic chamber 48a and at the first pressure port 49a.

[0076] Although not illustrated, and similar to those previously described, a sensor or sensor device may be located on or near the annular piston 54 and / or chamber 48 to detect movement of the annular piston 54 and send information to the user about the positioning of the annular piston 54.

[0077] Located directly below the upper annular engagement ring 50 is the hanger engagement member 56, which includes an engagement profile for engaging the hanger feed tool 10 with the pipe hanger 14. The hanger engagement member 56 is held in place by a lower annular ring 58. Furthermore, an upper sealing device is disposed between the thicker end 54a and base member 28 of the annular piston 54 and the upper annular engagement ring 50, while a lower sealing device is disposed between the thinner end 54b and base member 28 of the annular piston 54 and the lower annular ring 58. The upper annular engagement ring 50 additionally includes a locking key 60, which may be spring-loaded and can engage with the annular piston 54 to lock the annular piston 54. As shown in detail A, the annular piston 54 is positioned such that the hanger engagement member 56 contacts the pipe hanger 14, thereby engaging the hanger feed tool 10 with the pipe hanger 14 and locking the hanger feed tool 10 in that position.

[0078] In use, the hanger insertion tool 10 can be connected (e.g., attached, engaged) to the pipe hanger 14 at a location at sea, such as on a ship, drilling rig, or warehouse. This can be done by attaching a first pressure conduit 34, either in the form of a pump or compressor, or by attaching a first pressure source provided by a pump or compressor, to provide an increase in pressure in the upper chamber 48a—the end of the hydraulic chamber where the thicker end 54a of the annular piston 54 is located. The increased pressure in the upper section of the hydraulic chamber causes the annular piston 54 to move downwards. As the annular piston 54 moves downwards, the hanger engagement member 56 changes from contacting the thinner end 54b of the annular piston 54 to contacting the thicker end 54a of the annular piston 54, thereby having the effect of moving the hanger engagement member 56 relative to the pipe hanger 14 from a disengaged position to an engaged position.

[0079] The hanger engagement member 56 may be biased toward the disengaged position, for example, by being spring-loaded, to avoid undesirable engagement with the pipe hanger 14. Once in the engaged position, the locking key 60 may inhibit the movement of the piston 54, thereby preventing the hanger engagement device 26 and the hanger feed tool 10 from disengaging from the pipe hanger 14, for example, during transport.

[0080] Once the dropper 10 and the pipe hanger 14 have been engaged, both can be deployed, for example via a marine riser and BOP, to their desired positions on the seabed (e.g., within the BOP, Christmas tree, wellhead, etc.). To assist in positioning the pipe hanger 14, a sensor device can be used, such as a sensor capable of conveying to the user that the pipe hanger has passed a point in the BOP, has been engaged with the wellhead, either directly or indirectly (e.g., via a seat on the wellhead, via a casing hanger on the wellhead, via a seat in the Christmas tree engaged with the wellhead, etc.), or has reached another desired position. Additionally or alternatively, the positioning of the tool can be confirmed by a hydraulic device, for example by having a tool in the dropper 10 or pipe hanger 14 that measures the pressure buildup around the tool as it descends into position, thereby indicating the position of the pipe hanger 14 to the user. This information can be transmitted to users at ground locations via any suitable device, such as through communication cables or optical fibers attached to the marine riser, or through wireless transmission.

[0081] With the pipe hanger 14 in the desired position, it may then be necessary to install the pipe hanger 14 in that position. Initially, the pipe hanger 14 and the hanger insertion tool 10 will be in... Figure 1 The position shown is such that the anchoring engagement profile 24 is in a retracted configuration and does not engage with the anchoring points of the Christmas tree, BOP, wellhead, etc., or any surrounding components. For the pipe hanger 14 to engage with anchoring points (e.g., wellhead, BOP, Christmas tree), it is necessary to configure the pipe hanger 14 and the hanger insertion tool 10 as shown. Figure 2 The engagement position is shown in the diagram. At this time, the pressure-controlled anchoring actuator 42 moves in the downward direction. When the anchoring actuator 42 contacts the actuation sleeve 22, this has the effect of moving the anchoring engagement profile 24 to an engaged and radially extended configuration as previously described, in which the anchoring engagement profile 24 engages with the anchoring point. The movement of the anchoring actuator 42 can be achieved by increasing the pressure in the wellbore, tree, BOP, etc. (e.g., via a flow-blocking / killing line bypassing the smooth joint 16). This can be achieved by moving the pressure head or BOP annular stopper to a sealing contact with the smooth joint 16, and then increasing the pressure below the smooth joint 16.

[0082] It is possible Figure 1 and Figure 2As can be seen from both, there is an actuation cavity 40 between the anchor actuator 42 and the base component 28. A sealing device may be located between the anchor actuator 42, the base component 28 and the upper annular ring 50 to isolate the pressure in the actuation cavity 40 from the rest of the suspension actuator 26 (e.g., from the hydraulic chamber 48, as will be described in the following paragraphs).

[0083] A sensor or sensor device may be located on or near the anchor actuator 42 to provide indication of the state of the anchor actuator 42. The sensor or sensor device may be located on or near at least one of the anchor actuator or tool body (e.g., base member 28). In some examples, the sensor or sensor device may be directly attached to or connected to the actuator 42, base member 28, etc., while in other examples, the sensor or sensor device may be provided as a separate component that may be attached to or connected to the actuator 42, base member 28, any other adjacent components, etc.

[0084] like Figure 1 and Figure 2 As illustrated in both diagrams, the second pressure port 38 leads to a channel in the base component 28, which allows pressure communication between the actuation chamber 40 and the second pressure port 38. Since the second pressure port 38 is coupled to the second discharge conduit 36, which extends to a position above the smooth connector 16, the pressure in the actuation chamber 40 will be equal to the pressure in the region above the smooth connector 16, which can be equal to the pressure inside the marine riser. Therefore, once the sealing head is positioned in sealing contact with the smooth connector 16, and the pressure below the smooth connector increases, an unbalanced force will act on the laterally extending shoulder and actuation surface 42a of the anchor actuator 42 due to the pressure difference between the actuation chamber 40 and the region outside the anchor actuator 42. This causes the anchor actuator 42 to move downwards, thereby engaging the anchor engagement profile 24 at the anchor point, and the pipe hanger 14 is installed in the desired position. Simultaneously, the contents of the actuation chamber 40 can be discharged via the discharge conduit 36 ​​to a position above the smooth connector 16. The valve 36a in the discharge conduit 36 ​​allows for some degree of control over the discharge from the actuation chamber 40. For example, the valve 36a can be user-operated to open only when needed. Additionally or alternatively, the valve can open automatically, for example, under a set pressure limit.

[0085] Although the term "above" is used to describe relative terms, it has been chosen to aid the reader in understanding the invention within the context of the provided drawings. While the described components may be provided in the orientation shown in the drawings, they may also be provided in other configurations, such as rotated 90 degrees, 45 degrees, or some other angle. Therefore, the reader should understand that in such cases, the meaning of the term "above" (and equivalent similar descriptive relative terms such as "below," "upward," and "downward") may differ from its conventional understanding.

[0086] Once the pipe hanger 14 has been installed in the desired position, it may be necessary to use the hanger insertion tool 10 to unlock the pipe hanger 14 for retraction. To perform this operation, a pressure sealing device (e.g., such as...) Figure 1 The sleeve 44, or hanger plug, or other device, can be installed (or pre-installed) in the hanger feed tool 10, and if necessary, an actuating object such as a ball or dart can fall into the valve seat 46 in the sleeve. The ball (not shown) forms a seal with the valve seat or hanger plug or any other pressure sealing device of the sleeve 44, forming a seal in the central bore 30, and the pressure inside the hanger feed tool 10 can be increased over the valve seat 46, hanger plug, other pressure sealing devices, etc. Thus, a first pressure region and a second pressure region can be established inside the central bore 30. The pressure increase above the pressure sealing device (e.g., the first pressure region of the pressure sealing device) can be achieved by increasing the pressure in the tubular member 12 attached to the hanger feed tool 10. For example, it can be... Figure 1As can be seen, a pressure passage 62 (or multiple circumferentially arranged passages) extends between the central bore 30 and the actuator 55 defined by the hydraulic chamber assembly 48 and the piston 54. Here, the pressure passage 62 is located in (and may be defined by) the base component 28, thereby allowing pressure communication between the central bore 30 and the hydraulic chamber 48 of the actuator. In particular, the pressure passage 62 allows (in this example) pressure communication between the lower hydraulic chamber 48b located below the upper sealing device and the fluid port in the central bore 30 located above the height of a pressure sealing device such as a valve seat, hanger plug, etc. Therefore, with the pressure sealing device in place (e.g., the actuating object (a ball in this example) engaged in the valve seat 46), the increased pressure in the central bore 30 acts on the lower sealing device in the lower hydraulic chamber 48b, resulting in the following effects: once the pressure in the central bore 30 reaches the actuating pressure, it pushes the annular piston 54 therein in an upward direction; and overcomes the locking force of the locking key 60, which is provided by a biasing member such as a spring that biases the locking key 60 toward the locking configuration; and also overcomes the pressure in the upper hydraulic chamber 48a, which in this example is equal to the pressure above the smooth connector 16 via the first pressure conduit 34. Although only one locking key 60 is illustrated in this position, more than one locking key may be present (e.g., a separate array of locking keys may be present). A simple outline of the locking key is illustrated in detail A, but different, more complex outlines (e.g., outlines including multiple teeth) may be used in other examples. In this example, the locking key 60 is spring-supported, allowing it to disengage when a lateral force is applied. Depending on different operating conditions (e.g., different depths the tool is inserted using a pipe hanger or different operating pressures), the locking key can be designed in different ways to ensure that the tool 10 does not accidentally unlock from the hanger 14 under given specific operating conditions. For example, more or fewer locking keys 60 can be used, the spring stiffness can be varied, and / or the engagement profile can have varying shapes (e.g., varying number of teeth). These variables can be controlled to provide an arrangement that requires the minimum desired horizontal lateral force for unlocking.

[0087] Due to the sealing device in the pipe hanger inserted into tool 10 and the pressure balance within the cavity / chamber of tool 10, tool 10 can be relatively unaffected by external pressures and / or differential pressures acting on tool 10. Additionally, the pressure acting on both ends of the annular piston 54 will be identical (both ends will be subjected to pressure surrounding tool 10), which will then serve to prevent accidental actuation of the pipe hanger inserted into tool 10 during installation.

[0088] As the annular piston 54 moves in the upward direction, the hanger engagement member 56 contacts the thinner end 54b of the piston 54. When the hanger engagement member 56 is biased toward the disengaged configuration, it moves toward the disengaged configuration, and the hanger feed tool 10 is now disengaged from the pipe hanger 14. The hanger feed tool 10 can then be retracted.

[0089] To further assist the annular piston 54 in moving toward the disengaged position, the valve 34a in the first pressure conduit 34 can be opened to allow the upper hydraulic chamber 48a to be discharged.

[0090] The tool may also have auxiliary operating devices that allow the tool 10 to be released from the pipe hanger 14 in the event of failure of the above process. Figure 1 and Figure 2 In the example, the hanger feed tool 10 may include a shearing ring 64. Here, the shearing ring is located between the base member 28 and the lower annular ring 58, and the base member 28 directly above the shearing ring may have a threaded profile configured to engage with the threaded profile of the lower annular ring 58.

[0091] To release the hanger 14 from the feed tool 10, the base component 28 can be rotated. The lower annular ring 58 can engage with a sleeve located radially outward therefrom (e.g., via a key-like portion located between the lower annular ring and the sleeve), and therefore may not rotate with the base component 28, resulting in shearing of the shear ring 64. Once the shear ring is sheared, rotation between the lower annular ring 58 and the base component 28 due to the threaded connection between the lower annular ring 58 and the base component 28 can cause the lower annular ring 58 to move downward until it disengages from the base component 28. At this point, the base component can be pulled upward, causing the annular piston 54 to move upward and the tool 10 to disengage from the hanger 14, allowing the tool 10 to be retracted. Using this method, the tool 10 can be retracted if the primary hydraulic actuation method fails.

[0092] Although one means of assisting operation has been described, it should be noted that users should not be limited to this means. As described, other means of assisting operation can also be used in conjunction with the delivery tool 10 and the hanger 14 as described.

[0093] Figure 3 and Figure 4 Another example of a segment of the hanger feed tool 110 is illustrated, which can be... Figure 1 and Figure 2 The tools described herein are the same tools, but in different configurations, as will be described in detail B. Figure 3 Part of it. The hanger insertion tool 110 is basically similar to Figure 1 and Figure 2 The hanging feeder tool shown in the figure, and therefore the equivalent number will be used for the equivalent part, increased by 100.

[0094] exist Figure 3 In this example, a removable retrieval module 166 is included. In this example, the removable retrieval module 166 is attached to the hanger delivery tool 110 between the anchor actuators 142. The removable retrieval module 166 can be attached to the hanger delivery tool 110 before being delivered downhole.

[0095] The detachable retraction tool includes a biasing member 168 (which may be in the form of a retaining ring or a spring-loaded key) movable between a radially inward position and a radially outward position, and biased toward the radially outward position, for example, by a spring member. As can be seen, the biasing member 168 (in this case, a retaining ring) includes a lip 170 capable of engaging a corresponding lip 172 of the actuating sleeve 122. As previously described, the hanger feed tool 110 can be positioned using electronic or hydraulic sensors. As the retaining ring 168 is movable between the radially inward and radially outward positions, the retaining ring 168 can effectively contract and then expand to engage with the lip 172 of the sleeve 122.

[0096] The pressure above the pressure sealing device can be increased to construct the anchoring device to the disconnected engagement position via the discharge conduit 136, which has been rerouted as described below.

[0097] Once engaged with the lip of the sleeve, the hanger feed tool 110 can be pulled upward (e.g., upward relative to the orientation in the figures) to complete the disconnection process between the pipe hanger 114 and the anchor point. The hanger feed tool 110 engages with the pipe hanger 114 via the hanger engagement member 156 before the pipe hanger 114 can be retracted from the borehole.

[0098] It should be noted that, in Figure 3 and Figure 4In this example, the first pressure conduit 134 and the second discharge conduit 136 have been rerouted such that they connect corresponding portions of the hanger engagement 126 (as described with respect to the previous figures) to the interior of the tubular member 112, which is in pressure and fluid communication with the central bore 130 of the feed tool 110. Therefore, the pressure inside the feed tool 110 can be increased to provide a pressure increase at the first pressure port 132 and the second pressure port 138, thereby moving the annular piston 154 downward and engaging the hanger engagement member 156 with the hanger 114. Thus, in this example, a dedicated fluid source may not be required to operate the feed tool 110, as the pressure inside the feed tool 110 (or, for example, the BOP) can be increased to move the piston 154 downward. To facilitate the downward movement of the annular piston 154, ports and streamlines 163 are illustrated in detail B of the retraction tool 110 to allow the discharge of the lower hydraulic chamber 148b. Similarly, the increased pressure inside the actuation chamber 140 causes the anchoring actuator 142 to move in the upward direction, and thus also helps to disengage the feed tool 110 from the hanger 114. A sealing device 174 is provided between the removable retraction module 166 and the anchoring actuator 142 to form a pressure-sealed actuation chamber 140, the pressure in which can be increased / decreased via the discharge conduit 138 (it should be noted that this sealing device may also be present in the tool 10 in the mounting configuration).

[0099] Although not illustrated, at least one (or both) of the first pressure conduit 134 and the second discharge conduit 136 may include features similar to those described above. Figure 1 The pilot valve described.

[0100] It should also be noted that when tool 110 is in the retracted configuration, sleeve 144 includes an additional sealing ring 144a, which isolates port 162 from the central bore 130. Therefore, when pressure increases are applied at ports 132 and 138, there will be no corresponding pressure increase at port 162. Sealing ring 144a can be a separate component, or it can be integrally formed with sleeve 144, or it can be a separate component. Sealing ring 144a can be connected to sleeve 144, for example, via a mating profile or a threaded profile.

[0101] Then, further upward movement of the pipe hanger 114 can have the effect of retracting the pipe hanger 114 from the wellbore. Having such a retraction module provides a direct way to retract the pipe hanger 114 without requiring complex positioning operations to retract it.

[0102] Those skilled in the art will recognize that this disclosure is not limited to the preferred embodiments described above. They will also recognize that modifications and variations can be made within the scope of the appended claims. Furthermore, through a study of the drawings, the disclosure, and the appended claims, those skilled in the art can understand and implement variations of the disclosed embodiments in practicing the claimed disclosure.

Claims

1. A hanger delivery tool (10) for installing a hanger in a well, the hanger delivery tool (10) comprising: Central hole (30); A suspension engagement device (26) is configured to be engaged between an engaged position and an unengaged position, wherein in the engaged position the suspension engagement device (26) is connected to the suspension (14), and in the unengaged position the suspension engagement device (26) is disconnected from the suspension (14). A pressure-controlled anchoring actuator (42) is used to actuate the anchoring device and includes an actuating surface (42a); the hanger engagement device (26) is configured to the engagement position in response to an increase in pressure at the first pressure source, and to the disengaged engagement position in response to an increase in pressure inside the central hole (30); and the anchoring actuator (42) is actuated in response to an increase in pressure on the actuating surface (42a), such that the anchoring device anchors the hanger (14) to the anchoring point.

2. The suspension feeder tool (10) according to claim 1, wherein, The suspension delivery tool (10) can be configured to be located inside at least one of the blowout preventer, the subsea tree, and the wellbore, and the anchoring actuator (42) can be configured to be actuated in response to an increase in pressure inside the blowout preventer, the subsea tree, or the wellbore, thereby causing an increase in pressure on the actuation surface (42a).

3. The suspension feeder tool (10) according to claim 1 or 2, wherein, The first pressure source is an external pressure source generated by a pump or compressor.

4. The suspension feeder tool (10) according to claim 1 or 2, wherein, The hanger engagement device (26) can be configured to disconnect from the first pressure source before the hanger insertion tool (10) is positioned in the well.

5. The hanger insertion tool (10) according to claim 1 or 2, wherein the hanger engagement device (26) and the anchoring actuator (42) are positioned outside the central hole (30) and around the periphery of the central hole (30).

6. The hanger insertion tool (10) according to claim 1 or 2, comprising a pressure sealing device configured to be positioned in the central bore (30) to enable pressure increase in the central bore (30) above the sealing object.

7. The suspension feeder tool (10) according to claim 6, wherein, The sealing object provides a first pressure region and a second pressure region in the central hole (30).

8. The hanger feeder tool (10) according to claim 1 or 2, comprising a valve (44) including a valve seat (46) located in the central bore (30), the valve (44) being capable of closing to increase the pressure inside the hanger feeder tool (10).

9. The suspension feeder tool (10) according to claim 8, wherein, The valve (44) is at least one of a ball valve or a valve actuated by an actuating object.

10. The suspension feeder tool (10) according to claim 8, wherein, The valve (44) can be removed from the hanger by the feeding tool (10).

11. The suspension feeder tool (10) according to claim 1 or 2, wherein, The suspension engagement device (26) includes an actuator that can be configured to be in pressure communication with a first pressure source and to be in pressure communication with the central hole (30).

12. The suspension feeder tool (10) according to claim 1 or 2, wherein, The suspension engagement device (26) includes an actuator (55) having a first pressure inlet and a second pressure inlet, the first pressure inlet being configured to communicate with the first pressure source via a first pressure conduit (34), and the second pressure inlet communicating with the pressure in the central hole via a bore pressure channel (62).

13. The suspension feeder tool (10) according to claim 1 or 2, wherein, The suspension engagement device (26) includes an actuator (55) comprising a piston housed in a hydraulic chamber assembly (48) divided into an upper hydraulic chamber (48a) and a lower hydraulic chamber (48b), wherein the first pressure source and the central bore (30) are configured to be in pressure communication with the hydraulic chambers (48a, 48b) of the hydraulic chamber assembly (48).

14. The suspension feeder tool (10) according to claim 13, wherein, The first pressure source is configured to be in pressure communication with the upper hydraulic chamber (48a) located at the upper end of the hydraulic chamber device (48), and the central hole is configured to be in pressure communication with the lower hydraulic chamber (48b) located at the lower end of the hydraulic chamber device (48), such that the pressure from the first pressure source increases to move the piston in a first direction, and the pressure from the central hole (30) increases to move the piston in a second direction.

15. The suspension feeder tool (10) according to claim 1 or 2, wherein, The anchoring actuator (42) is in the form of an annular piston.

16. The suspension feeder tool (10) according to claim 1 or 2, wherein, The anchoring device includes an anchoring engagement profile, and the anchoring actuator (42) is configured to operate the anchoring device as an engagement anchor point.

17. The hanger delivery tool (10) according to claim 1 or 2, comprising a locking device (60) configured to lock the hanger engagement device (26) in the engagement position.

18. The suspension feeder tool (10) according to claim 1 or 2, wherein, The hanger delivery tool (10) is configured to retrieve the hanger (14) from the well.

19. The hanger feeding tool (10) according to claim 18, comprising a removable retraction module (166) for engaging the hanger feeding tool (10) with the hanger (14) for retraction, the removable retraction module (166) comprising a retraction profile (170) for engaging the hanger (14) for retraction.

20. The suspension feeder tool (10) according to claim 1 or 2, wherein, The central hole (30) can be configured to allow a retractable plug to be inserted through the central hole (30).

21. A method for installing a hanger (14) in a well, the method comprising: A hanger insertion tool (10) is provided, the hanger insertion tool (10) including a central hole (30), a hanger engagement device (26) and an anchoring actuator (42) for actuating the anchoring device. By providing increased pressure at the first pressure source to configure the hanger engagement device (26) into engagement configuration, the hanger is fed into the tool (10) and engaged with the hanger (14). Position the hanger (14) and the hanger insertion tool (10) in the well at the desired location; The anchoring actuator (42) is actuated by providing an increase in pressure in the well to engage the anchoring device with the anchoring point, and the hanger (14) is engaged with the anchoring point; By providing an increase in pressure in the central hole (30) to configure the hanger engagement device (26) to a disengaged configuration, the hanger feed tool (10) disengages the hanger (14) from the hanger; as well as The hanger is sent into the tool (10) and retrieved from the well.

22. The method according to claim 21, wherein, The desired location in the well is at least one of the desired location inside the blowout preventer, the desired location inside the subsea tree, and the desired location inside the wellbore.

23. The method according to claim 21 or 22, further comprising providing a valve seat (46) in the central orifice (30), and positioning an actuating object in the valve seat (46) to restrict fluid flow through the valve seat (46) and provide a pressure increase in the central orifice (30).

24. The method according to claim 21 or 22, comprising increasing the pressure in the well to move the anchoring actuator (42) from a first position to a second position, thereby engaging the anchoring device with the anchoring point.

25. The method according to claim 21 or 22, comprising feeding a tool (10) to the hanger to attach a removable retrieval module (166), and retrieving the hanger (14) from the well by attaching the removable retrieval module (166) to the hanger (14).

26. The method of claim 25, further comprising reconfiguring the hanger delivery tool (10) for retrieving the hanger (14) from the well, such that the first pressure source is the pressure inside the central borehole (30).

27. The method according to claim 21 or 22, comprising installing the retractable plug in the well by inserting the retractable plug through the central hole (30) of the hanger insertion tool (10).

28. The method of claim 27, comprising performing well cleaning operations prior to the installation of the retractable plug.

29. The method according to claim 23, wherein, The launching object is a ball or a dart.

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