CN117365360A - Double-setting tail pipe running tool - Google Patents

Abstract

The invention relates to a running tool of a tail pipe string, which can be used for hanging a tail pipe on another pipe string in a well bore, and is expanded through slips and set on the well bore to realize hanging of the tail pipe. The technical proposal is as follows: the double-setting tail pipe running tool mainly comprises: the device comprises a connector, a valve sleeve, an execution setting device, a running tool, a setting device, an upper pipe, a middle pipe, a lower pipe, a bypass, an outer light pipe, a tail pipe, a setting device and a tail pipe hanger. The pipe barrel is connected to the connector through a bolt, the outer light pipe is connected with the connector through a claw, the outer light pipe, the outer sleeve and the slips are sequentially connected in a threaded mode, and the cone is connected with the fixed sleeve, the expansion cone and the slope, the slip assembly and the movable sleeve through threads. The sleeve is releasably connected to the adapter sleeve by the shearable pin, the adapter sleeve is releasably connected to the outer light pipe by the pawl, and the sleeve is releasably connected to the barrel by the shearable pin. The upper pipe, the lower tool, the middle pipe and the lower pipe are connected through bolts in sequence.

Description

Double-setting tail pipe running tool

Technical Field

The invention mainly relates to a running tool for a casing series, belonging to a well completion matching device for petroleum and natural gas.

Background

A Liner hanger (Liner hanger) is used to hang the Liner from another string in the wellbore. Conventional hydraulic liner hangers activate when a pressure threshold is exceeded, causing the slips to expand, setting. The tailpipe string is long and there may be bends and corners in the wellbore. During the launch, it may be desirable to increase the circulation of fluid in the liner string to pass smoothly over the bend or corner. The increased fluid circulation in the liner string may inadvertently activate the liner hanger above the set position. The inadvertent setting of the liner hanger results in the need to remove the liner string to allow subsequent wellbore operations.

There is a need for a liner hanger running tool to prevent premature liner hanger start-up.

Disclosure of Invention

The invention includes a running tool for a liner string. The double-setting tail pipe running tool mainly comprises: the device comprises a connector, a valve sleeve, an execution setting device, a running tool, a setting device, an upper pipeline, a middle pipeline, a lower pipeline, a bypass, an outer light pipe, a tail pipe, a setting device and a tail pipe hanger.

In one embodiment, the liner string includes a liner hanger assembly (liner hanger assembly) and a liner hanger deployment assembly (liner hanger running assembly) that is connectable to the liner hanger assembly. The liner hanging run assembly includes a central bore and a running tool movable from a locked position to an unlocked position, the running tool including a flow path in communication with the central bore. The liner string further includes a chamber located between the liner hanger running assembly and the liner hanger assembly, wherein the chamber is in selective fluid communication with the flow passage. When the flow passage is closed, the chamber is isolated from the central bore, and when the flow passage is open, fluid communication is established between the central bore and the chamber through the flow passage.

In one embodiment, a liner string suspended from a wellbore includes a liner suspension assembly and a liner suspension run assembly. The liner hanger operation assembly includes a running tool coupled to the liner hanger assembly in a locked position and released from the liner hanger assembly in an unlocked position. The running tool includes a tubular body having an aperture, a body sleeve disposed about the tubular body, a shearable member having a flow passage, and a closure member, wherein the closure member prevents fluid communication between the flow passage and the aperture, and a first sleeve movable from a closed position to an open position to remove the closure member to expose the flow passage. The liner string further includes a chamber formed between the liner hanger assembly and the liner hanger running assembly, the chamber being isolated from fluid communication with the bore when the first sleeve is in the closed position and the running tool is in the unlocked position.

In one embodiment, a method of operating a liner string includes deploying a liner string including a liner hanger running assembly connected to a liner hanger assembly into a wellbore, wherein a chamber is provided between the liner hanger running assembly and the liner hanger assembly and isolated from a central bore of the liner hanger running assembly. The method further includes operating a running tool of the liner hanging run assembly to open a flow path between the chamber and the central bore. The method further includes increasing pressure within the chamber after the running tool is activated to set a liner hanger of the liner hanger assembly.

Drawings

So that the manner in which the above recited features of the present disclosure can be understood in detail, a more particular description of the invention, briefly summarized above, may be had by reference to embodiments, some of which are illustrated in the appended drawings. It is to be noted, however, that the appended drawings illustrate only example embodiments, and are therefore not considered limiting of its scope, for other equally effective embodiments may exist.

In the figure: 1-center bore, 2-barrel, 3-valve body, 4-valve sleeve, 5-chamber, 6-connector, 7-shearable pin, 9-groove, 10-tailpipe string, 11-dog, 12-port, 14-inner seal, 17-sleeve, 18-buckle, 20-tailpipe hanging run assembly, 21-adapter sleeve, 22-upper tube, 24-middle tube, 26-lower tube, 27-barrel, 27 a-buckle, 28-run-out seat, 29-barrel, 30-tailpipe hanging assembly, 31-running tool, 32-outer light tube, 33-seal ring, 34-port, 35-valve seat, 37-valve seat sleeve, 40-shearable plug, 41-groove, 42-dog, 43-shear ring 44-shearable pin, 45-sleeve, 45 c-seat, 46-outer sleeve, 47-barrel, 48-shearable pin, 49-setting, 50-seal, 51-setting assembly, 52-valve body, 53-shearable pin, 54-slip, 55-cone, 56-shearable pin, 57-fixed sleeve, 58-resilient jaw, 59-expansion cone, 60-barrel, 61-liner hanger, 63-stop collar 2, 64-sealing washer 2, 67-sealing washer 1, 68-movable sleeve, 69-slip drive assembly, 70-shearable pin, 71-fixed member, 72-seal, 73-ramp, 74-slip, 75-slip assembly, 76-stop collar 1, 77-seal stack, 78-seal ring, 79-bypass.

FIG. 1 is a schematic diagram of a dual setting liner running tool according to the present invention.

Fig. 2 is a schematic structural view of a connection sleeve in a dual setting liner running tool according to the present invention.

FIG. 3 is a schematic view of the valve seat cover of the dual setting tailpipe running tool of the present invention.

FIG. 4 is an enlarged view of a portion of a second stage slip and setting member of a dual setting liner running tool of the present invention.

FIG. 5 is an enlarged view of a portion of a first stage slip in a dual setting liner running tool according to the present invention.

Detailed Description

The liner string 10 includes a liner hanger running assembly 20 and a liner hanger assembly 30, with the liner hanger running assembly 20 being located within the liner hanger assembly 30. The liner hanging run assembly 20 may be connected to a liner hanging assembly 30. After the liner string 10 is run into the wellbore, the liner hanger running assembly 20 is released from the liner hanger assembly 30 to retrieve the liner hanger running assembly 20 to the surface while the liner hanger assembly 30 remains in the wellbore.

Liner hanging run assembly 20 may include a connector 6, a valve housing 4, an actuating setting tool 28, a running tool 31, a setting tool 49, an upper conduit 22, a middle conduit 24, a lower conduit 26, and a bypass 79. The liner hanging run assembly 20 has a central bore 1. The upper pipe 22 is connected at one end to a string suspended above the surface and at the other end to a running tool 31. The middle pipe 24 is connected at one end to the running tool 31 and at the other end to one end of the lower pipe 26.

The liner hanger assembly 30 includes an outer light pipe 32, a liner, a setting tool 49 and a liner hanger 61. A chamber 5 is formed between the liner hanging run assembly 20 and the liner hanging run assembly 30. When running the liner string 10, the liner hanging run assembly 20 is placed into the liner hanging assembly 30. The liner hanging run assembly 20 is connected to the liner hanging assembly 30 by engagement of the connector 6 with the outer light pipe 32, the running tool 31 and the liner hanging assembly 30. The chamber 5 is isolated from the annulus around the central bore 1 of the liner string 10 and liner hanging run assembly 20. During run-in, circulation of the tailpipe string 10 may be increased to facilitate passage of the tailpipe string 10 through deviated wells and turns in the wellbore. The running tool 31 may prevent premature activation of the liner hanger 61 during running of the liner string 10. After completion of running the liner string 10, the running tool 31 is activated, allowing fluid communication between the central wellbore 1 and the chamber 5. Once fluid communication between the central wellbore 1 and the chamber 5 is established, the liner hanger 61 may respond by reaching a pressure threshold.

The connector 6 and valve housing 4 are shown in fig. 1. The connector 6 connects the liner hanging run assembly 20 to the upper end of the outer light pipe 32. The connector 6 may comprise a barrel 2, a jaw 11, a sleeve 17 and a shear pin 7. The barrel 2 may be a unitary component or may be formed of multiple parts. An upper conduit 22 is provided in the bore 16, the barrel 2 having a first shoulder 25, a second shoulder 8, a connection sleeve 21, a third shoulder 23 and a flow port 12. The second shoulder 8 is near the end of the outer light pipe 32. The flow port 12 allows fluid communication between the wellbore and the bore 16 above the valve sleeve 4.

The jaws 11 are arranged in the respective openings as shown in fig. 1. When in the radially extended position, the jaws 11 are partially disposed in the opening of the outer light pipe 32 and the corresponding recess 9. When the dogs 11 are in the radially expanded position, the connector 6 and liner hanging run assembly 20 are connected to the outer light pipe 32. The dogs 11 are movable to a radially retracted position releasing the connector 6 from the outer light pipe 32 thereby unlocking the liner hanging run assembly 20 from the outer light pipe 32.

The sleeve 17 is arranged in the hole 16 and is held in the first position by the shearable pin 7. The sleeve 17 may comprise a bayonet 18, a groove 19. In the first position, the socket 17 holds the jaws 11 in a radially extended position. When the sleeve 17 is in the second position, the recess 19 is located immediately adjacent the catch 11 to allow the catch 11 to be released from the outer light pipe 32.

The valve sleeve 4 is arranged in a bore 16 of the connector 6, the valve sleeve 4 may comprise a valve body 3, an outer seal and an inner seal 14. The external seal seals against the inner surface of the barrel 2. The inner seal 14 seals against the outer surface of the upper conduit 22. The valve sleeve 4 is movable relative to said upper conduit 22 and the connector 6. The valve sleeve 4 has an upper piston area 13 and a lower piston area 15. The upper piston area 13 is in fluid communication with the wellbore via a flow port 12 and the lower piston area 15 is in fluid communication with the chamber 5.

The construction of the connecting sleeve 21 is shown in fig. 2. The connecting sleeve 21 is connected with the sleeve 2 through bolts, and is releasably connected with the polishing tube 32 through the claw 11. The force can be transferred to the polishing tube 32 by the second shoulder 8, when the retaining ring 18 and the catch 27a are engaged, exerting force, shearing the shearable pin 7, the sleeve 17 moving from the first position to the second position, the jaws 11 falling into the grooves 19, the connecting sleeve 21 being disconnected from the polishing tube 32, and being able to be lifted from the polishing tube 32. The sleeve 17 engages the third shoulder 23 of the connecting sleeve 21 and the force is transmitted to the sleeve 17 and, through the second shoulder 8, to the polishing tube 32. The connection sleeve 21 is configured to transfer force to the polishing tube 32 to set the setting tool 49 and to unlock the polishing tube 32, thereby leaving the liner string 10 in the wellbore.

Setting tool 28 and running tool 31 are performed as shown in fig. 1. The implement setting device 28 comprises a barrel 27 provided with a catch 27a at one end, the implement setting device 28 being connectable to the upper pipe 22. When the liner hanging run assembly 20 is lifted relative to the liner hanging assembly 30, the setting tool 28 engages the sleeve 17 and the catch 27a engages the setting ring 18. Once the catch 27a is engaged with the setting ring 18, a force (e.g., weight) may be applied to the liner hanging run assembly 20 to move the sleeve 17 to the second position. The force is transferred from the second shoulder 8 to the outer light pipe 32, which helps drive the setting tool 49. The setting device 49 and its actuation will be described in more detail below.

A structural diagram of the running tool 31 is shown in fig. 1. The running tool 31 is shown in the locked position. Running tool 31 may include barrel 29, sleeve 45, valve seat sleeve 37, shearable plug 40, jaws 42. The tube 29 may be a single piece or may be made of multiple parts. The barrel 29 has a stop surface 36, an opening, a port 38. A sleeve 45 is disposed around the barrel 29. Sleeve 45 may include shear ring 43, base 47c, and threads. Sleeve 45 may be a unitary component or may be made of multiple parts. A shearable pin 44 connects the barrel 29 to a valve body sleeve 45. The barrel 29 and valve body sleeve 45 also include flow ports 34, with an annulus 5b between the running tool 31 and the outer light pipe 32, and between the running tool 31 and the barrel 29 of the setting tool 49.

Valve seat cover structure as shown in fig. 3, a valve seat cover 37 is provided in the central bore 1. The valve seat cover 37 may include a valve seat 35, a groove 41, and a groove 38. The valve seat sleeve 37 is held in the closed position by a shearable plug 40. The shearable plugs 40 are partially disposed in the respective ports 40 and grooves 38. One or more seals 33 may be provided between the valve seat sleeve 37 and the barrel 29. In some embodiments, the seal rings 33 have the same diameter so that the valve seat cover 37 is pressure balanced. When the valve seat cover 37 is in the closed position, the jaws 42 are in a radially extended position, as shown in fig. 2. The position of the recess 41 is such that the catch 42 can return to the radially contracted position when the valve seat cover 37 is in the open position.

The shearable plug 40 may have threads 82, a flow bore 81, and a shear head 83. Threads 82 correspond to threads of port 39. Each shearable plug 40 is partially disposed in the port 39 and recess 38 to lock the valve seat cover 37 in the closed position, and the shear head 83 is partially disposed in the recess 38. Fluid communication between the central bore 1 and the chamber 5 is blocked by the shearable plug 40 before the valve seat 37 is actuated from the closed position to the open position. The shearable plug 40 is configured to apply sufficient pressure to shear off the shearing head 83 of the shearable plug 40 to open the flowbore 81. When the valve seat cover 37 is driven to move from the closed position to the open position, the shearing head 83 may be sheared off by the valve seat cover 37. The groove 38 may receive a sheared shear head 83 to prevent the sheared portion from falling downhole. Once the flow aperture 81 is opened, a flow path exists between the central aperture 1 and the chamber 5.

The running tool 31 is movable from a first position to a second position. A force is applied to the barrel 29 to shear the shearable pin 44, the barrel 29 moving axially relative to the sleeve 45. Axial movement of the barrel 29 relative to the sleeve 45 causes the flow bore of the shearable plug 40 to move axially to block the flow bore and the running tool 31 is in the second position when the flow bore is blocked.

As shown in fig. 1, the jaws 42 engage the shear ring 43 in the radially extended position. The shear ring 43 and the jaws 42 help to prevent unintentional shearing of the shearable pins 44. During running, the liner hanging run assembly 30 may briefly contact the casing or wellbore wall, and thus additional force may need to be applied to the liner hanging run assembly 20 to continue downhole movement of the liner string 10. The additional force applied to the liner hanging run assembly 20 may exceed the shear strength of the shearable pins 44. Engagement of the dogs 42 with the shear ring 43 allows force to be transferred from the barrel 29 to the sleeve 45 and then to the liner hanger assembly 30 via the engaged teeth 45c, 47c. When the sleeve 40 is in the second position, the jaws 42 are allowed to disengage the shear ring 43, allowing the force applied to the liner hanging run assembly 20 to shear the shearable pin 44.

An unset position of the setting device 49 is shown in fig. 1, for example, with the setting device 49 being mechanically actuated. The setting tool 49 includes a casing 47, an outer sleeve 46, a plurality of slips 54, a cone 55, a set sleeve 57, a setting assembly 51, and an expansion cone 59. The sleeve 47 includes an opening 50 and 47c at one end corresponding to the tooth 45 c. The sleeve 47 may be a unitary component or may be made of multiple parts, with the sleeve 47 including corresponding threads of the nut 49. Cone 55 and expansion cone 59 are connected to casing 47. A sleeve 47 is provided in the outer sleeve 46. The outer sleeve 46 may be a unitary member or may be formed of multiple sections.

A fixing sleeve 57 is provided around the sleeve 47. The fixed sleeve 57 is held in the first position by a shearable pin 56, the fixed sleeve 57 comprising a resilient jaw 58 at one end. The setting assembly 51 is connected to the fixed sleeve 57 by means of resilient fingers 58, the setting assembly 51 having a valve body 52 and a seal 50. The setting assembly 51 moves along the expansion cone 59 expanding from a radially contracted position to a radially expanded position in response to mechanical power. When the setting assembly 51 is in the radially expanded position, it is in sealing engagement with the inner surface of the casing or wellbore in which the liner string 10 is located.

Slips 54 are provided at one end of the outer sleeve 46. The outer sleeve 46 is initially held in the first position by the shearable pins 53. As shown in fig. 1, the slips 54 are shown in a radially contracted position. The slips 54 move along the cone 55 from a radially contracted position to a radially extended position in response to mechanical power. The outer sleeve 46 and slips 54 apply sufficient force to the cone 55 to shear the shearable pins 56 and move the setting sleeve 57 to the second position to radially expand the setting assembly 51 before the slips 54 move along the cone 55 to the radially extended position.

To actuate the setting tool 49, the liner hanging run assembly 20 is lifted, engaging the run setting tool 28 with the sleeve 17. When a force (e.g., weight) is applied to the liner hanging run assembly 20, the sleeve 17 moves to the second position releasing the dogs 11 and transmitting the force from the second shoulder 8 to the upper end of the outer light pipe 32. The force exerted on the outer light pipe 32 is transferred to the outer sleeve 46. After shearing of the shearable pins 53, the outer sleeve 46 moves relative to the sleeve 47. The outer sleeve 46 and slips 54 contact the cone 55, shearing the shearable pins 48 to allow the cone 55 to move relative to the casing 47. Once the shearable pin 48 shears, the driving force causes the fixed sleeve 57 to shear the shearable pin 56 to allow the fixed sleeve 57 to move relative to the sleeve 47. The outer sleeve 46, slips 54, cone 55 and set sleeve 57 move relative to the casing 47, pushing the setting assembly 51 along the expansion cone 59 until the setting assembly 51 is in the radially expanded position. Once the setting assembly 51 is in the radially expanded position, the force applied to the casing 47 moves the slips 54 along the cone 55 into engagement with the inner surface of the casing or wellbore. Once the slips 54 are in contact with the wellbore or casing, the setters 49 are in a fixed set position.

An enlarged view of a portion of the second stage slip and setting assembly is shown in fig. 4. The setting member 51 is comprised of a valve body 52 and a seal 50, with the seal 50 contacting the inner wall of the wellbore when the setting member 51 is in the radially expanded position, thereby achieving a sealing effect. Once the setting assembly 51 is in the radially expanded position, the slips 54 are moved along the cone 55 to the radially expanded position, where the slips 54 contact the inner wall of the wellbore, completing the setting. Once the slips 54 and setting member 51 are in contact with the inner wellbore wall, the dual setting liner hanging tool completes the second stage setting.

Fig. 1 shows an example of a liner hanger 61 in an unset position. The liner hanger 61 may include a casing 60, a slip assembly 75, and a slip drive assembly 69. The casing 60 defines a central bore 62 of the liner hanger 61 and includes a port 66, and the liner hanger 61 may have a plurality of ports 66. The slip assembly 75 may include a ramp 73 and a plurality of slips 74, the slips 74 traveling along the slope of the ramp 73 connected to the casing 60. The slip drive assembly 69 includes a movable sleeve 68, stop collar 2 63, stationary member 71, shearable pin 70, and movable chamber 65 disposed between seal washer 1 67 and seal washer 2 64.

The securing member 71 is connected to the sleeve 60, such as by a plurality of fasteners. The movable sleeve 68 is connected at one end to the stop collar 2 63. The sealing gasket 2 64 is coupled with a movable sleeve 68. The movable sleeve 68 is releasably connected to the stationary member 71 by a shearable pin 70. In some embodiments, the shearable plugs 40 may be configured to shear at a lower pressure than that required by the shearable members 70. A sealing gasket 1 67 is disposed between the sleeve 60 and a movable sleeve 68, the sealing gasket 1 67 being in contact with the outer surface of the sleeve 60, the movable chamber 65 being in fluid communication with the port 66.

As shown in fig. 5, which is an enlarged view of a portion of the first stage slip, to set the slips 74, pressure is increased in the movable chamber 65 until the force applied to the movable head 68d of the movable casing 68 is sufficient to shear the shearable pins 70. The movable sleeve 68, sealing washer 2 64 and stop collar 2 63 then move relative to the sleeve 60 in response to the fluid in the movable chamber 65 until the thrust member 63 engages the stop collar 1 76. Once engaged, the stop collar 1 76 moves in response to continued movement of the stop collar 2 63 and the movable casing 68 until the slips 74 engage the casing or wellbore inner surface along the ramp 73, the dual setting liner running tool completes the first stage setting. In some embodiments, the pressure required to shear one shearable member 70 corresponds to the pressure required to shear shearable plugs 40.

FIG. 1 illustrates an exemplary embodiment of bypass 79. As shown in fig. 1, bypass 79 is located in a position below sealer 72. When liner hanging run assembly 20 is lifted relative to liner hanging assembly 30 such that performance setting tool 28 engages sleeve 17, bypass 79 is located adjacent to seal stack 77 of seal 72. When bypass 79 is located adjacent to seal stack 77, seal stack 77 cannot seal against the outer surface of lower tube 26. Thus, when bypass 79 is located near seal stack 77, fluid is allowed to flow around seal stack 77. When bypass 79 is located near seal stack 77, chamber 5 is not fluidly isolated from the wellbore.

Bypass 79 may be a longitudinally running slot formed in lower tube 26. The grooves are of sufficient length and depth to prevent the seal stack 77 from sealing against the down tube 26 when adjacent thereto. Alternatively, the bypass 79 is designed to be one flow path in the third tube 26, with two openings of the flow paths being located on either side of the seal stack 77 when the bypass 79 is adjacent to the seal stack 77.

When the liner hanging run assembly 20 is raised to engage the run set 28 with the sleeve 17, the bypass 79 is located adjacent to the seal stack 77. When the liner hanging run assembly 20 is lifted to move the seal 72 to the unlocked position, the bypass 800 is also located adjacent the seal stack 77.

The chamber 5 is shown in fig. 1. The chamber 5 is part of the annulus between the liner hanging run assembly 20 and the liner hanging run assembly 30. As shown in fig. 1, the upper end of the chamber 5 is bounded by the engagement of the outer seal with the tubular body 3 and the engagement of the inner seal 14 with the upper tube 22. As shown in fig. 1, the lower end of the chamber 5 is bounded by the engagement of the seal ring 78 with the inner surface of the sleeve 60 and the engagement of the seal stack 77 with the outer surface of the down tube 26. The additional seal between the interconnected components of the liner hanging run assembly 20 and the liner hanging run assembly 30 prevents fluid flow between the chamber 5 and the outer annulus of the liner string 10 and the central bore 1 of the liner hanging run assembly 20.

As shown in fig. 1, the chamber 5 includes an annulus 5a between the connector 6 and the upper tubular 22 and between the outer light pipe 32 and the upper tubular 22, and the chamber 5 includes an annulus 5b. The flow port 37 facilitates fluid communication between the upper and lower portions of the chamber 5, which are positioned above and below the running tool 31. The chamber includes an annulus 7c between the setting tool 49 and the middle tube 24 and the chamber 5 includes an annulus 5d between the middle tube 24, the lower tube 26 and the liner hanger 61.

The chamber 5 may be filled with a fluid at a selected pressure, for example water at atmospheric pressure. The valve sleeve 4 is movable relative to the connector 6 and floats on the fluid in the chamber 5. The valve sleeve 4 may be moved in or down the well depending on the volume change of the fluid in the chamber 5 due to environmental thermal effects or hydrostatic effects of the wellbore fluid acting on the piston areas 13, 15 of the valve sleeve 4. The fluid pressure in the chamber 5 is equal to the wellbore fluid pressure because the valve sleeve 4 floats on the fluid in the chamber 5 and moves in response to the forces acting on the piston areas 13, 15. The uniform pressure in the chamber 5 prevents the liner suspension assembly 30 from collapsing due to wellbore fluid pressure.

During run in, the chamber 5 is isolated from the outer annulus of the liner string 10 and the central bore 1 of the liner hanger running assembly 20 to prevent inadvertent activation of the liner hanger 61. To actuate liner hanger 61, the running tool 31 is actuated to communicate fluid between the central bore 1 and the chamber 5 by shearing the shearable plug 40 to expose the flow bore. When the running tool 31 is released from the setting tool 49, the tubular body 29 has moved relative to the valve body sleeve 45 so that the flowbore is sealingly surrounded. Thus, the chamber 5 is re-isolated from the central bore 1. When liner hanging run assembly 20 is lifted relative to liner hanging assembly 30 such that run setting tool 28 engages sleeve 17, bypass 79 is moved into the well and positioned adjacent seal stack 77 to establish fluid communication between chamber 5 and wellbore fluid to facilitate actuation of setting tool 49.

Once the liner string reaches the setting depth, an object (e.g., a ball or dart) may be lowered into the central wellbore from the surface. The object passes through the central bore 1 until it engages the valve seat 35. Pressure is increased over the object engaged with the valve seat 35 until the shearable plugs 40 shear and the valve seat sleeve 37 moves to the open position. Once the shearable plugs 40 are sheared, the flow holes are exposed for fluid communication between the central bore 1, the chambers 5 and the movable chambers 65. The fluid pressure is further increased above the object until the pressure on the movable head 68d of the movable sleeve 68 is sufficient to shear the one or more shearable pins 70 and move the slips 74 into engagement with the wellbore, and then setting the liner hanger 61. Installation of the liner hanger 61 causes the valve sleeve 4 to be displaced. After setting the liner hanger 61, the running tool 31 is released from the liner hanger assembly 30. The object may be removed from the valve seat 35 before, during or after releasing the running tool 31.

After the running tool 31 is released from the liner hanger assembly 30, the cementing operation may begin to fix the liner in the wellbore. Fluid, such as mud, may be circulated through the central bore 1 and up the annulus between the wellbore and the liner string 10 to condition the wellbore fluid prior to introducing the fluid with the mud into the central bore 1. An additional object, which may be a dart or a ball, for example, for separating the fluid portions, may be placed in the central bore 1.

Once the cementing operation is completed, the setting tool 49 may be set. To set the setting tool 49, the liner hanging run assembly 20 is lifted, engaging the run setting tool 28 with the sleeve 17. When the liner hanging run assembly 20 is raised, the first pipe 22 moves relative to the connector 6. An actuating setting device 28 is located adjacent the sleeve 17, the clasp 27a being disposed in a bore which interfaces with the clasp 18. The connector 6 remains connected to the outer light pipe 32. The running tool 31 is axially displaced relative to the setting device 49, the stop surface 36 of the running tool 31 engaging the first shoulder 25. The third tube 26 with bypass 79 moves axially relative to the sealer 72. Bypass 79 is located adjacent to seal stack 77 to allow fluid to flow around seal stack 77. Thus, the chamber 5 is placed in fluid communication with the wellbore.

Once the setting tool 28 is raised above the setting ring 18, a force (e.g., weight) may be applied to the liner hanging run assembly 20. The catch 27a engages the retaining ring 18 to transfer the force applied to the liner hanging run assembly 20 to the sleeve 17. The force shears the one or more shearable members 7 allowing the sleeve 17 to move from the first position to the second position. The groove 19 is adjacent to the jaw 11 allowing the jaw 11 to move to the radially retracted position. Once the jaws 11 are no longer in the radially extended position, the connector 6 is released from the outer light pipe 32 and the sleeve 17 is also in contact with the third shoulder 23. Once the sleeve 17 is also engaged with the third shoulder 23, the force applied to the liner hanging run assembly 20 from the surface is transferred to the outer light pipe 32 through the second shoulder 8. As described above, the force exerted on the outer light pipe 32 may mechanically drive the setting device 49.

After setting the setting tool 49, the liner hanging run assembly 20 may be removed from the liner hanging run assembly 30. When liner hanging run assembly 20 is removed from liner hanging assembly 30, bypass 79 is located adjacent seal stack 77 and shoulder 80 contacts seal 72, leaving seal 72 in the disengaged position. Seal bypass 79 allows fluid in chamber 5 above seal 72 to drain as seal 72 moves into the well. The sealer 72 is then disengaged from the liner hanger running assembly 30 while continuing to remove the liner hanger running assembly 20.

Claims (7)

1. A double-setting tail pipe running tool mainly comprises the following structure: a pipe barrel (2), a liner suspension deployment assembly (20), a liner suspension assembly (30), a slip drive assembly (69), a sealer (72); liner hanging assembly (30) comprises: an outer light pipe (32), a tailpipe, a setting tool (49) and a tailpipe hanger (61); the liner hanger deployment assembly (20) includes: a connector (6), a valve sleeve (4), an execution setting device (28), a running tool (31), a setting device (49), an upper pipe (22), a middle pipe (24), a lower pipe (26) and a bypass (79); the connector (6) comprises a claw (11), a sleeve (17), a retaining ring (18) and a shearing pin (7); executing the setting tool (28) includes: a buckle (27 a) and a tube (27); the running tool (31) comprises: the valve comprises a pipe barrel (29), a flow port (34), a valve seat (35), a valve seat sleeve (37), a shearable plug (40) and a shearing ring (43); the setting device (49) comprises: an outer sleeve (46), a tube (47), a sealing piece (50), a valve body (52), slips (54), a cone (55), a fixed sleeve (57) and an expansion cone (59); the liner hanger (61) comprises: the pipe barrel (60), the limit sleeve 1 (76), the limit sleeve 2 (63), the sealing gasket 1 (67), the sealing gasket 2 (64), the movable sleeve (68), the fixed component (71), the slope (73) and the slips (74). The pipe barrel (2) is connected to the connector (6) through bolts, the outer light pipe (32) is connected with the connector (6) through clamping jaws, the outer light pipe (32), the outer sleeve (46) and the slips (54) are sequentially connected in a threaded mode, and the cone (55) is connected with the fixed sleeve (57), the expansion cone (59) is connected with the slope (73) through threads, and the slips assembly (75) is connected with the movable sleeve (68) through threads. The sleeve (17) is releasably connected to the connection sleeve (21) by a shearable pin, the connection sleeve (21) is releasably connected to the outer light pipe (32) by a claw (11), and the sleeve (45) is releasably connected to the barrel (29) by a shearable pin (44). The upper pipe (22), the lower tool (31), the middle pipe (24) and the lower pipe (26) are connected through bolts in sequence. The working principle of the device is as follows: once the liner string reaches the setting depth, an object (e.g., a ball or dart) may be lowered into the central wellbore from the surface. The object passes through the central bore (1) until it engages the valve seat (35). Pressure is increased over an object engaged with the valve seat (35) until the shearable plug (40) shears and the valve seat sleeve (37) moves to an open position. Once the shearable plug (40) is sheared, the flow bore is exposed for fluid communication between the central bore (1), the chamber (5) and the movable chamber (65). The fluid pressure is further increased above the object until the pressure on the movable head (68 d) of the movable casing (68) is sufficient to shear the one or more shearable pins (70) and move the slips (74) into engagement with the wellbore, and then setting the liner hanger (61). Installing the liner hanger (61) causes the valve sleeve (4) to be displaced. After setting the liner hanger (61), the running tool (31) is released from the liner hanger assembly (30). The object may be removed from the valve seat (35) before, during or after releasing the running tool (31). After the running tool (31) is released from the liner hanger assembly (30), the cementing operation may begin to fix the liner in the wellbore. Fluid, such as mud, may be circulated through the central bore (1) and up the annulus between the wellbore and the liner string (10) to condition the wellbore fluid prior to introducing the fluid with the mud into the central bore (1). An additional object, which may be a dart or a ball, for example, for separating a fluid portion, may be placed in the central hole (1). Once the cementing operation is completed, the setting tool (49) may be set. To set the setting tool (49), the liner hanging run assembly (20) is lifted, engaging the setting tool (28) with the sleeve (17). When the liner hanging run assembly (20) is raised, the first pipe (22) moves relative to the connector (6). An actuating setting device (49) is located adjacent the sleeve (17), and the clasp (27 a) is disposed in a bore that interfaces with the clasp (18). The connector (6) is still connected to the outer light pipe (32). The running tool (31) is axially displaced relative to the setting device (49), and a stop surface (36) of the running tool (31) engages the first shoulder (25). A third tube (26) having a bypass (79) is axially movable relative to the sealer (72). A bypass (79) is located adjacent the seal stack (77) to allow fluid flow around the seal stack (77). Thus, the chamber (5) is placed in fluid communication with the wellbore. Once the setting tool (28) is raised above the setting ring (18), a force (e.g., weight) may be applied to the liner hanging run assembly (20). The clasp (27 a) engages the buckle ring (18) to transfer the force applied to the liner hanging run assembly (20) to the sleeve (17). The force shears one or more shearable members (7) allowing the sleeve (17) to move from a first position to a second position. The groove (19) is adjacent to the jaws (11) allowing the jaws (11) to move to a radially retracted position. Once the jaws (11) are no longer in the radially extended position, the connector (6) is released from the outer light pipe (32) and the sleeve (17) is also in contact with the third shoulder (23). Once the sleeve (17) is also engaged with the third shoulder (23), the force applied to the liner hanging run assembly (20) from the surface is transferred to the polishing tube (32) through the second shoulder (8). As described above, the force exerted on the outer light pipe (32) may mechanically drive the setting tool (49). After setting the setting tool (49), the liner hanging and running assembly (20) can be removed from the liner hanging and running assembly (30). When the liner hanger running assembly (20) is disengaged from the liner hanger assembly (30), the bypass (79) is positioned adjacent the seal stack (77) and the shoulder (80) contacts the seal (72) leaving the seal (72) in the disengaged position. The seal bypass (79) allows fluid in the chamber (5) above the seal (72) to drain as the seal (72) moves into the well. The sealer (72) is then removed from the liner hanger running assembly (30) while continuing to remove the liner hanger running assembly (20).

2. The dual setting tailpipe running tool of claim 1, wherein: a liner string for a wellbore includes a liner hanger assembly; a liner hanger deployment assembly (liner hanger running assembly) releasably connected to the liner hanger assembly, comprising: a central bore; and a running tool movable from a locked position to an unlocked position, the running tool including a flow passage in communication with the central bore; and a chamber disposed between the liner hanger running assembly and the liner hanger assembly, wherein the chamber is in selective fluid communication with the flow passage; wherein: when the flow channel is closed, the chamber is isolated from the central hole; the flow passage provides fluid communication between the central bore and the chamber when the flow passage is open.

3. The dual setting tailpipe running tool of claim 1, wherein: a shearable plug having a flow path, wherein the flow path is closed by a portion of the shearable plug; a valve seat sleeve movable from a closed position to an open position to shear away a portion of the shearable plug to open the flow passage.

4. The dual setting tailpipe running tool of claim 1, wherein: when the running tool is in the unlocked position, the flow passage is configured to close to prevent fluid communication between the chamber and the central bore.

5. The dual setting tailpipe running tool of claim 1, wherein: a valve sleeve movable relative to the running tool and sealing an upper end of the enclosed chamber; and a seal ring having a seal stack and sealingly surrounding a lower end of the chamber.

6. The dual setting tailpipe running tool of claim 1, wherein: the liner hanging run assembly further includes a bypass moveable from a first position adjacent the seal stack to a second position, wherein the bypass is configured to allow fluid communication between the chamber and wellbore fluids when positioned adjacent the seal stack.

7. The dual setting tailpipe running tool of claim 1, wherein: the liner hanging operation assembly further comprises: executing a setting mechanism; a connector selectively connects the liner hanging run assembly to an upper portion of the liner hanging assembly, wherein a valve sleeve is movably disposed within the connector, the connector being configured to separate from the liner hanging assembly in response to a force applied by an actuating setting device.