A wellbore tool setting arrangement

Abstract

A wellbore tool setting arrangement (1) comprising an inner sleeve (210) and an actuation sleeve (315) which are axially movable A locking arrangement (3) is interchangeable between a ratcheting and a non-ratcheting mode. One or more ratchet elements (201) are axially fixed in slots (204) of the inner sleeve (210). The ratchet elements are radially movable between an inner radial position and an outer radial position. When in the inner radial position, it is in the non-ratcheting mode, and when in the outer radial position, it is in the ratcheting mode. A ratchet device (318) is axially fixed to the actuation sleeve. When in the ratcheting mode, the actuation sleeve is movable with respect to the inner sleeve in a first axial direction and not movable in an opposite second axial direction. When in the non-ratcheting mode, the actuation sleeve is movable with respect to the inner sleeve in the first axial direction and in the second axial direction.

Description

A WELLBORE TOOL SETTING ARRANGEMENTTechnical Field

[0001] The present invention relates to a wellbore tool setting arrangement used for installing tools in a subsea or subterranean well. The wellbore tool setting arrangement is suited for setting, releasing and re-setting the wellbore tool on a single run.Background Art

[0002] When installing a wellbore tool inside a wellbore, the operator uses a setting tool. The wellbore tool is connected to the setting tool, run down into the well, and the wellbore tool is set at a desired location. After setting the wellbore tool, for instance a wellbore plug, the setting tool is disconnected from the wellbore tool and retrieved to surface. The setting tool can be of various types, for instance hydraulic or electric.

[0003] In some cases, however, the operator may need to re-set the wellbore tool. This can typically occur if a wellbore plug is set inside a wellbore casing but is not properly sealing or is not properly fixed to the casing. The operator then wishes to move the wellbore plug to another position and set the plug at the new position.

[0004] There are known some wellbore tool setting arrangements that exhibit this possibility. However, they are large, complex and expensive.

[0005] There are known well tool devices which have ratchet function. For instance, publication US11268336 discloses a ratchet system with a ratchet split ring.

[0006] US3054450 describes a retrievable packer apparatus with a ratchet function.Summary of invention

[0007] There is disclosed a wellbore tool setting arrangement, comprising an inner sleeve and an actuation sleeve which are axially movable with respect to each other. It further comprises a locking arrangement that is interchangeable between a ratcheting mode and a non-ratcheting mode. The locking arrangement comprises ratchet elements that are axially fixed in slots of the inner sleeve. The ratchet elements are radially movable between an inner radial position and an outer radialposition. When in the inner radial position, the locking arrangement is in the nonratcheting mode, and when in the outer radial position, the locking arrangement is in the ratcheting mode. The locking arrangement further comprises a ratchet device axially fixed to the actuation sleeve. When the locking arrangement is in the ratcheting mode, the actuation sleeve is movable with respect to the inner sleeve in a first axial direction and not movable in an opposite second axial direction. When the locking arrangement is in the non-ratcheting mode, the actuation sleeve is movable with respect to the inner sleeve in the first axial direction and in the second axial direction.

[0008] The wellbore tool setting arrangement can be used to set various types of wellbore tools, for instance a wellbore plug.

[0009] In some embodiments, the ratchet device is in the form of a ratchet ring. The ratchet ring is a split ring. Hence, the ratchet ring can expand and retract in the radial direction.

[0010] In other embodiments, the ratchet device can have another design. For instance, the ratchet device may comprise a ratchet sleeve with one or more windows, wherein one or more ratchet members are supported within the respective windows.

[0011] In some embodiments, the wellbore tool setting arrangement can further comprise an actuation member that extends inside a bore of the inner sleeve and that comprises an actuation face, and wherein the respective ratchet elements can comprise a climbing face configured to slide against the actuation face upon a mutual axial activation movement between the actuation member and the inner sleeve.

[0012] The said mutual axial movement between the actuation member and the inner sleeve makes the ratchet elements move radially outwards, thus setting the locking arrangement in the ratcheting mode.

[0013] Preferably, the ratchet elements each comprise a plurality, e.g. two, of climbing faces and the actuation member comprises a plurality, e.g. two, of actuation faces. This will contribute to maintaining a constant orientation of the ratchet elements, meaning that they are not pivoted during their radial movement.

[0014] It will be appreciated that the climbing face of the ratchet elements preferably are inclined climbing faces. However, it is possible to use non-inclined climbing faces if the actuation face of the actuation member is inclined. Oppositely, the actuation face of the actuation member may not be inclined if the climbing faces of the ratchet element is inclined. However, it is preferred that both faces are inclined, hence being an inclined climbing face and an inclined actuation face.

[0015] The actuation member can comprise a retraction face and the respective ratchet elements can comprise a retraction shoulder. An engagement between the retraction face and the retraction shoulder can provide radial retraction of the ratchet elements upon a mutual axial deactivation movement between the actuation member and the inner sleeve. The deactivation movement is opposite of the mutual axial activation movement.

[0016] The deactivation movement deactivates the ratcheting mode.

[0017] The wellbore tool setting arrangement can further comprise a setting rod and a shear element, wherein the shear element connects the setting rod to the inner sleeve.

[0018] The shear element, which can be in the form of a shear stud, enables disconnecting the setting rod from the actuation member by shearing off the shear element.

[0019] The wellbore tool setting arrangement may further comprise a first contact face axially fixed with respect to the actuation member and a second contact face axially fixed with respect to the inner sleeve. The first contact face faces the second contact face. Furthermore, when the locking arrangement is in its non-ratcheting mode, there is an axial distance between the first and second contact faces and when the locking arrangement is in its ratcheting mode, the first contact face abuts against the second contact face.

[0020] Advantageously, when the first and second contact faces have the said axial distance between them, the locking arrangement is in the non-ratcheting mode, while when they are in contact with each other, the locking arrangement is in the ratcheting mode.

[0021] In some embodiments, the ratchet elements can comprise a first ratchet pattern on their radially outer face, wherein the ratchet device comprises a second ratchet pattern on its inner face. When the locking arrangement is in the ratcheting mode, the first and second ratchet patterns will be in engagement with each other, and when the locking arrangement is in the non-ratcheting mode, the first and second ratchet patterns are not in engagement with each other.

[0022] As the skilled reader will appreciate, it is the engagement between the first and second ratchet patterns that provides the ratchet function of the locking arrangement.

[0023] The respective ratchet elements can comprise one or a plurality of protrusions that are received inside slot recesses of the slots. Alternatively, or in addition, the respective slots can comprise one or a plurality of protrusions that are received inside recesses of the ratchet elements.

[0024] The engagement between the protrusions and the recesses contributes to transmit axial force between the ratchet elements and the inner sleeve.

[0025] The wellbore tool setting arrangement can further comprise a setting sleeve and a latching sleeve arrangement axially fixed to an inside of the setting sleeve. The setting rod can comprise a forward facing shoulder. The latching sleeve arrangement can comprise a sleeve portion attached to the setting sleeve and a plurality of latching arms that extend axially from the sleeve portion. Furthermore, the latching sleeve arrangement latches the setting sleeve to the actuation sleeve when the ends of the latching arms are on one axial side of the forward facing shoulder and releases the setting sleeve from the actuation sleeve when the ends of the latching arms are on the opposite axial side of the forward facing shoulder.

[0026] The skilled reader will appreciate, as will also be understood from the detailed presentation of an example embodiment below, that the setting sleeve may be directly or indirectly attached to the actuation sleeve. In other words, the actuation sleeve may be connected to one or more intermediate parts that constitute parts of the interconnection.

[0027] In some embodiments, the wellbore tool setting arrangement can be attached to a wellbore plug comprising gripping elements and a packer element configured to be set by axial compression along the inner sleeve.

[0028] The skilled person will appreciate that the inner sleeve may be in one part but may also be in several parts interconnected along an axial direction.

[0029] Advantageously, the actuation member can be connected to a central stem that extends along and inside the bore of the inner sleeve.

[0030] With the disclosed wellbore tool setting arrangement, the operator is enabled to repeatedly set or install a wellbore tool on a single run. Furthermore, the operator may disconnect from the wellbore tool to retrieve the wellbore tool setting arrangement. With the same wellbore tool setting arrangement, the operator may reengage with the wellbore tool to release it.

[0031] Also disclosed is a downhole system comprising a wellbore tool setting arrangement as introduced above and a wellbore plug with gripping elements and a packer element. The wellbore tool setting arrangement is configured to set and release the wellbore plug on a single run.Detailed description of the invention

[0032] While various features have been discussed in general terms above, a more detailed and non-limiting example of embodiment will be presented in the following with reference to the drawings, in whichFig. 1 is a perspective view of a wellbore tool setting arrangement, connected to a wellbore tool in the form of a wellbore plug;Fig. 2 is a perspective view substantially corresponding to Fig. 1, however with some parts removed for illustrational purpose;Fig. 3 is a cross section side-view of the wellbore plug;Fig. 4 is another cross section side-view of the wellbore plug, shown in a set state;Fig. 5 is a cross section side-view of the wellbore tool setting arrangement with a locking arrangement being in a non-ratcheting mode;Fig. 6 is a cross section side-view of the wellbore tool setting arrangement with the locking arrangement being in a ratcheting mode;Fig. 6a is an enlarged cross section side-view of a part of Fig. 6, depicting the locking arrangement when in the ratcheting mode;Fig. 7 is a perspective view of a ratchet element;Fig. 8 is a side view of the ratchet element shown in Fig. 7;Fig. 9 is an enlarged cross section side-view of the locking arrangement when in the ratcheting mode;Fig. 10 is an enlarged cross section side-view corresponding to Fig. 9, however depicting the locking arrangement when in the non-ratcheting mode;Fig. 11 is a perspective view of a ratchet device, shown in the form of a ratchet ring;Fig. 12 is a perspective view of the locking arrangement;Fig. 13 is a cross section side-view of the wellbore tool setting arrangement when the wellbore plug is in a set state;Fig. 14 is a cross section side-view corresponding to Fig. 13, however with the setting rod and setting sleeve detached from the locking arrangement;Fig. 15 is a cross section side-view illustrating re-entry of the setting rod and setting sleeve, before re-connection to the locking arrangement;Fig. 16 is a cross section side-view of the wellbore tool setting arrangement with the locking mechanism in a non-ratcheting mode and with the wellbore plug (not shown) still set;Fig. 17 is a perspective view of a portion of the inner sleeve;Fig. 18 is a perspective view of another embodiment of the ratchet ring;Fig. 19 is an enlarged cross section side-view of another embodiment of the locking arrangement;Fig. 20 is a front view of an embodiment of the ratchet element;Fig. 21 is a front view of an alternative embodiment of the ratchet element;Fig. 22 is a perspective view of an embodiment of the actuation member;Fig. 23 is a perspective view of another embodiment of the actuation member;Fig. 24 is an enlarged perspective view of a portion of the wellbore tool setting arrangement with some parts removed for illustrational purpose;Fig. 25 is a perspective view of an alternative embodiment of the ratchet device;Fig. 26 shows ratchet members of the ratchet device shown in Fig. 25; andFig. 27 depicts a ratchet sleeve 324 for supporting the ratchet members shown in Fig. 26 and Fig. 25.

[0033] Fig. 1 depicts a wellbore plug 400 with a perspective view. It comprises a plurality of gripping elements 401 (often referred to as slips) configured to be moved radially into engagement with the inner wall of a casing. The wellbore plug 400 further comprises a packer element 403 configured to expand radially under axial compression, to seal against the casing.

[0034] Fig. 2 depicts the same wellbore plug 400 with some parts removed for illustrational purpose.

[0035] The function of the gripping elements 401 and packer element 403 is conventional. Fig. 3 and Fig. 4 depict the plug 400 inside a casing 405 in a non-set and a set state, respectively.

[0036] Radially within the gripping elements 401 and the packer element 403 is an inner sleeve 210 with an inner bore 214. Outside the inner sleeve 210 is a first gripping element actuation element 409a and a second gripping element actuation element 409b. The second gripping element actuation element 409b is axially fixed with respect to the inner sleeve 210, while the first gripping element actuation element 409a is slidingly arranged on the inner sleeve 210. Furthermore, the first and second gripping element actuation elements 409a, 409b comprise an inclined actuation face 411 that abuts against the gripping elements 401 . In the shown embodiment, the gripping elements 401 have an opposite inclined actuation face 401a.

[0037] The packer element 403 is axially arranged between a first packer actuation element 413a and a second packer actuation element 413b. The second packeractuation element 413b connects to a packer mandrel 414 that is slidingly arranged outside the inner sleeve 210. Furthermore, the first packer actuation element 413a and the packer element 403 is slidingly arranged outside the packer mandrel 414.

[0038] The first packer actuation element 413a connects to an actuation sleeve 315. As illustrated in Fig. 4, when the actuation sleeve 315 is moved towards the front portion of the wellbore plug 400, with respect to the inner sleeve 210, the packer element 403 is compressed between the first and second packer actuation element 413a, 413b. This makes the packer element 403 expand radially to seal against the casing 405. Simultaneously, the gripping elements 401 slide on the inclined faces 411 of the first and second gripping element actuation elements 409a, 409b, thus moving radially outwards to engage the wall of the casing 405. The wellbore plug 400 is now locked to the casing 405 in a sealing state. The inner sleeve 210 connects to a head body 402 at the end of the wellbore plug 400. The second gripping element actuation element 409b connects to the head body 402.

[0039] The axial mutual movement between the actuation sleeve 315 and the inner sleeve 210 can be provided in various ways. For instance, a (not shown) hydraulic or electric setting tool can be used. As previously indicated, the radial activation of the packer element 403 and the gripping elements 401 is considered conventional. The actuation arrangement used for providing the axial movement of the actuation sleeve 315 will thus not be discussed herein.

[0040] To maintain the wellbore plug 400 in its set state, a locking arrangement 3 of a wellbore tool setting arrangement 1 is used. For brevity, the term setting arrangement 1 is used when discussing the example embodiment. The setting arrangement 1 will now be discussed, first referring to Fig. 5.

[0041] The setting arrangement 1 comprises three sets of components that are mutually movable with respect to each other. To facilitate understanding of the function, the components of an inner set is given reference numbers in the 100 series, the components of an intermediate set is given reference numbers in the 200 series, while components of an outer set is given reference numbers in the 300 series.

[0042] Fig. 5 is a cross section side view of the setting arrangement 1. The shown state corresponds to the state shown in Fig. 3, where the wellbore plug 400 has beenrun into position inside the casing 405, but is not yet set. Fig. 5 depicts the setting arrangement without the surrounding casing 405.

[0043] Recognizable from Fig. 3 and Fig. 4 are the actuation sleeve 315, the packer mandrel 414, the inner sleeve 210, and the first packer actuation element 413a.

[0044] As discussed with reference to Fig. 3 and Fig. 4, to set the plug, the actuation sleeve 315 was moved forward with respect to the inner sleeve 210, i.e. towards the right in the shown figures. The skilled person will appreciate that one could also move the inner sleeve 210 backwards with respect to the actuation sleeve 315, or both movements could occur simultaneously.

[0045] The setting arrangement 1 comprises a locking arrangement 3. The locking arrangement 3 comprises an actuation member 101. In the shown embodiment, the actuation member 101 comprises a central stem 103 that extends into a bore of the inner sleeve 210 in a sliding manner. In other embodiments, the actuation member 101 may be without the central stem 103.

[0046] At a rear portion, the actuation member 101 connects to a shear element, which in the shown embodiment is in the form of a shear stud 105. The shear stud 105 has a threaded engagement with the actuation member 101 but could also be connected in other ways. The shear stud 105 further connects to a setting rod 107, such that the setting rod 107 and the actuation member 101 are connected via the shear stud 105.

[0047] Between its engagement with the setting rod 107 and the actuation member 101 , the shear stud 105 has a weak link 105a. When exerting a pulling force, the shear stud 105 can be broken at the position of the weak link 105a.

[0048] The shear stud 105 is not compulsory. The shear stud 105 enables the operator to disconnect from the wellbore tool, such as the plug 400, to retrieve the wellbore tool setting arrangement.

[0049] The locking arrangement 3 comprises a plurality of ratchet elements 201 that are arranged radially outside of the actuation member 101. The ratchet elements 201 are radially movable, as will be discussed further below. They are arranged in slots 204 provided the inner sleeve 210 (shown in Fig. 17). The inner sleeve 210 is connected with threads to a rear sleeve part 210a at its rear end portion. The rearsleeve part 210a has a rear bore 207 that receives a front part of the setting rod 107. The inner sleeve 210 and the rear sleave part 210a could theoretically be made as one part but is made in two parts for assembling purposes.

[0050] To activate the locking arrangement 3, the setting rod 107 is pulled backwards with respect to the inner sleeve 210. Since the setting rod 107 connects to the actuation member 101 , via the shear stud 105, the actuation member 101 is also moved. This is shown in Fig. 6 and Fig. 6a. Fig. 6a depicts an enlarged portion of Fig. 6.

[0051] As a result of the backwards movement of the actuation member 101 , the ratchet elements 201 move radially outwards. The ratchet elements 201 comprise inclined climbing faces 209 that slide on oppositely facing inclined actuation faces 109 of the actuation member 101. As the skilled person will appreciate, it would suffice to have an inclined face only on the actuation member 101 or only on the ratchet element 201. However, having oppositely arranged and abutting inclined faces will distribute the forces over a larger area and is thus preferable.

[0052] When the actuation member 101 is moved backwards with respect to the inner sleeve 210, a split lock ring 102 (Fig. 6a) slips radially outwards over a lock shoulder 210b. When in the locking position, as shown in Fig. 6, the split lock ring 102 can carry the weight of the actuation member 101 and central stem 103. However, if a sufficient axial and downwardly directed force is applied to the actuation member, the split lock ring 102 can be radially moved inwards, back to its non-locking position.

[0053] Furthermore, when moving the actuation member 101 backwards with respect to the inner sleeve 210, a first contact face 104 abuts against a second contact face 210c of the rear sleeve part 210a.

[0054] Fig. 7 and Fig. 8 illustrate one of the ratchet elements 201 with a perspective view and a side view, respectively. In addition to the inclined climbing faces 209, the ratchet element 201 has inclined retraction shoulders 211 that face rearwards. The retraction shoulders 211 are used when releasing the wellbore plug 400, which will be discussed later.

[0055] The ratchet element 201 further comprises protrusions 213 that are received inside slot recesses 206 (cf. Fig. 17) of the slots 204 of the inner sleeve 210. This will also be discussed later.

[0056] On a radially outer face, the ratchet element 201 is provided with a first ratchet pattern 215. The first ratchet pattern 215 is configured to engage with a radially inward facing second ratchet pattern 317 of a ratchet device 318, which in the shown embodiment is in the form of a ratchet ring 319. The enlarged cross section view of Fig. 9 illustrates the ratchet element 201 in such an engagement with the ratchet ring 319.

[0057] As shown with the perspective view of Fig. 11 , the ratchet ring 319 is a split ring with the said second ratchet pattern 317 arranged on its inner face.

[0058] Thus, when the actuation member 101 has moved backwards with respect to the ratchet elements 201 , as illustrated with the difference between Fig. 5 and Fig. 6, the locking arrangement 3 is put in a ratcheting mode. In the ratcheting mode, the second ratchet pattern 317 of the ratchet ring 319 is in a ratcheting engagement with the first ratchet pattern 215 of the ratchet elements 201. The enlarged cross section view of Fig. 9 also depicts the locking arrangement 3 in the ratcheting mode.

[0059] As the skilled reader now will appreciate, the ratchet elements 201 can move axially backwards with respect to the ratchet ring 319. However, when in the ratcheting mode, the ratchet elements 201 cannot move axially forwards with respect to the ratchet ring 319.

[0060] Fig. 10 is an enlarged cross section view illustrating the locking arrangement 3 when in the non-ratcheting mode. Fig. 10 shows an enlarged portion of Fig. 5. In this non-ratcheting mode, the second ratchet pattern 317 of the ratchet ring 319 is not in engagement with the first ratchet pattern 215 of the ratchet elements 201.

[0061] The ratchet ring 319 is supported radially within a ratchet support sleeve 321. The ratchet support sleeve 321 comprises a ratchet support face 323 that faces radially inwards. The ratchet support face 323 limits the radially outward movement of the split ring 319 but allows it to move radially outwards to obtain the ratcheting function of the locking arrangement 3. The ratchet support sleeve 321 is connected to the actuation sleeve 315 and a rear actuation sleeve 325. The rear actuationsleeve 325, the actuation sleeve 315, and the ratchet support sleeve 321 are thus interconnected and move as one single component.

[0062] An alternative embodiment of the locking arrangement 3, with a different design of the ratchet ring 319 will be discussed further below with reference to Fig. 18 and Fig. 19.

[0063] Fig. 12 depicts parts of the locking arrangement 3 with some parts removed for illustrational purpose. The ratchet elements 201 are distributed about the center axis, within the ratchet ring 319.

[0064] While the locking arrangement 3 and its ratchet function have been discussed above, the setting of the wellbore plug 400 with the setting arrangement 1 will now be discussed.

[0065] As discussed above with reference to Fig. 3 and Fig. 4, the wellbore plug 400 was set by moving the actuation sleeve 315 axially forwards with respect to the inner sleeve 210 (or the moving the inner sleeve 210 backwards with respect to the actuation sleeve 315, or a combination thereof). This movement makes the ratchet elements 201 move backwards with respect to the ratchet ring 319. During this movement, force from the actuation element 101 is exerted on the rear sleeve part 210a through the abutting engagement between the first contact face 104 and the second contact face 210c.

[0066] This is illustrated in Fig. 13. In this situation, the wellbore plug 400 is set. Because of the ratcheting function of the locking arrangement 3, it cannot be unset (or released) as long as the ratchet elements 201 are in their outer radial position, i.e. when the locking arrangement 3 is in its ratcheting mode.

[0067] After setting the wellbore plug 400, the operator may typically perform pressure tests to ensure that the plug is properly sealing against the casing 405. If the pressure tests are successful, the operator may wish to retract the (not shown) setting tool and the string (e.g. a wire).

[0068] With a pulling force exerted onto the setting rod 107, the operator pulls off the shear stud 105. The setting rod 107 can then be pulled out of the well, while the wellbore plug 400 remains in its set state due to the locking arrangement 3 which is in a locking state. Fig. 14 depicts the shear stud 105 after breaking, with the lockingarrangement 3 in its locking state. The shear stud 105 has broken into a first part 105b and a second part 105c. The setting tool can then be retrieved together with the setting rod 107 and the setting sleeve 329.

[0069] Still referring to Fig. 14, a latching sleeve arrangement 327 is connected to an inner side of a setting sleeve 329. The setting sleeve 329 and the setting rod 107 are mutually movable, as discussed above, by operation of an actuator (not shown), such as a hydraulic or electric setting tool.

[0070] The latching sleeve arrangement 327 comprises a sleeve portion 327a which connects to the setting sleeve 329. It further comprises a plurality of latching arms 327b that extend axially forwards out from the sleeve portion 327a. When the setting rod 107 has been pulled a sufficient distance backwards, the ends of the latching arms 327b move free of a forward facing shoulder (107a) of the setting rod 107. The latching arms 327b are then free to move off a latching shoulder 331 of the rear actuation sleeve 325. This disconnects the setting sleeve 329 and the setting rod 107 such that these parts can be pulled out of the well.

[0071] When the operator wishes to retrieve the wellbore plug 400, the setting rod 107 is moved back down into the well, as shown in Fig. 15. The part of the shear stud 105 that was still attached to the setting rod 107 after breaking the shear stud 105, has been replaced with a force application element 111. The force application element 111 is attached to the setting rod 107 with threads, as was the shear stud 105.

[0072] The force application element 111 comprises a ring-shaped protrusion 113 with a receiving cavity 115. Although not shown with figures, when the setting rod 107 is moved towards the remaining part of the shear stud 105, the ring-shaped protrusion 113 abuts the actuation member 101 while the remaining part of the shear stud 105 is received inside the receiving cavity 115. The skilled person will, however, realize that force could be applied also directly on the remaining part of the shear stud 105 (i.e. without the force application element 111).

[0073] Due to the axial and forwardly directed force applied on the actuation member 101 , the actuation member 101 slides forwards with respect to the ratchet elements 201. As a result, the ratchet elements 201 eventually move to their radiallyinner position, out of engagement with the ratchet ring 319. This is the same position as shown in Fig. 5. This releases the wellbore plug 400, which now can be retrieved.

[0074] As discussed above, after setting the wellbore plug 400, the operator may perform pressure tests to ensure that the wellbore plug 400 is in fact sealing against the casing 405. The operator may also test that the wellbore plug 400 is properly secured to the casing 405, i.e. that the gripping elements 401 have a proper engagement with the casing 405. If the operator finds that the wellbore plug 400 is not properly sealing against the casing 405, or that it is not properly secured, the operator may release the wellbore plug 400 by moving the actuation member 101 downwards, i.e. without having pulled off the shear stud 105.

[0075] The said tests would occur when in the situation shown in Fig. 13. By forcing the setting rod 107 back downwards, the locking arrangement 3 would return from the ratcheting mode to the non-ratcheting mode, wherein the ratchet elements 201 are in their radial inner position. This is shown in Fig. 16. This enables the operator to move the ratcheting elements 201 downwards with respect to the ratchet ring 319. This makes the gripping elements 401 retract and the packer element 401 to disengage from the contact with the casing 405. During this movement, i.e. a forward movement of the actuation member 101 , the retraction faces 112 of the actuation member 101 will engage the retraction shoulders 212 of the ratchet elements 201 and thus move these radially inwards to the non-ratcheting mode.

[0076] The operator can then, when the wellbore plug 400 is released, move it to another location and attempt a new setting of the wellbore plug 400. If tests at the new location are successful, the operator may break off the shear stud 105 and leave the wellbore plug 400 at the new location.

[0077] When moving the ratchet elements 201 from the radially outer ratcheting mode to the radially inner non-ratcheting mode, inclined retraction faces 112 engage the retraction shoulders 211 of the ratchet elements 201.

[0078] Fig. 17 is a perspective view of a portion of the locking arrangement 3, with several components removed for illustrational purpose. This image illustrates in particular the inner sleeve 210 with its slots 206 that receive the ratchet elements 201 (not shown in Fig. 17). The image of Fig. 17 also shows the locking arrangement 3 without the actuation member 101 arranged inside the inner sleeve 210.

[0079] Fig. 18 depicts an embodiment of the ratchet ring 319 with a planar outer face. Fig. 19 is an enlarged cross section view of this ratchet ring 319 when the locking arrangement 3 is in a ratcheting mode. In other words, the ratchet elements 201 are in the radially outer position.

[0080] Fig. 20 and Fig. 21 are front views of two different embodiments of the ratchet element 201. While both have a curved outer face, where the first ratchet pattern 215 is located, they have different inner faces. The ratchet element 201 shown in Fig. 20 has a planar inner face configured to abut against a planar face of the actuation member 101 . Contrary to this, the ratchet element 201 shown in Fig. 21 has a curved inner face, configured to abut against a curved face of the actuation member 101.

[0081] Fig. 22 depicts a perspective view of an actuation member 101 with all outer faces being curved. This actuation member 101 would be suited for engaging with the ratchet element 201 shown in Fig. 21.

[0082] Fig. 23 shows another type of actuation member 101 , having ratchet element interfaces 101a configured to engage with the ratchet element 201 shown in Fig. 20.

[0083] Fig. 24 depicts latching arms 327b of the latching sleeve arrangement 327 distributed about the setting rod 107. Also shown is the rear sleeve part 210a of the inner sleeve 210. The rear actuation sleeve 325 is not shown for illustrational purpose but would enclose the latching arms 237.

[0084] Fig. 25 to Fig. 27 illustrate another embodiment of a part of the locking arrangement 3. In this embodiment, instead of the ratchet ring 319 (as shown inter alia in Fig. 11), the ratchet device 318 is in the form of a plurality of ratchet members 320 supported within windows 322 of a ratchet sleeve 324. The ratchet members 320 can move radially within the windows 322 to enable the ratcheting function when engaging the ratchet elements 210. The ratchet members 320 comprise a ratchet pattern 317 on their inner face (corresponding to the ratchet pattern 317 of the ratchet ring 319).

[0085] The skilled reader will appreciate that the ratchet device 318 could instead have only one ratchet member 320. However, a plurality of ratchet members 320 is considered advantageous.

[0086] The ratchet device 318 shown in Fig. 25 to Fig. 27 could be used in the same manner as the previously discussed ratchet ring 319.

Claims

Claims1. A wellbore tool setting arrangement (1) comprising- an inner sleeve (210) and an actuation sleeve (315) which are axially movable with respect to each other;- a locking arrangement (3) interchangeable between a ratcheting mode and a non-ratcheting mode, comprising- one or more ratchet elements (201) that are axially fixed in slots (204) of the inner sleeve (210), wherein the one or more ratchet elements (201) are radially movable between an inner radial position and an outer radial position, wherein when in the inner radial position, the locking arrangement is in the non-ratcheting mode, and when in the outer radial position, the locking arrangement (3) is in the ratcheting mode;- a ratchet device (318) axially fixed to the actuation sleeve (315); wherein,- when the locking arrangement (3) is in the ratcheting mode, the actuation sleeve (315) is movable with respect to the inner sleeve (210) in a first axial direction and not movable in an opposite second axial direction; and- when the locking arrangement (3) is in the non-ratcheting mode, the actuation sleeve (315) is movable with respect to the inner sleeve (210) in the first axial direction and in the second axial direction.

2. A wellbore tool setting arrangement (1) according to claim 1 , further comprising an actuation member (101) that extends inside a bore (214) of the inner sleeve (210) and that comprises an actuation face (109), and wherein the respective ratchet elements (201) comprise a climbing face (209) configured to slide against the actuation face (109) upon a mutual axial activation movement between the actuation member (101) and the inner sleeve (210).

3. A wellbore tool setting arrangement (1) according to claim 2, wherein the actuation member (101) comprise a retraction face (112) and the respective ratchet elements (201) comprise a retraction shoulder (211), wherein an engagement between the retraction face (112) and the retraction shoulder (112) provides radial retraction of the ratchet elements (201) upon a mutual axialdeactivation movement between the actuation member (101) and the inner sleeve (210), which is opposite of the mutual axial activation movement.

4. A wellbore tool setting arrangement (1) according to one of the preceding claims, further comprising a setting rod (107) and a shear element (105), wherein the shear element (105) connects the setting rod (107) to the inner sleeve (210).

5. A wellbore tool setting arrangement (1) according to one of the preceding claims, further comprising- a first contact face (104) axially fixed with respect to the actuation member (101); and- a second contact face (210c) axially fixed with respect to the inner sleeve (210); wherein the first contact face (104) faces the second contact face (210c), and wherein, when the locking arrangement (3) is in its non- ratcheting mode, there is an axial distance between the first and second contact faces (104, 210c) and when the locking arrangement (3) is in its ratcheting mode, the first contact face (104) abuts against the second contact face (210c).

6. A wellbore tool setting arrangement (1) according to any one of the preceding claims, wherein the ratchet elements (201) comprise a first ratchet pattern (215) on their radially outer face, wherein the ratchet device (318) comprises a second ratchet pattern (317) on its inner face, and wherein, when the locking arrangement (3) is in the ratcheting mode, the first and second ratchet patterns (215, 317) are in engagement with each other, and when the locking arrangement (3) is in the non-ratcheting mode, the first and second ratchet patterns (215, 317) are not in engagement with each other.

7. A wellbore tool setting arrangement (1) according to any one of the preceding claims, wherein the respective ratchet elements (201) comprise one or a plurality ofprotrusions (213) that are received inside slot recesses (206) of the slots (204), or wherein the respective slots (204) comprise one or a plurality of protrusions that are received inside recesses of the ratchet elements (201).

8. A wellbore tool setting arrangement (1) according to claim 4, or according to claim 4 and any other preceding claim, further comprising a setting sleeve (329) and a latching sleeve arrangement (327) axially fixed to an inside of the setting sleeve, wherein the setting rod (107) comprises a forward facing shoulder (107a), the latching sleeve arrangement (327) comprising- a sleeve portion (327a) attached to the setting sleeve (329);- a plurality of latching arms (327b) that extend axially from the sleeve portion (327a); and wherein, the latching sleeve arrangement (327) latches the setting sleeve (329) to the actuation sleeve (315) when the ends of the latching arms (327b) are on one axial side of the forward facing shoulder (107a) and releases the setting sleeve (329) from the actuation sleeve (315) when the ends of the latching arms (327b) are on the opposite axial side of the forward facing shoulder (107a).

9. A wellbore tool setting arrangement (1) according one of the preceding claims, wherein it is attached to a wellbore plug (400) comprising gripping elements (401) and a packer element (403) configured to be set by axial compression along the inner sleeve (210).

10. A downhole system comprising- a wellbore tool setting arrangement (1) according to any one of claims 1 to 8; and- a wellbore plug (400) comprising gripping elements (401) and a packer element (403); wherein the wellbore tool setting arrangement (1) is configured to set and release the wellbore plug on a single run.

Images