TENSION SET PACKER
CROSS-REFERENCE TO A RELATED APPLICATION
[0001] The application claims all benefit including priority to U.S. Provisional Application No. 62/669,087, filed on May 9, 2018, the contents of which are incorporated herein by reference.
FIELD
[0002] The present disclosure relates to packers, in particular to tension-set packers, which are deployed downhole for creating a sealed interface within a wellbore.
BACKGROUND
[0003] Packers for creating a sealed interface within a wellbore are known. Packers are a key component of downhole equipment and function as sealing devices that can be used to isolate zones within the tubing string or wellbore.
Various types of packers exist and can often be classified into two groups:
retrievable packers, or permanent packers. Retrievable packers are desirable for the ability to remove the packer from the wellbore as needed and/or reset the packer in place within the wellbore. Tension set packers are a type of retrievable packer and require the packer assembly to be constantly pulled in tension to ensure that the packer remains actuated and in position effecting the required sealed interface. The need to have the assembly constantly pulled in tension to ensure proper functioning of the packer can interfere with other wellbore operations.
Accordingly, tension-set packers that do not require the packer assembly to be constantly pulled in tension are desirable. SUMMARY
[0004] In accordance with an example embodiment of the present disclosure there is provided a downhole tool comprising: a sealing engagement effector disposable in a non-actuated state and an actuated state; a sealing engagement effector actuating assembly; a retainer disposable in a non-actuated state and an actuated state; the sealing engagement effector and the sealing engagement effector actuating assembly are co-operatively configured such that, in response to application of a tensile force to the sealing engagement effector actuating
assembly, deformation of the sealing engagement effector is effected such that the sealing engagement effector becomes disposed in the actuated state, with effect that the sealing engagement effector and the sealing engagement effector actuating assembly become co-operatively disposed in a sealing engagement effector-actuated state; the sealing engagement effector, the sealing engagement effector actuating assembly, and the retainer are co-operatively configured for co- operative disposition in a retained state while the tool is disposed within a wellbore, wherein, in the retained state: (a) the sealing engagement effector and the sealing engagement effector actuating assembly are co-operatively disposed in the sealing engagement effector-actuated state; and (b) the retainer is disposed in the actuated state such that the retainer is disposed, relative to the wellbore, for preventing, or substantially preventing, downhole displacement of the sealing engagement effector actuating assembly within the wellbore; and the sealing engagement effector, the sealing engagement effector actuating assembly, and the retainer are further co-operatively configured such that, while the sealing
engagement effector, the sealing engagement effector actuating assembly, and the retainer are co-operatively disposed in the retained state, in response to release of the tensile force being applied to the sealing engagement effector actuating assembly, there is an absence of defeating of the actuated state of the sealing engagement effector.
[0005] In accordance with another aspect the present disclosure of the downhole tool disposable within a wellbore, comprising: a mandrel; a sealing
R&M REF: 52619-3114 engagement effector disposed on the mandrel and disposable in a non-actuated state and an actuated state; a sealing engagement effector actuating assembly disposed on the mandrel; a retainer mounted on the mandrel and displaceable relative to the mandrel wherein the retainer is disposable in a non-actuated state and an actuated state; and a retainer actuator mounted on the mandrel and displaceable relative to the mandrel; wherein the mandrel, the sealing engagement member, the sealing engagement effector actuating assembly, the retainer, and the retainer actuator are cooperatively configured for co-operative disposition such that: (a) displacement of the mandrel in an uphole direction in response to application of a tensile force applied to the mandrel in the uphole direction effects actuation of the retainer such that the retainer becomes disposed in the actuated state wherein displacement of the retainer relative to the wellbore is prevented, or substantially prevented; and while the retainer is disposed in the actuated state, further displacement of the mandrel in the uphole direction in response to application of the tensile force effects: (i) actuation of the sealing engagement effector actuating assembly such that the sealing engagement effector becomes disposed in the actuated state; and (ii) releasable coupling of the mandrel and the retainer such that displacement of the mandrel in a downhole direction is
prevented, or substantially prevented, with effect that the sealing engagement effector remains disposed in the actuated state upon removal of the tensile force being applied to the mandrel.
[0006] In accordance with another aspect of the present disclosure there is provided a wellbore string incorporating a downhole tool according to the example embodiments of the present disclosure.
[0007] In accordance with another aspect of the present disclosure there is provided a system comprising a wellbore string incorporating a downhole tool according to the example embodiments of the present disclosure wherein the wellbore string is disposed within a wellbore.
R&M REF: 52619-3114 [0008] In accordance with another aspect of the present disclosure there is provided a method of setting a packer element within a wellbore, comprising deploying an downhole tool according to the example embodiments of the present disclosure into the wellbore; applying a tensile force to the sealing engagement effector actuating assembly such that the sealing engagement effector, the sealing engagement effector actuating assembly, and the retainer become cooperatively configured for cooperative disposition in the retained state and the sealing engagement effector is disposed in the actuated state; and maintaining disposition of the sealing engagement effector in the actuated state upon release of the tensile force applied to the sealing engagement effector actuating assembly.
BRIEF DESCRIPTION OF THE DRAWINGS
[0009] Reference will now be made, by way of example, to the accompanying drawings which show example embodiments of the present application, and in which :
[0010] Figure 1 is a side elevation view of the apparatus according to an example embodiment of the present disclosure;
[0011] Figure 2 is a sectional side elevation view of the apparatus of Figure 1 illustrating a run-in-hole (RIH) position;
[0012] Figure 3 is a sectional side elevation view of the apparatus of Figure 1 illustrating a pull-out-of-hole (POOH) position; and
[0013] Figure 4 is a sectional side elevation view of a portion of the apparatus of Figure 1 disposed in within a wellbore string with the apparatus in a set or actuated state;
[0014] Figure 5 is an unwrapped view of a J-slot profile of the apparatus of Figure 1; and
[0015] Figure 6 is a detail view of a portion of a mandrel coupler of the apparatus of Figures 1-5;
R&M REF: 52619-3114 [0016] Figure 7 is a schematic illustration of the apparatus disposed within a wellbore; and
[0017] Figure 8 is a detail, sectional side elevation view of the encircled portion of Figure 2.
[0018] Similar reference numerals may have been used in different figures to denote similar components.
DESCRIPTION OF EXAMPLE EMBODIMENTS
[0019] As used herein, the terms "up", "upward" or "uphole", etc. mean relativistically in closer proximity to the surface and further away from the bottom of the wellbore, when measured along the longitudinal axis of the wellbore. The terms "down", "downward", "lower", or "downhole" mean relativistically, further away from the surface and in closer proximity to the bottom of the wellbore, when measured along the longitudinal axis of the wellbore.
[0020] Referring to Figure 7, there is provided a downhole tool or apparatus 10 for creating a sealed interface within a wellbore 12 of a subterranean formation 14. The apparatus 10 is deployable within the wellbore 12. The wellbore 12 may be a cased or lined wellbore having a wellbore casing or wellbore string 16 disposed therein. The wellbore casing or wellbore string 16 may include a plurality of successive casing sections (not shown) joined together by a corresponding plurality of collars or any other suitable means. The wellbore casing or string 16 lines the wellbore 12 and is, typically, cemented within the subterranean formation 14.
[0021] Referring now to Figures 1-5, the apparatus or downhole tool 10 according to an example embodiment of the present disclosure is shown. The apparatus 10 includes a mandrel 18 configured for disposition within the wellbore 12 and displacement relative to the wellbore casing or string 16. A packing element or sealing engagement effector 20 is disposed about the mandrel 18, the sealing engagement effector 20 having a first, non-seal-effecting position or non-actuated state and a second, seal-effecting position or actuated state wherein the sealing
R&M REF: 52619-3114 engagement effector 20 becomes disposed in sealing engagement, or substantially sealing engagement, with an inner surface 17 of the wellbore casing or wellbore string 16.
[0022] In some embodiments, for example, the sealing engagement effector 20 is a tubular member that extends axially, relative to a central longitudinal axis of the mandrel, between first and second ends 21, 23. In some embodiments, for example, the sealing engagement effector 20 is a flexible member. In some embodiments, for example, the sealing engagement effector 20 includes an elastomeric material that deforms under compression such that the sealing engagement effector 20 expands or bulges outwardly in a radial direction, relative to the central, longitudinal axis 15 of the mandrel 18, in response to opposing compressive forces applied to opposite ends 21, 23 of the sealing engagement effector 20 along an axis parallel, or substantially parallel, to the central,
longitudinal axis 15 of the mandrel 18.
[0023] The first, non-seal-effecting position or non-actuated state of the sealing engagement effector 20 generally corresponds to the sealing engagement effector 20 being disposed in a neutral condition or non-operative orientation wherein a surface portion 19 of the sealing engagement effector 20 disposed furthest outwardly relative to the central longitudinal axis 15 of the mandrel 18 is disposed in a first position relative to the central longitudinal axis of the mandel 18, while the second, seal-effecting position or actuated state of the sealing
engagement effector 20 generally corresponds to the sealing engagement effector 20 being disposed in a compressed condition or operative orientation wherein the sealing engagement effector 20 becomes disposed such that the surface portion 19 of the sealing engagement effector 20 disposed furthest outwardly relative to the central longitudinal axis of the mandrel 18 is disposed in a second position relative to the central longitudinal axis 15 of the mandrel 18, where the second position is further outwardly disposed, relative to the central longitudinal axis ol5 f the mandrel 18, than the first position.
R&M REF: 52619-3114 [0024] In some embodiments, for example, the apparatus or downhole tool 10 comprises a sealing engagement effector actuating assembly 22. In some embodiments, for example, the sealing engagement effector 20 and the sealing engagement effector actuating assembly 22 are co-operatively configured such that, in response to application of a tensile force to the sealing engagement effector actuating assembly 22, deformation of the sealing engagement effector 20 is effected such that the sealing engagement effector 20 becomes disposed in the actuated state or its operative orientation, with effect that the sealing engagement effector 20 and the sealing engagement effector actuating assembly 22 become co- operatively disposed in a sealing engagement effector-actuated state.
[0025] In some embodiments, for example, the sealing engagement effector actuating assembly 22 includes a sealing engagement effector retainer or downhole engager 25 and an uphole engager 50 wherein the sealing engagement effector 20 is disposed between the uphole engager 50 and the downhole engager 25.
[0026] In some embodiments, for example, the sealing engagement effector 20 and the sealing engagement effector actuating assembly 22 are co-operatively configured such that while the cooperative disposition of the sealing engagement effector 20 and the sealing engagement effector actuating assembly 22 in the sealing engagement effector actuated state is established, the sealing engagement effector 20 is compressed between the uphole engager 50 and the downhole engager 25 such that the surface portion 19 of the sealing engagement effector 20 becomes disposed in its operative orientation wherein the surface portion 19 is dispsed in sealing engagement, or substantially sealing engagement, with the inner surface 17 of the wellbore string 16.
[0027] In some embodiments, for example, downhole engager 25 is disposed on and coupled to the mandrel 18 such that the downhole engager 25 is fixed relative to the mandrel 18 and configured for displacement with the mandrel 18. In some embodiments, for example, the sealing engagement effector retainer or
R&M REF: 52619-3114 downhole engager 25 is coupled to the mandrel by one or more shear pins or shear screws 26. The one or more shear pins 26 extend though corresponding openings disposed in the downhole engager 25 and the mandrel 18 to releasably secure the downhole engager 25 to the mandrel 18.
[0028] In some embodiments, for example, the downhole engager 25 has an end 24 configured for abutting a corresponding end, or the second end 23, of the sealing engagement effector 20 and prevents downhole displacement of the sealing engagement effector 20 relative to the mandrel 18 thereby retaining the sealing engagement effector 20 in position relative to the mandrel 18.
[0029] A slip assembly or retainer 30 is mounted on the mandrel 18 such that the mandrel 18 is displaceable relative to the retainer 30. The retainer 30 is also displaceable with the mandrel 18 relative to the wellbore 12 or wellbore string 16 and is disposable in a non-interfering or non-actuated state and in an interfering or actuated state wherein the retainer 30 becomes fixed, or substantially fixed, relative to the wellbore 12 or wellbore string 16 such that displacement of the retainer 30 relative to the wellbore 12 or wellbore string 16 is prevented, or substantially prevented.
[0030] In some embodiments, for example, the sealing engagement effector 20, the sealing engagement effector actuating assembly 22, and the retainer 30 are co-operatively configured for co-operative disposition in a retained state while the downhole tool or apparatus 10 is disposed within the wellbore 12, wherein, in the retained state: (a) the sealing engagement effector 20 and the sealing engagement effector actuating assembly 22 are co-operatively disposed in the sealing
engagement effector-actuated state; and (b) the retainer 30 is disposed in the actuated state such that the retainer 30 is disposed, relative to the wellbore 12, for preventing, or substantially preventing, downhole displacement of the sealing engagement effector actuating assembly 22 within the wellbore 12. While in the retained state, the sealing engagement effector 20, the sealing engagement
R&M REF: 52619-3114 effector actuating assembly 22, and the retainer 30 are further co-operatively configured such that, while the sealing engagement effector 20, the sealing engagement effector actuating assembly 22, and the retainer 30 are co-operatively disposed in the retained state such that, in response to release of the tensile or pulling force being applied to the sealing engagement effector actuating assembly 22, there is an absence of defeating of the actuated state of the sealing
engagement effector 20.
[0031] In some embodiments, for example, the retainer 30 includes a plurality of slip elements 32 disposed about an end of a retainer housing 34. Each slip element 32 has a gripping end 36 having an outer surface configured for releasably securing the gripping end 36 of the slip elements 32 to the inner surface 17 of the wellbore casing 16.
[0032] In some embodiments, for example, each slip element 32 includes a drag-block element 38 for resisting displacement of the retainer 30 relative to the wellbore casing 16. In some embodiments, for example, the drag-block element 38 induces a frictional drag force relative to the wellbore casing 16 in a direction opposite to the direction of displacement of the mandrel 18.
[0033] In some embodiments, for example, the retainer 30 includes a biasing member 40 for biasing the retainer 30 in the non-actuated or non-interfering position wherein the gripping end 36 of the slip elements 32 is disposed away from the inner surface of the wellbore casing 16. In some embodiments, for example, while the retainer 30 is disposed or biased in the non-actuated or non-gripping position, the biasing member 40 also serves to bias the drag-block element 38 of the slip elements 32 in a drag-inducing position such that the drag-block element contacts, or substantially contacts, the inner surface 17 of the wellbore casing 16 so as to resist inadvertent displacement of the retainer 30 relative to the casing 16 while the downhole tool or apparatus 10 is being disposed downhole within the wellbore 12.
R&M REF: 52619-3114 [0034] In some embodiments, for example, the biasing member 40 includes one or more springs 42 disposed intermediate the slip elements 32 and a portion of the retainer housing 34 such that the slip elements 32 can pivot relative to the gripper housing 34 about a pivot point 44. In some embodiments, for example, the pivot point 44 includes a strap 45 configured for holding the slip elements 32 in position relative to the retainer housing 34.
[0035] In some embodiments, for example, the downhole tool or apparatus 10 includes a retainer actuator 51 that is slidably mounted on the mandrel 18 and displaceable relative to the mandrel 18. In the subject example embodiment, the sealing engagement effector actuating assembly 22 includes the retainer actuator 51 and, in some embodiments, for example, the retainer actuator 51 is the uphole engager 50.
[0036] The retainer actuator 51 is configured for releasable coupling with the retainer 30 such that the releasable coupling is with effect that the retainer 30 becomes disposed in its interfering or actuated state. More specifically, disposition of the retainer actuator 51 intermediate the sealing engagement effector 20 and the retainer 30 is such that displacement of the mandrel 18 in an uphole or first direction in response to application of a pulling force or tensile force applied to the mandrel 18 in the uphole direction is with effect that the retainer actuator 51 becomes releasably coupled with the retainer 30 by the urging of the sealing engagement effector 20 and the downhole engager 25, together, pushing or displacing the retainer actuator 51 uphole towards the retainer 30 with the uphole displacement of the mandrel 18.
[0037] The releasable coupling of the retainer actuator 51 with the retainer 30 is such that the retainer 30 is urged into the actuated state by the retainer actuator 51 in response to displacement of the mandrel 18 relative to the retainer 30 along an axis parallel, or substantially parallel, to the central longitudinal axis 15 of the mandrel 18 that is effected in response to an application of a tensile force to the
R&M REF: 52619-3114 mandrel 18. In some embodiments, for example, the releasable coupling of the retainer actuator 51 with the retainer 30 is such that the slip elements 32 are displaced radially outwardly, with respect to the central longitudinal axis 15 of the mandrel 18, such that they become disposed in the interfering or gripping position with the gripping ends 36 of the slip elements 32 releasably engaging with the inner surface 17 of the casing 16 such that displacement of the retainer 30 relative to the wellbore casing or string 16 is prevented, or substantially prevented.
[0038] In some embodiments, for example, the retainer actuator 51 includes an interface surface 52 for engaging a corresponding interface surface 37 on the retainer 30. In some embodiments, for example, the corresponding interface surface 37 is disposed on an inner surface of the gripping end 36 of the slip elements 32.
[0039] In some embodiments, for example, the retainer actuator interface surface 52 and the retainer interface surface 37 include complementary frusto- conical surfaces wherein the retainer 30 and the retainer actuator 51 are
cooperatively configured such that the retainer actuator 51 becomes disposed within an end of the retainer 30 such that the disposition of the retainer 30 into the actuated state is effected by displacement of the frusto-conical retainer interface surface 37 over the corresponding frusto-conical retainer actuator interface surface 52. Displacement of the frusto-conical retainer interface surface 37 over the corresponding frusto-conical retainer actuator interface surface 52 urges the retainer 30 or slip elements 32 radially outwardly, relative to the central
longitudinal axis of the mandrel 18 such that the slip elements 32 grip the inner surface 17 of the wellbore casing 16 thereby actuating the retainer 30 and setting the retainer 30 of the apparatus or downhole tool 10 in position within the wellbore 12.
[0040] In some embodiments, for example, the releasable coupling of the retainer 30 with the wellbore 12 or wellbore casing 16 effected by the disposition of
R&M REF: 52619-3114 the retainer 30 into the actuated state includes an interference fit. In some embodiments, for example, the interference fit includes the gripping of teeth against the inner surface 17 of the wellbore 12 or wellbore casing 16.
[0041] In some embodiments, for example, the mandrel 18 and the retainer 30 are cooperatively configured for cooperative disposition in one of a
displacement-permitting state and a displacement-interfering state. In the
displacement-permitting state, the mandrel 18 and the retainer 30 are
cooperatively configured and cooperatively disposed such that the mandrel 18 is displaceable relative to the retainer 30 in response to pushing and/or pulling forces applied to the mandrel 18 along an axis parallel, or substantially parallel, to the central longitudinal axis 15 of the mandrel 18. In the displacement-interfering state, the mandrel 18 and the retainer 30 are cooperatively configured and cooperatively disposed such that the retainer 30 is disposed relative to the mandrel 18 for preventing or substantially preventing downhole displacement of the mandrel 18, relative to the retainer 30, within the wellbore 12 while uphole displacement of the mandrel 18 relative to the retainer 30 is permitted.
[0042] In some embodiments, for example, the apparatus or downhole tool 10 includes a mandrel coupler 60 for releasably coupling the mandrel 18 to the retainer 30 such that the mandrel 18 and the retainer 30 are disposed in the displacement-interfering state.
[0043] In some embodiments, for example, the releasable coupling of the mandrel 18 to the retainer 30 includes an interference fit.
[0044] In some embodiments, for example, the mandrel coupler 60 includes a ratchet mechanism.
[0045] In some embodiments, for example, the releasable coupling of the mandrel 18 to the retainer 30 includes meshing of corresponding sets of teeth.
More specifically, in some embodiments, for example, the retainer 30 includes a
R&M REF: 52619-3114 first displacement-interfering effector or a first set of teeth 62, while the mandrel 18 includes a second displacement-interfering effector or a second set of teeth 64 configured for meshing with the first set of teeth 62 such that displacement of the first set of teeth 62 relative to the second set of teeth 64 is permitted in only one direction.
[0046] In some embodiments, for example, the first set of teeth 62 includes a first set of threads and the second set of teeth 64 includes a second set of threads wherein meshing of the first set of teeth 62 with the second set of teeth 64 is effected by linear displacement of the mandrel 18 in the uphole direction relative to the retainer 30 in response to application of a pulling force or a tensile force applied to the mandrel 18.
[0047] In some embodiments, for example, the mandrel 18 includes a threaded coupling ring 68 disposed on the mandrel 18 while a corresponding threaded coupling portion 70 is disposed on an inner surface of the retainer housing 34 and configured for releasably coupling with the coupling ring 68. In some embodiments, for example, the coupling ring 68 includes the second set of teeth 64 while the coupling portion 70 includes the first set of teeth 62.
[0048] Referring now to Figure 6 there is shown a detail view of one of the corresponding sets of meshing teeth or threads of the mandrel coupler 60. In some embodiments, for example, the teeth 64 or the threaded profile of the coupling ring 68 includes a buttress thread. In some embodiments, for example, the teeth 64 or threaded profile of the coupling ring 68 are characterized by about 6 threads per inch wherein each thread has a first angled surface 65 disposed at an angle a of about 20 degrees with respect to an axis parallel, or substantially parallel, relative to the central longitudinal axis of the mandrel 18 and a second angled surface 67 disposed at an angle b of about 60 degrees relative to the central longitudinal axis 15 of the mandrel 18. The corresponding set of teeth 62 or threaded profile disposed in the corresponding inner surface of the retainer 30 is configured for
R&M REF: 52619-3114 cooperative disposition or mating relationship with the first set of threads. As engagement between the threaded profile or first set of teeth 62 disposed on the retainer 30 advance over the corresponding threaded profile or second set of teeth 64 disposed on the mandrel 18, more of the teeth associated with the retainer 30 become engaged with the teeth associated with the mandrel 18 effectively increasing the strength of the releasable coupling between the mandrel 18 relative to the retainer 30 in the displacement-interfering state.
[0049] In some embodiments, for example, the retainer housing 34 includes a first, outer sleeve 72 and a second, inner sleeve 74 wherein the second sleeve 74 is received within a portion of the outer sleeve 72 and coupled thereto such that the first and second sleeves 72, 74 are fixed relative to each other.
[0050] In some embodiments, for example, the displacement of the mandrel 18, relative to the retainer 30 is effected via coupling of the mandrel 18 to the retainer 30 via a j-slot 80. In some embodiments, for example, the mandrel 18 includes j-slot 80 and the retainer 30 includes a j-slot engager 82. The j-slot 80 is defined by or provided in the external surface of the mandrel 18 and the retainer 30 is disposed on the mandrel 18 such that the j-slot engager 82 is disposed within the j-slot 80 such that displacement of the mandrel 18 relative to the retainer 30 is limited or guided by the interaction of the j-slot engager 82 with the j-slot 80.
Accordingly, in some embodiments, the cooperative disposition of the mandrel 18 and the retainer 30 is such that j-slot engager 82 is disposed within the j-slot 80 such that displacement of the mandrel 18 relative to the retainer 30 is limited, or substantially limited, by translation of the j-slot engager 82 within the j-slot 80.
[0051] In some embodiments, for example, the j-slot engager 82 includes a j- pin that extends from an inner surface of the gripper housing 30.
[0052] In some embodiments, for example, the j-slot engager 82 is disposed within the retainer housing 34 such that the retainer housing 34 is rotatable relative
R&M REF: 52619-3114 to the j-slot engager 82. In some embodiments, for example, the j-slot engager 82 is disposed intermediate the first, outer sleeve 72 and a second, inner sleeve 74 of the retainer housing 34, the first, outer sleeve 72 and the second, inner sleeve 74 being secured together or coupled such that the first outer sleeve 72 and the second inner sleeve 74 are fixed, or substantially fixed, relative to one another. In some embodiments, for example, the coupling of the first outer sleeve 72 and the second inner sleeve 74 is such that the retainer housing 34 defines an annular channel 75 configured for receiving the j-slot engager 82.
[0053] In some embodiments, for example, the j-slot 80 includes a first portion 84 that defines a first length of linear displacement of the mandrel 18 relative to the retainer 30, and a second portion 86 that defines a second length of linear displacement of the mandrel 18 relative to the retainer 30. The first portion 84 of the j-slot 80 having a length greater than the length of the second portion 86 of the j-slot, the first portion 84 of the j-slot 80 being connected to the second portion of the j-slot 84 by an actuation portion 88, the j-slot engager 82
transitioning from travel along or within the first portion 84 of the j-slot 80 to travel within the second portion 86 of the j-slot 80 by translation through the actuation portion 88 of the j-slot 80.
[0054] In some embodiments, for example, while the apparatus or downhole tool 10 is being disposed downhole within the wellbore 12, the j-slot engager 82 is disposed for travel within the first portion 84 of the j-slot 80. As the downhole tool or apparatus 10 is disposed downhole or pushed or "run-in hole" (RIH) by
application of a pushing or downhole force applied to the mandrel 18, the j-slot engager 82 becomes disposed at a first end or first terminus 89 of the j-slot 80 with effect that the retainer 30 is disposed for downhole displacement with the mandrel 18 due to the interaction between the j-slot engager 82 and the first terminus 89 of the j-slot 80.
R&M REF: 52619-3114 [0055] Uphole displacement of the mandrel 18 relative to the retainer 30 un- seats the j-slot engager 82 from the first terminus 89 of the j-slot 80, the mandrel 18 travelling uphole relative to the retainer 30 until the j-slot engager 82 is disposed at a second end of the first portion 84 or second terminus 90 of the j-slot 80. During the uphole displacement of the mandrel 18 relative to the retainer 30, the retainer 30 remains stationary, or substantially stationary, relative to the wellbore 12 due to the interaction between the drag-blocks 38 of the retainer 30 relative to the inner surface 17 of the wellbore casing or string 16. Further downhole displacement of the retainer 30 relative to the wellbore 12 is achieved once the j-slot engager 82 becomes disposed at the first terminus 89 of the first portion 84 of the j-slot 80 in response to application of a compressive or downhole force applied to the mandrel 18, the retainer 30 once again being disposed, relative to the mandrel 18, for downhole displacement with the mandrel 18. The uphole and downhole displacement, or "cycling", of the mandrel 18 relative to the retainer 30 guided by displacement of the j-slot engager 82 within the first portion 84 of the j- slot 80 between the first terminus 89 and second terminus 90 of the first portion 84 of the j-slot 80 continues until the apparatus or downhole tool 10 achieves the desired depth or location within the wellbore 12.
[0056] Once the apparatus or downhole tool 10 has reached the desired depth or desired location within the wellbore 12 or wellbore casing 16 where the sealing engagement, or substantially sealing engagement, of the downhole tool or apparatus 10 relative to the wellbore 12 is to be effected, displacement of the mandrel 18 relative to the retainer 30 is effected such that the j-slot engager 82 transitions from the first portion 84 of the j-slot 80 to the second portion 86 of the j-slot 80 via translation through the actuation portion 88 of the j-slot 80. In a first step of the actuation of the j-slot 80, the mandrel 18 is displaced uphole relative to the retainer 30 via application of a pulling force or tensile force applied to the mandrel 18 such that the j-slot engager 82 becomes disposed at the second terminus 90 of the j-slot 80.
R&M REF: 52619-3114 [0057] Once the mandrel 18 is displaced relative to the retainer 30 such that the j-slot engager 82 becomes disposed in the second terminus 90 of the j-slot 80, further displacement of the mandrel 18 relative to the retainer 30 in the uphole direction is prevented by the interaction between the j-slot engager 82 and terminus 90 of the j-slot 80. Accordingly, in order to continue actuation of the j- slot 80 and translation of the j-slot engager 82 through the actuation portion 88 of the j-slot 80, the mandrel 18 is displaced downhole, relative to the retainer 30, in response to application of a pushing or downhole force applied to the mandrel 18 until the j-slot engager 82 is disposed at a first, intermediate terminus 92, wherein the downhole displacement of the mandrel 18 relative to the retainer 30 is guided by translation of the j-slot engager 82 through the actuation portion 88 of the j-slot 80 from the second terminus 90 to the first intermediate terminus 92, which translation effects further rotation of the mandrel 18. The downhole displacement of the mandrel 18 relative to the retainer 30 between the second terminus 90 and the first intermediate terminus 92 defines a second step in the actuation sequence through the j-slot 80.
[0058] The downhole displacement of the mandrel 18 relative to the retainer 30 such that the j-slot engager 82 becomes disposed at the first intermediate terminus 92 is followed by displacement of the mandrel 18, relative to the retainer 30, in the uphole direction by application of a pulling force or tensile force applied to the mandrel 18 such that the j-slot engager 82 becomes disposed at a second, intermediate terminus or entrance 94 of the second portion 86 of the j-slot 80.
[0059] Once the actuation sequence through the actuation portion 88 of the j- slot 80 is completed and the j-slot engager 82 is disposed at the second
intermediate terminus or at the entrance 94 of the second portion 86 of the j-slot 80, the retainer actuator 51, the sealing engagement effector 20 and the downhole engager 24 are disposed proximal to the retainer 30 as a result of the uphole displacement of the mandrel 18 relative to the retainer 30. However, with the j-slot engager 82 disposed at the second intermediate terminus 94 or at the entrance of
R&M REF: 52619-3114 the second portion 86 of the j-slot, the retainer 30 remains disposed in its non- actuated state. In some embodiments, for example, completion of the actuation sequence through the j-slot 80 is with effect that the retainer actuator 51 begins coupling with the retainer 30 but does not actuate the retainer 30 such that the retainer 30 becomes disposed in the actuated state wherein the retainer 30 is releasable coupled relative to the wellbore strong 16.
[0060] Once the mandrel 18 is displaced relative to the retainer 30 such that the j-slot engager 82 is disposed at the entrance 94 of the second portion 86 of the j-slot 80, continued application of the pulling force or tensile force to the mandrel 18 such that the mandrel 18 is displaced further uphole relative to the retainer 30 which effects displacement of the downhole engager 24 and sealing engagement effector 20 towards the retainer actuator 51 (or uphole engager 50) such that the retainer actuator 51 becomes disposed within the retainer 30 such that the retainer 30 becomes disposed in the actuated stated. The apparatus or downhole tool 10 is now disposed such that the retainer 30 is disposed in a "set position" wherein the retainer 30 is releasably coupled to the wellbore casing 16 such that displacement of the retainer 30 relative to the wellbore casing or string 16 is prevented, or substantially prevented.
[0061] While the apparatus or downhole tool 10 is disposed such that the retainer 30 begins effecting releasable coupling with the inner surface 17 of the wellbore string 16, un-coupling of the retainer 34 relative to the wellbore string 16 via downhole displacement of the mandrel 18 relative to the retainer 30 is permissible such that the j-slot engager 82 returns to the first portion 84 of the j- slot 80 via translation through the actuation portion 88 of the j-slot 80 provided that the retainer 30 and the mandrel 18 remain cooperatively disposed in the displacement-permitting state. Accordingly, downhole displacement of the mandrel 18 relative to the retainer 30 while the retainer 30 and the mandrel 18 remain cooperatively disposed in the displacement-permitting state is with effect that the
R&M REF: 52619-3114 retainer actuator 51 is urged out of engagement with the retainer 30 such that the retainer 30 becomes disposed in the non-actuated state.
[0062] Once the retainer 30 is disposed in the actuated state wherein the retainer actuator 51 is disposed within the retainer 30 such that the retainer 30 is releasably coupled to the inner surface 17 of the wellbore casing 16 with effect that displacement of the retainer 30 relative to the wellbore casing or string 16 is prevented, or substantially prevented, continued application of the pulling force or tensile force applied to the mandrel 18 effects further uphole displacement of the mandrel 18 relative to the retainer 30, guided by translation of the j-slot engager 82 within the second portion 86 of the j-slot 80, which displacement effects actuation of the mandrel coupler 60 such that the mandrel 18 is releasably coupled relative to the retainer 30 such that downhole displacement of the mandrel 18 relative to the retainer 30 is prevented, or substantially prevented. Once the releasable coupling of the mandrel 18 relative to the retainer is effected, continued application of the pulling force or tensile force applied to the mandrel 18 is with effect that the mandrel 18 is displaced further uphole relative to the retainer 30 such that the j-slot engager 82 becomes disposed at the end of the second portion 86 of the j-slot or at a third terminus 96 of the j-slot 80. Displacement of the mandrel 18 relative to the retainer 30 such that the j-slot engager 82 is disposed at the end of the second portion 86 of the j-slot or at the third terminus 96 of the j- slot 80 effects actuation of the sealing engagement effector actuating assembly 22 such that the sealing engagement effector 20 is compressed between the retainer actuator 51, or uphole engager 50, and the downhole engager 25 with effect that the sealing engagement effector 20 is disposed in the actuated state with the surface portion 19 of the sealing engagement effector 20 assuming its second, operative orientation in sealing engagement, or substantial sealing engagement, with the inner surface 17 of the wellbore string 16.
[0063] In some embodiments, for example, the cooperative disposition of the mandrel and the retainer in the displacement-interfering state begins upon
R&M REF: 52619-3114 application of a minimum pulling force or tensile force of 3000lbs applied to the mandrel 18 with continued application of an increasing pulling force or tensile force applied to the mandrel 18 effecting further cooperative disposition of the mandrel 18 relative to the retainer 30 in the displacement-interfering state.
[0064] In some embodiments, for example, actuation of the sealing
engagement effector actuating assembly is effected upon application of a pulling force or tensile force applied to the mandrel 18 greater than 3000lbs.
[0065] Once the mandrel 18 is releasably coupled to the retainer 30 via actuation of the mandrel coupler 60, displacement of the mandrel 18 relative to the retainer 30 such that the j-slot engager 82 becomes disposed in or returns to the first portion 84 of the j-slot 80 is no longer permitted through a reverse sequence of actuation steps through the actuation portion 88 of the j-slot 80 as downhole displacement of the mandrel 18 relative to the retainer 30 is prevented, or substantially prevented. Continued application of the pulling or tensile force applied to the mandrel 18 effects actuation of the sealing engagement effector 22 such that the sealing engagement effector 22 is disposed in sealing engagement, or substantial sealing engagement, with the wellbore string 16. Accordingly, the release or cessation or termination of the pulling force or tensile force applied to the mandrel 18 in the uphole direction is with effect that the sealing engagement effector actuating assembly 22 remains disposed in the sealing engagement effector actuated state with an absence of defeating of the actuated state of the sealing engagement effector 20.
[0066] As set out above, once the mandrel coupler 60 has been actuated and the mandrel 18 is releasably coupled to the retainer 30 through, for example, the meshing of the corresponding first and second sets of teeth 62, 64, continued application of the pulling or tensile force applied to the mandrel 18 in the uphole direction effects displacement of the downhole engager 24 towards the retainer actuator 51, which is now fixed relative to the retainer 30, such that the sealing engagement effector 20 is compressed between the retainer actuator 51 (or uphole engager 50) and the downhole engager 24 by the uphole displacement of the downhole engager 24 towards the retainer actuator actuator 51 or uphole engager 50 with displacement of the mandrel 18. Compression of the sealing engagement effector 20 against the retainer actuator 51 or uphole engager 50 is with effect that the sealing engagement effector 22 becomes disposed in its actuated state or operative orientation wherein the surface portion 19 of the sealing engagement effector 22 bulges radially outwardly and becomes disposed in sealing engagement, or substantially sealing engagement, with the inner surface 17 of the wellbore 12 or wellbore housing 16.
[0067] In some embodiments, for example, disposition of the apparatus 10 in the "set" position such that the mandrel 18 is disposed in a retained state relative to the retainer 30 and the sealing engagement effector 20 is disposed in the actuated state is effected upon displacement of the j-slot engager 82 relative to the j-slot 80 along the second portion 86 of the j-slot 80 such that the j-slot engager 82 becomes disposed at a third terminus 96 of the j-slot 80.
[0068] Once the sealing engagement effector 20 is disposed in its actuated state, removal or release of the pulling force or tensile force applied to the mandrel 18 required to effect actuation of the sealing engagement effector actuating assembly 22 does not result in the release the sealing engagement effector 20 from its actuated state since the mandrel 18 is prevented, or substantially prevented, from downhole displacement relative to the retainer 30. Accordingly, release or removal of the pulling force or tensile force required to effect sealing engagement of the sealing engagement effector 20 relative to the wellbore 12 does not defeat the sealing engagement, or substantial sealing engagement, of the sealing engagement effector 20 relative to the wellbore string 16 since the mandrel 18 and the retainer 30 remain cooperatively disposed in the displacement-interfering state with the mandrel 18 remaining coupled, relative to the retainer 30, such that displacement of the mandrel 18 in the downhole direction is prevented, or substantially prevented.
[0069] Positions of the mandrel 18 relative to the j-slot engager 82 of the retainer 30 within the j-slot 80 and corresponding to each of the steps for effecting actuation of the sealing engagement effector 20 within the wellbore are illustrated schematically in Figure 5.
[0070] In order to release or un-set the packer or sealing engagement effector 20 from sealing engagement, or substantial sealing engagement, within the wellbore 12, the coupling or co-operative disposition of the mandrel 18 and the retainer 30 in the displacement-interfering state must be released or defeated in order to allow for downhole displacement of the mandrel 18 relative to the retainer 30 such that the sealing engagement effector actuating assembly 22 assumes a non-actuated state. In some embodiments, for example, rotation the mandrel 18 relative to the retainer 30 is with effect that the coupling between the mandrel 18 and the retainer 30 is defeated such that downhole displacement of the mandrel 18 relative to the retainer 30 is permitted.
[0071] In some embodiments, for example, the rotation of the mandrel 18 relative to the retainer 30 is with effect that the first and second sets of teeth associated with the mandrel coupler 60 become un-meshed thereby permitting displacement of the mandrel 18, relative to the retainer 30, in the downhole direction.
[0072] Rotation of the mandrel 18 relative to the retainer 30 once the retainer 30 has been actuated and the sealing engagement effector 20 is disposed in the actuated state is possible, in the subject example embodiment, as a result of the j- slot engager 82 being rotatable relative to the retainer housing 34. More
specifically, given that while the retainer 30 is disposed in its actuated state and the sealing engagement effector 20 is disposed in its seal-effecting position or actuated state the j-slot engager 82 is disposed at the terminus 96 associated with the end of the second portion 86 of the j-slot 80, disposition of the j-slot engager 82 within the j-slot 80 is with effect that the j-slot engager 82 will rotate with rotation of the mandrel 18. As the j-slot engager 82 is mounted within the retainer housing 34 such that the j-slot engager 82 is rotatable relative to the retainer housing 34, un- meshing of the corresponding sets of teeth 62, 64 is permitted by rotation of the mandrel 18 relative to the retainer housing 34. Once the corresponding sets of teeth 62, 64 are un-meshed and/or the mandrel coupler 60 becomes disengaged, the mandrel 18 is free for displacement, relative to the retainer 30, in the downhole direction which downhole displacement of the mandrel 18 effects displacement of the downhole engager 24 away from the retainer 30 and retainer actuator 51 thereby returning the sealing engagement effector 20 to its non-actuated state or non-operative orientation with the surface portion 19 of the sealing engagement effector 20 disposed in its first or neutral position.
[0073] In some embodiments, for example, un-setting of the sealing
engagement effector 20 is effected by application of an uphole or tensile force applied to the mandrel 18 that is sufficient to effect shearing of the shear pins or shear screws 26 that effect coupling of the downhole engager 25 to the mandrel 18. Shearing the shear pins or shear screws 26 is with effect that the downhole engager 24 becomes displaceable relative to the mandrel 18 allowing the downhole engager 24 to move away from the retainer actuator 51 or uphole engager 50 which displacement away from retainer actuator 51 or uphole engager 50 is with effect that the sealing engagement effector 20 returns to its neutral or non- actuated state. Once the sealing engagement effector 20 has been returned to its neutral or non-actuated state, the retainer actuator 51, which is slidable relative to the mandrel 18, is also free to move downhole as the sealing engagement effector 20 and downhole engager 24 no longer impede its downhole displacement relative to the mandrel 18 which, in turn, allows to the retainer 30 to return to its non- interfering position or non-actuated state. [0074] In some embodiments, for example, un-setting of the sealing engagement effector 20 is effected by shearing of the shear pins or shear screws 26 used for securing the downhole engager 25 to the mandrel 18. In some
embodiments, for example, each shear pin 26 is designed to fail or shear when subjected to a minimum tensile or pulling force of about 4600lbs, the number of shear pins 26 and their displacement about the downhole engager 25 being specifically selected in order to ensure that the downhole engager 25 remains fixed to the mandrel 18 until such time as a predetermined tensile force or pulling force is applied to the mandrel 18 to effect shearing of the pins 26 thereby releasing the downhole engager 25 relative to the mandrel 18.
[0075] In some embodiments, for example, un-setting of the sealing engagement effector 20 is effected by application of a pushing or compressive downhole force of about 10,000lbs applied to the mandrel 18 which releases engagement of the mandrel coupler 60 with effect that the corresponding sets of teeth 62, 64 become un-meshed or disengaged allowing downhole displacement of the mandrel 18 relative to the retainer 30. Once the corresponding sets of teeth 62, 64 of the mandrel coupler 60 become un-meshed, the mandrel 18 can be displaced in the downhole direction which allows the sealing engagement effector 20 to return to its neutral, non-actuated state as the downhole engager 24 can, once again, be displaced downhole away from the retainer 30 with displacement of the mandrel 18.
While various example embodiments of the apparatus or downhole tool 10 have been described, it will be understood that certain adaptations and modifications of the described embodiments can be made. Therefore, the above discussed embodiments are considered to be illustrative and not restrictive.