Embodiments usable within the scope of the present disclosure relate, generally, to apparatus, systems, and methods for setting an anchor within a wellbore, and more specifically to apparatus, systems and methods usable to accurately locate, position, and actuate cutters, torches, perforators, setting tools, and/or other types of tools used downhole.
Many wellbore operations necessitate anchoring a tool downhole and within a wellbore. Such downhole tools include, for example, torches, perforators, setting tools, fracturing equipment, and the like (collectively referred to herein as downhole tools).
A need exists, in the oil and gas industry, for the ability to anchor, clock in direction, and eventually release a transient tool or the tool string that will allow for precise and effective tool system performance. Enabling the precise location of: a force, an application of torque, a sensor, a perforation or cut, and a drilling exit or other downhole operation, at an optimal position, further reduces the requirement to reposition multiple-run, single location tools and tool processes, while reducing the chances of misguided or off-position deployments of the tools.
Some existing tool systems, deployed within a wellbore, are constructed with control lines surrounding the periphery of a pipe or tubular string. Removal of the pipe requires cutting both the pipe at the target location, and the control line or lines. Without cutting both, operators cannot complete the required finishing operations. Cutting operations that are powerful enough to cut through all the elements, however, are restricted in their use due to the danger of causing harm to the backside infrastructure. Thus, having the ability to make multiple, precise cuts at a single target plane can enable all elements to be cut. A need exists for placing tools that enable precise energy delivery for cut effectiveness.
To precisely position a tool, it is useful to place an anchor or anchoring system in a single position, such that multiple tools may lock into that anchor or anchoring system for an exact placement and positioning of each tool. With the anchor placed downhole, the tool does not have to rely on measurement or clocking from the surface. Alternatively, anchoring systems are needed to enable the positioning and repositioning of the same or multiple downhole tools, and to enable the orienting or clocking of the tool while downhole. The clocking of the downhole tool enables future operations to be performed by the downhole tool at the same downhole location or at an offset. The offset can include an angular offset (e.g., azimuthal, radial, polar, etc.) of the tool or a positional offset of the location of the downhole tool (e.g., a lower or higher depth within the wellbore, from the previous location within the wellbore at which the prior operations were conducted).
When screwed together and properly torqued, joints between pipes within a tubular string become relatively seamless, and the lack of distinguishable features makes the joints difficult to locate using conventional well logging devices. While casing collar locators and similar devices can assist in positioning a tool within a tubular string, existing devices are limited in their accuracy, which may generally be, at best, in the range of a few feet. A joint target within a tubular string may be just inches in length, requiring far more precise placement of a tool than current collar locators and similar devices can provide.
Completion processes taking place within a wellbore often require placing sensors, perforating a wall for communication, and perforating a casing such that contact with a geological feature is made. Operations such as gauge integration, cement squeezing, fracturing and jet drilling become subsequent processes.
Other positioning systems can include providing physical features within the interior of a tubular string that interact with corresponding physical features of a locating tool; however, these positioning systems require numerous, precisely crafted features to ensure proper function and interaction, including various moving parts to cause selective engagement between corresponding features.
A need exists for removable positioning apparatus and methods for positioning a tool with complementary mating integration capacity within a tubular string, for enabling precise positioning of anchorable tools at a preselected location, including joints, within the tubular string to facilitate the effectiveness of the tools. Having the flexibility of a selectively placed locking feature within a tubular member greatly enhances the tool's ability to positively fixate a tool, using pre-positioned anchoring profile mechanisms within a wellbore system.
A further need exists for positioning apparatus and methods usable for positioning a tool within a tubular string that are simple in construction and function, able to incorporate reusable, machinable, and re-machinable parts that are able to accommodate a variety of latching and/or engaging orientations.
A need also exists for positioning apparatus and methods usable for positioning a tool within a tubular string that are conveyable and deployable utilizing readily available setting tools.
The present embodiments meet these needs.
Embodiments of the present invention include apparatus, systems and methods usable to accurately locate, position, and actuate packers, cutters, torches, perforators, setting tools, and/or other types of tools used downhole.
The disclosed embodiments include a system for providing a self-centering reusable anchor location within a wellbore. The system includes an extreme range anchor having a first extending assembly configured to engage the wellbore. The first extending assembly can comprise a first set of arms that can connect to a first brace, a second set of arms that can connect to a second brace, and a set of footplates. Each footplate in the set of footplates can be connected at a first side to the first set of arms and can be connected at a second side to the second set of arms. Each footplate can comprise a fixator that can be coupled to a radially external face and configured to securely engage the wellbore. The extreme range anchor can include a pull rod that can be rigidly coupled to the first brace and slidably connected to the second brace. Forcing the pull rod in an axial direction can shorten the distance between the first brace and the second brace and can force the set of footplates to move in a radial direction toward the wellbore.
In certain embodiments, the system may include a second extending assembly configured to engage the wellbore. The second extending assembly may include a third set of arms connected to the second brace, a fourth set of arms connected to a third brace, and a second set of footplates. Each footplate in the second set of footplates can be connected at a first side of the third set of arms and connected at a second side to the fourth set of arms.
In certain embodiments, the system may include a body and an engagement key. The engagement key may be configured to engage with the body to maintain an axial position of the pull rod relative to the body when the pull rod is forced in the axial direction. In certain embodiments, the engagement key may be configured to disengage from within the body in response to the body being forced in the axial direction at a disengage threshold of force.
In certain embodiments, the set of footplates are configured to move a distance up to fifteen (15) centimeters in the radial direction to engage with the wellbore. In certain embodiments, the fixators may include cone-shaped fixators, half cone-shaped fixators, serrated fixators, or other fixators to securely engage the wellbore. In certain embodiments, the first extending assembly may include a pull rod spring, securing pins, securing bands, or other securing implements to prevent radial movement of the set of footplates, prior to the forcing of the pull rod.
In certain embodiments, the system may include fixator covers configured to cover the fixators. The fixator covers may prevent engagement between the fixators and the wellbore while the extreme range anchor is being deployed to a depth within the wellbore. In certain embodiments, the extreme range anchor may include a setting rod configured to connect to the pull rod with a tab at a first end, and to a setting tool at a second end. The setting tool may pull the setting rod to force the pull rod in the axial direction. In certain embodiments, the tab may be configured to shear the setting rod from the pull rod when pulled at a set force.
The disclosed embodiments can include a method of performing a downhole operation within a wellbore. The method can include lowering an extreme range anchor into the wellbore, wherein the extreme range anchor may include a tool connecting head. The method can include the step of actuating a setting tool to force a pull rod in an axial direction to extend a set of footplates in a radial direction. The footplates may be configured to securely engage the wellbore with fixators coupled to a radially external face of the footplates. The method can further include the steps of lowering a first tool onto the tool connecting head, completing a first operation with the first tool, retrieving the first tool to a surface of the wellbore, lowering a second tool onto the tool connecting head, completing a second operation with the second tool at a second location, and retrieving the second tool to the surface of the wellbore.
The method of the disclosed embodiments may also include pulling on the tool connecting head in the axial direction to disengage the set of footplates from the wellbore. The step of completing the first operation, the second operation, or combinations thereof, may include actuating an axial torch cutter, a radial torch cutter, a wellbore perforator, a production tubing cutter, or combinations thereof. Also, actuating the setting tool may include shearing a setting rod from the pull rod. The shearing may be configured to occur when the set of footplates are engaged with the wellbore. In certain embodiments of the methods disclosed, the first operation may be completed at a target location and the second operation may be completed within three (3) centimeters (1.18 inches), or less than three 3 centimeters of the target location. Also, the footplates may be configured to extend in the radial direction up to fifteen (15) centimeters.
In certain disclosed embodiments of a system for securely engaging a wellbore, the system can include a first arm rotatably connected to a first brace at a first end of the first arm, a second arm rotatably connected to a second brace at a first end of the second arm, and a pull rod rigidly connected to the first brace and slidably connected to the second brace and configured to translate in a longitudinal direction. When the pull rod translates the longitudinal direction, the first arm and the second arm may be configured to rotate so that a second end of the first arm and a second end of the second arm protrude in an axial direction perpendicular to the longitudinal direction.
In certain embodiments, the system can include a footplate rotatably connected to the second end of the first arm and the second end of the second arm. The system can further include a protrusion attached at the second end of the second arm. The protrusion can be configured to protrude into the wellbore after the pull rod translates in the longitudinal direction. The first arm may include a recess configured to house the protrusion during transport of the system into the wellbore, and the first arm, the second arm or combinations thereof can comprise flex features, as described below.
In the detailed description of various embodiments usable within the scope of the present disclosure, presented below, reference is made to the accompanying drawings, in which:
Before describing selected embodiments of the present disclosure in detail, it is to be understood that the present invention is not limited to the particular embodiments described herein. The disclosure and description herein is illustrative and explanatory of one or more presently preferred embodiments and variations thereof, and it will be appreciated by those skilled in the art that various changes in the design, organization, means of operation, structures and location, methodology, and use of mechanical equivalents may be made without departing from the spirit of the invention.
As well, it should be understood that the drawings are intended to illustrate and plainly disclose presently preferred embodiments to one of skill in the art, but are not intended to be manufacturing level drawings or renditions of final products and may include simplified conceptual views to facilitate understanding or explanation. As well, the relative size and arrangement of the components may differ from that shown and still operate within the spirit of the invention.
Moreover, it will be understood that various directions such as “upper”, “lower”, “bottom”, “top”, “left”, “right”, and so forth are made only with respect to explanation in conjunction with the drawings, and that components may be oriented differently, for instance, during transportation and manufacturing as well as operation. Because many varying and different embodiments may be made within the scope of the concept(s) herein taught, and because many modifications may be made in the embodiments described herein, it is to be understood that the details herein are to be interpreted as illustrative and non-limiting.
Referring now to
As shown in
To lock the extreme range anchor 10 into place, the lower section 12 can include a number of extending assemblies that can be retracted while the extreme range anchor 10 is lowered into the wellbore. Then, when the extreme range anchor 10 is in place the extending assemblies can extend outwardly, as explained in detail below.
The embodiment illustrated in
As shown in
The assemblies 20, 22 can extend radially outward in response to a pull rod 32, which pulls on a bottom end 34 of the extreme range anchor 10 to shorten the distance between the braces 28, 29, 30. That is, a setting tool, an electromechanical anchor, or other tool for pulling, urges the pull rod 32 (perhaps through intermediary components, as explained below) in an upper direction 36; and in response, the footplates 26 in the lower assembly 20 and the upper assembly 22 simultaneously extend in a radially outward direction 44. The simultaneous movement of all sets of arms 24a-d and footplates 26a-b self-centers the extreme range anchor 10 within the wellbore, tubing, etc. A pull rod spring 40 can be used to exert a force in a downward direction 42 during the time that the extreme range anchor 10 travels down the wellbore to keep the assemblies 20, 22 radially inward 38 and to prevent vibration or accidental movement of the assemblies 20, 22 due to loose movement of the arms 24a-d and/or the footplates 26a-b.
To deploy the extreme range anchor 10, the pull rod 32 is pulled in the upward radial direction 36, as mentioned above.
A deployed embodiment of the extreme range anchor 10 of
As an additional but not limiting example,
To protect the fixators 64 during travel down the wellbore, the footplate 26 may include a fixator cover 84 (shown in
The pull rod 32 can be kept in place by a variety of securing devices. For example, the upper section 14 may include an engagement key 110, retention shear pin 122, and ridges 112 inside the cavity 102 of the body 98. The ridges 112 in the illustrated embodiment are shaped to enable the engagement key 110 to slide axially upward 36, but prevent the engagement key 110 from sliding downward 42. A lower edge 114 of each ridge 112 can be angled slightly to reduce the friction between a top edge 116 of the engagement key 110. An upper edge 118 of the ridges 112, however, is angled to increase the retaining ability of a bottom edge 120 of the engagement key 110. The engagement key 110 may also include an engagement spring 124 that increases the radially outward 44 force of the engagement key 110 against the ridges 112. The engagement key 110 may include embodiments where the engagement spring 124 is a coil spring, or as illustrated, may include a resilient material, or an arc spring that forces the engagement key 110 toward the ridges 112.
After deployment, the anchor 10 may stay in the deployed location for a number of operations. One or more tools can be lowered downhole and onto the alignment member 16 for operation. After all desired tool operations are completed, an operator may retrieve the extreme range anchor 10 by returning the extending assemblies 20, 22 to the traveling position. For example, the electromechanical may use a motor to move the pull rod 32 back down 42 relative to the upper section 14 and the upper brace 30. The pull rod 32 may also be released by fracturing or shearing the retention shear pin 122. The retention shear pin 122 may be calibrated to fracture at a disengaged threshold of force on the extreme range anchor 10. Alternatively, a retrieving tool may be lowered and secured onto the alignment member 16 and pulled axially upward 36. At the disengage threshold, the retention shear pin 122 shears, allowing the pull rod 32 to be disconnected from the engagement key 110. The downhole end of the collar 100 will make contact with the uphole end of the shoulder 120 upon retrieval. The pull rod spring 40 forces the pull rod 32 to stay in the extended position, which keeps the extending assemblies 20, 22 radially inward 38 so the anchor 10 can be fully retrieved. The retrieval operation may be completed by the last tool to be oriented on the anchor 10. The last tool in that instance would be positioned to apply sufficient overpull to the anchor 10 so that the retention shear pin 122 breaks or shears.
During transport of the anchor 10 down the wellbore, the lower arm 132a and the upper arm 132b are substantially parallel to the pull rod 32, slimming the profile of the extreme range anchor 10 in a similar manner to the embodiment shown in
The upper arm 132b (or the lower arm 132a, in certain embodiments) may also include flex features 144, or other cushioning features, that enable the upper arm 132b to cushion or flex during deployment. Flex and cushion may be useful to set and maintain connection between the protrusion 134 and the wellbore. For example, as shown in
To prevent this traction loss, the flex features 144 (as shown in
The flex features 144 may include slots, striations, grooves, or other physical changes to the arm (e.g., upper arm 132b) that enable an otherwise rigid arm to flex or arch without deforming or permanently bending. The flex features 144 may also include material differences to the arms. For example, the arms 132 may be constructed from a flexible metal, polymer, rubber, or other material that does not deform under a load. Furthermore, the flex features 144 may include combinations of these or other features that enable the arms 132 to provide an increased force normal to the interior surface of the wellbore.
In certain embodiments, the anchor 10 may be purposefully offset from a center of the wellbore. For example, the lower arms 132a and upper arms 132b may vary in length from one set of the extending assembly 130 to another set. That is, the upper arm 132b of one set may be longer than the upper arms 132b of the other sets of the particular extending assembly 130. This may result in the shorter upper arm 132b being attached to the middle brace 29 while the longer upper arm 132b is attached to a different middle brace. When the extending assembly 130 is deployed, the longer arms of one set will force the anchor 10 away from the center of the wellbore before the shorter arms of another set engage the wall of the wellbore. Alternatively or additionally, to offset the anchor 10 from the center of the wellbore, a connection point 146 between the lower arm 132a and the upper arm 132b may be adjusted. In the illustrated embodiment of
In embodiments with longer recesses 138, the connection 148 may be located closer to the middle brace 29 by an extended length 150, thus relocating the connection point 146 to the connection 148. The lengths of the upper arms 132b may remain the same, however, the connection point 146 can be changed to any connection 148 along the upper arm 132b. When the connection point 146 is located at the connection 148, and is closer to the middle brace 29, the deployment of the extending assembly 130 can cause the protrusion 134 to extend further from the lower extending assembly 130. This would allow the upper arm 132b, with the protrusion 134, to extend further away from the extreme range anchor 10 for a given translation distance by the pull rod 32. Thus, if the connection point 146 were located at different a different connection 148 for each set of arms 132a, 132b, the extreme range anchor 10 would be positioned at a non-central position within the wellbore.
While various embodiments usable within the scope of the present disclosure have been described with emphasis, it should be understood that within the scope of the appended claims, the present invention can be practiced other than as specifically described herein.
The present application is a continuation application of co-pending U.S. patent application Ser. No. 15/340,835, having the title of “Systems and Methods for Setting an Extreme-Range Anchor within a Wellbore, filed Nov. 1, 2016, which is a continuation-in-part of U.S. patent application Ser. No. 14/143,534, having the title of “Tool Positioning And Latching System,” filed Dec. 30, 2013, U.S. patent application Ser. No. 14/727,609, having the title of “Anchor System For Pipe Cutting Apparatus”, filed Jun. 1, 2015, U.S. patent application Ser. No. 13/507,732, having the title of “Permanent Or Removable Positioning Apparatus And Method For Downhole Tool Operations,” filed Jul. 24, 2012, and U.S. patent application Ser. No. 14/930,369, having the title of “Setting Tool For Downhole Applications”, filed Nov. 2, 2015, all of which are incorporated in their entireties by reference herein.
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3460625 | Ellis | Aug 1969 | A |
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Number | Date | Country |
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2014044843 | Jul 2014 | WO |
2016137465 | Sep 2016 | WO |
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20190271201 A1 | Sep 2019 | US |
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Parent | 15340835 | Nov 2016 | US |
Child | 16414547 | US |
Number | Date | Country | |
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Parent | 14143534 | Dec 2013 | US |
Child | 15340835 | US | |
Parent | 14727609 | Jun 2015 | US |
Child | 14143534 | US | |
Parent | 14930369 | Nov 2015 | US |
Child | 14727609 | US | |
Parent | 13507732 | Jul 2012 | US |
Child | 14930369 | US |