CN110114550B - System and method for deploying an end-of-range anchor in a wellbore - Google Patents

Abstract

Systems and methods include an extreme range anchor having an extension assembly configured to engage a wellbore for providing a self-centering reusable anchoring location within the wellbore. The extension assembly includes a first set of arms connected to the first support, a second set of arms connected to the second support, and a set of pedals. Each pedal of the set of pedals is connected to the first set of arms and the second set of arms. Each tread includes a retainer coupled radially outward and configured to securely engage the wellbore. The system also includes a tie rod rigidly coupled to the first support and slidably connected to the second support. Pushing the tie rod in an axial direction shortens the distance between the first and second supports and pushes the set of pedals to move in a radial direction towards the wellbore.

Description

System and method for deploying an end-of-range anchor in a wellbore

Cross Reference to Related Applications

The present application is a Patent Cooperation Treaty (PCT) application claiming priority from U.S. patent application No. 15/340835 entitled "System And Method For Setting An Extreme Range Anchor in a Wellbore" filed on day 11/2 2016, U.S. patent application No. 14/143,534 entitled "Tool Positioning And locking System (Tool Positioning And locking System)" filed on day 12/30 2013, U.S. patent application No. 14/143,534 entitled "Anchor System For Pipe Cutting Apparatus (Anchor System For Pipe Cutting Apparatus, U.S. patent application No. 14/727,609 filed on day 6/1 2015, U.S. patent application No. 3524 filed on day 7, U.S. patent application No. 13/507732 entitled" Permanent Or Removable Positioning Apparatus And Method For Downhole Tool operation "(U.S. patent application No. 13/507732 entitled" Permanent Or Removable Positioning Apparatus For Downhole Tool operation ", filed on day 11/2 of 2016) And filed on day 11/2 2015, a priority continuation of U.S. patent application No. 14/930,369 entitled Setting Tool For Downhole Applications, all of which are incorporated herein in their entirety.

Technical Field

Embodiments usable within the scope of the present disclosure generally relate to apparatus, systems, and methods for emplacing anchors within wellbores, and more particularly, to apparatus, systems, and methods that may be used to accurately position, and actuate cutters, flames, perforators, emplacement tools, and/or other types of tools used downhole.

Background

Many wellbore operations require anchoring tools downhole and within the wellbore. Such downhole tools include, for example, fires, perforators, setting tools, fracturing equipment, and the like (collectively referred to herein as downhole tools).

In the oil and gas industry, there is a need to be able to anchor, orient, and ultimately release transient tools or tool strings to allow accurate and efficient tool system performance. Achieving precise locations of forces, applied moments, sensors, perforations or cuts, and drilling or other downhole operations at optimal locations further reduces the need to relocate multiple runs, single unit tool and tool processes, while reducing the chance of misleading or off-site deployment of tools.

Some existing tool systems deployed within a wellbore are configured with control lines around the perimeter of the pipe or tubing string. Removing the pipe requires cutting the pipe at the target location and one or more control lines. Without cutting, the operator cannot complete the desired surface treatment operation. The cutting operation is sufficient to sever all the components, however, it is limited in use due to the risk of injury to the rear side infrastructure. Thus, having the ability to make multiple precision cuts on a single target plane allows all of the components to be cut. It is desirable to place a tool that enables precise energy delivery to improve cutting efficiency.

In order to accurately position the tools, it is useful to place an anchor or anchor system in a single location so that multiple tools can be locked into the anchor or anchor system for accurate placement and positioning of each tool. The tool does not have to rely on measurements or pointing from the surface when placing the anchor downhole. Alternatively, an anchoring system is needed to enable positioning and repositioning of the same or multiple downhole tools, and to enable orientation or pointing of the tools while downhole. The orientation of the downhole tool enables future operations to be performed by the downhole tool at the same downhole location or offset. The offset may include an angular offset (e.g., azimuthal, radial, polar, etc.) of the tool, a positional offset (e.g., a lower or higher depth within the wellbore from a previous position within the wellbore where a previous operation was performed, etc.) of a location of the downhole tool.

When screwed together and twisted properly, the joint between the pipes within the string becomes relatively seamless and the lack of distinguishable features makes it difficult to locate the joint using conventional logging devices. While casing collar locators and similar devices may help locate tools within a pipe string, the accuracy of existing devices is limited, which can typically be in the range of up to several feet. The joint targets within the tubular string may be only a few inches long, providing more accurate tool placement than existing ferrule positioners and similar devices.

Completing a procedure within a wellbore often requires placing sensors, perforating the wall for communication, and perforating the casing to make contact with the geologic features. Operations such as wire path integration, cement extrusion, fracturing and jet drilling become subsequent processes.

Other positioning systems may include providing physical features inside the tubular string that interact with corresponding physical features of the positioning tool; however, these positioning systems require a number of precisely fabricated features to ensure proper function and interaction, including various moving parts to cause selective engagement between the respective features.

There is a need for a removable positioning apparatus and method for positioning a tool having complementary mating integration capabilities within a tubular string so as to enable precise positioning of an anchorable tool at preselected locations within the tubular string, including joints, to facilitate the effectiveness of the tool. The flexibility in having selectively placed locking features within the tubular member greatly enhances the ability of the tool to reliably secure the tool using pre-positioned anchoring profile mechanisms within the wellbore system.

There is also a need for a positioning apparatus and method that can be used to position a tool within a tubular string that is simple in structure and function, and can incorporate reusable, machinable, and remachinable components that can accommodate various locking and/or engagement orientations.

There is also a need for a positioning apparatus and method that can be used to position a tool within a tubular string that can be transported and deployed with an easily available setting tool.

Embodiments of the present invention meet these needs.

Disclosure of Invention

Embodiments of the present invention include apparatuses, systems, and methods that may be used to accurately position, place, and actuate packers, cutters, flames, perforators, setting tools, and/or other types of tools used downhole.

The disclosed embodiments include a system for providing a self-centering reusable anchor position within a wellbore. The system includes a limit range anchor having a first extension assembly configured to engage the wellbore. The first extension assembly may include a first set of arms connectable to the first support, a second set of arms connectable to the second support, and a set of pedals. Each pedal of the set of pedals may be connected at a first side of the first set of arms and may be connected at a second side of the second set of arms. Each pedal may include a retainer coupleable to the radially outer face and configured to securely engage the wellbore. The limit range anchor may include a tie rod that may be rigidly coupled to the first support and slidably connected to the second support. Pushing the tie rod in an axial direction shortens the distance between the first and second supports and pushes the set of pedals to move in a radial direction towards the wellbore.

In certain embodiments, the system may include a second extension assembly configured to engage the wellbore. The second extension assembly may include a third set of arms connected to the second support, a fourth set of arms connected to the third support, and a second set of pedals. Each pedal of the second set of pedals may be connected at a first side of the third set of arms and may be connected at a second side of the fourth set of arms.

In certain embodiments, a system may include a body and an engagement wedge. The engagement wedge may be configured to engage with the body to maintain an axial position of the tie rod relative to the body when the tie rod is pushed in an axial direction. In certain embodiments, the engagement wedge may be configured to disengage from within the body in response to pushing the body in an axial direction with a disengagement threshold force.

In certain embodiments, the set of pedals is configured to move in a radial direction a distance of up to fifteen (15) centimeters to engage the wellbore. In certain embodiments, the retainers may include tapered retainers, semi-tapered retainers, serrated retainers, or other retainers to securely engage the wellbore. In certain embodiments, the first extension assembly may include a pull rod spring, a fastening pin, a fastening band, or other fastening means to prevent radial movement of the set of pedals prior to pushing the pull rod.

In certain embodiments, the system may include a retainer cover configured to cover the retainer. The retainer cap may prevent engagement between the retainer and the wellbore when the limit range anchor is deployed to a depth within the wellbore. In certain embodiments, the limit range anchor may include a setting rod configured to be connected at a first end to a pull rod having a protrusion and at a second end to a setting tool. The setting tool may pull the setting rod to push the pulling rod in the axial direction. In certain embodiments, the protrusion is configured to shear the mounting rod from the pull rod when pulled at a set force.

The disclosed embodiments may include a method of performing a downhole operation within a wellbore. The method may include lowering a limit range anchor into the wellbore, where the limit range anchor may include a tool connector. The method may include the step of actuating a setting tool to push a pull rod in an axial direction to extend a set of pedals in a radial direction. The pedal may be configured to securely engage the wellbore, wherein the retainer is coupled to a radially outer face of the pedal. The method may further comprise the steps of: the method includes lowering a first tool onto a tool connector, performing a first operation with the first tool, retrieving the first tool to a surface of a wellbore, lowering a second tool onto the tool connector, performing 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 the tool connector in an axial direction to disengage the set of pedals from the wellbore. The step of completing the first operation, the second operation, or a combination thereof may include actuating an axial flame cutter, a radial flame cutter, a wellbore perforator, a production tubing cutter, or a combination thereof. Further, actuating the placement tool may include shearing the placement rod from the pull rod. The shearing may be configured to occur when the set of treads engage the wellbore. In certain embodiments of the disclosed method, the first operation may be completed at the target location and the second operation may be completed within three (3) centimeters (1.18 inches) or less than three 3 centimeters from the target location. Further, the pedal may be configured to extend up to fifteen (15) centimeters in the radial direction.

In certain disclosed embodiments of a system for securely engaging a wellbore, the system may comprise: a first arm rotatably connected to the first support at a first end of the first arm; a second arm rotatably connected to the second support at a first end of the second arm; and a pull rod rigidly connected to the first support and slidably connected to the second support, and configured to translate in a longitudinal direction. When the pull rod translates in the longitudinal direction, the first arm and the second arm may be configured to rotate such that the second end of the first arm and the second end of the second arm protrude in an axial direction perpendicular to the longitudinal direction.

In some embodiments, the system may include a pedal rotatably coupled to the second end of the first arm and the second end of the second arm. The system may further comprise a projection attached at the second end of the second arm. The extension may be configured to extend into the wellbore after the pull rod is translated in the longitudinal direction. The first arm may include a groove configured to receive the extension during delivery of the system to the wellbore, and the first arm, the second arm, or a combination thereof may include a flex feature, as described below.

Drawings

In the detailed description of various embodiments presented below that can be used within the scope of the present disclosure, reference is made to the accompanying drawings in which:

fig. 1 depicts a perspective view of an embodiment of an extreme range anchor that may be used within the scope of the present disclosure.

FIG. 2 depicts a cross-sectional view of an embodiment of the extreme range anchor of FIG. 1.

FIG. 3 depicts a cross-sectional view of an embodiment of the extreme range anchor of FIG. 1.

FIG. 4 depicts a perspective view of an embodiment of a pedal that may be used as part of the limit range anchor of FIG. 1.

FIG. 5 depicts a perspective view of an embodiment of a pedal that may be used as part of the limit range anchor of FIG. 1.

FIG. 6 depicts a cross-sectional view of an embodiment of the extreme range anchor of FIG. 1.

Fig. 7 depicts a cross-sectional side view of the additional or alternative lower extension assembly 130.

Fig. 8 illustrates an embodiment of a limit range anchor using the electromechanical anchor of the present invention.

One or more embodiments are described below with reference to the listed figures.

Detailed Description

Before selected embodiments of the present disclosure are described in detail, it is to be understood that the invention is not limited to the specific embodiments described herein. The disclosures and descriptions herein are 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, manner of operation, structure and location, method, and use of mechanical equivalents may be made without departing from the spirit of the invention.

Also, it should be understood that the drawings are intended to illustrate and clearly disclose presently preferred embodiments to those skilled in the art, but are not intended to be a reproduction of a manufacturing level drawing or end product, and may contain simplified conceptual views for ease of understanding or explanation. The relative sizes and arrangements of the components may also be varied from that shown and still function within the spirit of the invention.

Moreover, it should be understood that various orientations, such as "upper," "lower," "bottom," "top," "left," "right," and the like, are made solely with respect to the illustrations in connection with the figures, and that the components may be oriented differently, such as during shipping and manufacturing and during operation. Because many varying and different embodiments may be made within the scope of the concepts taught herein, 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 not in a limiting sense.

Referring now to FIG. 1, a perspective view of an embodiment of an extreme range anchor 10 that may be placed in a downhole wellbore. The limit range anchor 10 may be placed within a wellbore or production tubing of a drill string, or in some embodiments, may be secured within the casing of a wellbore. The limit range anchor 10 provides utility for anchoring within a wide range of pipes. For example, as explained in detail below, the same embodiment of the limit range anchor 10 may be placed in 8.9 centimeter (3.5 inch) production tubing, retrieved, and then subsequently placed in 27.3 centimeter (10.75 inch) production tubing. As depicted, the anchor 10 may include: a lower section 12, which as explained below includes a securing feature; and an upper portion 14 that may include electronic, mechanical, or chemical deployment features as explained below.

As shown in fig. 1, an alignment member 16 to which a downhole tool may be connected may be attached to upper portion 14. For example, alignment member 16 may include a fish neck, as shown, to connect to a downhole tool. With this alignment member 16, the downhole tool 17 can be lowered onto the neck of a fish (surrounding the alignment member 16). Alignment member 16 may include a tab 18 that may provide downhole tool 17 with an azimuthal direction that downhole tool 17 may point. With the lug 18 providing azimuthal orientation, precise orientation can be performed multiple times using one or more tools. That is, the anchor 10 remains within the wellbore and additional downhole tools 17 may be lowered onto the alignment member 16, oriented over the nubs 18, activated and retrieved. The downhole tool 17 may be locked into place on the fish neck, on the alignment member 16, or on the lug 18.

To lock the limit anchor 10 into place, the lower section 12 may include several extension assemblies that may be retracted as the limit anchor 10 is lowered into the wellbore. Then, when the limit range anchor 10 is in place, the extension assembly may extend outwardly, as explained in detail below.

The embodiment illustrated in fig. 1 shows a lower extension assembly 20 and an upper extension assembly 22. Each of the assemblies 20, 22 includes an arm 24 and a pedal 26 arranged as a set of arms 24 and a set of pedals 26. Fig. 1 illustrates an embodiment in which each set includes three arms 24 (i.e., a first set of three arms is designated 24a (third arm 24a is not shown in fig. 1), a second set of three arms is designated 24b (third arm 24b is not shown in fig. 1), a third set of three arms is designated 24c (third arm 24c is not shown in fig. 1), a fourth set of three arms is designated 24d (third arm 24d is not shown in fig. 1)) and three pedals 26 (i.e., a first set of three pedals is designated 26a (third pedal 26a is not shown in fig. 1), and a second set of three pedals is designated 26b (third pedal 26b is not shown in fig. 1)), respectively. The lower assembly 20 includes a set of lower arms 24a, a set of pedals 26a, and a set of upper arms 24 b. Likewise, upper assembly 22 includes a set of lower arms 24c, a set of pedals 26b, and a set of upper arms 24 d. Each set of arms 24 or pedals 26 may contain as few as two members or many more members. For example, a set may include 3 (as in the illustrated embodiment), 4, 5, 6, 7, 8, 9, or more arms 24 or pedals 26, or sets of arms 24a-d and pedals 26 a-b. Although the embodiment of the limit range anchor 10 shown in FIG. 1 includes two assemblies 20, 22, each including a set of arms 24a-d and a set of pedals 26a-b, the limit range anchor 10 may include any number of assemblies 20, 22 to ensure a secure connection within the wellbore.

As shown in fig. 1, the arm 24 may connect the pedal 26 to a support that may join the assemblies 20, 22 together. For example, as further shown in FIG. 1, the lower arm 24a in the lower assembly 20 (for simplicity, each of the sets of arms 24a-d may be discussed below as an individual arm; it should be understood that "lower arm 24 a" shall mean a lower arm in each set of lower arms 24 a) may connect a first end of the first tread plate 26a to the lower support 28, and the upper arm 24b in the lower assembly 20 may connect a second end of the first tread plate 26a to the intermediate support 29. With respect to the upper assembly 22, the lower arm 24c in the upper assembly 22 can connect the second pedal 26b to the intermediate support 29, and the upper arm 24d of the upper assembly 22 can connect the second pedal 26b to the upper support 30. The connections between the arms 24a-d and the supports 28, 29, 30 may be rotatably hinged such that the arms 24a-d are free to change the angle at which they are connected to each of the supports 28, 29, 30.

The assemblies 20, 22 may be extended radially outward in response to tie rods 32 pulling on the bottom end 34 of the extreme range anchor 10 to shorten the distance between the supports 28, 29, 30. That is, a setting tool, electromechanical anchor, or other tool for pulling advances the pull rod 32 in the upper direction 36 (possibly through an intermediate assembly, as explained below); and in response, the pedals 26 in the lower assembly 20 and the upper assembly 22 extend in a radially outward direction 44 simultaneously. The simultaneous movement of all sets of arms 24a-d and pedals 26a-b centers the limit range anchor 10 itself within a wellbore, pipe, etc. The tension rod spring 40 may be used to exert a force in a downward direction 42 during the time that the limit range anchor 10 is traveling down the wellbore to hold the assemblies 20, 22 radially inward 38 and prevent vibration or unintended movement of the assemblies 20, 22 due to loose movement of the arms 24a-d and/or pedals 26 a-b.

Fig. 2 is a cross-sectional view of the embodiment of the limit range anchor 10 shown in fig. 1. Specifically, FIG. 2 shows the lower assembly 20 in a running or unextended position with the tie rods 32 fully in the downward radial direction 42. To further ensure stable travel conditions, the pedal 26a may be secured in place with a pin 46 that may be attached to the pull rod spring 40 or other area of the limit range anchor 10. The pin 46 may clamp the pedal 26 at a clamping surface 48 that is stably secured until the tie rod 32 is deployed in the upward radial direction 36. In other words, the lower assembly 20 illustrated in FIG. 2 will maintain the travel angle 50 of the arms 24a-b relative to the supports 28, 29 throughout the descent into the wellbore. The angle of travel 50 may typically be approximately 90 degrees, meaning that the arms 24a-b travel generally parallel to the wellbore during lowering. However, in some embodiments, the travel angle 50 may be greater or less than 90 degrees to accommodate faster deployment or other requirements of deployment of the limit range anchor 10.

To deploy the limit range anchor 10, the tension rod 32 is pulled in the upward radial direction 36, as mentioned above. Fig. 2 shows that the tie rod 32 is rigidly attached to the bottom end 34 such that when the tie rod 32 is pulled, the bottom end 34, the bottom support 28 and the attached arm 24a are all pulled in an upward radial direction 36. In contrast, the intermediate support 29 may travel along the outer diameter of the tie rod 32 such that the tie rod 32 is free to slide through the intermediate support 29. The force from the upper assembly 22 urges the intermediate support 29 downward (i.e., in a downward radial direction 42) relative to the bottom end 34 and thus the arms 24a-b and the pedal 26a are urged radially outward 44.

An embodiment of the deployment of the extreme range anchor 10 of fig. 2 is illustrated in fig. 3. As shown in fig. 3, bottom support 28 (having bottom end 34) has been pulled closer to intermediate support 29, and arms 24a-b and pedal 26a have moved radially outward 44. The arms 24a-b now form a deployed angle 52 with respect to the supports 28, 29, while the pedals 26a remain parallel to the tie rods 32 and, importantly, to the tube wall 62. The deployed angle 52 is substantially less than the travel angle 50 such that the limit range anchor 10 travels down the wellbore with a smaller profile than when the anchor 10 is deployed. The pedal 26a travels a distance 56 from the travel position (fig. 2) to the deployed position (fig. 3). In certain embodiments, the distance 56 may be any length up to 30 centimeters. For example, the range may be between 1 and 15 centimeters, 1 and 20 centimeters, 1 and 25 centimeters, 5 and 15 centimeters, and so on. After pulling on the pull rod 32 and deploying the anchors, the face 60 of the pedal 26a may abut the tube wall 62 and the retainer 64 (shown in fig. 4 and 5) may bite into the tube wall 62 to ensure a secure fit. Because the arms 24a-b and the pedals 26a can be deployed or extended simultaneously, the pedals 26a and/or anchors 64 (shown in fig. 4 and 5) in each set or assembly 20, 22 can bite into the tubular wall 62 with the same force and timing. That is, while one step 26a may contact the tube wall 62 before the other steps 26a, the limit range anchor 10 will center itself before any of the steps 26a exerts any pressure that will actually place the anchor 64 into the tube wall 62. The retainer 64 reduces the likelihood of slippage or displacement after deployment, and the retainer 64 may comprise any combination of shapes and sizes to securely bite into the vessel wall 62. The illustrated embodiment includes a flat cone holder 70, a pointed cone holder 72, and a multi-point holder 74, as shown in fig. 2 and 3.

Fig. 4 is an embodiment of a pedal 26 that may be used in the extreme range anchor 10 of fig. 1-3. As shown, the pedal 26 employs a retainer 64 having a uniform size and shape. Specifically, FIG. 4 illustrates a two-by-three version of the awl fixture 72. The size, shape, and/or pattern of retainer 64 may depend on the type of tubular wall 62 into which retainer 64 will bite. For example, a highly corroded and/or rusted pipe wall 62 with loose or softened material on the inner surface 80 (shown in FIG. 3) may employ a retainer 64 that penetrates deeper into the inner surface 80. On the other hand, if the tube wall 62 is made of a hard surface and/or a polished surface, the retainer 64 may employ smaller, steeper, and/or more points on the face 60 of the pedal 26.

As an additional but non-limiting example, fig. 5 shows an embodiment of the pedal 26 having five retainers 64 disposed on the face 60 of the pedal 26. Included on the embodiment of fig. 5 is a larger multi-point anchor 74 positioned in the center of the pedal 26, and several smaller oblate cone anchors 70 positioned toward the corners of the pedal 26. In addition, the footplate 26 in the embodiment illustrated in FIG. 5 includes a chemical retainer 82, which may employ glue, epoxy, adhesive, or other chemicals to attach the footplate 26 to the tube wall 62.

To protect the retainer 64 during travel down the wellbore, the foot pedal 26 may include a retainer cap 84 (shown in fig. 2 and 3). Retainer cap 84 may be attached to face 60 during travel and, in certain embodiments, is made of a material having a low coefficient of friction. For example, the retainer cap 84 may include a polymer, ceramic, plastic, silicone, rubber, or other protective material. The cover enables the limit range anchor 10 and the pedal 26 to traverse a passing feature within the wellbore that could otherwise contact the retainer 64 and interfere with travel. In addition, retainer cap 84 protects retainer 64 so that any sharp points of retainer 64 maintain their sharpness until deployment. After deployment of the limit range anchor 10, the retainer cap 84 may be deformed, compressed, or broken such that the retainer 64 can conform to the inner surface 80 of the vessel wall 62. In the illustrated embodiment of fig. 3, the retainer cap 84 has been broken and will dissolve or fall down the wellbore.

Fig. 6 is an embodiment of the upper portion 14 of the extreme range anchor 10 shown in fig. 1. As shown, the upper portion 14 of the limit reach anchor 10 may be used to house a body 98 that helps to maintain the extension assemblies 20, 22 in the deployed position after deployment. Fig. 6 shows the upper section 14 before the pull rod 32 has been pulled. As depicted, collar 100 of drawbar 32 is located at the bottom of cavity 102, against shoulder 120, which is in contact with body seat 104. As explained above, the limit range anchor 10 may be run down the wellbore in this position. To deploy the limit range anchor 10, the tension rod 32 may be connected to a first end of the deployment rod 106 using a shear stud 108. The setting stem 106 may be connected at another end to a setting tool, electromechanical anchor, or other downhole pulling device that pulls the setting stem 106. The placement rod 106, shear stud 108 and pull rod 32 are movable upwardly 36 relative to the body 98. Similar to the intermediate support 29 explained above, the upper support 30 is slidably coupled to the tie rod 32, which is capable of moving the tie rod 32 axially upward 36 and thus pushing the arms 24 radially outward 44. To prevent deformation of the tubular wall 62, the shear studs 108 may be calibrated to shear at a given deployment force. In certain embodiments, the electromechanical anchors may be calibrated or programmed to shut off power after a deployment force (e.g., less than the force that deforms the tube wall 62) has been detected. In such embodiments, the limit range anchor 10 may not have the shear stud 108. The deployment force is large enough to seat the retainer 64 in the inner surface 80 of the vessel wall 62, but small enough so that the end-of-range anchor 10 and vessel wall 62 do not deform or otherwise suffer damage. After deployment of the limit range anchor 10, any portion of the setting tool (if used), the setting stem 106, and the shear stud 108 attached to the setting stem 106 may be retrieved to the surface of the wellbore. In certain embodiments, the electromechanical anchor used to seat the limit range anchor 10 may remain downhole until the limit range anchor 10 is ready to be retrieved.

The tie rod 32 may be held in place by various fastening means. For example, the upper portion 14 may include a joining wedge 110, a retaining shear pin 122, and a ridge 112 inside the cavity 102 of the body 98. The ridges 112 in the illustrated embodiment are shaped to allow the engagement wedge 110 to slide axially upward 36, but prevent the engagement wedge 110 from sliding downward 42. The lower edge 114 of each ridge 112 may be angled slightly to reduce friction between the top edge 116 of the engaging wedge 110 and the lower edge 114 of each ridge 112. However, the upper edge 118 of the spine 112 is angled to increase the holding capacity of the bottom edge 120 of the engagement wedge 110. The engagement wedge 110 may also include an engagement spring 124 that increases the radially outward 44 force of the engagement wedge 110 against the spine 112. The engagement wedge 110 may include an embodiment in which the engagement spring 124 is a coil spring, or, as illustrated, may include a resilient material or an arcuate spring that urges the engagement wedge 110 toward the spine 112.

After deployment, the anchor 10 may remain in the deployed position for multiple operations. One or more tools may be lowered downhole and onto alignment member 16 for operation. After completing all required tool operations, the operator may retrieve the limit range anchor 10 by returning the extension assemblies 20, 22 to the travel position. For example, the electromechanical device may use a motor to move the pull rod 32 in a reverse downward direction 42 relative to the upper portion 14 and the upper support 30. The tie rod 32 may also be released by fracturing or shearing the retained shear pin 122. The retention shear pin 122 may be calibrated to fracture at the threshold of disengagement of force on the extreme range anchor 10. Alternatively, the retrieval tool may be lowered and tightened onto alignment member 16 and pulled axially upward 36. At the disengagement threshold, the shear pin 122 is held in shear to allow the tie rod 32 to disengage from the engagement wedge 110. After retrieval, the downhole end of the collar 100 will make contact with the uphole end of the shoulder 120. The tension rod spring 40 urges the tension rod 32 to remain in the extended position, thereby maintaining the extension assemblies 20, 22 radially inward 38 so that the anchor 10 may be fully retrieved. The retrieval operation may be accomplished by the last tool to be oriented on the anchor 10. The last tool in the example will be positioned to apply sufficient overstretch force to the anchor 10 so as to keep the shear pins 122 broken or sheared.

Fig. 7 illustrates a cross-sectional side view of an additional or alternative lower extension assembly 130. The lower extension assembly 130 includes a lower arm 132a that may be attached to the lower support 28 in a similar manner as the other lower arms 24 a. Likewise, the upper arm 132b may be attached to the intermediate support 29 in a similar manner as described above. However, as illustrated, the lower extension assembly 130 may include embodiments that secure the anchor 10 to the wellbore without the pedal 26 described above. Alternatively, the lower extension assembly 130 may employ a fixed extension 134 extending from the upper end 142 of the upper arm 132 b. The extension 134 includes a ridge 136 that bites into the wellbore. The snap-in of the ridge 136 secures the positioning of the anchor 10 during orientation of the tool for subsequent anchoring. The ridges 136 may have additional or alternative sizes, shapes, and/or patterns to those shown in fig. 7, depending on the material into which the ridges 136 will bite. As with retainer 64 (explained above), if tube wall 62 is highly corroded, rusted, or has loose or softened material on its inner surface 80, the size, shape, and/or pattern of ridges 136 may penetrate deeper into the inner surface. On the other hand, if the tube wall 62 is made of a hard surface and/or a polished surface, the ridges 136 may take on smaller, steeper, and/or more points.

During conveyance of the anchor 10 down the wellbore, the lower arm 132a and upper arm 132b are substantially parallel to the tie rod 32, thereby refining the profile of the limit range anchor 10 in a similar manner to the embodiment illustrated in fig. 2 described above. The extension 134 is in line with the arms 132a, 132 b. Lower arm 132a includes a recess 138 cut out from lower arm 132 a; and during delivery, the projection 134 is located within the groove 138 to protect the ridge 136 and ensure smooth descent of the anchor 10. Lower arm 132a may be attached to left side 137 and right side 140 of upper arm 132b, ensuring even and secure deployment of extension 134 against the wellbore. In certain embodiments, the lower arm 132a may include a protrusion having a ridge on an upper end to further secure the anchor 10 into the wellbore. In additional or alternative embodiments, the upper arm 132b and the lower arm 132a may function switchably. That is, the lower arm may include the projection 134, while the upper arm 132b includes the recess 138.

The upper arm 132b (or lower arm 132a in some embodiments) may also include a flex feature 144, or other cushioning feature, that enables the upper arm 132b to cushion or flex during deployment. Flexing and buffering may be used to place and maintain the connection between the extension 134 and the wellbore. For example, as shown in fig. 6, as the engaging wedge 110 slides up 36 along the ridges 112, each ridge 112 slides individually past the engaging wedge 110. The engagement wedge 110 may experience a reverse slip as the shear stud 108 shears. Such a small slip may occur, particularly if the engaging wedge 110 is only partially pulled from one ridge 112 to the next ridge 112. Because of the small length of the ridge 112, this slippage can be a minimal amount (e.g., 0.006 inches or 0.152mm), but can still cause the extension 134 to lose some traction with the wellbore.

To prevent this loss of traction, the flex feature 144 (as shown in fig. 7) provides some spring potential energy to accumulate before the shear stud 108 shears. That is, the pull rod 32 pulls the supports 28, 29 to move the arms 132a, 132b outward 44 until the extension 134 contacts the wellbore. The upper arm 132b may then flex to create spring potential energy between the wellbore and the pull rod 32. After flexing of the upper arm 132b, the shear stud 108 shears and the spring potential energy from flexing absorbs any loss of traction caused by the displacement of the engagement wedge 110 between the ridges 112. The spring potential energy pushes the extension 134 against the wellbore with additional force, which increases friction and thus the overall ability to hold the limit range anchor 10 in a fixed position.

The flex feature 144 may include grooves, striations, grooves, or other physical changes to the arm (e.g., upper arm 132b) that are capable of otherwise flexing or arching the rigid arm without deforming or permanently bending. The flex feature 144 may also include material differences from the arms. For example, the arm 132 may be constructed of a flexible metal, polymer, rubber, or other material that does not deform under load. Further, the flex feature 144 may include a combination of these or other features that enable the arms 132 to provide increased force normal to the inner surface of the wellbore.

In certain embodiments, the anchor 10 may be purposefully offset from the center of the wellbore. For example, the lower arm 132a and the upper arm 132b may differ in length from one set of extension assemblies 130 to another. That is, one set of upper arms 132b may exceed other sets of upper arms 132b of a particular extension assembly 130. This may result in the shorter upper arm 132b being attached to the intermediate support 29 and the longer upper arm 132b being attached to a different intermediate support. When the extension assembly 130 is deployed, one set of longer arms will push the anchor 10 away from the center of the wellbore before the other set of shorter arms engages the walls of the wellbore. Alternatively or additionally, the connection point 146 between the lower arm 132a and the upper arm 132b may be adjusted in order to offset the anchor 10 from the center of the wellbore. In the illustrated embodiment of fig. 7, the two lower arms 132a and the two upper arms 132b have substantially equal lengths, and the connection point 146 is near the ends of these arms 132a, 132b, as shown. However, in some embodiments, lower arm 132a may be longer, with recess 138 enclosing a greater proportion of upper arm 132 b. That is, the lower arm 132a may extend to any one connection point on either side of the upper arm 132b, see, for example, connection 148.

In embodiments with longer grooves 138, the connection 148 may be positioned closer to the intermediate support 29 by extending the length 150, thus repositioning the connection point 146 to the connection 148. The length of the upper arm 132b may remain the same, however, the connection point 146 may vary to any connection 148 along the upper arm 132 b. When the connection point 146 is located at the connection 148 and closer to the intermediate support 29, deployment of the extension assembly 130 may extend the projection 134 farther from the lower extension assembly 130. This will allow the upper arm 132b with the extension 134 to extend a given translational distance further away from the limit range anchor 10 by the tie rod 32. Thus, if the connection point 146 is located at a different connection 148 for each set of arms 132a, 132b, the extreme range anchor 10 will be positioned at a non-central location within the wellbore.

Fig. 8 illustrates an embodiment of the limit range anchor 10 using an electromechanical anchor in the upper portion 14. The electromechanical portion will be positioned at the wellhead 36 of the upper support 30. The electromechanical portion may include an engagement wedge 110, a shear pin 122, a rotating device (e.g., an actuator, a motor, an extender, etc.), and a communication device (e.g., an electronic circuit board). A signal may be sent to the communication device to initiate the placement procedure, or to retrieve the procedure. The signal may be communicated from the surface by sending pressure waves detected by the communication device or by direct electronic communication via a cable connection. Additionally, the communication device may initiate a deployment procedure when a set of conditions is detected within the wellbore. The set of conditions may include pressure, temperature, chemicals, orientation (e.g., deployed only in a horizontal wellbore axis), acceleration (e.g., not deployed while moving), and time (e.g., will not be deployed until a certain period of time has elapsed since falling into the wellbore). The communication device will send a signal to the rotating device to initiate the placement sequence. Activation of the rotating device will cause the wellhead 36 of the drawbar 32 to move and the function of the system will react as described above. Additionally, the retrieval process may include a second signal or set of detected signals to reverse the movement of the rotating device. The retrieval process may also include a strong upward 36 force applied to the system to shear the pin engaging wedge 110 and drawbar 32. Shearing of the pin will cause the profile to disengage from the sleeve and the anchor arms will collapse to the travel angle 50.

While emphasis has been placed upon various embodiments usable within the scope of the invention, it will be appreciated that within the scope of the appended claims, the invention may be practiced other than as specifically described herein.

Claims (20)

1. A system for providing a self-centering reusable anchor location within a wellbore, the system comprising: Limit Range Anchor, which includes: A first extension assembly configured to engage the wellbore, the first extension assembly comprising: a first set of arms connected to the first support; a second set of arms connected to the second support; and a set of pedals, wherein each pedal of the set of pedals is connected to the first set of arms at a first side and to the second set of arms at a second side, and wherein each pedal includes a fixed a retainer coupled to the radially outer portion and configured to securely engage the wellbore; and A pull rod rigidly coupled to the first support and slidably connected to the second support, wherein the pull rod is configured to move in an axial direction to shorten the first support and the second support distance between the two supports and pushes the first set of arms and the second set of arms to move the set of pedals in a radial direction towards the wellbore. 2. The system of claim 1, comprising: A second extension assembly configured to engage the wellbore, the second extension assembly comprising: a third set of arms connected to the second support; a fourth set of arms connected to the third support; and A second set of pedals, wherein each pedal in the second set of pedals is connected to the second set of pedals at a first side A third set of arms is connected at the second side to the fourth set of arms. 3. The system of claim 1, wherein the extreme range anchor includes a body and the tie rod includes an engagement wedge, wherein the engagement wedge is configured to engage the body to when in the axial direction The axial position of the tie rod relative to the body is maintained when the tie rod is pushed up. 4. The system of claim 3, wherein the engagement wedge is configured to disengage from within the body in response to pushing the body in the axial direction with a disengagement threshold force. 5. The system of claim 1, wherein the set of pedals is configured to move a distance of up to 15 centimeters in the radial direction to engage the wellbore. 6. The system of claim 1, wherein the retainer comprises a tapered retainer, half-conical retainer, serrated retainer, or other retainer to securely engage the wellbore. 7. The system of claim 1 , wherein the first extension assembly includes a pull rod spring, fastening pin, strap, or other fastening device to prevent the set of pull rods prior to the push of the pull rod Radial movement of the pedals. 8. The system of claim 1, comprising an anchor cover configured to cover the anchor, wherein when the extreme range anchor is deployed to a depth within the wellbore, The retainer cover prevents engagement between the retainer and the wellbore. 9. The system of claim 1, wherein the extreme range anchor includes a placement rod configured to connect to the tie rod having a protrusion at a first end and at a second end Connected to a placement tool, wherein the placement tool pulls the placement rod to push the pull rod in the axial direction. 10. The system of claim 9, wherein the protrusion is configured to shear the placement rod from the pull rod when pulled with a set force. 11. A method of performing downhole operations in a wellbore, the method comprising: lowering a limit range anchor into the wellbore, wherein the limit range anchor includes a tool connector; Actuating the placement tool to push the pull rod in an axial direction to extend a set of arms in a radial direction, wherein each pedal of a set of pedals is connected at a first side to a first arm of the set of arms and is connected at a second side to a second one of the set of arms, and extending the set of arms moves the pedals in the radial direction to securely engage the wellbore, wherein fixed a device coupled to the radially outer side of the pedal; lowering the first tool onto the tool connector; use the first tool to complete the first operation; retracting the first tool to the surface of the wellbore; lowering a second tool onto the tool connector; performing a second operation with the second tool at a second location; and The second tool is retracted to the surface of the wellbore. 12. The method of claim 11, comprising pulling the tool connector in the axial direction to disengage the set of treads from the wellbore. 13. The method of claim 11, wherein the step of performing the first operation, the second operation, or a combination thereof comprises actuating an axial flame cutter, a radial flame cutter, a wellbore perforator, production tubing cutter or a combination thereof. 14. The method of claim 11, wherein actuating the placement tool comprises shearing a placement rod from the tie rod, wherein the shearing is configured to occur when the set of treads is engaged with the wellbore. 15. The method of claim 11, wherein the first operation is performed at a target location and the second operation is performed within 3 centimeters or less of the target location. 16. The method of claim 11, wherein the pedal is configured to extend up to 15 centimeters in the radial direction. 17. A system for securely engaging a wellbore, the system comprising: a first arm rotatably connected to the first support at a first end of the first arm; a second arm rotatably connected to the second support at a first end of the second arm; a pedal rotatably connected to the second end of the first arm and the second end of the second arm; and a pull rod rigidly connected to the first support and slidably connected to the second support and configured to translate in a longitudinal direction, wherein the pull rod is configured to translate in the longitudinal direction, and The first arm and the second arm are configured to rotate such that the second end of the first arm and the second end of the second arm are in an axial direction perpendicular to the longitudinal direction extend upward and move the pedal in the axial direction. 18. The system of claim 17, comprising an extension attached at the second end of the second arm, wherein the extension is configured to be over the tie rod Projecting into the wellbore after translating in the longitudinal direction. 19. The system of claim 18, wherein the first arm, the second arm, or a combination thereof includes a flexure feature. 20. The system of claim 18, comprising an alignment member configured to receive a downhole tool and lock the downhole tool in place.

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