RU2802720C1 - Device and method for well bore isolation (embodiments) - Google Patents

Abstract

FIELD: wellbore isolation.

SUBSTANCE: device for isolating the wellbore comprises a mandrel, a system of sealing elements and a metal support ring. The mandrel includes a cylindrical main part with an outer surface and a central flow channel. The system of sealing elements is located around the mandrel and is configured for radial expansion from the first running diameter to the introduction into sealing engagement with the inner surface of the wellbore. The metal support ring is located on the mandrel and contacts with one side of the system of sealing elements with the initial height H and configured for radial expansion and axial deformation to adjoin the inner surface of the wellbore. The metal support ring has a concave cross-section around a mandrel supported up the wellbore and supported down the wellbore. The sealing element system is configured to expand radially into the sealing engagement due to the applied compression force. The metal support ring is configured for radial expansion and axial deformation for contact with the inner surface of the wellbore with a radial contact stress providing a sealing contact pressure.

EFFECT: increased reliability of wellbore isolation.

13 cl, 20 dwg

Description

TECHNICAL FIELD

[0001] This document describes downhole tools used in the oil and gas industry, and more specifically, wellbore isolation devices that utilize expandable seal systems.

BACKGROUND OF THE ART

[0002] Various downhole tools are used when drilling, completing and stimulating hydrocarbon production wells. For example, it is often necessary to seal parts of a wellbore to be treated. For example, during hydraulic fracturing operations, various fluids and slurries are injected into the casing from the surface and expelled into the surrounding subterranean formation, but the fracturing fluid must be delivered only to certain desired zones of interest. Thus, there is a need to seal the wellbore and therefore provide zone isolation for targeted treatment in the desired zone. Wellbore isolation devices such as packers, packer plugs and hydraulic fracturing plugs (ie, fracturing plugs) are designed for these basic purposes and are well known in the art of hydrocarbon production such as oil and gas. Such wellbore isolation devices may be used in direct contact with the formation surface of the wellbore with casing running and secured in the wellbore, or with perforated pipe or metal mesh. From publication US 2019/0071949, a device and method for isolating a wellbore are known. However, these known solutions have a number of disadvantages. In particular, they do not provide the proper degree of sealing between the parker mandrel and the inside of the wellbore due to insufficient sealing contact of the sealing elements used in them with the wellbore.

[0003] Wellbore isolation devices, such as packers, packer plugs, and fracturing plugs, provide a sealing system between the outer surface of the main body of the isolation device and the inner surface of the casing to prevent fluid from leaking beyond the tubing used in the wellbore. well operations. The packer assembly can allow fluid to flow through its mandrel and therefore through the tubing to which it is connected. A plug packer may have a solid mandrel and block all fluid flow in the tubing. The frac plug is provided with a one-way valve to allow one-way upward flow through the tubing by regulating the flow through a frac plug mandrel that is in fluid communication with the tubing.

[0004] Wellbore isolation devices may include a sealing system and a fastening system. Sealing systems may rely on a single element or multiple elements to form an insulating seal. The fastening system may contain one or two sets of slips for fastening to the tubing.

[0005] After completion of the required downhole operation, the seal formed by the wellbore isolation device can be released, the mounting system released, and the tool itself can be removed from the wellbore. Removing the wellbore isolation device may allow hydrocarbon production operations to begin without being hindered by the presence of downhole tools. Removal of the wellbore isolation device may be accomplished by a retrieval tool that disengages the assembly, a retrieval operation that involves milling or drilling out a portion of the wellbore isolation device, or degradation of the wellbore isolation device material by dissolution, erosion, or corrosion.

BRIEF DESCRIPTION OF GRAPHIC MATERIALS

[0006] For a more complete understanding of the present invention, reference is made to the following brief description when taken in conjunction with the accompanying drawings and detailed description, wherein like reference numerals refer to like parts.

[0007] In FIG. 1 is a cutaway view of one embodiment of a wellbore isolation device in accordance with one embodiment.

[0008] In FIG. Figure 2 shows a cross-sectional view of one embodiment of a hydraulic fracturing plug in a wellbore.

[0009] In FIG. 3A-3B are cross-sectional views of one embodiment of a wellbore isolation device.

[0010] In FIG. 4A-4B are cross-sectional views of one embodiment of a wellbore isolation device support ring.

[0011] In FIG. 5A-5B are cross-sectional views of one embodiment of a wellbore isolation device.

[0012] In FIG. 6 is a cross-sectional view of one embodiment of a wellbore isolation device support ring.

[0013] In FIG. 7A-7B are cross-sectional views of one embodiment of a wellbore isolation device.

[0014] In FIG. 8A-8B are cross-sectional views of one embodiment of a wellbore isolation device.

[0015] In FIG. 9A-9B are cross-sectional views of one embodiment of a wellbore isolation device.

[0016] In FIG. 10A-10B are cross-sectional views of one embodiment of a wellbore isolation device.

[0017] In FIG. 11A-11B are cross-sectional views of one embodiment of a wellbore isolation device.

[0018] In FIG. 12 is a cross-sectional view of one embodiment of a wellbore isolation device support ring.

IMPLEMENTATION OF THE INVENTION

[0019] At the outset, it should be understood that while the following is an exemplary application of one or more embodiments, the systems and methods described may be implemented using any number of techniques currently known or existing. The present invention is not to be limited in any way by the exemplary embodiments, drawings and methods illustrated below, but may be modified within the scope of the appended claims along with their full scope of equivalents.

[0020] Unless otherwise indicated, any use of any form of the terms “attach,” “engage,” “connect,” “attach,” or any other term describing interaction between elements is not intended to limit the interaction to direct interaction between elements and may also include indirect interactions between the described elements. In the following discussion and in the claims, the terms “including” and “comprising” are used in a non-limiting form and, thus, should be interpreted to mean “including, but not limited to...”. Reference to “up” or “down” will be made for purposes of description, with “up”, “upper”, “upward” or “above” meaning the direction towards the surface of the wellbore, and the terms “down”, “lower”, “ downward" or "below" means the direction towards the downhole end of the well, regardless of the orientation of the wellbore. Reference to “in” or “out” will be made for purposes of description, with the terms “in,” “in,” or “inward” meaning toward the center or central axis of the wellbore, and the terms “out,” “out,” or “ "outward" means toward the wellbore tubular member and/or the wellbore wall. Reference to “longitudinal,” “in the longitudinal direction,” or “in the axial direction” means a direction substantially aligned with the major axis of the wellbore and/or the tubular element of the wellbore. Reference to "radial" or "radially" means a direction substantially aligned with a line between the major axis of the wellbore and/or wellbore tubular member and the wall of the wellbore that is substantially perpendicular to the major axis of the wellbore and/or wellbore tubular member, although the radial direction need not pass through the central axis of the wellbore and/or the wellbore tubular element. The various features mentioned above, as well as other features and characteristics described in more detail below, will be apparent to those skilled in the art in using the present invention upon reading the following detailed description of embodiments and upon reference to the accompanying drawings. In addition, combinations of the embodiments described herein are also contemplated by this invention.

[0021] Packers are used in production wells to provide an annular seal between the outside of the production tubing string and the inside of the well casing. Packers are typically placed downhole near where produced fluids, such as oil and gas, are introduced into the well through perforations or an open section. The produced fluids may also contain corrosive elements such as sand, water and acids, which are produced to the surface along with the desired hydrocarbons. The ring seal isolates corrosive production fluids from the well casing above the packer to the surface and directs the flow of production fluids to the attached production tubing.

[0022] Packers may use slips to secure or grip well casing. A slip system typically uses one toothed part, called a slip, which can be pushed up a conical part, called a deflector, to engage the well casing. The slip holds the packer in place against the hydraulic forces of the O-ring.

[0023] Packers are a type of downhole tool that provides isolation of the wellbore using sealing elements and slips. Production packers protect the wellbore from produced fluids throughout the life of the well. Retrievable maintenance packers can be temporarily placed in a well for well maintenance operations such as cement plugging, acidizing, hydraulic fracturing and well testing. Plug packers are used as temporary plugs to isolate part of a well or to plug a well for temporary abandonment. Fracturing plugs isolate pressure from above but allow flow from below. Fracturing plugs isolate the lower zone of the well so that the upper zone can be hydraulically fractured using water and sand. All of these tools are examples of wellbore isolation devices.

[0024] Wellbore isolation devices use expandable sealing systems to provide a seal between the packer mandrel and the interior of the casing. Sealing element systems typically comprise a metal back-up ring and plastic, elastomeric or rubber sealing elements. These element systems expand from the sealing tool against the casing. The amount of expansion is generally limited by the design of the support ring.

[0025] This document describes an apparatus for isolating a wellbore, with embodiments describing a system of sealing elements for sealing and isolating portions of a wellbore. Expandable sealing systems comprise a metal back-up ring and plastic, elastomeric or rubber sealing elements and can allow the sealing systems to expand across large gaps and therefore provide various advantages over traditional elastomeric or rubber sealing elements. For example, the expandable sealing systems described herein are capable of providing a seal across a much wider gap between the outer surface of the isolating device and the inner surface of the casing within the wellbore, which can allow the wellbore isolating device to be used in a larger casing while being used simultaneously. fewer parts. The metal back-up ring expands to contact the casing and contains plastic, elastomeric or rubber sealing elements to prevent slippage, spreading or loss of sealing element material due to increased pressure or temperatures. The metal support ring may also attach the wellbore isolation device to the casing by gripping the inner surface as it expands. The sealing elements can be made from degradable or non-degradable materials. The metal support ring can be made from degradable or non-degradable materials.

[0026] With reference to FIG. 1 illustrates a well that may implement or otherwise use one or more principles of the present invention in accordance with one or more embodiments. As illustrated, the wellbore system 100 may include a maintenance rig 2 that may be located on the earth's surface 4 and extends over and around a wellbore 6 penetrating the subterranean formation 8. The drilling rig 2 may be a drilling rig, a completion rig, a workover rig, or the like. In some embodiments, the maintenance rig 2 may be lowered and replaced with a standard surface wellhead system or completion rig without departing from the scope of the present invention. Although the wellbore system 100 is depicted as operating on land, it should be understood that the principles of the present invention can equally be applied to any marine or subsea application, and the maintenance rig 2 may be a floating platform or an underground wellhead, as is generally known. in this field of technology.

[0027] The wellbore 6 may be drilled into the subterranean formation 8 using any suitable drilling method and may extend in a substantially vertical direction from the earth's surface 4 above the vertical wellbore portion 10. At a certain point in the wellbore 6, the vertical portion 10 of the wellbore may deviate from vertical relative to the earth's surface 4 and transition into a substantially horizontal portion 12 of the wellbore. In some embodiments, wellbore 6 may be completed by cementing casing 14 within wellbore 6 along all or part of the wellbore. However, in other embodiments, casing 14 may be run throughout all or part of the wellbore 6, and the principles of the present invention may equally apply to an "open hole" environment. The term "wellbore" can refer to the casing or open-hole environment.

[0028] The wellbore system 100 may further include a wellbore isolation device 16 that can be transported to the wellbore 6 on a transport device 18 that extends from the drilling rig 2 for maintenance. The wellbore isolation device 16 may include or otherwise comprise any type of casing or wellbore isolation device known to those skilled in the art, including, but not limited to, a frac plug, a plug packer, or a wellbore packer. wells, scraper plug, cement plug or any combination thereof. The conveyance device 18 that delivers the wellbore isolation device 16 down the wellbore may be, but is not limited to, a logging cable, wireline, electrical line, coiled tubing, drill pipe, production tubing, etc. P.

[0029] The wellbore isolation device 16 may be transported down the wellbore to a target location (not shown) within the wellbore 6. At the target location, the wellbore isolation device may be activated or "set" to seal the wellbore 6 and may otherwise provide a fluid isolation point within the wellbore 6. In some embodiments, the wellbore isolation device 16 may be pumped to a target location using hydraulic pressure applied by the surface maintenance drilling rig 2 4. In such embodiments, the wellbore isolation device 18 serves to maintain control of the wellbore isolation device 16 wellbore when it intersects the wellbore 6, and can provide power to operate and install the wellbore isolation device 16 after reaching the target location. In other embodiments, the wellbore isolation device 16 freely falls to a predetermined location under the influence of gravity, traversing all or part of the wellbore 6.

[0030] Those skilled in the art will appreciate that although FIG. 1 shows a wellbore isolation device 16 installed and operating in a horizontal wellbore portion 12 of a wellbore 6, the embodiments described herein are equally applicable for use in portions of a wellbore 6 that are vertical, deviated, or otherwise inclined. Additionally, directional terms such as "above", "below", "top", "bottom", "upwards", "downwards", "uphole", "downhole", etc. etc., is used with respect to illustrative embodiments as depicted in the figures, wherein the up or uphole direction refers to the direction towards the top of the corresponding figure, and the down direction refers to the direction towards the bottom of the corresponding figure, the direction up the wellbore refers to the direction towards the surface of the wellbore, and the downhole direction refers to the direction towards the toe of the wellbore.

[0031] Next, with reference to FIG. 2 and with further reference to FIG. 1 illustrates a cross-sectional view of an exemplary wellbore isolation device 200 that may utilize one or more principles of the present invention in accordance with one or more embodiments. The wellbore isolation device 200 may be similar to the wellbore isolation device 16 shown in FIG. 1. Accordingly, the wellbore isolation device 200 may be configured to extend into the wellbore 6 at a target location and seal it, and thereby prevent fluid from flowing past the wellbore isolation device 200 for wellbore completion operations and/or or intensification of inflow. As illustrated, wellbore 6 may be lined with casing 14 or other type of wellbore liner or tubing in which wellbore isolation device 200 may be suitably installed.

[0032] Wellbore isolation device 200 is generally illustrated and described herein as a fracturing plug. However, those skilled in the art will appreciate that the principles of the present invention may be equally applied to any of the other aforementioned types of casing or wellbore isolation devices without departing from the scope of the present invention. Indeed, the wellbore isolation device 200 may be a frac plug, a packer plug, a wellbore packer, an open hole packer, a scraper plug, a cement plug, or any combination thereof in accordance with the principles of the present invention.

[0033] As illustrated, the wellbore isolation device 200 may include a ball box 22 extending from or otherwise connected to the upper end of the mandrel 24. The sealing ball or fracturing ball 26 is located in the ball box 22, and the mandrel 24 defines the central flow channel 28. The mandrel 24 also forms a ball seat 30 at its upper end. In other embodiments, the ball box 22 may be lowered and the ball 26 may alternatively be lowered into the wellbore at a different time than the rest of the wellbore isolation device 200. One or more spacer rings 32 (one shown) may be attached to and otherwise extend around the mandrel 24. The spacer ring 32 provides a support that axially secures a set of upper slips 34A, which are also positioned circumferentially around the mandrel 24. As illustrated, a set of lower slips 34B may be positioned more distally from the upper slips 34A.

[0034] One or more slip deflectors 36 (shown as upper slip deflector 36A and lower slip deflector 36B, respectively) may also be positioned circumferentially around the mandrel 24, and one or more sealing elements 38 may be located between the upper deflector wedge. 36A of the slip and the lower slip deflector 36B and are otherwise located around the mandrel 24. In some embodiments, one of the upper slip deflector and the upper slip deflector 36A may be replaced by a radial shoulder (not shown) provided by the mandrel 24. In such embodiments, one end of the sealing elements 38 may move and otherwise engage the radial shoulder during operation. Although in Fig. 2 shows three sealing elements 38, the principles of the present invention are equally applicable to wellbore isolation devices that use more or less than three sealing elements 38, without departing from the scope of the present invention.

[0035] The seat shoe 40 may be located on or otherwise attached to the mandrel 24 at its lower or distal end. It should be understood that the lowermost portion of the wellbore isolation device 20 need not be a landing shoe 40, but may be any type of section that serves to complete the structure of the wellbore isolation device 20 or otherwise serves as a connector for a connection a device 20 for isolating a wellbore with other tools, such as a valve, tubing, or other downhole equipment.

[0036] In some embodiments, spring 42 may be located within a chamber 44 formed in mandrel 24 and may otherwise be coaxial with and fluidly coupled to central flow path 28. At one end, the spring 42 engages a shoulder 48 formed by the chamber 44, and at the opposite end, the spring 42 biases and otherwise supports the ball 26. The ball box 22 may define a plurality of holes 46 (three shown) that allow fluids to flow through them, thereby allowing fluids to flow along the entire length of the wellbore isolation device 20 through the central flow channel 28.

[0037] When the wellbore isolation device 200 is lowered into the wellbore 6, a spring 42 prevents the ball 26 from engaging the ball seat 30. As a result, fluids can flow through the wellbore isolation device 200; those. through the holes 46 and the central flow channel 28. The ball box 22 secures the ball 26 so that it is not lost while moving into the wellbore 6 to its target location. Once the wellbore isolation device 200 reaches the target location, a positioning tool (not shown) of a type known in the art can be used to move the wellbore isolation device 200 from its uninstalled position (shown in FIG. 2) to its installed position. The installation tool may operate through various mechanisms to secure the wellbore isolation device 200 into the wellbore 6, including, but not limited to, hydraulic installation, mechanical installation, hydrostatic pressure installation in the well, installation by swelling, installation by inflation, etc. P.

[0038] In some embodiments, the wellbore isolation device 200 may include a mechanism for installing the wellbore isolation device 200 in the wellbore 6. That is, the wellbore isolation device 200 may have a mechanism for moving from an unset position (shown in FIG. 2) to a set position. The mounting mechanism of the wellbore isolation device 200 may include a mechanical force generator such as a compressed spring, a hydraulic force generator such as an internal piston driven by surface pressure, a hydrostatic force generator such as an internal piston with an atmospheric pressure chamber, a motorized conveying device, such as a longitudinal propeller motor, or any combination of these methods. The mounting mechanism of the wellbore isolation device 200 may be actuated remotely from the surface to move the wellbore isolation device 200 from an unset position to a set position.

[0039] Installation of the wellbore isolation device 200 moves the parts from the lowering position into the wellbore shown in FIG. 2, to the installed or working position. The installation force generated by the installation tool (not shown) presses on the slips 34A-B to move the slips 34A-B axially and radially upward onto the inclined surface of the slip deflectors 36A-B to bring them into contact with the wellbore 6. The deflection wedges 36A-B of the slips press on the sealing element 38 to compress and radially expand the sealing element 38. The installation force applied to the sealing element 38 creates a contact stress in the wellbore 6. The applied installation force can provide sealing engagement with the sealing elements 38 and cause the slips to be firmly engaged with the wellbore 6.

[0040] Once the wellbore isolation device 200 is installed, the fluid pressure within the wellbore 6 may be increased to overcome the spring force of said spring 42 when the ball 26 is pressed against the spring 42. Overcoming the spring force may cause the ball 26 to engage the seat 30 the ball and seal thereto and thus prevent fluid communication through the central flow channel 28. When the ball 26 is in sealing engagement with the ball seat 30, fluids within the wellbore 6 may be forced into other areas of the wellbore or the surrounding formation for one or more wellbore completion and/or stimulation operations. After the wellbore completion and/or stimulation operation, the fluid pressure may be reduced within the wellbore 6, thereby causing the spring 42 to disengage the ball 26 from the ball seat 30.

[0041] As will be explained in more detail in the following embodiments, the metal support ring may support the sealing element 38 when the wellbore isolation device 200 is installed in the wellbore 6. The installation force applied to the sealing element 38 radially expands the sealing element 38 to provide sealing engagement with the wellbore 6. The sealing element 38 bridges the gap between the outer diameter of the wellbore isolation device 200 and the inner diameter of the wellbore 6. The pressure difference in the wellbore annulus between the annulus fluid up the wellbore and the annulus fluid down the wellbore causes the sealing element 38 to move from the high pressure side to the low pressure side. The uphole direction refers to the side of the sealing element 38 that is closest to the surface wellhead. The downhole direction refers to the side of the sealing element 38 that faces the bottom of the wellbore. Increased pressure drop in the annular space may cause element material to move into the gap between the outer diameter of the wellbore isolation device 200 and the inner diameter of the wellbore 6. The sealing element 38 was loaded with a compressive force applied by the mounting mechanism to radially expand the sealing element 38 into the wellbore 6. The pressure difference in the wellbore between the annulus up the wellbore and the annulus down the wellbore increases the stress within the sealing element 38. As the element material moves into the gap, the stressed material becomes unsupported and begins to fail due to extrusion when a small portion material is torn off or squeezed through the gap. A metal support ring may span the gap between the outer diameter of the wellbore isolation device 200 and the wellbore 6 to support the element material and prevent the sealing element 38 from moving into the gap.

[0042] Next, with reference to FIG. 3A, an embodiment of the wellbore isolation device 300 includes a sealing element 38, a metal support ring 60, a lower slip deflector 36B, a lower slip 34B, and an end ring 62. The sealing element 38 is mounted on the outer surface 54 of the mandrel 24 and abuts the shoulder 52 of the mandrel. . The sealing element 38 is shown as a single element, however two, three or any number of sealing elements can be used. A metal support ring 60 is slidably seated on the outer surface 54 of the mandrel to bring the sealing element 38 into contact with the end surface 73 up the wellbore. The lower deflector wedge 36B of the slip is slidingly seated on the outer surface 54 of the mandrel and comes into contact with a metal support ring 60 with the end surface 64. The lower slip 34B is slidingly seated on the outer surface 54 of the mandrel in connection with the conical surface 37B with the inner surface 35B deflector wedge. The end ring 62 is slidably seated on the outer surface 54 of the mandrel 24 so that it abuts the lower slip 34B. The radial clearance G is measured between the outer diameter 53 of the mandrel and the inner surface 50 of the wellbore 6. The sealing element 38 and the lower clip 34B bridge the radial gap G for contact with the inner surface 50 of the wellbore 6 when the wellbore isolation device 300 is installed in the wellbore.

[0043] The metal support ring 60, shown in more detail in FIG. 4A may have a generally inverted U-shape that is slidably placed on the outer surface 54 of the mandrel and abuts the sealing element 38. The metal back-up ring 60 may have an outer support surface 78 up the wellbore and an outer support surface 76 down the hole. wells. The uphole side will be the side that is closest to the surface wellhead along the axis of the metal support ring 60 or the axis of the mandrel 24. Likewise, the downhole side will be the side that is closest to the bottom of the well along the axis of the part or mandrel 24. The upper radius 67 represents the outer curve where the outer support surface 78 up the wellbore and the outer support surface 76 down the wellbore meet. The height of the ring H is measured from the upper radius 67 to the lower edge 74, perpendicular to the lower edge 74. The angle A measured between the outer support up the wellbore and the axis of the part generally ranges from 15 to 45 degrees. The outer support surface 78 up the wellbore and the outer support surface 76 down the wellbore have generally the same length and angle with the axis. The upwell support inner surface 68 is the upwell support inner surface 68. The inner support surface 66 down the wellbore is the inner surface of the inner support.

[0044] The metal support ring 60 may be composed of a decomposable metal material that is a decomposable alloy, the decomposable alloy being a magnesium alloy and an aluminum alloy or a combination thereof. Other components of the frac plug may further consist of a degradable material, including any degradable metallic material (eg, a degradable alloy) or a degradable elastomer, such as a packer element, without departing from the scope of the present invention.

[0045] The metal support ring 60 may be composed of a soft material that can be milled or drilled for removal with a drill bit or cutter, such as a brass alloy, a bronze alloy, a magnesium alloy, and an aluminum alloy, or combinations thereof. Other components of the frac plug may additionally consist of a millable or drillable material, including any soft metal materials (e.g., brass alloy, aluminum alloy, or magnesium alloy) or composite polymer material (e.g., fiberglass, carbon fiber composites), without departing from scope of this invention.

[0046] The configuration of the metal support ring 60 can be changed as shown in FIG. 4B, after expansion to an increased height H' with the supports stacked up the wellbore and down the wellbore. The installation force applied to the wellbore isolation device 300 is transmitted to the metal support ring 60 with an end surface 72 down the wellbore and an end surface 73 up the wellbore. The end surface 72 down the wellbore may contact the end ring 62, the lower deflector 36B of the slip, the sealing element 38 or the second metal support ring 60 depending on the implementation. The uphole end surface 73 may contact a mandrel shoulder 52, a deflector 36A, a sealing member 38, or a second metal support ring 60, depending on the embodiment. The installation force applied to the connecting parts may be transmitted from the end surface 72 down the wellbore through the ring to the end surface 73 up the wellbore. The metal support ring 60 will expand radially and deflect in the axial direction when the installation force exceeds the yield strength of the material. The metal support ring 60 will expand radially from the initial height H shown in FIG. 4A, to the increased height H' shown in FIG. 4B. In the expanded state, the inner support surface 68 up the wellbore and the inner support surface 66 down the wellbore are deflected towards each other and can come into contact with each other. The upper radius 67 and lower radius 70 may decrease in size or otherwise deviate as the height changes radially from H to H'. Although the height increase is shown as a free-standing ring in FIG. 4B, it is understood that the radial height change may be limited by the inner surface 50 of the wellbore 6 such that the new height H' may be a formed, radially expanded height to the inner surface 50 of the wellbore 6.

[0047] Next, with reference to FIG. 3B, the sealing element 38' can expand under the action of a compressive force applied by an installation tool adapted to the wellbore isolation device 300. The installation tool produces an axial compression force F, which can be transmitted using an adapter set (not shown) to the end ring 62. The axial force F is transmitted through the end ring 62, pushing the lower slip 34B on the conical surface 37B of the lower slip wedge 36B and driving it engages with the inner surface 50 of the wellbore 6. The end ring 62 can lock the axial force F using a locking ring (not shown) that locks or fixes the position of the end ring 62 on the mandrel 24. The axial compression force F is transmitted through the end surface 64 of the lower slip deflector 36B to the end surface 72 down the barrel. wells of the metal support ring 60 and onto the metal support ring 60, the sealing element 38 and onto the shoulder 52 of the mandrel. The axial force compresses the sealing element 38 between the mandrel shoulder 52 and the metal support ring 60, bringing it into sealing contact with the inner surface 50 of the casing. The axial force compresses the metal back-up ring 60 between the sealing element 38 and the end surface 64 on the lower slip deflector 36B and expands the metal back-up ring 60 into an expanded state. The engagement of the sealing members 38 between the inner surface of the casing, the outer surface 54 of the mandrel, the shoulder 52 of the mandrel and the expanded metal support ring 60' under the action of the axial force F can create a high contact stress. As a result, the sealing elements 38 can provide sealing engagement with the wellbore 6. Contact stress within the sealing element 38 may cause the stressed material 39 of the element to move into the gap G between the outer diameter 53 of the mandrel and the inner surface 50 of the wellbore 6. The extended seal element 38' isolates the upper wellbore surrounding environment WA (fluid pressure and composition) from the downhole surrounding wellbore environment WB (fluid pressure and composition).

[0048] In one embodiment, the metal back-up ring 60' may expand as a percentage of the gap G. The metal back-up ring 60 and sealing member 38 expand under the compressive force applied by the installation tool adapted to the wellbore isolation device 300. The axial force compresses the sealing element 38 between the mandrel shoulder 52 and the metal support ring 60, bringing it into sealing contact with the inner surface 50 of the casing. The axial force compresses the metal support ring 60 between the sealing element 38 and the end surface 64 on the lower slip deflector 36B and expands the metal support ring 60 into an expanded state with an expanded height H', and the uphole and downhole supports are folded together. A radial change in height from H to H' can widen the gap G by 80%, but not to contact the inner surface 50 of the wellbore 6. In one embodiment, the extended height H' of the metal support ring 60' may be within 2.286 mm (0.09 inch) of the inner surface 50 of the wellbore 6. In one embodiment, the extended height H' of the metal support ring 60' may abut the inner surface 50 of the wellbore 6 in one or more locations, but not along the entire inner circumference. Although the radial height change from H to H' may expand by 80%, it is understood that the percentage may be any number from 80% to 100%. Although the extended height H' may be 2.286 mm (0.09 inch) from the inner surface 50 of the wellbore 6, it is understood that this distance can be any number from 2.286 mm (0.09 inch) down to zero.

[0049] The wellbore isolation device 300 shown in FIG. 3B isolates the higher pressure of the wellbore environment WA up the wellbore from the wellbore environment WB down the wellbore. Higher pressure from the wellbore environment WA up the wellbore can dislodge the energized element material 39 of the sealing element 38 from the gap G between the outer diameter 53 of the mandrel and the inner surface 50 of the wellbore 6 and bring it into contact with the expanded metal support ring 60' . The extended metal support ring 60' supports the sealing element 38 by filling the gap G and preventing movement of the unsupported sealing element 38. However, the element is not supported due to high pressure from the opposite direction. That is, the high pressure of the fluid WB down the wellbore can move the stressed element material 39 of the sealing element 38 into the gap G between the outer diameter 53 and the inner surface 50. The stressed element material 39 can become unsupported and begin to pull away or extrude.

[0050] In FIG. 5A is a cross-sectional view illustrating a preferred embodiment of a wellbore isolation device 400 comprising a sealing element 38, a metal back-up ring 60, and an end ring 62. The sealing element 38 is mounted on the outer surface 54 of a mandrel and abuts a shoulder 52 of the mandrel. A metal support ring 60 is slidably seated on the outer surface 54 of the mandrel to bring the sealing element 38 into contact with the end surface 73 up the wellbore. The end ring 62 is slidably seated on the outer surface 54 of the mandrel and brings the metal support ring 60 into contact with the end surface 64. The radial clearance G is measured between the outer diameter 53 of the mandrel and the inner surface 50 of the wellbore 6.

[0051] Next, with reference to FIG. 5B, the sealing element 38 can expand under the action of a compressive force applied by an installation tool adapted to the wellbore isolation device 400. The installation tool creates an axial compressive force F, which can be transferred using an adapter set (not shown) to the end ring 62. The axial force F is transmitted through the end ring 62 to the metal support ring 60, the sealing element 38 and the mandrel shoulder 52. The axial force compresses the sealing element 38 between the mandrel shoulder 52 and the metal support ring 60, bringing it into sealing contact with the inner surface 50 of the casing. The axial force compresses the metal support ring between the sealing element 38 and the end surface 64 on the end ring 62 and expands the metal support ring 60 into an expanded state. The end ring 62 can lock the axial force F using a locking ring (not shown) that locks or fixes the position of the end ring 62 on the mandrel 24. The engagement of the sealing elements 38 between the inner surface of the casing, the outer surface 54 of the mandrel, the mandrel shoulder 52 and the expanded metal the support ring 60' under the influence of the axial force F can create a high contact stress. As a result, the sealing elements 38 can provide sealing engagement with the wellbore 6. Contact stress within the sealing element 38 may cause the stressed material 39 of the element to move into the gap G between the outer diameter 53 of the mandrel and the inner surface 50 of the wellbore 6. The extended seal element 38' isolates the upper wellbore surrounding environment WA (fluid pressure and composition) from the downhole surrounding wellbore environment WB (fluid pressure and composition).

[0052] The extended metal support ring 60 may secure the wellbore isolation device 400 to the inner surface 50 of the wellbore 6. An alternative embodiment of the extended metal support ring 60 is shown in FIG. 6. The outer surface may have an abrasive gravel coating 92 on all or part of the outer surface. The gravel may consist of hard alloy particles such as tungsten carbide, ceramic particles such as sintered bauxite or alumina, or other suitable high strength particles. The gravel particle size can range from 37 to 400 microns. The abrasive gravel coating 92 can be applied by plasma spraying metal or epoxy resin. As the metal back-up ring 60 expands and comes into contact with the inner surface 50 of the wellbore 6, gravel can be pressed by the material of the metal back-up ring 60' into the material of the inner surface 50 of the wellbore 6. Gravel can penetrate the surface of the borehole material to a depth of 400 microns. The gravel, in combination with the compressive stress between the expanded metal support ring 60' and the inner surface 50 of the wellbore 6, can secure the wellbore isolation device 400 at a specific location in the wellbore 6.

[0053] In FIG. 7A is a cross-sectional view illustrating one embodiment of a wellbore isolation device 500 comprising an upper slip 34A, an upper slip deflector 36A, a metal back-up ring 60A, a sealing member 38, a metal back-up ring 60B, a lower slip deflector 36B, a lower slip 34B and an end ring 62. An upper slip 34A and an upper slip deflector 36A may be mounted on a mandrel 24, with the upper slip 34A abutting a shoulder 52 of the mandrel. A metal back-up ring 60A, a sealing member 38, and a metal back-up ring 60B may be mounted on the mandrel 24, with the metal back-up ring 60A in contact with the upper slip deflector 36A. The lower slip deflector 36B, the lower slip 34B, and the end ring 62 may be installed such that the end surface 64 of the lower slip deflector 36B is in contact with the downhole end surface 72 of the metal support ring 60B. A metal support ring 60A may be attached to the uphole side of the seal element 38. A metal support ring 60B may be attached to the downhole side of the seal element 38. The metal support ring 60B, the seal element 38, and the lower metal support ring 60B are seated with sliding onto the outer surface 54 of the mandrel. The radial clearance G is measured between the outer diameter 53 of the mandrel and the inner surface 50 of the wellbore 6.

[0054] Next, with reference to FIG. 7B, the sealing element 38 may expand radially into the sealing engagement due to the compressive force applied by the installation tool adapted to the wellbore isolation device 500. The installation tool generates an axial compressive force F, which can be transferred using an adapter set (not shown) to the end ring 62. The axial force F is transmitted through the end ring 62 to radially expand the upper slip 34A to the upper slip deflector 36A and to grip the inner surface 50 trunk 6 wells. The axial compression force F expands the metal support ring 60A, the sealing element 38 and the metal support ring 60B into engagement with the inner surface 50 of the wellbore 6. The axial force F expands the lower slip 34B onto the lower slip wedge 36B and moves the end ring 62 into contact with the lower slip 34B. The metal back-up ring 60A, sealing member 38, and metal back-up ring 60B may be expanded into sealing engagement with the wellbore 6. The end ring 62 can fix the axial force F using a locking ring (not shown) that locks or fixes the position of the end ring 62 on the mandrel 24. The engagement of the sealing element 38 between the inner surface of the casing, the outer surface 54 of the mandrel, the expanded metal support ring 60' A and the expanded metal support ring 60'B, under the action of the axial force F, can create a high contact stress, and as a result, the sealing elements 38 can provide sealing engagement with the wellbore 6. The extended seal element 38 isolates the upper wellbore environment WA (fluid pressure and composition) from the downhole environment WB (fluid pressure and composition). The expanded metal support rings 60'A and 60'B may be sealed against the wellbore 6. The expanded metal support rings 60'A and 60'B may be gravel coated and secured to the inner surface 50 of the wellbore 6.

[0055] In FIG. 8A is a cross-sectional view illustrating an embodiment of a wellbore isolation device 600 comprising a metal back-up ring 60A, a sealing member 38, a metal back-up ring 60B, and an end ring 62. Metal back-up ring 60A, a sealing member 38, a metal back-up ring 60B and the end ring 62 is mounted on the mandrel 24, with the metal support ring 60A abutting the shoulder 52 of the mandrel. A metal support ring 60A may be attached to the uphole side of the seal element 38, and a metal support ring 60B may be attached to the downhole side of the seal element 38. The metal support ring 60B, the seal element 38, and the lower metal support ring 60B are seated. with sliding onto the outer surface 54 of the mandrel. The radial clearance G is measured between the outer diameter 53 of the mandrel and the inner surface 50 of the wellbore 6.

[0056] Next, with reference to FIG. 8B, the sealing element 38 may expand radially into the sealing engagement due to the compressive force applied by the installation tool adapted to the wellbore isolation device 600. The installation tool creates an axial compressive force F, which can be transferred using an adapter set (not shown) to the end ring 62. The axial force F expands the metal back-up ring 60A, the sealing element 38 and the metal back-up ring 60B, bringing them into engagement with the inner surface 50 trunk 6 wells. The end ring 62 can fix the axial force F using a locking ring (not shown) that locks or fixes the position of the end ring 62 on the mandrel 24. The engagement of the sealing element 38' between the inner surface of the casing, the outer surface 54 of the mandrel, the expanded metal support ring 60 'A and the expanded metal support ring 60'B under the action of the axial force F can create a high contact stress, and as a result, the sealing elements 38' can provide sealing engagement with the wellbore 6. The extended seal element 38' isolates the upper wellbore surrounding environment WA (fluid pressure and composition) from the downhole surrounding wellbore environment WB (fluid pressure and composition). The expanded metal support rings 60'A and 60'B may be in sealing contact with the wellbore 6. The expanded metal support rings 60'A and 60'B may be gravel coated and secured to the inner surface 50 of the wellbore 6.

[0057] In FIG. 9A is a cross-sectional view illustrating an embodiment of a wellbore isolation device 700 comprising a sealing member 38, a metal backing ring 144, a metal backing ring 146, and an end ring 62. The sealing member 38, a metal backing ring 144, a metal backing ring 146, and the end ring 62 is slidingly seated on the outer surface 54 of the mandrel 24, and the sealing element 38 abuts the shoulder 52 of the mandrel. A metal support ring 144 may be attached to the downhole side of the sealing element 38. The radial clearance G is measured between the outer diameter 53 of the mandrel and the inner surface 50 of the wellbore 6.

[0058] Next, with reference to FIG. 9B, the sealing element 38 may expand radially into the sealing engagement due to the compressive force applied by the installation tool adapted to the wellbore isolation device 700. The installation tool creates an axial compressive force F, which can be transferred using an adapter set (not shown) to the end ring 62. The axial force F expands the sealing element 38, the metal back-up ring 144 and the metal back-up ring 146, bringing them into engagement with the inner surface 50 trunk 6 wells. The sealing element 38, the metal support ring 144 and the metal support ring 146 can be expanded into sealing engagement with the wellbore 6. The end ring 62 can lock the axial force F using a locking ring (not shown) that locks or fixes the position of the end ring 62 on the mandrel 24. Engagement of the sealing element 38' between the inner surface of the casing, the outer surface 54 of the mandrel and the expanded metal support ring 144 ' under the influence of the axial force F can create a high contact stress, and as a result, the sealing elements 38 ' can provide sealing engagement with the wellbore 6. The extended seal element 38' isolates the upper wellbore surrounding environment WA (fluid pressure and composition) from the downhole surrounding wellbore environment WB (fluid pressure and composition). The expanded metal support rings 144' and 146' may be in sealing contact with the wellbore 6. The expanded metal support rings 144' and 146' may be gravel coated and secure the wellbore isolation device 700 to the inner surface 50 of the wellbore 6.

[0059] In FIG. 10A is a cross-sectional view illustrating an embodiment of a wellbore isolation device 800 comprising a sealing element 38, a metal back-up ring 118, and an end ring 62. The sealing element 38 is mounted on the outer surface 54 of a mandrel and abuts a shoulder 52 of the mandrel. A metal support ring 118 is slidably seated on the outer surface 54 of the mandrel 24 to bring the sealing element 38 into contact with the end surface 122. The metal support ring 118 has an outer support surface 136 down the wellbore and an outer support surface 138 up the wellbore that converge. at the upper radius 130. The metal support ring 118 has an initial height H measured from the upper radius 130 to the bottom surface 124. The metal support ring 118 has an inner downhole support surface 126 and an upwellbore inner support surface 128 that converge at lower radius 120. The inner uphole support surface 128 has an inner uphole projection 134 that extends inward toward the inner downhole support surface 126. The inner downhole support surface 126 has an inner downhole projection 132 that extends inward toward the inner uphole support surface 128. The end ring 62 is slidably seated on the outer surface 54 of the mandrel and brings the metal support ring 118 into contact with the end surface 64. The radial clearance G is measured between the outer diameter 53 of the mandrel and the inner surface 50 of the wellbore 6.

[0060] Next, with reference to FIG. 10B, the sealing element 38 can expand under the action of a compressive force applied by an installation tool adapted to the wellbore isolation device 800. The installation tool creates an axial compressive force F, which can be transferred using an adapter set (not shown) to the end ring 62. The axial force F is transmitted through the end ring 62 to the metal support ring 118, the sealing element 38 and the mandrel shoulder 52. The axial force compresses the sealing element 38 between the mandrel shoulder 52 and the metal support ring 118, bringing it into sealing contact with the inner surface 50 of the wellbore 6. The axial force compresses the metal support ring 118 between the sealing member 38 and the end surface 64 on the end ring 62 and expands the metal support ring 118 into an expanded state with an expanded height H'. The extended height H' is measured from the top radius 130' to the outer surface 54 of the mandrel. The metal support ring 118 is axially deformed such that the inner projection 132 down the wellbore comes into contact with the internal projection 134 up the wellbore. The axial deflection of the metal support ring 118 may be limited such that the inner support surface 128 up the wellbore can approach, but not contact, the inner support surface 126 down the wellbore. The end ring 62 can lock the axial force F using a locking ring (not shown) that locks or fixes the position of the end ring 62 on the mandrel 24. The engagement of the sealing elements 38' between the inner surface of the casing, the outer surface 54 of the mandrel, the mandrel shoulder 52 and the expanded metal support ring 60' under the influence of axial force F can create a high contact stress. As a result, the sealing elements 38' can provide sealing engagement with the wellbore 6. Contact stress within the sealing element 38' may cause the stressed material 39 of the element to move into the gap G between the outer diameter 53 of the mandrel and the inner surface 50 of the wellbore 6. The extended seal element 38 isolates the upper wellbore environment WA (fluid pressure and composition) from the downhole environment WB (fluid pressure and composition).

[0061] In FIG. 11A is a cross-sectional view illustrating an embodiment of a wellbore isolation device 900 comprising a sealing member 38, a metal back-up ring 140, and an end ring 62. The sealing member 38 is mounted on the outer surface 54 of a mandrel and abuts a shoulder 52 of the mandrel. A metal back-up ring 140 is slidably seated on an outer surface 54 of the mandrel to bring the sealing element 38 into contact with the end surface 152. The metal back-up ring 140 has an outer downhole support surface 166 and an outer uphole support surface 168 that converge at top radius 160. The metal support ring 140 has an initial height H measured from the top radius 160 to the bottom surface 154. The metal support ring 140 has an inner downhole support surface 156 and an upwellbore inner support surface 158 that converge at the bottom radius 150. The outer surface 166 of the downhole support may be longer than the outer surface 168 of the upwell support, and the angle between the inner surface 158 of the upwell support and the outer surface 54 of the mandrel may be greater than the angle between the inner surface 156 supports down the wellbore and the outer surface 54 of the mandrel. The difference in length between the uphole support and the downhole support can cause the shorter support, the uphole support, to deflect or deform before the longer support, which is the downhole support. The end ring 62 is slidably seated on the outer surface 54 of the mandrel and brings the metal support ring 118 into contact with the end surface 64. The radial clearance G is measured between the outer diameter 53 of the mandrel and the inner surface 50 of the wellbore 6.

[0062] Next, with reference to FIG. 11B, the sealing element 38 can expand under the action of a compressive force applied by an installation tool adapted to the wellbore isolation device 900. The installation tool creates an axial compressive force F, which can be transferred using an adapter set (not shown) to the end ring 62. The axial force F is transmitted through the end ring 62 to the metal support ring 140, the sealing element 38 and the mandrel shoulder 52. The axial force compresses the sealing element 38 between the mandrel shoulder 52 and the metal support ring 140, bringing it into sealing contact with the inner surface 50 of the wellbore 6. The axial force compresses the metal support ring 140 between the sealing member 38 and the end surface 64 on the end ring 62 and expands the metal support ring 140 into an expanded state with an expanded height H'. The extended height H' is measured from the top radius 160' to the outer surface 54 of the mandrel. The metal support ring 140 deforms axially such that the shorter support, outer support surface 168 up the wellbore, first contacts the sealing element 38 before the longer support, outer support surface 166 down the wellbore expands the upper radius 160' in engagement with the inner surface 50 of the wellbore 6. The longer support of the metal support ring 140 can stop axial deformation and radial expansion of the support ring when the upper radius 160' contacts the wellbore 6 by wedging the outer support surface 166 down the wellbore between the inner surface 50 of the wellbore 6 and the outer surface 54 of the mandrel. . The end ring 62 can lock the axial force F using a locking ring (not shown) that locks or fixes the position of the end ring 62 on the mandrel 24. The engagement of the sealing elements 38 between the inner surface of the casing, the outer surface 54 of the mandrel, the mandrel shoulder 52 and the expanded metal the support ring 140' under the action of the axial force F can create a high contact stress. As a result, the sealing elements 38' can provide sealing engagement with the wellbore 6. Contact stress within the sealing element 38' may cause the stressed material 39 of the element to move into the gap G between the outer diameter 53 of the mandrel and the inner surface 50 of the wellbore 6. The extended seal element 38 isolates the upper wellbore environment WA (fluid pressure and composition) from the downhole environment WB (fluid pressure and composition).

[0063] Next, with reference to FIG. 12, an alternative embodiment of the metal support ring 180 is described. The uphole support and the downhole support of the metal support ring 180 can be manufactured separately and connected to each other at the upper radius 210 by a mechanical connection, a welding operation, a chemical binder, or similar joining methods to form a cross-section that is generally inverted U-shaped or inverted V-shaped. Mechanical connection refers to any method, threads or fasteners for connecting or attaching a support up the wellbore to a support down the wellbore. The welding procedure generally refers to the joining of a support up a wellbore and a support down a wellbore using an electrode that provides a flow of material in response to an electrical current applied through the parts. Chemical bonding generally refers to any method of bonding together a support up the wellbore and a support down the wellbore. The support up the wellbore and the support down the wellbore may be shaped like a truncated cone with straight edges. In one embodiment, the support up the wellbore and the support down the wellbore may have curved sides. In one embodiment, the angle A formed between each outer surface and the outer surface 54 of the mandrel may be generally between 15 and 45 degrees. The metal support ring 180 has a downhole outer support surface 206 and an upwellbore outer support surface 208 that converge where both parts are welded or interlocked at an upper radius 210. The metal support ring 200 has an initial height H measured from an upper radius 210 to a lower surface 194. The metal support ring 180 has an inner downhole support surface 196 and an uphole inner support surface 198 that converge at a lower radius 190. The lower surface 194 has a sliding fit, a fit that provides movement, with outer surface 54 mandrels. Each metal support ring support can be machined, extruded, sintered, forged, molded, or manufactured using an additive manufacturing process. The metal support ring 180 has an end surface 192 that is generally flat and vertical and a bottom surface 194 that is generally parallel to the outer surface 54 of the mandrel. The metal back-up ring 180 may have a clearance fit that is slidably engaged with the outer surface 54 of the mandrel. The metal support ring 180 may have an outer uphole support surface 208 and an outer downhole support surface 206 that are generally the same length. One embodiment of the metal support ring 180 may have one side longer than the other. An embodiment of the metal support ring 180 may have a gravel coating on all or part of the outer surface.

[0064] Again with reference to FIG. 1, with further reference to other figures discussed herein, the wellbore isolation device 16 may be transported into the well by wireline, coiled tubing, tubing, or drill pipe for completion or stimulation operations. The wellbore isolation device 16 may be attached to the installation tool or may have actuation means built into it. A wellbore isolation device 16 is mounted within the wellbore 6 to isolate the wellbore environment up the wellbore from the wellbore environment down the wellbore. In some cases, the wellbore isolation device 16 is a packer with a central flow channel 28. In other cases, the wellbore isolation device 16 is a bridge plug with a blocked central flow channel 28. In other cases, the wellbore isolation device 16 is a plug for hydraulic fracturing with a valve in the central flow channel 28, which allows flow from one direction, but blocks flow from the opposite direction.

[0065] The wellbore isolation device 16 may have one or more metal support rings 60 that radially expand to support the sealing element 38, which radially expand to seal the inner surface 50 of the wellbore 6. The wellbore isolation device 16 may be actuated by a compression force applied by a setting tool or a setting mechanism incorporated therein. When the wellbore isolation device 16 is located at a location in close proximity to the area of interest, a compressive force is applied to the wellbore isolation device 16, the installation tool or installation mechanism incorporated therein.

[0066] In the embodiment shown with the wellbore isolation device 300, the axial compression force F moves the lower slip 34B onto the conical surface 37B of the lower slip deflector 36B and into radial engagement with the inner surface 50 of the wellbore 6 for securing in the wellbore 6 . The axial compression force F compresses the sealing element 38 and the metal support ring 60 between the lower slip deflector 36B and the mandrel shoulder 52 to radially expand the sealing element 38 and the metal support ring 60 to contact the inner surface 50 of the wellbore 6. The metal support ring 60 deforms axially, with the inner support surface 66 downhole moving in close proximity to the inner support surface 68 up the wellbore as the upper radius 67 radially expands from the original height H to the expanded height H'. The expanded metal back-up ring 60' supports the expanded sealing element 38 to prevent the sealing element material from moving past the expanded metal back-up ring 60'. The metal support ring 60 can contact the inner surface 50 of the wellbore 6 without contact stress or with a stress level sufficient to provide sealing engagement with the wellbore 6. In the first embodiment, lower clips 34B secure the wellbore isolation device 16 to the wellbore 6, sealing elements 38 seal the wellbore isolation device 16 to the wellbore 6, and a metal support ring 60 supports the sealing element 38 to prevent the sealing element material from moving past the wellbore. a metal support ring 60. The wellbore isolation device 16 isolates the environment surrounding the wellbore from one direction; that is, from the uphole side to the downhole side, but not from the downhole side to the uphole side.

[0067] In another embodiment, shown with wellbore isolation device 400, an axial compression force F moves sealing element 38 and metal back-up ring 60 between end ring 62 and mandrel shoulder 52 to radially expand sealing element 38 and metal back-up ring 60 to contact with the inner surface 50 of the wellbore 6. The metal support ring 60 deforms axially, with the inner support surface 66 downhole moving in close proximity to the inner support surface 68 up the wellbore as the upper radius 67 radially expands from the original height H to the expanded height H'. The expanded metal back-up ring 60' supports the expanded sealing element 38 to prevent the sealing element material from moving past the expanded metal back-up ring 60'. In an alternative embodiment, the metal back-up ring 60 may have an abrasive gravel coating 92 applied to all or part of the outer surface. The metal back-up ring 60 may contact the inner surface 50 of the wellbore 6 without contact stress, or with a stress level sufficient to provide sealing engagement with the wellbore 6, or with a stress level sufficient to trap abrasive gravel between the expanded metal back-up ring 60 and the inner surface. 50 of the wellbore 6 for securing the wellbore isolation device 400 in the wellbore 6. The wellbore isolation device 200 isolates the environment surrounding the wellbore from one direction; that is, from the uphole side to the downhole side, but not from the downhole side to the uphole side.

[0068] In another embodiment, shown with the wellbore isolation device 500, the axial compression force F moves the lower slip 34B onto the conical surface 37B of the lower slip deflector 36B and into radial engagement with the inner surface 50 of the wellbore 6 to secure the device 300 for isolating the wellbore in the wellbore. The axial compression force F compresses the sealing element 38 between the metal support ring 60A and the metal support ring 60B to radially expand the sealing element 38 and the metal support ring 60A and the metal support ring 60B to contact the inner surface 50 of the wellbore 6 by transmitting an axial force F through the lower slip deflector 36V. The upper slip 34A moves onto the conical surface 37A of the upper slip deflector 36A and into radial engagement with the inner surface 50 of the wellbore 6 when an axial force F compresses the upper slip 34A between the mandrel shoulder 52 and the metal support ring 60A. The metal support rings 60A and 60B deform axially, with the inner support surface 66 moving downhole in close proximity to the inner support surface 68 up the wellbore as the upper radius 67 radially expands from the original height H to the expanded height H'. The expanded metal back-up rings 60A' and 60B' support the expanded sealing element 38 to prevent the sealing element material from moving past the expanded metal back-up ring 60A' and 60B'. The metal support ring 60A' and 60B' may contact the inner surface 50 of the wellbore 6 without contact stress or at a stress level sufficient to provide sealing engagement with the wellbore 6. In one embodiment, upper clips 34A and lower clips 34B secure the wellbore isolation device 16 to the wellbore 6, sealing elements 38 seal the wellbore isolation device 16 to the wellbore 6, and metal support rings 60A and 60B support the sealing element 38 to preventing the sealing element material from moving past the metal support rings 60A and 60B. The wellbore isolation device 16 isolates the environment surrounding the wellbore from both directions; that is, from the uphole side to the downhole side and from the downhole side to the uphole side.

[0069] In another embodiment, shown with a wellbore isolation device 600, an axial compression force F compresses the sealing element 38 between the metal back-up ring 60A and the metal back-up ring 60B to radially expand the sealing element 38 and the metal back-up ring 60A and the metal back-up ring 60V for contact with the inner surface 50 of the wellbore 6. The axial force F is transmitted from the end ring 62 to the metal support ring 60B, to the sealing element 38, to the metal support ring 60A and to the mandrel shoulder 52. The metal support rings 60A and 60B deform axially, with the inner support surface 66 moving downhole in close proximity to the inner support surface 68 up the wellbore as the upper radius 67 radially expands from the original height H to the expanded height H'. The expanded metal back-up rings 60A' and 60B' support the expanded sealing element 38 to prevent the sealing element material from moving past the expanded metal back-up ring 60A' and 60B'. The metal support ring 60A' and 60B' can contact the inner surface 50 of the wellbore 6 without contact stress, with a voltage level sufficient to provide sealing engagement with the wellbore 6. Alternatively, the metal backing ring 60 may have an abrasive gravel coating 92 applied to all or part of the outer surface. The metal support ring 60 may contact the inner surface 50 of the wellbore 6 with a contact stress level sufficient to trap abrasive gravel between the expanded metal support ring 60 and the inner surface 50 of the wellbore 6 to secure the wellbore isolation device 400 in the wellbore 6. In one embodiment, metal support rings 60A and 60B secure the wellbore isolation device 16 to the wellbore 6, sealing elements 38 seal the wellbore isolation device 16 to the wellbore 6, and metal backup rings 60A and 60B support the sealing element 38 to prevent movement of the material of the sealing element behind the metal support rings 60A and 60B. The wellbore isolation device 16 isolates the environment surrounding the wellbore from both directions; that is, from the uphole side to the downhole side and from the downhole side to the uphole side.

[0070] In another embodiment, shown with wellbore isolation device 700, an axial compression force F moves sealing element 38, metal back-up ring 144, and metal back-up ring 146 between end ring 62 and mandrel shoulder 52 to radially expand sealing element 38. a metal support ring 144 and a metal support ring 146 for contacting the inner surface 50 of the wellbore 6. The metal support ring 144 and 146 deforms in the axial direction, with the inner surface of the support down the wellbore moving in close proximity to the inner surface of the support up the wellbore as the upper radius radially expands from the original height H to the expanded height H'. The expanded metal back-up ring 144' supports the expanded sealing element 38' to prevent the sealing element material from moving past the expanded metal back-up ring 144'. In an alternative embodiment, one or both of the metal back-up rings 144 and 146 may have an abrasive gravel coating applied to all or a portion of the outer surface. The metal support ring 144' and 146' may contact the inner surface 50 of the wellbore 6 without contact stress or at a stress level sufficient to provide sealing engagement with the wellbore 6, or at a stress level sufficient to trap abrasive gravel between the expanded metal support ring 144, 146 and the inner surface 50 of the wellbore 6 for securing the wellbore isolation device 700 in the wellbore 6. The wellbore isolation device 700 isolates the environment surrounding the wellbore from one direction; that is, from the uphole side to the downhole side, but not from the downhole side to the uphole side.

[0071] In another embodiment, the axial compression force F moves the sealing element 38 and the metal support ring 118 between the end ring 62 and the mandrel shoulder 52 to radially expand the sealing element 38 and the metal support ring 118 into contact with the inner surface 50 of the wellbore 6. The metal support ring 118 is deformed axially until the internal projection 134 up the wellbore comes into contact with the internal projection 132 down the wellbore. The uphole inner support surface 128 may approach, but not contact, the downhole inner support surface 126 as the upper radius 130 radially expands from the original height H to the expanded height H'. The expanded metal back-up ring 118' supports the expanded sealing element 38 to prevent the sealing element material from moving past the expanded metal back-up ring 60'. In an alternative embodiment, the metal back-up ring 118 may have an abrasive gravel coating 92 applied to all or a portion of the outer surface. The metal back-up ring 118 may contact the inner surface 50 of the wellbore 6 without contact stress, or with a stress level sufficient to provide sealing engagement with the wellbore 6, or with a stress level sufficient to trap abrasive gravel between the expanded metal back-up ring 118 and the inner surface. 50 of the wellbore 6 for securing the wellbore isolation device 400 in the wellbore 6. The wellbore isolation device 800 isolates the environment surrounding the wellbore from one direction; that is, from the uphole side to the downhole side, but not from the downhole side to the uphole side.

[0072] In another embodiment, the axial compression force F moves the sealing element 38 and the metal support ring 140 between the end ring 62 and the mandrel shoulder 52 to radially expand the sealing element 38 and the metal support ring 140 into contact with the inner surface 50 of the wellbore 6. The metal support ring 140 deforms axially with the inner support surface 158 up the wellbore approaching the inner support surface 156 down the wellbore until the upper radius 160 comes into contact with the inner surface 50 of the wellbore 6 and the outer the support surface 166 down the wellbore will not become wedged between the inner surface 50 and the outer surface 54 of the mandrel. As the outer support surface 166 moves down the wellbore toward the inner wellbore surface 50, the upper radius 160 expands radially from the original height H to the expanded height H'. The expanded metal back-up ring 118' supports the expanded sealing element 38 to prevent the sealing element material from moving past the expanded metal back-up ring 60'. In an alternative embodiment, the metal back-up ring 140 may have an abrasive gravel coating 92 applied to all or part of the outer surface. The metal back-up ring 140 may contact the inner surface 50 of the wellbore 6 without contact stress, or with a stress level sufficient to provide sealing engagement with the wellbore 6, or with a stress level sufficient to trap abrasive gravel between the expanded metal back-up ring 140 and the inner surface. 50 of the wellbore 6 for securing the wellbore isolation device 900 in the wellbore 6. The wellbore isolation device 900 isolates the environment surrounding the wellbore from one direction; that is, from the uphole side to the downhole side, but not from the downhole side to the uphole side.

[0073] Having described various systems and methods herein, some embodiments may include, but are not limited to, the following:

[0074] In a first embodiment, a wellbore isolation device comprising: a mandrel 24 having a cylindrical main body with an outer mandrel surface 54 and a central flow channel 28; a sealing element 38 located around the mandrel 24 and configured to expand radially from the first rolling diameter before being brought into sealing engagement with the inner surface 50 of the wellbore 6; a metal support ring 60 located on the mandrel 24, in contact with one side of the sealing elements 38 with an initial height H and configured to expand radially, and configured to deform axially to abut the inner surface 50 of the wellbore 14; wherein the metal support ring 60 has a concave cross-section around the mandrel 24 with support up the wellbore and support down the wellbore; and wherein the applied compressive force expands the sealing elements 38 into sealing engagement with the wellbore 6, and the metal support ring 60 radially expands under axial deformation to abut the inner surface 50 of the wellbore 6 without contact pressure.

[0075] The second embodiment may include a retrievable wellbore isolation device of the first embodiment, wherein the removable wellbore isolation device is a device selected from the group consisting of a fracturing plug ( hydraulic fracturing), plug packer, cased hole packer, open hole packer, cement plug and any combination thereof.

[0076] The third embodiment may include a retrievable wellbore isolation device of the first embodiment, characterized in that the metal support ring 60 radially expands from the original height H to an increased height H', which is equal to 80% of the distance from initial height H to the inner surface 50 of the 6th wellbore.

ADDITIONAL DESCRIPTION

[0077] The following are non-limiting specific aspects in accordance with this invention:

[0078] The first embodiment, which is a wellbore isolation device, comprising: a mandrel 24 having a cylindrical main body with an outer surface 54 and a central flow channel 28, a sealing element system 38 located around the mandrel 24 and configured to expand radially from the first rolling diameter to insertion into sealing engagement with the inner surface 50 of the wellbore 6, a metal support ring 60 located on the mandrel 24 contacting one side of the sealing element system 38 with an initial height H and configured to expand radially, and configured to axial deformation to abut the inner surface 50 of the wellbore, wherein the metal support ring 60 has a concave cross-section around the mandrel 24 with a support up the wellbore and a support down the wellbore, and the sealing element system 38 is configured to radially expand into a sealing engagement of - due to the applied compressive force, and wherein the metal support ring 60 is configured to radially expand and axially deform to abut the inner surface 50 of the wellbore 6 without contact pressure due to the applied compressive force.

[0079] The second embodiment, which is a wellbore isolation device of the first embodiment, characterized in that the wellbore isolation device is a device selected from the group consisting of a hydraulic fracturing plug, a packer plug, cased hole packer, open hole packer and cement plug.

[0080] The third embodiment, which is a wellbore isolation device of the first embodiment, characterized in that the metal support ring 60 is configured to radially expand from the original height H to an increased height H', which is equal to 80% of the distance from the original height N to the inner surface 50 of the 6th wellbore.

[0081] The fourth embodiment, which is a wellbore isolation device of the first embodiment, characterized in that the abutment of the inner surface 50 of the wellbore 6 increases the increased height H' of the metal support ring 60 to within 2.286 mm (0.09 inch) from the inner surface 50 of the wellbore 6.

[0082] The fifth embodiment, which is a wellbore isolation device of the first embodiment, characterized in that the metal support ring 60 is radially expanded and axially deformed to contact the inner surface 50 of the wellbore 6, and wherein the metal support ring 60 is configured to abut the inner surface 50 of the wellbore 6 with a contact stress ranging from no contact pressure to sealing contact pressure.

[0083] The sixth embodiment, which is a wellbore isolation device of the first embodiment, characterized in that the metal support ring 60 is radially expanded and axially deformed to contact the inner surface 50 of the wellbore 6, and the metal support ring 60 made with the possibility of abutting with contact stress in the range from sealing contact pressure to contact pressure exceeding the maximum shear stress of the wellbore 6.

[0084] The seventh embodiment, which is a wellbore isolation device of the first embodiment, characterized in that the cross-section of the metal support ring 60 has a corrugated shape, an inverted arc shape, a bell shape, or an inverted U shape, and wherein the support is upward along the wellbore and the support down the wellbore are curved.

[0085] The eighth embodiment, which is a wellbore isolation device of the first embodiment, characterized in that the cross-section of the metal support ring 60 has an inverted V-shape, and wherein the upwell support and the downwell support have truncated cone shape.

[0086] The ninth embodiment, which is a wellbore isolation device of the first embodiment, characterized in that one or more metal support rings 60 has an element for limiting axial deflection on the inner surface of one or more uphole support and downhole support along the wellbore.

[0087] The tenth embodiment, which is a wellbore isolation device of the first embodiment, characterized in that the uphole support and downhole support of the one or more metal support rings 60 are of different lengths.

[0088] An eleventh embodiment, which is a wellbore isolation device of the first embodiment, characterized in that one or more metal support rings 60 have an abrasive coating of sand, gravel or carbide on part or all of the outer surface.

[0089] The twelfth embodiment, which is a wellbore isolation device of the first embodiment, comprising a second metal support ring 60 located on a mandrel 24 on the opposite side of the sealing element system 38.

[0090] The thirteenth embodiment, which is the wellbore isolation device of the twelfth embodiment, comprising two or more metal support rings 60 located on a mandrel 24 on one side of the sealing element system 38.

[0091] A fourteenth embodiment, which is a device for isolating a wellbore of any of the first, twelfth, or thirteenth embodiments, comprising two or more metal support rings 60 located on a mandrel 24 on the opposite side of the sealing element system 38.

[0092] A fifteenth embodiment, which is a device for isolating a wellbore of any one of the first, eighth, ninth, or tenth embodiments, comprising one or more attachment devices located on a mandrel 24 and expandable to be firmly engaged with the inner surface of the casing or wellbore in response to a compressive force applied to the retrievable wellbore isolation device.

[0093] The sixteenth embodiment, which is a wellbore isolation device of the fifteenth embodiment, characterized in that the fastening device is composed of one or more metal support rings 60.

[0094] The seventeenth embodiment, which is a wellbore isolation device of the fifteenth embodiment, characterized in that the fastening device is a slip on a deflector.

[0095] An eighteenth embodiment, which is a device for isolating a wellbore of any of the sixth, tenth, eleventh or twelfth embodiments, characterized in that the metal support ring 60 is expandable to engage the casing with limited axial deflection due to the applied compression force.

[0096] The nineteenth embodiment, which is a wellbore isolation device of the first embodiment, characterized in that the metal support ring 60, the mandrel 24 and the sealing element system 38 are made of soluble materials.

[0097] The twentieth embodiment, which is a wellbore isolation device of the first embodiment, characterized in that the wellbore isolation device is removable by drilling, milling, chemical application, corrosion or dissolution.

[0098] A twenty-first embodiment, which is a method including inserting a wellbore isolation device into a wellbore, the wellbore isolation device comprising a mandrel 24, a sealing member system 38 located around the mandrel 24, one or more metal retaining ring 60, located on a mandrel 24 on one or more sides of the sealing element system 38 and configured to be radially expanded and axially deformed for sealing engagement with the wellbore; providing an axial compression force on the metal support ring 60, radial deformation of the sealing element system 38 for sealing engagement with the wellbore, and radial and axial deformation of the metal support ring 60 for engagement with the wellbore.

[0099] Twenty-second embodiment, which is a method of the twenty-first embodiment, characterized in that providing an axial compressive force expands the slip onto the deflector for rigid engagement with the inner wall of the wellbore.

[00100] Twenty-third embodiment, which is a method of the twenty-first embodiment, characterized in that one or more metal support rings 60 are rigidly engaged with the inner wall of the wellbore.

[00101] The twenty-fourth embodiment, which is a method of the twenty-first embodiment, characterized in that the expandable support ring 60 maintains the sealing element 38 in sealing engagement with the wellbore on one side.

[00102] The twenty-fifth embodiment, which is a method of the twenty-first embodiment, characterized in that the expandable support ring 60 maintains the sealing element 38 in sealing engagement with the wellbore on both sides.

[00103] A twenty-sixth embodiment, which is a method including: introducing a wellbore isolation device into a wellbore, extending the sealing element system 38 into sealing engagement with the inner surface 50 of the wellbore 6, isolating the wellbore environment down the wellbore well from the expanded sealing element system 38 from the wellbore environment up the wellbore from the sealing element system 38, axially supporting one side of the sealing element system 38 by means of an expandable ring 60 that extends from the outer surface 54 of the mandrel 24 to abut the inner surface 50 of the wellbore 6, and separating the axially supported sealing element system 38 from the annular wellbore environment up the wellbore or the annular wellbore environment down the wellbore.

[00104] At least one embodiment is described, with variations, combinations and/or modifications of the embodiment(s) and elements of the embodiment(s) made by one skilled in the art falling within the scope of the present invention. Alternative implementations that result from combining, embedding and/or omitting elements of the embodiment(s) are also within the scope of this invention. If numerical ranges or limits are stated explicitly, it should be understood that such explicit ranges or limits include iteration ranges or limits of similar magnitude falling within the explicitly stated ranges or limits (e.g., the range from about 1 to about 10 includes 2, 3, 4, etc. .etc.; more than 0.10 includes 0.11, 0.12, 0.13, etc.). For example, whenever a numerical range with a lower limit R _l and an upper limit R _u is described, any number falling within that range is specifically described. In particular, the following numbers within the range are specifically disclosed: R=R _l +k*(R _u -R _l ), where k is a variable ranging from 1 percent to 100 percent in 1 percent increments, i.e. k is 1 percent, 2 percent, 3 percent, 4 percent, 5 percent, 50 percent, 51 percent, 52 percent, 95 percent, 96 percent, 97 percent, 98 percent, 99 percent, or 100 percent. Additionally, any numerical range defined by two R numbers as defined above is also specifically described. The use of the term "optional" in relation to any element of the claims means that the element is required, or alternatively, the element is not required, both alternatives being within the scope of the claims. The use of broader terms such as “comprises”, “includes” and “having” should be understood as supporting narrower terms such as “consisting of”, “consisting essentially of” and “comprising essentially”. Accordingly, the scope of protection is not limited to the above description, but is defined by the following claims, the scope of which includes all equivalents of the subject matter of the claims. Each of the claims is included as additional description in the description, and the claims are embodiment(s) of the present invention.

[00105] Although certain embodiments have been suggested herein, it should be understood that the systems and methods described may be implemented in many other specific forms without departing from the spirit and scope of the present invention. These examples are to be considered illustrative and not limiting, and the invention is not limited to the details given herein. For example, various elements or components may be combined or integrated into another system, or some functionality may be omitted or not implemented.

[00106] Also, the methods, systems, subsystems, and methods described and illustrated in various embodiments as separate or distinct may be combined or incorporated into other systems, modules, methods, or methods without departing from the scope of the present invention. Other elements shown or described as being directly connected or coupled to every other element may be indirectly connected or coupled through some interface, device or intermediate component, either electrically, mechanically or otherwise. Other examples of changes, substitutions or variations can be readily determined by one skilled in the art and can be made without departing from the spirit and scope described herein.

Claims (13)

1. A device for isolating a wellbore, comprising a mandrel having a cylindrical main part with an outer surface and a central flow channel, a system of sealing elements located around the mandrel and configured to expand radially from the first rolling diameter to being introduced into sealing engagement with the inner surface of the wellbore , a metal support ring disposed on a mandrel, contacting one side of a sealing element system with an initial height H and configured to expand radially, and configured to deform axially to abut the inner surface of the wellbore, the metal support ring having a concave cross-section around a mandrel supported up the wellbore and supported down the wellbore, wherein the sealing element system is configured to radially expand into the sealing engagement due to applied compressive force, wherein the metal support ring is configured to radially expand and axially deform to contact the inner surface wellbore with radial contact stress providing sealing contact pressure. 2. A device for isolating a wellbore according to claim 1, characterized in that the device for isolating a wellbore is a device selected from the group consisting of a plug for hydraulic fracturing (fracturing), a packer plug, a packer for a cased wellbore, a packer for open hole and cement plug. 3. A device for isolating a wellbore according to any one of claims. 1, 2, characterized in that the cross-section of the metal support ring has a corrugated shape, an inverted arc shape, a bell shape or an inverted U-shape, and the support up the wellbore and the support down the wellbore are curved. 4. A device for isolating a wellbore according to any one of claims. 1, 2, characterized in that the cross-section of the metal support ring has an inverted V-shape, and the support up the wellbore and the support down the wellbore have the shape of a truncated cone. 5. A device for isolating a wellbore according to any one of claims. 1-4, characterized in that one or more metal support rings have an element for limiting axial deflection on the inner surface of one or more uphole supports and downhole supports. 6. A device for isolating a wellbore according to any one of claims. 1-5, characterized in that the support up the wellbore and the support down the wellbore of one or more metal support rings have different lengths. 7. A device for isolating a wellbore according to any one of claims. 1-6, characterized in that one or more metal support rings have an abrasive coating of sand, gravel or hard alloy on part or all of the outer surface. 8. A device for isolating a wellbore according to any one of claims. 1-7, containing a second metal support ring located on a mandrel on the opposite side of the sealing element system. 9. A device for isolating a wellbore according to any one of claims. 1-8, characterized in that the device for isolating the wellbore is designed to be removable by drilling, milling, chemical application, corrosion or dissolution. 10. A method for isolating a wellbore, comprising inserting a device for isolating a wellbore into a wellbore, wherein the device for isolating the wellbore comprises a mandrel, a system of sealing elements located around the mandrel, one or more metal support rings located on the mandrel on one or more sides systems of sealing elements and made with the possibility of radial expansion and made with the possibility of axial deformation for introduction into sealing engagement with the wellbore, providing an axial compression force on the metal support ring, radial deformation of the system of sealing elements for introduction into sealing engagement with the wellbore, radial and axial deformation of the metal support ring to be brought into sealing engagement with the wellbore. 11. The method according to claim 10, characterized in that the expandable support ring supports the sealing element in sealing engagement with the wellbore on one side. 12. The method according to claim 10, characterized in that the expandable support ring supports the sealing element in sealing engagement with the wellbore on both sides. 13. A method for isolating a wellbore, including introducing a device for isolating a wellbore into a wellbore, expanding a system of sealing elements for insertion into sealing engagement with the inner surface of the wellbore, isolating the environment of the wellbore down the wellbore from the expanded system of sealing elements from the environment of the wellbore up the wellbore from the sealing element system, axially supporting one side of the sealing element system with an expandable ring that expands from the outer surface of the mandrel to contact the inner surface of the wellbore with sealing contact pressure, separating the axially supported sealing element system from the annular wellbore environment up the wellbore or the annular wellbore environment down the wellbore.