Patent Publication Number: US-11047186-B2

Title: Actuating a downhole tool with a degradable actuation ring

Description:
CROSS REFERENCE TO RELATED APPLICATION(S) 
     The present application is a U.S. National Stage patent application of International Patent Application No. PCT/US2017/017128, filed on Feb. 9, 2017, the disclosure of which is hereby incorporated by reference in its entirety. 
     TECHNICAL FIELD 
     The present disclosure generally relates to systems and methods for using degradable tools in a wellbore, and, more specifically, degradable components that can be used to actuate downhole tools, and thereafter be dissolved or otherwise degraded to remove possible obstructions to subsequent wellbore operations. 
     BACKGROUND 
     During some wellbore operations, (e.g. fracturing, treating, producing, injecting, washing, etc.), shifting tools can be used to selectively actuate a downhole tool, such as a sliding sleeve valve, a packer, etc. The shifting tool can engage a profile of the downhole tool to displace an actuator to actuate, activate, set, or otherwise reconfigure the downhole tool to perform a different function (e.g. a valve changed from open to closed, a packer changed from unset to set, etc.). Alternatively, or in addition to, the shifting tool can engage the profile to ensure proper location within the downhole tool allowing telemetry communication between the shifting tool and the downhole tool to command the downhole tool to perform a reconfiguration. In these examples, the shifting tool engagement means must be able to engage the profile of the downhole tool, in order to manipulate downhole tool components and/or enable telemetry communication with the downhole tool. Therefore, shifting tools used further downhole in the wellbore, may not be compatible with profiles of components in downhole tools closer to the surface. 
     One example of this can be seen when a wash pipe is installed in a wellbore along with a tubing string. An isolation valve in the tubing string can be positioned above a lateral connection in a wellbore, so that, when the washing operation is complete, a shifting tool connected at a lower end of the wash pipe can be used to actuate the isolation valve to a closed position when the wash pipe is removed to the surface through the tubing string. However, the engagement profile of the shifting tool may be too small to engage the profile of the isolation valve, due to decreased diameters farther downhole in the wellbore. Some well systems use a parking sub that is installed with the tubing string and wash pipe. When the wash pipe is removed from the tubing string, the shifting tool engages the parking sub and carries the parking sub with it to increase a radial engagement distance of the shifting tool, thereby allowing it (along with the parking sub) to successfully engage the isolation valve profile and actuate the valve to the closed position. It should be understood that the shifting tool can be seen as one example of an actuation tool. 
     Another example of an actuation tool for reconfiguring downhole tools by engaging profiles in a downhole tool can be dropped balls. A dropped ball can be carried by a fluid through the tubing string to a downhole tool where the ball can engage a profile (such as “ball seat”) and provide increased restriction to flow of the fluid though the tubing string at the point of the engagement. By isolating the tubing string into separate intervals, operations can be performed on one interval while not significantly affecting the tubing string and downhole tools in the other interval. Additionally, multiple engagement profiles can be provided, allowing the tubing string to be divided into multiple wellbore intervals. Generally, engagement profiles that are farther downhole have smaller inner diameters than those profiles that are farther uphole. This allows a smaller ball to pass through all the upper engagement profiles to land in its intended engagement profile. This system allows multiple intervals to be individually operated on, but the increasingly restrictive profiles that are further downhole may provide an undesirable restriction to fluid flow or downhole tool access. It should be understood that the ball can be any object that can be carried by fluid in the tubing string to actuate a downhole tool, such as a ball, dart, plug, etc. 
     Therefore, it will be readily appreciated that improvements in the arts of actuating downhole tools via engagement profiles are continually needed. 
    
    
     
       BRIEF DESCRIPTION OF THE DRAWINGS 
       Various embodiments of the present disclosure will be understood more fully from the detailed description given below and from the accompanying drawings of various embodiments of the disclosure. In the drawings, like reference numbers may indicate identical or functionally similar elements. Embodiments are described in detail hereinafter with reference to the accompanying figures, in which: 
         FIG. 1  is a representative partial cross-sectional view of a marine-based well system with multiple wellbore intervals and completion tubing in the wellbore according to an embodiment; 
         FIG. 2  is a representative partial cross-sectional view of a downhole tool (such as a valve or packer) in a tubing string that can benefit from the principles of this disclosure; 
         FIG. 3  is a representative partial cross-sectional view of the downhole tool with an engagement profile in the tubing string, according to one or more example embodiments; 
         FIG. 4  is a representative partial cross-sectional view of the downhole tool with a degradable engagement profile that can be engaged by an actuation tool, according to one or more example embodiments; 
         FIG. 5  is a representative partial cross-sectional view of the downhole tool with a degradable engagement profile that can be engaged by another type of actuation tool, according to one or more example embodiments; 
         FIG. 6  is a representative partial cross-sectional view of the valve in the tubing string after actuation and after removal of the engagement profile, according to one or more example embodiments; 
     
    
    
     DETAILED DESCRIPTION OF THE DISCLOSURE 
     The disclosure may repeat reference numerals and/or letters in the various examples or Figures. This repetition is for the purpose of simplicity and clarity and does not in itself dictate a relationship between the various embodiments and/or configurations discussed. Further, spatially relative terms, such as beneath, below, lower, above, upper, uphole, downhole, upstream, downstream, and the like, may be used herein for ease of description to describe one element or feature&#39;s relationship to another element(s) or feature(s) as illustrated, the upward direction being toward the top of the corresponding figure and the downward direction being toward the bottom of the corresponding figure, the uphole direction being toward the surface of the wellbore, the downhole direction being toward the toe of the wellbore. Unless otherwise stated, the spatially relative terms are intended to encompass different orientations of the apparatus in use or operation in addition to the orientation depicted in the Figures. For example, if an apparatus in the Figures is turned over, elements described as being “below” or “beneath” other elements or features would then be oriented “above” the other elements or features. Thus, the exemplary term “below” can encompass both an orientation of above and below. The apparatus may be otherwise oriented (rotated 90 degrees or at other orientations) and the spatially relative descriptors used herein may likewise be interpreted accordingly. 
     Moreover even though a Figure may depict a horizontal wellbore or a vertical wellbore, unless indicated otherwise, it should be understood by those skilled in the art that the apparatus according to the present disclosure is equally well suited for use in wellbores having other orientations including vertical wellbores, slanted wellbores, multilateral wellbores or the like. Likewise, unless otherwise noted, even though a Figure may depict an offshore operation, it should be understood by those skilled in the art that the method and/or system according to the present disclosure is equally well suited for use in onshore operations and vice-versa. Further, unless otherwise noted, even though a Figure may depict a cased hole, it should be understood by those skilled in the art that the method and/or system according to the present disclosure is equally well suited for use in open hole operations. 
     As used herein, the words “comprise,” “have,” “include,” and all grammatical variations thereof are each intended to have an open, non-limiting meaning that does not exclude additional elements or steps. While compositions and methods are described in terms of “comprising,” “containing,” or “including” various components or steps, the compositions and methods also can “consist essentially of” or “consist of” the various components and steps. It should also be understood that, as used herein, “first,” “second,” and “third,” are assigned arbitrarily and are merely intended to differentiate between two or more objects, etc., as the case may be, and does not indicate any sequence. Furthermore, it is to be understood that the mere use of the word “first” does not require that there be any “second,” and the mere use of the word “second” does not require that there be any “first” or “third,” etc. 
     The terms in the claims have their plain, ordinary meaning unless otherwise explicitly and clearly defined by the patentee. Moreover, the indefinite articles “a” or “an,” as used in the claims, are defined herein to mean one or more than one of the element that it introduces. If there is any conflict in the usages of a word or term in this specification and one or more patent(s) or other documents that may be incorporated herein by reference, the definitions that are consistent with this specification should be adopted. 
     Generally, this disclosure provides a system and method for engaging profile(s) in a downhole tool to reconfigure the tool, and after reconfiguration of the tool, removing the engagement profile by degradation, thereby decreasing resistance to flow of fluid or a restriction to access of other wellbore tools through the downhole tool. 
     Turning to  FIG. 1 , this figure shows an elevation view in partial cross-section of a wellbore production system  10  which can be utilized to produce hydrocarbons from wellbore  12 . Wellbore  12  can extend through various earth strata in an earth formation  14  located below the earth&#39;s surface  16 . Wellbore production system  10  can include a rig (or derrick)  18 . The rig  18  can include a hoisting apparatus, a travel block, and a swivel (not shown) for raising and lowering casing, or other types of conveyance vehicles  30  such as drill pipe, coiled tubing, production tubing, and other types of pipe or tubing strings, such as wireline, slickline, and the like. In  FIG. 1 , the conveyance vehicle  30  is a substantially tubular, axially extending work string or production tubing, formed of a plurality of pipe joints coupled together end-to-end supporting a completion assembly as described below. However, it should be understood that the conveyance vehicle  30  can be any of the other suitable conveyance vehicles, such as those mentioned above. The conveyance vehicle  30  can include one or more packers  20  to prevent (or at least restrict) flow of production fluid through an annulus  32 . However, packers  20  are not required. 
     The wellbore production system  10  in  FIG. 1  is shown as an offshore system. A rig  18  may be mounted on an oil or gas platform, such as the offshore platform  44  as illustrated, and/or semi-submersibles, drill ships, and the like (not shown). One or more subsea conduits or risers  46  can extend from platform  44  to a subsea wellhead  40 . The tubing string  30  can extend down from rig  18 , through subsea conduits  46 , through the wellhead  40 , and into wellbore  12 . However, the wellbore production system  10  can be an onshore wellbore system, in which case the conduits  46  may not be necessary. 
     Wellbore  12  may be formed of single or multiple bores, extending into the formation  14 , and disposed in any orientation (e.g. vertical, inclined, horizontal, combinations of these, etc.). The wellbore production system  10  can also include multiple wellbores  12  with each wellbore  12  having single or multiple bores. The rig  18  may be spaced apart from a wellhead  40 , as shown in  FIG. 1 , or proximate the wellhead  40 , as can be the case for an onshore arrangement. One or more pressure control devices (such as a valve  42 ), blowout preventers (BOPs), and other equipment associated with drilling or producing a wellbore can also be provided in the wellbore production system  10 . The valve  42  can be a rotating control device proximate the rig  18 . Alternatively, or in addition to, the valve  42  can be integrated in the tubing string  30  to control fluid flow into the tubing string  30  from an annulus  32 , and/or controlling fluid flow through the tubing string  30  from upstream well screen assemblies  24 . 
     A computer  52  can be coupled to a cable  50  installed along the tubing string  30  in the wellbore  12 . The computer  52  can be used to collect sensor data from sensors in the wellbore, and/or control well system operations. The cable  50  is shown in  FIG. 1  extending through the annulus  32  along the tubing string  30 , and past wellbore intervals  60 ,  62 ,  64  and can provide command and control to various downhole tools. One or more well screen assemblies  24  can be positioned at each location of the wellbore intervals  60 ,  62 ,  64 . 
     Prior to the installation of the production string  30  shown in  FIG. 1 , various completion operations can occur, such as washing, fracturing, treating, gravel packing, etc. These operations can include a tubing string  30  that may include one or more downhole tools (such as a valve  42 , a packer  20 , etc.) that can require engagement of a profile to reconfigure the tools  42 ,  20 . Each tool  42 ,  20  can include a body  43  that can support interconnection in the tubing string  30 . These profiles can be an integral part of a component of tools  42 ,  20 , or can be separate components that interact with other components of the tools  42 ,  20 . These engagement profiles  70  can be removed by degradation after the desired operations are complete to provide a more open flow passage through the tubing string  30  for less fluid flow restrictions and/or less downhole tool access restrictions. These profiles  70  can be removed without additional tripping in and out of tubing strings to remove the through-bore restrictions in the tubing string  30 . Also, the degraded engagement profiles may not leave debris in the wellbore that can interfere with follow-on operations. Therefore, in the case with dropped balls that land on progressively smaller engagement profiles, these profiles can be removed by degradation (e.g. dissolution, corrosion, erosion, reaction, etc.) to remove interference of the engagement profiles to subsequent wellbore operations. Additionally, many other configurations of the wellbore production system  10  can require engagement profiles that may be desirably removed after completing all tasks. 
       FIG. 2  shows an example of a portion of a downhole tool  42 ,  20  with a closure member  48  that can be axially and/or rotationally displaced, as indicated by arrows  80 ,  82 , to position the closure member in either an opened, closed or partially opened position. In this example, a profile  72  of the closure member  48  can be engaged by a actuation tool  26  to slide the closure member  48  axially up or down and/or rotationally in the downhole tool  42 ,  20 . The actuation tool  26  (see  FIGS. 4 and 5 ) can be positioned proximate the profile  72  and engage the profile with an engagement means of the actuation tool  26 . After engagement, movement of the actuation tool  26  or at least movement of the engagement means can axially and/or rotationally displace the closure member  48 . The inner diameter D 1  of the closure member  48  can be slightly larger than the inner diameter D 2  of the profile  72 , which can allow the engagement means  28  of the actuation tool  26  to locate on the profile without also engaging an inner surface  68  of the closure member  48 . 
     Of course, the engagement means can engage the surface  68  as long as that engagement does not prevent engagement with the profile  72 . However, after displacing the closure member  48  by the actuation tool  26 , the profile  72  remains the smallest diameter restriction through the closure member  48 . This tends to drive the design of this profile to protrude as little as possible from the inner surface  68 , so that the restriction to flow (or tool access) through the downhole tool  42 ,  20  is minimized. As stated above, if an actuation tool  26  is small enough to access tools farther downhole from the valve  42 , then the engagement means  28  of the actuation tool  26  may not properly engage the profile  72 , thereby not properly displacing the closure member  48 . 
     The downhole tool  42 ,  20  shown in  FIG. 3  contains an actuation ring  76  with a profile  70  that can be used by a actuation tool  26  to displace the closure member  48 . The actuation ring  76  can be made from a material that is degradable, such that the actuation ring  76  can be degraded when it is desired to remove flow obstructions that may be caused by the ring  76  and/or the profile  70 . Other features of the ring  76  can be included that extend into the flow passage  38 , and these features can also be made of the degradable material and degraded when desired, such as after the actuation tool  26  displaces the closure member  48  to a desired axial and/or rotational position. 
     As used herein, the term “degradable” and all of its grammatical and functional variants (e.g., “degrade,” “degradation,” “degrading,” “dissolve,” dissolving,” “dissolution,” “corrode,” “corrodible,” “corrosion,” “erode,” “erosion,” and the like) refers to the dissolution or chemical conversion of solid materials such that reduced-mass solid end products by at least one of solubilization, hydrolytic degradation, biologically formed entities (e.g., bacteria or enzymes), chemical reactions (including electrochemical and galvanic reactions), thermal reactions, or reactions induced by radiation. In complete degradation, no solid end products result. In some instances, the degradation of the material may be sufficient for the mechanical properties of the material to be reduced to a point that the material no longer maintains its integrity and, in essence, falls apart or sloughs off to its surroundings. The conditions for degradation are generally wellbore conditions where an external stimulus may be used to initiate or affect the rate of degradation. For example, the pH of the fluid that interacts with the material may be changed by introduction of an acid or a base. The term “wellbore environment” includes both naturally occurring wellbore environments and materials or fluids introduced into the wellbore. It should also be understood that naturally occurring wellbore fluids can be used to degrade the material without requiring introduction of further materials into the wellbore. 
     In one or more embodiments, the degradable material may be degradable when acted upon by a degrading agent. The degrading agent may be provided from the surface. The degradable materials can be or include, but are not limited to, magnesium, aluminum, gallium, alloys thereof, or any mixture thereof. In some examples, the degradable material can be or include one or more magnesium alloys and/or one or more aluminum alloys. The dissolving agents can be or include, but are not limited to, one or more acids, one or more bromides, one or more chlorides, or any mixture thereof. For example, the degrading agent can be or include calcium bromide, hydrochloric acid, brine (e.g., sodium chloride and/or other salts in water), or any mixture thereof. Specifically, in one example, completion fluid that contains calcium bromide may be used in an operation, and the degradable material may include a magnesium alloy, which is readily reactive. 
     The inner diameter D 3  of the profile  70  can be any desired distance that supports actuation of the downhole tool  42 ,  20 . The profile  70  can be significantly restrictive to allow complete isolation between separate wellbore intervals when a ball is dropped to seat with the profile  70 . After the operations are complete (or at any desired time during the operation), then the ring  76  (or at least the profile  70 ) can be degraded to remove obstructions in the flow passage  38  of the downhole tool  42 ,  20  and tubing string  30 . As seen in  FIG. 3 , the profile  70  is slightly larger (i.e. smaller inner diameter) than the profile  72 . This reduced diameter profile  70  can be used to properly engage the actuation tool  26  to actuate the downhole tool  42 ,  20 . When it is desired to degrade the actuator ring  76 , a degrading agent can degrade the ring  76  and/or profile  70 , such that the smallest diameter in the downhole tool  42 ,  20  can be the profile  72 , with the profile  70  removed. It should be understood that, since the profile  70  can be used to actuate the downhole tool  42 ,  20 , then the profile  72  can be removed from the closure member  48  during manufacture, thereby providing an almost full-bore access through the tool  42 ,  20  when the profile  70  is degraded. A full-bore access can allow larger downhole tools and/or more fluid to pass through the tool  42 ,  20 . 
     The actuation ring  76  can be installed in the downhole tool  42 ,  20  in various ways to support actuation of the tool. For example, the ring  76  can be free floating between a shoulder  58  and an end  74  of the closure member  48 , as seen in  FIG. 3 . The ring  76  can be held captive between the shoulder  58  and the end  74 , without being securely attached to the closure member  48 , thus free floating. Alternatively, the actuator ring  76  can be securely attached to the end  74  of the closure member  48  by threads, adhesive, collets, welding, and any other suitable attachment means, such that any axial and/or rotational movement of the ring  76  will impart an axial and/or rotational movement to the closure member  48 . 
       FIG. 4  shows the downhole tool (e.g. valve  42 , packer  20 , etc.) that includes a degradable actuation ring  76  with a profile  70 , and an actuation tool  26  with an engagement means  28 . The actuation tool  26  can be positioned within the downhole tool  42 ,  20  to engage the profile  70  via the engagement means  28  and then displace the actuation ring  76 , thereby displacing the closure member  48  in axial and/or rotational directions (see arrows  80 ,  82 ). 
       FIG. 5  shows the downhole tool (e.g. valve  42 , packer  20 , etc.) that includes a degradable actuation ring  76  with a profile  70 , and another kind of actuation tool  26  with an engagement means  28 . The actuation tool  26  in  FIG. 5  can be seen as a ball, a dart, or a plug that can be carried through the tubing string  30  to land in the profile  70 , thereby engaging the profile  70  with the engagement means  28 , which in this example can merely be the outer surface of the actuation tool  26 . The engagement of the actuation tool  26  with the profile  70  can be used to displace the actuation ring  76  and thereby displace the closure member  48  into a new configuration. 
     Referring to  FIG. 6 , the ring  76  and thus the closure member  48  have been moved axially away from the shoulder  58  with the downhole tool  42 ,  20  in a changed configuration from the configuration shown in  FIG. 3 . The changed configuration can be opened, closed, or partially open. It is also illustrated in  FIG. 4  that the actuation ring  76  has been degraded to the point of being removed from the downhole tool  42 ,  20 , thereby reducing flow restriction or tool access restriction to the profile  72 , instead of the more restrictive profile  70  of the ring  76 . 
     Thus, a downhole tool  42 ,  20  with a degradable engagement profile  70  is provided. The tool  42 ,  20  can include a body  43 , a closure member  48  within the body  43 , and an actuation ring  76  that includes the profile  70 , where displacement of the actuation ring  76  via the profile  70  displaces the closure member  48  and a portion of the actuator ring  76  is degraded downhole. Portions of the actuation ring  76  (or the whole actuation ring  76 ) can be made from a degradable material that can be degraded downhole. 
     For any of the foregoing embodiments, the downhole tool  42 ,  20  may include any one of the following elements, alone or in combination with each other: 
     The downhole tool  42 ,  20  can be a packer  20 , and displacement of the closure member  48  can cause the packer  20  to be set. The displacement can enable pressure communication between a flow passage  38  (or interior) of the tubing string  30  to a chamber in the packer  20 , thereby allowing pressure in the tubing string  30  to set the packer  20 . 
     The downhole tool  42 ,  20  can also be a valve  42 , where the displacement of the closure member  48  to a new position actuates the valve  42  to one of a closed, an open, or a partially open position. The valve  42  can maintain the position of the closure member  48  as the actuation ring  76  is being degraded downhole. 
     The profile  70  of the actuation ring  76  can be configured to engage an actuation tool  26 , where the actuation tool  26  includes an engagement means  28  (such as extendable members and/or a surface of the actuation tool  26 ) that can engage the actuation ring  76  and displace the actuation ring  76  by moving the engagement means  28  relative to the downhole tool  42 ,  20  or moving the actuation tool  26  relative to the downhole tool  42 ,  20 , where displacement of the ring  76  occurs in response to the engagement of the profile  70  with the actuation tool  26 . The displacement of the ring  76  can also occur in response to displacement of at least a portion of the actuation tool  26 . The actuation tool  26  can be one of a shifting tool, a setting tool, a ball, a dart, and a plug. 
     A minimum inner diameter D 3  of the downhole tool  42 ,  20  can be increased due to the degradation of the profile  70 . Said another way, a clearance (diameter D 3 ) through the downhole tool  42 ,  20  can be increased due to the degradation. 
     The body  43  of the downhole tool  42 ,  20  can interconnect the downhole tool in a tubing string  30 . At least the profile  70  of the actuation ring  76  can be degraded downhole. It should be understood that not all of the profile has to be degraded downhole. Only a portion of the profile can be degraded. However, it is preferred that at least enough of the profile  70  is degraded such that the profile  70  does not determine the minimum inner diameter (D 1 , D 2 , D 3 , D 4 ) of the downhole tool  42 ,  20 . 
     The actuation ring  76  can be made from a degradable material selected from the group consisting of magnesium, aluminum, gallium, alloys thereof, and any mixture thereof. Other degradable materials, such as PLA (Poly Lactic Acid or polylactide) and/or PLGA (Poly Lactic co-Glycolic Acid) can also be used to manufacture the actuation ring  76 . 
     The actuation ring  76  can be free floating in the body  43  between a shoulder  58  of the body  43  and an end  74  of the closure member  48  or the actuation ring  76  can be securely attached (or coupled) to the end  74  of the closure member  48 . Attaching or coupling the closure member  48  to the actuation ring  76  can use various attachment means, such as threads, collets, snapfit connection, pressfit connection, bonding material, welding, etc. 
     A method for actuating downhole tools  42 ,  20  via a degradable actuation ring  76  is provided, which can include operations of installing the downhole tool  42 ,  20  in a wellbore  12 , where the downhole tool  42 ,  20  can include a body  43 , a closure member  48 , and the actuation ring  76  with a profile  70 . The operations can also include engaging the profile  70  with an actuation tool  26 , actuating the downhole tool  42 ,  20  by displacing the closure member  48  via the engaged profile  70 , degrading the actuation ring  76 , and increasing a diameter D 3  of a flow passage  38  through the downhole tool  42 ,  20  due to the degrading. The diameter (one of D 1 , D 2 , D 3 , D 4 ) of the flow passage  38  can also be seen as a minimum inner diameter D 2  of the downhole tool  42 ,  20 , with this minimum inner diameter D 3  being increased in response to the degrading. The degrading can also cause a clearance (or minimum inner diameter D 3  of the downhole tool  42 ,  20 ) to increase. 
     The downhole tool  42 ,  20  can be a packer  20  and/or a valve  42  (the valve  42  could possibly be incorporated into the packer  20 ). The actuating can displace the closure member  48  to one of an open, a closed, or a partially open position. The downhole tool  42 ,  20  can maintain the displacement of the closure member  48  after the degrading. The actuation tool  26  can be selected from a group consisting of a shifting tool, a setting tool, a ball, a dart, and a plug. The operations can also include degrading the actuation ring  76  by contacting the actuation ring  76  with a degrading agent. The degrading agent can be in the wellbore  12  and/or delivered to the downhole tool  42 ,  20  in the wellbore  12 . The actuation ring  76  can be made from a degradable material selected from the group consisting of magnesium, aluminum, gallium, alloys thereof, and any mixture thereof. 
     A system for actuating a downhole tool  42 ,  20  in a wellbore  12 , where the system can include the downhole tool  42 ,  20  connected in a tubing string  30  in the wellbore  12 , with the tool  42 ,  20  including, a closure member  48 , and an actuation ring  76  with a profile  70 . The actuation tool  26  can be configured to engage the profile  70  and displace the actuation ring  76  via the engagement with a configuration of the downhole tool  42 ,  20  being changed in response to the displacement. Additionally, a degrading agent can degrade the actuation ring  76  (or at least a portion of it) upon contact with the actuation ring. 
     For any of the foregoing embodiments, the method may include any one of the following elements, alone or in combination with each other: 
     The downhole tool  42 ,  20  in the system can be one of a packer  20  and a valve  42 , and the displacement of the actuation ring  76  changes a position of the closure member  48  between one of an open, a closed, and a partially open position. The closure member  48  in the packer  20  can provide pressure access to a chamber that can be pressurized through the tubing string  30  to set the packer  20 . The closure member  48  in the valve  42  can provide variable adjustment to fluid flow through the valve. 
     A clearance through the downhole tool  42 ,  20  can be increased due to the degradation. The clearance can also be represented by a minimum inner diameter D 3 , D 2  of the downhole tool  42 ,  20 , therefore, increased clearance can also be represented by an increased minimum inner diameter D 3 , D 2  of the downhole tool. The actuation tool  26  can be selected from a group consisting of a shifting tool, a setting tool, a ball, a dart, and a plug. 
     Although various embodiments have been shown and described, the disclosure is not limited to such embodiments and will be understood to include all modifications and variations as would be apparent to one skilled in the art. Therefore, it should be understood that the disclosure is not intended to be limited to the particular forms disclosed; rather, the intention is to cover all modifications, equivalents, and alternatives falling within the spirit and scope of the disclosure as defined by the appended claims.