EXPANDABLE LINER HANGER HAVING A PHASE CHANGE MATERIAL SUPPORT

Description

BACKGROUND

Wellbores are often drilled through one or more subterranean formations for the purpose of collecting downhole hydrocarbons. In some instances, a portion of the wellbore may be cased, for example by placing, and typically cementing, a casing into the wellbore. A tubing string may then be run in and out of the casing. Alternatively, the tubing string may be run in and out of any uncased portion of the wellbore as well.

In some operations, a liner may be suspended from the casing string with a liner hanger. The liner hanger anchors to the interior of the casing string and suspends the liner below the casing string. In this aspect, the liner hanger and liner do not extend to the surface, for example as the casing string does. The liner hanger also forms a seal with the casing string, thereby preventing fluid there between. Thus, the fluid flow is directed through the interior of the liner instead.

BRIEF DESCRIPTION

Reference is now made to the following descriptions taken in conjunction with the accompanying drawings, in which:

FIG. 1, illustrates a schematic of an example well system designed, manufactured and/or operated according to one or more embodiments of the disclosure;

FIG. 2 illustrates an enlarged cross-section illustration of the well system of FIG. 1;

FIGS. 3A through 3D, illustrate various different views of an embodiment of a liner hanger (e.g., as might be used for suspending a liner) designed, manufactured and/or operated according to one or more embodiments of the disclosure;

FIGS. 4A through 4D, illustrate various different views of an embodiment of a liner hanger (e.g., as might be used for suspending a liner) designed, manufactured and/or operated according to one or more alternative embodiments of the disclosure;

FIGS. 5A through 5D, illustrate various different views of an embodiment of a liner hanger (e.g., as might be used for suspending a liner) designed, manufactured and/or operated according to one or more alternative embodiments of the disclosure;

FIGS. 6A through 6D, illustrate various different views of an embodiment of a liner hanger (e.g., as might be used for suspending a liner) designed, manufactured and/or operated according to one or more alternative embodiments of the disclosure;

FIGS. 7A through 7D, illustrate various different views of an embodiment of a liner hanger (e.g., as might be used for suspending a liner) designed, manufactured and/or operated according to one or more alternative embodiments of the disclosure;

FIGS. 8A through 8D, illustrate various different views of an embodiment of a liner hanger (e.g., as might be used for suspending a liner) designed, manufactured and/or operated according to one or more alternative embodiments of the disclosure; and

FIGS. 9A through 17B illustrated a method for deploying a liner hanger within a wellbore tubular according to one or more embodiments of the disclosure.

DETAILED DESCRIPTION

In the drawings and descriptions that follow, like parts are typically marked throughout the specification and drawings with the same reference numerals, respectively. The drawn figures are not necessarily to scale. Certain features of the disclosure may be shown exaggerated in scale or in somewhat schematic form and some details of certain elements may not be shown in the interest of clarity and conciseness. The present disclosure may be implemented in embodiments of different forms.

Specific embodiments are described in detail and are shown in the drawings, with the understanding that the present disclosure is to be considered an exemplification of the principles of the disclosure, and is not intended to limit the disclosure to that illustrated and described herein. It is to be fully recognized that the different teachings of the embodiments discussed herein may be employed separately or in any suitable combination to produce desired results.

Unless otherwise specified, use of the terms “connect,” “engage,” “couple,” “attach,” or any other like term describing an interaction between elements is not meant to limit the interaction to direct interaction between the elements and may also include indirect interaction between the elements described. Unless otherwise specified, use of the terms “up,” “upper,” “upward,” “uphole,” “upstream,” or other like terms shall be construed as generally away from the bottom, terminal end of a well; likewise, use of the terms “down,” “lower,” “downward,” “downhole,” “downstream” or other like terms shall be construed as generally toward the bottom, terminal end of a well, regardless of the wellbore orientation. Use of any one or more of the foregoing terms shall not be construed as denoting positions along a perfectly vertical axis. Unless otherwise specified, use of the term “subterranean formation” shall be construed as encompassing both areas below exposed earth and areas below earth covered by water such as ocean or fresh water.

In various examples, only certain values and/or ranges are explicitly disclosed herein. However, ranges from any lower limit may be combined with any upper limit to recite a range not explicitly recited. Similarly, ranges from any lower limit may be combined with any other lower limit to recite a range not explicitly recited. In the same way, ranges from any upper limit may be combined with any other upper limit to recite a range not explicitly recited. Additionally, whenever a numerical range with a lower limit and an upper limit is disclosed, any number and any included range falling within the range are specifically disclosed. In particular, every range of values (of the form, “from about a to about b,” or, equivalently, “from approximately a to b,” or, equivalently, “from approximately a-b”) disclosed herein is to be understood to set forth every number and range encompassed within the broader range of values even if not explicitly recited. Thus, every point or individual value may serve as its own lower or upper limit combined with any other point or individual value or any other lower or upper limit, to recite a range not explicitly recited. Similarly, an individual value disclosed herein may be combined with another value disclosed herein to form a range.

Traditional liner hangers (e.g., traditional expandable liner hangers) rely upon one or more sealing elements (e.g., a series of metal ribs), or the body of the liner hanger itself, to contact the wellbore tubular inside diameter (ID) (e.g., casing string ID). The contact between the liner hanger itself and the wellbore tubular ID may be used to hold the load of the liner, as well as address any pressure differential there across, all of which directly relates to the contact pressure between the two. Unfortunately, downhole pressure applied to the liner hanger attempts to displace the wellbore tubular ID radially outward (e.g., away from the liner hanger), as well as compress the liner hanger radially inward (e.g., away from the wellbore tubular ID), both of which may reduce the contact pressure between the liner hanger and the wellbore tubular ID. In certain high-pressure applications, the downhole pressure may be great enough to dislodge the liner hanger from the casing ID, or at least large enough to reduce the contact pressure to a value that provides an undesirable fluid path therebetween.

Based on the foregoing problems, the present disclosure has developed an improved liner hanger that is able to maintain a sufficient amount of contact pressure between the liner hanger and the wellbore tubular ID, even with the increased downhole pressure associated with those high-pressure applications. For example, one embodiment of the improved liner hanger includes a liner hanger body having a flow port extending through a sidewall thickness (t) thereof. In at least one embodiment, the flow port is located proximate a sealing element of the liner hanger. Accordingly, in at least one embodiment, the flow port couples an inside diameter (ID) of the liner hanger body with an outside diameter (OD) of the liner hanger body such that a phase change material in a liquid phase may move from the inside diameter (ID) of the liner hanger body to the outside diameter (OD) of the liner hanger body and into contact with the sealing element. This phase change material in liquid phase (e.g., it may originally exist in an initial solid phase) may, once in contact with the sealing element, change phases back to a subsequent solid phase, and thus address the contact pressure issues disclosed above.

The phase change material may comprise many different materials and remain within the scope of the disclosure. In at least one embodiment, the phase change material is a phase change metal. For example, in at least one embodiment, the phase change metal comprises bismuth, antimony, gallium, lead, tin, manganese, cadmium, aluminum, iron, magnesium, nickel, beryllium, barium, zinc, or any combination thereof. Nevertheless, in at least one other embodiment, the phase change metal is a bismuth alloy, antimony alloy or gallium alloy. In yet another embodiment, however, the phase change material is a phase change plastic or elastomer.

In at least one embodiment, as the phase change material goes from its initial solid state, to its liquid state, and then to its subsequent solid state, its volume increases. For example, the volume might increase by 2 percent or more, by 5 percent or more, by 10 percent or more, by 15 percent or more, by 20 percent or more, etc. However, in at least one other embodiment, as the phase change material goes from its initial solid state, to its liquid state, and then to its subsequent solid state, its volume decreases. For example, the volume might decrease by 2 percent or more, by 5 percent or more, by 10 percent or more, by 15 percent or more, by 20 percent or more, etc. In yet even another embodiment, as the phase change material goes from its initial solid state, to its liquid state, and then to its subsequent solid state, its volume stays the same. Given the foregoing, one skilled in the art would be able to determine the specific phase change material, as well as amount of initial phase change material required, to accomplish the desires herein.

Turning to FIG. 1, illustrated is a schematic of an example well system 100 designed, manufactured and/or operated according to one or more embodiments of the disclosure. The well system 100, in the illustrated embodiment, includes a wellbore 110 extending from a surface 105 and penetrating a subterranean formation 115. In the illustrated embodiment, the well system 100 includes a tubing system 120 located within the wellbore 110, the tubing system 120 designed, manufactured and/or operated according to one or more aspects of the disclosure. The tubing system 120, in one aspect, includes surface casing 130 and surface cement sheath 135 descending from the surface 105. In the illustrated embodiment, the tubing system 120 may additionally include multiple layers of intermediate casing 140 and intermediate cement sheaths 145 that are deployed and nested concentrically within the surface casing 130. In some examples, only one layer of intermediate casing 140 may be used, but in other embodiments two or more layers of intermediate casing 140 may be used. In some other examples, a shallow well may be drilled which may not employ a single layer of intermediate casing 140. Each of the surface casing 130 and intermediate casing 140 may also be referred to as a wellbore tubular.

In the illustrated embodiment, a liner hanger 150 is deployed within the innermost intermediate casing 140, the liner hanger 150 designed, manufactured and/or operated according to one or more embodiments of the disclosure. The liner hanger 150 may be used to suspend a liner 160 from within the previous casing (e.g., innermost intermediate casing 140). The liner 160 may be any conduit suitable for suspension within the wellbore 110. The liner 160, in one or more embodiments, is a conduit that does not run to the surface 105 (e.g., unlike the intermediate casing strings 140). The liner hanger 150 seals within the intermediate casing 140, allowing the liner 160 to functionally act as an extension of the intermediate casing 140.

Turning to FIG. 2, illustrated is an enlarged cross-section illustration of the well system 100 of FIG. 1. In the embodiment of FIG. 2, the tubing system 120 functions as a conduit for the wellbore 110 that penetrates subterranean formation 115. The tubing system 120 comprises surface casing 130 and surface cement sheath 135 that anchors the surface casing 130 in the wellbore 110. The surface casing 130 extends from the surface 105 down to a desired depth in the wellbore 110. Intermediate casing 140 is deployed concentrically within surface casing 130. Intermediate casing 140 may be held in place within the surface casing 130 with an intermediate cement sheath 145. Although only one layer of intermediate casing 140 is illustrated, it is to be understood that as many layers of intermediate casing 140 may be used as desired. Any subsequent layers of the intermediate casing 140 may be nested concentrically within one another within the illustrated intermediate casing 140.

The liner hanger 150 is deployed within the intermediate casing 140. The liner hanger 150 suspends a liner 160 from its end. The liner hanger 150 is anchored to the intermediate casing 140 with a one or more sealing elements 220 (e.g., a series of sealing elements), such as metal ribs. The sealing elements 220 form external seals with the adjacent inside diameter (ID) of the intermediate casing 140. The formed seals prevent wellbore fluid from bypassing the liner 160 and liner hanger 150. In one or more embodiments, space 230 exists between ones of the one or more sealing elements 220.

It should be clearly understood that the examples illustrated by FIGS. 1 and 2 are merely general applications of the principles of this disclosure in practice, and a wide variety of other examples are possible. Therefore, the scope of this disclosure is not limited in any manner to the details of any of the FIGS. described herein.

Turning to FIGS. 3A through 3D, illustrated are various different views of an embodiment of a liner hanger 300 (e.g., as might be used for suspending a liner) designed, manufactured and/or operated according to one or more embodiments of the disclosure. FIGS. 3A and 3B illustrate various different external views of the liner hanger 300 (e.g., rotated about a centerline of the liner hanger 300), whereas FIGS. 3C and 3D illustrate cross-sectional views of the liner hanger 300 illustrated in FIGS. 3A and 3B taken through the lines 3C-3C and 3D-3D, respectively.

The liner hanger 300, in the embodiment of FIGS. 3A through 3D, includes a liner hanger body 310. The liner hanger body 310, in one or more embodiments, comprises a metal, a polymer, or another suitable material that is capable of plastic deformation. The liner hanger body 310, in one embodiment, includes an expansion section 315 configured to move from a radially unexpanded state (e.g., as shown in FIGS. 3A through 3D) to a radially expanded state (e.g., not shown) in contact with an ID of a wellbore tubular. In the illustrated embodiment of FIGS. 3A through 3D, the expansion section 315 includes a sealing element 320 (e.g., a series of scaling elements 320 axially offset from one another and separated by space 330) positioned radially thereabout. In this embodiment, the sealing element 320 is configured to contact the ID of the wellbore tubular (e.g., casing string) when the expansion section 315 moves (e.g., is plastically deformed) to the radially expanded state. The sealing element 320, in one or more embodiments, may include a metal rib positioned radially about the liner hanger body 310. Any number of sealing elements 320 may be used and remain within the scope of the disclosure. Nevertheless, in one embodiment the number of sealing elements 320 ranges from 2 to 100, if not 3 to 20, if not 4 to 10, if not 5 to 8 (e.g., as shown).

In the illustrated embodiment of FIGS. 3A through 3D, a flow port 340 extend through a sidewall thickness (t) of the liner hanger body 310, for example coupling an ID and an OD of the liner hanger body 310. In at least one embodiment, the flow port 340 is located proximate (e.g., within 6 meters, if not within 4 meters, if not within 2 meters, if not within 1 meter, if not within. 5 meter, if not within 0.1 meter) the sealing element 320. In at least one embodiment, the flow port 340 is located uphole of at least one sealing element 320. In at least one other embodiment, the flow port 340 is located uphole of at least two sealing elements 320. In at least yet one other embodiment, the flow port 340 is located uphole of at least three sealing elements 320, if not uphole of all of the sealing elements 320. In yet another embodiment, the flow port 340 is located between one or more adjacent pairs of sealing elements 320, and thus in the space 330. In the embodiment of FIGS. 3A through 3D, however, a single flow port 340 is located uphole of all of the sealing elements 320, which in this embodiment would allow gravity to act on the phase change material in the liquid phase to fill the space(s) 330 between the series of sealing elements 320. As will be understood in greater detail below, the number and location of the flow ports 340 may vary greatly and remain within the scope of the disclosure.

Further to the embodiment of FIGS. 3A through 3D, one or more of the sealing elements 320 may include a flow channel 325 extending axially there across. In the illustrated embodiment of FIGS. 3A through 3D, multiple of the sealing elements 320 include the flow channels 325. In fact, in the embodiment of FIGS. 3A through 3D, all but the downhole most sealing element 320 include the flow channel 325. In this embodiment, the location of the single flow port 340, as well as the flow channels 325, would allow the allow gravity to act on the phase change material in the liquid phase to fill the space(s) 330 between the series of scaling elements 320. Furthermore, the downhole most sealing element 320 (e.g., which does not include the flow channel 325) would prevent the phase change material in the liquid phase from escaping too far downhole, and would thus confine the phase change material in the liquid phase to at least partially within the space 330 between the sealing elements 320.

In the embodiment of FIGS. 3A through 3D, a deployment body 380 is coupled to the liner hanger body 310. In the illustrated embodiment, the deployment body 380 includes a deployment profile 390. The deployment profile 390, in one or more embodiments, may be configured to engage with a running tool profile (not shown) of a running tool (not shown), as will be further discussed below. As shown in the embodiment of FIGS. 3A through 3D, the deployment body 380 couples (e.g., directly couples) to the liner hanger body 380. For example, in at least one embodiment the deployment body 380 directly couples to a downhole end of the liner hanger body 310 using threads (e.g., acme threads in one embodiment). In yet another embodiment, however, another tool feature (e.g., a support body or other related tool feature) may interpose the liner hanger body 310 and the deployment body 380.

In the illustrated embodiment, the deployment body 380 is positioned downhole of the liner hanger body 310. Nevertheless, other embodiments may exist wherein the deployment body 380 and liner hanger body 310 of the liner hanger 300 are placed in different configurations. Also, while the embodiment of FIGS. 3A through 3D illustrate that the liner hanger body 310 and the deployment body 380 are two separate features, other embodiments may exist wherein they are a single feature.

Turning to FIGS. 4A through 4D, illustrated are various different views of an embodiment of a liner hanger 400 (e.g., as might be used for suspending a liner) designed, manufactured and/or operated according to one or more alternative embodiments of the disclosure. FIGS. 4A and 4B illustrate various different external views of the liner hanger 400 (e.g., rotated about a centerline of the liner hanger 400), whereas FIGS. 4C and 4D illustrate cross-sectional views of the liner hanger 400 illustrated in FIGS. 4A and 4B taken through the lines 4C-4C and 4D-4D, respectively. The liner hanger 400 of FIGS. 4A through 4D is similar in many respects to the liner hanger 300 of FIGS. 3A through 3D. Accordingly, like reference numbers have been used to indicate similar, if not identical, features.

The liner hanger 400 differs, for the most part, from the liner hanger 300, in that the liner hanger 400 also includes flow channels 325 in its downhole most sealing element 320. In turn, however, the liner hanger 400 employs a flow prevention seal 410 positioned downhole of the downhole most sealing element 325. In this embodiment, the flow prevention seal 410 is configured to confine the phase change material in the liquid phase to at least partially within the space 330 between the sealing elements 320.

The flow prevention seal 410 may comprise a variety of different materials and remain within the scope of the disclosure. In at least one embodiment, the flow prevention seal 410 is a metal flow prevention seal. In yet another embodiment, the flow prevention seal 410 is a polymeric or elastomeric flow prevention seal. Additionally, while the embodiment of FIGS. 4A through 4D illustrate that the flow prevention seal 410 is located within the expansion section 315, other embodiments may exist wherein the flow prevention seal 410 is located outside of the expansion section 315.

Turning to FIGS. 5A through 5D, illustrated are various different views of an embodiment of a liner hanger 500 (e.g., as might be used for suspending a liner) designed, manufactured and/or operated according to one or more alternative embodiments of the disclosure. FIGS. 5A and 5B illustrate various different external views of the liner hanger 500 (e.g., rotated about a centerline of the liner hanger 500), whereas FIGS. 5C and 5D illustrate cross-sectional views of the liner hanger 500 illustrated in FIGS. 5A and 5B taken through the lines 5C-5C and 5D-5D, respectively. The liner hanger 500 of FIGS. 5A through 5D is similar in many respects to the liner hanger 300 of FIGS. 3A through 3D. Accordingly, like reference numbers have been used to indicate similar, if not identical, features.

The liner hanger 500 differs, for the most part, from the liner hanger 300, in that the liner hanger 500 does not include flow channels 325 in its uphole most sealing element 320. Moreover, in contrast to the liner hanger 300, the liner hanger 500 positions its flow port 540 between the uphole and downhole most sealing elements 320. While not required, in the embodiment of FIGS. 5A through 5D, the flow port 540 is located in the space 330 most proximate the uphole most sealing element 320. Accordingly, gravity (e.g., along with the flow channels 325) could be used to fill the remaining space(s) 330 with the phase change material in the liquid phase.

In one or more embodiments, the liner hanger 500 also includes one or more independent vent ports 550. The one or more independent vent ports 550, in one or more embodiments, are configured to provide a pathway for fluid (e.g., air or liquid) to exit the space 330 as it is being displaced by the phase change material in the liquid phase. In at least one embodiment, such as shown, the independent vent port 550 is located uphole of the uphole most flow port 540. Additionally, in at least one embodiment, the independent vent port 550 is misaligned (e.g., radially or axially misaligned) with the source of the phase change material in the liquid phase.

Turning to FIGS. 6A through 6D, illustrated are various different views of an embodiment of a liner hanger 600 (e.g., as might be used for suspending a liner) designed, manufactured and/or operated according to one or more alternative embodiments of the disclosure. FIGS. 6A and 6B illustrate various different external views of the liner hanger 600 (e.g., rotated about a centerline of the liner hanger 600), whereas FIGS. 6C and 6D illustrate cross-sectional views of the liner hanger 600 illustrated in FIGS. 6A and 6B taken through the lines 6C-6C and 6D-6D, respectively. The liner hanger 600 of FIGS. 6A through 6D is similar in many respects to the liner hanger 500 of FIGS. 5A through 5D. Accordingly, like reference numbers have been used to indicate similar, if not identical, features.

The liner hanger 600 differs, for the most part, from the liner hanger 500, in that the liner hanger 600 does not employ any flow channels. Thus, in the illustrated embodiment, the phase change material in the liquid phase would only be allowed to fill one of the spaces 330 via the single flow port 640. For example, in the illustrated embodiment the single flow port 640 would only fill the space 330 proximate the uphole most sealing element 320. In other embodiments, however, the single flow port 640 could be positioned in any of the spaces 330.

Turning to FIGS. 7A through 7D, illustrated are various different views of an embodiment of a liner hanger 700 (e.g., as might be used for suspending a liner) designed, manufactured and/or operated according to one or more alternative embodiments of the disclosure. FIGS. 7A and 7B illustrate various different external views of the liner hanger 700 (e.g., rotated about a centerline of the liner hanger 700), whereas FIGS. 7C and 7D illustrate cross-sectional views of the liner hanger 700 illustrated in FIGS. 7A and 7B taken through the lines 7C-7C and 7D-7D, respectively. The liner hanger 700 of FIGS. 7A through 7D is similar in many respects to the liner hanger 600 of FIGS. 6A through 6D. Accordingly, like reference numbers have been used to indicate similar, if not identical, features.

The liner hanger 700 differs, for the most part, from the liner hanger 600, in that the liner hanger 700 employs a single flow port 740 in multiple of the spaces 330 between the scaling elements 320. In the illustrated embodiment of FIGS. 7A through 7D, a single flow port 740 is located in each of the spaces 330 between each of the sealing elements 320. In yet other embodiments, however, the single flow ports 740 could be staggered (e.g., perfectly or imperfectly staggered), such that not all of the spaces 330 include a single flow port 740. In this embodiment, air or other fluid would remain in those spaces 330 that do not include the single flow port 740.

Turning to FIGS. 8A through 8D, illustrated are various different views of an embodiment of a liner hanger 800 (e.g., as might be used for suspending a liner) designed, manufactured and/or operated according to one or more alternative embodiments of the disclosure. FIGS. 8A and 8B illustrate various different external views of the liner hanger 800 (e.g., rotated about a centerline of the liner hanger 800), whereas FIGS. 8C and 8D illustrate cross-sectional views of the liner hanger 800 illustrated in FIGS. 8A and 8B taken through the lines 8C-8C and 8D-8D, respectively. The liner hanger 700 of FIGS. 8A through 8D is similar in many respects to the liner hanger 700 of FIGS. 7A through 7D. Accordingly, like reference numbers have been used to indicate similar, if not identical, features.

The liner hanger 800 differs, for the most part, from the liner hanger 700, in that the liner hanger 800 employs multiple flow ports 840 in one or more of the spaces 330. In fact, while not required, in the embodiment of FIGS. 8A through 8D, multiple flow ports 840 exist in all of the spaces 330. The multiple flow ports, in addition to allowing more flow area into each of the spaces 330, may also be used as a vent to allow fluid (e.g., air and/or liquid) to exit the spaces 330 as the phase change material in the liquid phase is entering the spaces 330.

Turning to FIGS. 9A through 17B, illustrated is a method for deploying a liner hanger 900 within a wellbore tubular 990 according to one or more embodiments of the disclosure. The liner hanger 900 is similar, in many respects, to the liner hanger 300 of FIGS. 3A through 3D discussed above (e.g., although, any of the liner hangers disclosed above could be used with the wellbore tubular 990 and remain within the scope of the disclosure). Accordingly, like reference numbers have been used to indicate similar, if not identical, features. The wellbore tubular 990, in one or more embodiments, is a casing string (e.g., similar to the surface casing and/or intermediate casing discussed above with regard to FIGS. 1 and 2). Nevertheless, the wellbore tubular 990 could be any other wellbore tubular that might be found in a well system.

With initial reference to FIGS. 9A and 9B, the liner hanger 900 is being positioned within the wellbore tubular 990 using a running tool 950. The running tool 950, in the illustrated embodiment, includes a running tool profile 955. For example, the running tool profile 955 is engaged with the deployment profile 390 in the deployment body 380, and thus may be used to position the liner hanger 900 at an appropriate location within the wellbore tubular 990.

The running tool 950, in the illustrated embodiment, additionally includes a heat source 960 coupled thereto. The heat source 960, in one or more embodiments, is configured to create an increase in temperature event. In at least one embodiment, the heat source 960 is an electric heat source. In yet another embodiment, the heat source 960 is a chemical heat source. It should be noted that any heat source (e.g., controllable heat source) whether currently known or developed in the future may be used with the running tool 950 and remain within the scope of the disclosure

The running tool 950, in the illustrated embodiment, additionally includes a phase change material 965 in an initial solid phase coupled thereto. As will be understood below, it is this phase change material 965 in the solid phase, which will be heated via the heat source 960, and thus change to a liquid phase, such that the phase change material 965 in the liquid phase may move from the inside diameter (ID) of the liner hanger body 310 to the outside diameter (OD) of the liner hanger body 310 and into contact with the sealing element 320 (e.g., before changing back to a subsequent solid phase). The phase change material 965 may comprise any of the phase change materials disclosed above, as well as any other suitable material.

The phase change material 965 is illustrated as being positioned radially inside of the liner hanger body 310 (e.g., between the heat source 960 and the deployment body 380, such as radially between the heat source 960 and the liner hanger body 310 after the running tool 950 has moved uphole). Nevertheless, the phase change material 965 may be positioned at any location, so long as it may be heated by the heat source 960 and have access to the flow ports 340.

In the embodiment of FIGS. 9A and 9B, the running tool 950 additionally includes an end seal member 970. The end seal member 970, which may comprise a variety of different materials, some of which may expand (e.g., later expand) into contact with the liner hanger body 310 in the radially expanded state, is configured to axially confine the phase changer material 965 in the liquid phase (e.g., and thus effectively force it into the flow ports 340 at the appropriate time, for example via gravity).

In the illustrated embodiment, an expansion cone 910 is positioned between an OD of the running tool 950 and an ID of the liner hanger body 310. Any type of expansion cone 910 may be used and remain within the scope of the disclosure. Nevertheless, in the embodiment of FIGS. 9A and 9B, the expansion cone 910 includes an expansion cone shoulder that is configured to engage with a liner hanger body shoulder of the liner hanger body 310.

Turning to FIGS. 10A and 10B, illustrated is the liner hanger 900 of FIGS. 9A and 9B after beginning to pressure down on the expansion cone 910. The pressure, in one or more embodiment, is a fluid pressure. However, in one or more other embodiments, the pressure is a mechanical pressure, among other pressures. As shown, the expansion cone 910 may engage with a shoulder of the liner hanger body 310, and thus may be used to plastically deform the expansion section 315 of the liner hanger body 310 into engagement with the ID of the wellbore tubular 990.

Turning to FIGS. 11A and 11B, illustrated is the liner hanger 900 of FIGS. 10A and 10B after employing the expansion cone 910 to plastically deform the expansion section 315 of the liner hanger body 310 into the radially expanded state, and thus into engagement (e.g., interference contact) with the ID of the wellbore tubular 990. In the illustrated embodiment, the expansion cone 910 radially expands the one or more sealing elements 320 into radial engagement with the ID of the wellbore tubular 990.

Turning to FIGS. 12A and 12B, illustrated is the liner hanger 900 of FIGS. 11A and 11B after disengaging the running tool profile 955 of the running tool 950 from the liner hanger 900. Accordingly, the running tool 950 may now be pulled at least partially uphole, as shown.

Turning to FIGS. 13A and 13B, illustrated is the liner hanger 900 of FIGS. 12A and 12B after the running tool 950 continues to be pulled uphole. As shown, the continued movement of the running tool 950 shifts the phase change material 965 in the initial solid phase proximate the flow port 340. In the illustrated embodiment, the phase change material 965 in the initial solid phase is positioned wherein a bottom 50 percent of the phase change material 965 in the initial solid phase overlaps with the flow port 340. In yet another embodiment, the phase change material 965 in the initial solid phase is positioned wherein a bottom 25 percent of the phase change material 965 in the initial solid phase overlaps with the flow port 340. In even yet another embodiment, the phase change material 965 in the initial solid phase is positioned wherein a bottom 15 percent (if not 10 percent, if not 5 percent, if not 2 percent) of the phase change material 965 in the initial solid phase overlaps with the flow port 340. Further as shown in the embodiment of FIGS. 13A and 13B, the end seal member 970 may radially expand to contact the liner hanger body 310 in the radially expanded state.

Turning to FIGS. 14A and 14B, illustrated is the liner hanger 900 of FIGS. 13A and 13B after subjecting the phase change material 965 in the initial solid phase to an event to change the phase change material 965 in the initial solid phase to a phase change material 1465 in a liquid phase. In at least one embodiment, the event is an increase in temperature event (e.g., that occurs after plastically deforming the expansion section 315 into the radially expanded state), such as could be generated using the heat source 960 (e.g., electric heat source, chemical heat source, etc.). As shown, the phase change material 1465 in the liquid phase thus moves (e.g., via gravity in one embodiment) from the inside diameter (ID) of the liner hanger body 310 to the outside diameter (OD) of the liner hanger body 310 and into contact with the sealing element 320 (e.g., in the space 330).

It should be noted that the volume of the phase change material 965 in the initial solid state may be specifically chosen to fill a desired amount of the space 330 between the sealing elements 320 (e.g., considering any know volumetric increase or decrease in the volume as the phase change material goes from its initial solid state, to its liquid state, and then to its subsequent solid state). One skilled in the art would be readily able to choose this desired amount based upon a desired amount of fill, as well as the known properties of the specific phase change material chosen. In the illustrated embodiment, the phase change material 1465 in the liquid phase substantially fills all of the space 330 between each of the sealing elements 320.

Turning to FIGS. 15A and 15B, illustrated is the liner hanger 900 of FIGS. 14A and 14B after subjecting the phase change material 1465 in the liquid phase to a second event to change the phase change material 1465 in the liquid phase to a phase change material 1565 in a subsequent solid phase. In at least one embodiment, the second event is a decrease in temperature event. The decrease in temperature event, in one or more embodiments, is a natural event that occurs a certain period of time after the heat source 960 is turned off. In yet another embodiment, the decrease in temperature event is an intentional event, such as subjecting an area surrounding the phase change material 1465 in the liquid phase to a lower temperature fluid.

What results, in one or more embodiments, is the phase change material 1565 in the subsequent solid phase remaining in contact with the sealing element. In at least one embodiment, the phase change material 1565 in the subsequent solid phase fills at least 80 percent of one of the spaces 330 (e.g., the downhole space 330). In yet another embodiment, the phase change material 1565 in the subsequent solid phase fills at least 90 percent, if not at least 95 percent or at least 98 percent, of one of the spaces 330 (e.g., the downhole space 330). In yet another embodiment, the phase change material 1565 in the subsequent solid phase fills 100 percent of one of the spaces 330 (e.g., is in contact with the wellbore tubular), and at least a portion of a second of the spaces 330. In yet another embodiment, the phase change material 1565 in the subsequent solid phase fills 100 percent of at least two of the spaces 330 (e.g., the two downhole spaces 330). In yet another embodiment, the phase change material 1565 in the subsequent solid phase fills 100 percent of at least three of the spaces 330 (e.g., the three downhole spaces 330). This is in direct contrast to other situations, where it may be desirable to leave a space between the phase change material 1565 in the subsequent solid phase and the wellbore tubular 990.

Turning to FIGS. 16A and 16B, illustrated is the liner hanger 900 of FIGS. 15A and 15B after the running tool 950 continues to be drawn uphole and entirely out of the wellbore tubular 990.

Turning to FIGS. 17A and 17B, illustrated is the liner hanger 900 of FIGS. 16A and 16B after high pressure fluid 1710 (e.g., downhole fluid) impinges upon the one or more scaling elements 320. As shown, the phase change material 1565 in the subsequent solid phase helps maintain the contact pressure of the one or more sealing elements 320 with the ID of the wellbore tubular 990, and thus prevents the high pressure fluid 1710 from traversing uphole of the one or more sealing elements 320.

Aspects Disclosed Herein Include:

• • A. A liner hanger for suspending a liner, the liner hanger including: 1) a liner hanger body, the liner hanger body having an expansion section configured to move from a radially unexpanded state to a radially expanded state; 2) a sealing element positioned radially about the liner hanger body, the sealing element configured to contact an inside diameter (ID) of a wellbore tubular when the expansion section moves to the radially expanded state; and 3) a flow port extending through a sidewall thickness (t) of the liner hanger body proximate the scaling element, the flow port coupling an inside diameter (ID) of the liner hanger body with an outside diameter (OD) of the liner hanger body such that a phase change material in a liquid phase may move from the inside diameter (ID) of the liner hanger body to the outside diameter (OD) of the liner hanger body and into contact with the sealing element.
  • B. A method, the method including: 1) positioning a liner hanger in a wellbore tubular located in a wellbore, the liner hanger including: a) a liner hanger body, the liner hanger body having an expansion section configured to move from a radially unexpanded state to a radially expanded state; b) a sealing element positioned radially about the liner hanger body, the sealing element configured to contact an inside diameter (ID) of the wellbore tubular when the expansion section moves to the radially expanded state; c) a flow port extending through a sidewall thickness (t) of the liner hanger body proximate the sealing element, the flow port coupling an inside diameter (ID) of the liner hanger body with an outside diameter (OD) of the liner hanger body; and d) a phase change material located proximate the flow port, the phase change material in an initial solid phase; 2) plastically deforming the expansion section into the radially expanded state; and 3) subjecting the phase change material in the initial solid phase to an event to change the phase change material in the initial solid phase to a liquid phase, such that the phase change material in the liquid phase moves from the inside diameter (ID) of the liner hanger body to the outside diameter (OD) of the liner hanger body and into contact with the sealing element.
  • C. A well system, the well system including: 1) a wellbore; 2) a wellbore tubular located within the wellbore; and 3) a liner hanger located with the wellbore tubular, the liner hanger including: a) a liner hanger body, the liner hanger body having an expansion section configured to move from a radially unexpanded state to a radially expanded state; b) a sealing element positioned radially about the liner hanger body, the sealing element configured to contact an inside diameter (ID) of a wellbore tubular when the expansion section moves to the radially expanded state; and c) a flow port extending through a sidewall thickness (t) of the liner hanger body proximate the sealing element, the flow port coupling an inside diameter (ID) of the liner hanger body with an outside diameter (OD) of the liner hanger body such that a phase change material in a liquid phase may move from the inside diameter (ID) of the liner hanger body to the outside diameter (OD) of the liner hanger body and into contact with the sealing element.

Aspects A, B, and C may have one or more of the following additional elements in combination: Element 1: wherein the sealing element is a first sealing element, and further including a second sealing element positioned radially about the liner hanger body, the second sealing element configured to contact the inside diameter (ID) of the wellbore tubular when the expansion section moves to the radially expanded state, the first and second sealing elements axially offset from each other by a first space. Element 2: wherein the flow port is located uphole of one of the first and second sealing elements. Element 3: wherein the flow port is located uphole of both of the first and second sealing elements. Element 4: wherein the first sealing element includes a first flow channel extending axially there across, the first flow channel configured to allow the phase change material in the liquid phase to move from the flow port past the first sealing element and into the first space to contact the second sealing element. Element 5: wherein the second sealing element includes a second flow channel extending axially there across, the first and second flow channels configured to allow the phase change material in the liquid phase to move from the flow port past the first and second sealing elements. Element 6: further including a flow prevention seal positioned downhole of the first and second scaling elements, the flow prevention seal configured to confine the phase change material in the liquid phase to at least partially within the first space between the first and second sealing elements. Element 7: further including a third sealing element positioned radially about the liner hanger body, the third sealing element configured to contact the inside diameter (ID) of the wellbore tubular when the expansion section moves to the radially expanded state, the second and third sealing elements axially offset from each other by a second space. Element 8: wherein a single flow port is located in the first space and a single flow port is located in the second space. Element 9: wherein multiple flow ports are located in the first space and multiple flow ports are located in the second space. Element 10: wherein the subjecting occurs after plastically deforming the expansion section into the radially expanded state. Element 11: further including subjecting the phase change material in the liquid phase to a second event to change the phase change material in the liquid phase to subsequent solid phase, such that the phase change material in the subsequent solid phase remains in contact with the sealing element. Element 12: wherein subjecting the phase change material in the initial solid phase to an event includes subjecting the phase change material in the initial solid phase to an increase in temperature event. Element 13: wherein subjecting the phase change material in the initial solid phase to an increase in temperature event includes subjecting the phase change material in the initial solid phase to the increase in temperature event via an electric heat source. Element 14: wherein subjecting the phase change material in the initial solid phase to an increase in temperature event includes subjecting the phase change material in the initial solid phase to the increase in temperature event via a chemical heat source. Element 15: wherein the phase change material is a phase change metal. Element 16: wherein the phase change metal comprises bismuth, antimony, gallium, lead, tin, manganese, cadmium, aluminum, iron, magnesium, nickel, beryllium, barium, zinc, or any combination thereof. Element 17: wherein the phase change metal is a bismuth alloy, antimony alloy or gallium alloy. Element 18: wherein the phase change material is a plastic or elastomer. Element 19: wherein the phase change material in the initial solid phase is located radially inside of the liner hanger body. Element 20: wherein the sealing element is a first sealing element, and further including a second sealing element positioned radially about the liner hanger body, the second sealing element configured to contact the inside diameter (ID) of the wellbore tubular when the expansion section moves to the radially expanded state, the first and second sealing elements axially offset from each other by a first space. Element 21: wherein the flow port is located uphole of one of the first and second sealing elements. Element 22: wherein the flow port is located uphole of both of the first and second sealing elements. Element 23: wherein the first sealing element includes a first flow channel extending axially there across, the first flow channel configured to allow the phase change material in the liquid phase to move from the flow port past the first sealing element and into the first space to contact the second sealing element. Element 24: wherein the second sealing element includes a second flow channel extending axially there across, the first and second flow channels configured to allow the phase change material in the liquid phase to move from the flow port past the first and second sealing elements. Element 25: further including a flow prevention seal positioned downhole of the first and second sealing elements, the flow prevention seal configured to confine the phase change material in the liquid phase to at least partially within the first space between the first and second sealing elements. Element 26: further including a third sealing element positioned radially about the liner hanger body, the third sealing element configured to contact the inside diameter (ID) of the wellbore tubular when the expansion section moves to the radially expanded state, the second and third sealing elements axially offset from each other by a second space. Element 27: wherein a single flow port is located in the first space and a single flow port is located in the second space. Element 28: wherein multiple flow ports are located in the first space and multiple flow ports are located in the second space. Element 29: further including phase change material in a subsequent solid phase located proximate the flow port. Element 30: wherein the phase change material in the subsequent solid phase is in contact with the sealing element. Element 31: wherein the phase change material in the subsequent solid phase is in contact with the wellbore tubular. Element 32: wherein the phase change material in the solid phase is a phase change metal. Element 33: wherein the phase change metal comprises bismuth, antimony, gallium, lead, tin, manganese, cadmium, aluminum, iron, magnesium, nickel, beryllium, barium, zinc, or any combination thereof. Element 34: wherein the phase change metal is a bismuth alloy, antimony alloy or gallium alloy. Element 35: wherein the phase change material in the solid phase is a plastic or elastomer. Element 36: wherein the sealing element is a first sealing element, and further including a second sealing element positioned radially about the liner hanger body, the second sealing element configured to contact the inside diameter (ID) of the wellbore tubular when the expansion section moves to the radially expanded state, the first and second sealing elements axially offset from each other by a first space. Element 37: wherein the flow port is located uphole of one of the first and second sealing elements. Element 38: wherein the flow port is located uphole of both of the first and second sealing elements. Element 39: wherein the first sealing element includes a first flow channel extending axially there across, the first flow channel configured to allow the phase change material in the liquid phase to move from the flow port past the first sealing element and into the first space to contact the second sealing element. Element 40: wherein the second sealing element includes a second flow channel extending axially there across, the first and second flow channels configured to allow the phase change material in the liquid phase to move from the flow port past the first and second scaling elements. Element 41: further including a flow prevention seal positioned downhole of the first and second sealing elements, the flow prevention seal configured to confine the phase change material in the liquid phase to at least partially within the first space between the first and second sealing elements. Element 42: further including a third sealing element positioned radially about the liner hanger body, the third sealing element configured to contact the inside diameter (ID) of the wellbore tubular when the expansion section moves to the radially expanded state, the second and third sealing elements axially offset from each other by a second space. Element 43: wherein a single flow port is located in the first space and a single flow port is located in the second space. Element 44: wherein multiple flow ports are located in the first space and multiple flow ports are located in the second space.

Those skilled in the art to which this application relates will appreciate that other and further additions, deletions, substitutions and modifications may be made to the described embodiments.