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A downhole tool, tool assembly, and method, of which the downhole tool includes an expandable sleeve defining a bore extending axially therethrough, and including a shoulder that extends inward from the bore, a first swage positioned at least partially within the bore and including a valve seat conf

A downhole tool, tool assembly, and method, of which the downhole tool includes an expandable sleeve defining a bore extending axially therethrough, and including a shoulder that extends inward from the bore, a first swage positioned at least partially within the bore and including a valve seat configured to receive an obstructing member, such that the obstructing member and the first swage substantially prevent fluid communication through the bore when the obstructing member is seated in the valve seat, a second swage positioned at least partially within the bore. The first and second swages are configured to deform the expandable sleeve radially outwards when the first and second swages are moved toward one another within the expandable sleeve, and the shoulder is configured to prevent at least one of the first and second swages from sliding therepast.

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1. A downhole tool, comprising: an expandable sleeve defining a bore extending axially therethrough, and comprising a shoulder that extends inward from the bore, the shoulder comprising a first end face extending from a first portion of the bore, and a second end face extending from a second portion

1. A downhole tool, comprising: an expandable sleeve defining a bore extending axially therethrough, and comprising a shoulder that extends inward from the bore, the shoulder comprising a first end face extending from a first portion of the bore, and a second end face extending from a second portion of the bore, wherein the first end face and the first portion of the bore define a first end-face angle where the first portion and the first end face meet, and wherein the second end face and the second portion of the bore define a second end-face angle where the second portion and the second end face meet, the first and second end-face angles each being non-zero;a first swage positioned at least partially within the bore and comprising a valve seat configured to receive an obstructing member, such that the obstructing member and the first swage substantially prevent fluid communication through the bore when the obstructing member is seated in the valve seat; anda second swage positioned at least partially within the bore,wherein the first and second swages are configured to deform the expandable sleeve radially outwards when the first and second swages are moved toward one another within the expandable sleeve, andwherein the first end face is configured to engage the first swage, or the second end face is configured to engage the second swage, or both, such that the shoulder is configured to prevent at least one of the first or second swages from sliding therepast. 2. The tool of claim 1, wherein: the first portion of the bore is tapered at a first bore angle, and the second portion of the bore is tapered at a second bore angle, such that an inner diameter of the first portion and an inner diameter of the second portion both decrease as proceeding towards the shoulder;the first swage is positioned at least partially in the first portion, and the second swage is positioned at least partially in the second portion; andthe first and second end-face angles are obtuse angles. 3. The tool of claim 1, wherein the first swage is configured to be uphole of the second swage, and wherein the shoulder is configured to engage the first swage and prevent the first swage from moving downhole through the second portion of the bore. 4. The tool of claim 1, wherein: the first swage comprises an outer surface;the expandable sleeve comprises an inner surface at least partially defining the bore, wherein the outer surface is configured to engage the inner surface when the first swage is moved with respect to the expandable sleeve; andthe tool further comprises a gripping feature on the outer surface, the inner surface, or both, wherein the gripping feature is configured to resist movement of the first swage relative to the expandable sleeve in at least one axial direction. 5. The tool of claim 4, wherein gripping feature comprises a friction-increasing material applied to the outer surface, the inner surface, or both. 6. The tool of claim 5, wherein the friction-increasing material comprises a grit. 7. The tool of claim 5, wherein the friction-increasing material comprises a thermal-spray metal. 8. The tool of claim 1, wherein the expandable sleeve comprises an outer surface, the outer surface being configured to engage a surrounding tubular when the expandable sleeve is expanded. 9. The tool of claim 8, wherein the outer surface comprises a gripping feature configured to grip the surrounding tubular when the expandable sleeve engages the surrounding tubular. 10. The tool of claim 9, wherein the gripping feature comprises a grit, teeth, wickers, buttons, a thermal-spray metal, or a combination thereof. 11. The tool of claim 1, wherein the expandable sleeve is at least partially formed from a material configured to dissolve in a wellbore. 12. The tool of claim 11, wherein the material comprises magnesium. 13. The tool of claim 1, wherein the first swage is, the second swage is, or both are, formed at least partially from a material configured to dissolve in a wellbore. 14. A tool assembly, comprising: a downhole tool comprising: an expandable sleeve defining a bore therethrough, the bore comprising a first portion and a second portion, wherein the expandable sleeve comprises a shoulder that extends inwardly from the bore, the shoulder comprising a first end face extending from the first portion of the bore, and a second end face extending from the second portion of the bore, wherein the first end face and the first portion of the bore define a first end-face angle where the first portion and the first end face meet, and wherein the second end face and the second portion of the bore define a second end-face angle where the second portion and the second end face meet, the first and second end-face angles each being non-zero;a first swage positioned at least partially within the first portion of the bore and comprising a valve seat configured to receive an obstructing member, such that the obstructing member and the first swage substantially prevent fluid communication through the bore when the obstructing member is seated in the valve seat; anda second swage positioned at least partially within the second portion of the bore; anda setting tool, comprising: an outer body configured to engage the first swage and apply a force on the first swage directed toward the shoulder; andan inner body extending through the first swage, the expandable sleeve, and the second swage, the inner body being coupled to the second swage and configure to apply a force on the second swage directed toward the shoulder,wherein the first and second swages are configured such that moving the first and second swages toward the shoulder deforms the expandable sleeve radially outwards, andwherein the first end face is configured to engage the first swage, or the second end face is configured to engage the second swage, or both, such that the shoulder is configured to prevent at least one of the first swage or the second swage from being forced therepast. 15. The tool assembly of claim 14, wherein the first swage comprises an outer surface that engages an inner surface of the expandable sleeve, and wherein the outer surface, the inner surface, or both comprise a gripping feature configured to relative movement in at least one direction therebetween. 16. The tool assembly of claim 15, wherein the gripping feature comprises a grit, a thermal spray metal, or a combination thereof. 17. The tool assembly of claim 14, wherein at least one of the expandable sleeve, the first swage, or the second swage is at least partially formed from a material configured to dissolve in a wellbore. 18. A method for plugging an oilfield tubular in a well, comprising: positioning a downhole tool in the oilfield tubular, the downhole tool comprising an expandable sleeve, a first swage positioned at least partially in the expandable sleeve, and a second swage positioned at least partially in the expandable sleeve;forcing the first and second swages toward one another within the expandable sleeve, to expand the expandable sleeve into engagement with the oilfield tubular, wherein the expandable sleeve comprises a bore against which the first and second swages slide, and a shoulder that extends inwardly from the bore, wherein the shoulder comprises a first end face extending from a first portion of the bore, and a second end face extending from a second portion of the bore, wherein the first end face and the first portion of the bore define a first end-face angle where the first portion and the first end face meet, and wherein the second end face and the second portion of the bore define a second end-face angle where the second portion and the second end face meet, the first and second end-face angles each being non-zero, the first end face being configured to engage the first swage, or the second end face being configured to engage the second swage, or both such that the shoulder is configured to prevent at least one of the first swage or the second swage from sliding therepast; anddeploying an obstructing member into the tubular, wherein the first swage comprises a valve seat that is configured to catch the obstructing member, the expandable sleeve, the first swage, and the obstructing member being configured to block the oilfield tubular when the expandable sleeve is expanded and the obstructing member is seated in the valve seat. 19. The method of claim 18, further comprising causing the expandable sleeve, the first swage, the obstructing member, or a combination thereof to dissolve. 20. The method of claim 18, wherein the expandable sleeve comprises an inner surface defining the bore, and the first swage comprises an outer surface that slides against the inner surface, to expand the expandable sleeve, when the first and second swages are forced together, wherein the outer surface, the inner surface, or both comprise a gripping feature configured to resist relative movement of the expandable sleeve and the first swage in at least one direction. 21. The method of claim 20, wherein the gripping feature comprises a thermal spray metal, a grit, or a combination thereof.