Valve for controlling flow of fluid through a fluid-conveying conduit

Abstract

A valve for controlling flow of a fluid through a fluid conduit. The valve includes a tubular body comprising a body axial bore extending therethrough, an annular seat comprising an inner sealing surface, and a plunger axially movable within the body axial bore. The plunger includes a bung comprising an outer sealing surface and a sleeve connected to the bung. The sleeve comprises a sleeve axial bore. The plunger is configured to move between: a closed position in which the outer sealing surface is engaged with the inner sealing surface to thereby prevent flow of the fluid in a first direction through the valve; and an open position in which: (i) the outer sealing surface is disengaged from the inner sealing surface to thereby permit flow of the fluid in a second direction through the valve; and (ii) the sleeve is located along and therefore covers the inner sealing surface.

Description

APPLICATION FOR PATENTINVENTOR:JAMES A. CUNNINGHAMTITLE:VALVE FOR CONTROLLING FLOW OF FLUID THROUGH A FLUIDCONVEYING CONDUITSPECIFICATIONCROSS REFERENCE TO RELATED APPLICATIONS

[0001] The present application claims priority to and the benefit of U.S. Provisional Patent Application No. 63 / 755,922, titled “VALVE FOR CONTROLLING FLOW OF FLUID THROUGH A DOWNHOLE FLUID-CONVEYING STRING,” filed on February 7, 2025, the entire disclosure of which is hereby incorporated herein by reference.FIELD

[0002] Embodiments of the present invention relate, generally, to a fluid valve for controlling flow of fluid through a fluid-conveying conduit, such as a tubular joint string or a tubing string. In particular, the fluid valve is designed to prevent fluid flow in one position and permit fluid flow in another position, while minimizing, inhibiting, or preventing friction, wear, and other corrosive effects of the fluid on internal components of the fluid valve.BACKGROUND

[0003] In the oil and gas industry, various downhole fluid-conveying strings (or conduits) conveyed, installed, or otherwise disposed within a wellbore can be used to pump a surface fluid from a wellsite surface to a predetermined downhole location within the wellbore to perform various downhole operations. Fluidconveying strings can include a drilling string that can be used to convey a drilling fluid to perform drilling operations. Fluid-conveying strings can also include a workover string or a coiled tubing string that can be used to convey a well servicing fluid to perform well servicing operations, such as workover, intervention, and completion operations.

[0004] A downhole pressure increase, which can be caused by a well control event, can cause an influx of downhole pressure ( / .< ., back-pressure) and flow of the surface fluid, as well as a wellbore fluid located within the wellbore, in an upward ( / .< ., uphole) direction along a fluid-conveying string. A pressure and / or fluid influxcan cause damage to the fluid-conveying string and / or surface equipment at the wellsite surface.

[0005] Fluid flow control valves, such as check valves, float valves, non-retum valves, or back pressure valves can be installed along, within, or otherwise connected to fluid-conveying strings to prevent the influx of downhole pressure and the flow of the surface fluid, as well as the wellbore fluid, upward along the fluidconveying string. Such fluid flow control valves permit flow of the surface fluid in the downward ( / .< ., downhole) direction.

[0006] However, during operations, as a surface fluid is being pumped downhole through a fluid-conveying string and a fluid flow control valve, contact between the flowing surface fluid, especially a surface fluid (e.g., drilling fluid, fracturing fluid, etc.) carrying or otherwise comprising solid particles, and internal components of the fluid flow control valve can cause friction, wear, and other corrosive effects on the internal components. Sealing surfaces and biasing members, such as springs, are especially vulnerable to the wear and corrosive effects caused by a surface fluid.

[0007] Existing fluid flow control valves for preventing the influx of downhole pressure and the flow of a surface fluid in the upward direction comprise relatively large internal components (e.g., a plunger) and / or a small-diameter inner flow path, thereby restricting the flow of the surface fluid through the fluid flow control valves in the downward direction and / or causing an associated pressure drop across the fluid flow control valves.

[0008] An example of prior art includes U.S. Patent No. 12,006,789 to Alharbi et aL, titled “Float Valve Assembly for Drilling and Workover Operations.” The patent discloses a float valve assembly 130 configured to be positioned within in a central bore 112 of a tubular string 106 disposed in a wellbore 102 drilled into a subterranean zone 104. The float valve assembly 130 comprises a valve main body 200 comprising an outer surface 202 substantially cylindrical in shape, a valve flow passage 132 defined in part by an inner surface 204 of the valve main body 200 and configured to be fluidically connected to the central bore 112, and a circumferential inner sealing surface 208 formed on a portion of the inner bodysurface 204. The float valve assembly 130 further comprises a plunger 136 having a sealing ring 212 positioned within the valve main body 200 and axially moveable therein, and a spring 138 configured to bias the plunger 136 toward the closed position to prevent flow of a fluid through the float valve assembly 130. However, the sealing surface 208 and the spring 138 are not covered or otherwise protected from the fluid passing through the float valve assembly 130 and, thus, are exposed to the effects of friction, wear, and corrosion caused by the flowing fluid. Furthermore, the outer diameter of the plunger 136 is similar to the inner diameter of the main body 200, which collectively restrict flow of the fluid through the float valve assembly 130.

[0009] Another example of prior art includes U.S. Patent No. 5,687,792 to Roger et al., titled “Drill Pipe Float Valve and Method of Manufacture.” The patent discloses a float valve 10 for sealing engagement with a float sub 20 positioned downhole within a wellbore. The float sub 20 comprises upper and lower threads 22, 24 for threaded engagement with an oilfield tubular. The float valve 10 comprises the generally sleeve-shaped valve body 12 having a sealing seat 58, a valve member 40 axially movable within the valve body 12 for disengaging and engaging the sealing seat 58 in response to fluid pressure during opening and closing of the float valve 10. The valve member 40 comprises a stem 50 for guiding axial movement of the valve member 52 within the valve body 12, and a valve cone 52 secured to the stem for sealing engagement with the seat 58 for blocking flow of fluid through the float valve 10. The float valve 10 further comprises a biasing member 42 for biasing the valve member 40 toward engagement with the seat 58. However, the sealing seat 58 and the biasing member spring 42 are not covered or otherwise protected from the fluid passing through the float valve 10 and, thus, are exposed to the effects of friction, wear, and corrosion caused by the flowing fluid. Furthermore, the outer diameter of the cone 52 is similar to the inner diameter of the valve body 12, which collectively restrict flow of the fluid through the float valve 10.

[0010] Therefore, a need exists for a fluid flow control valve that can be installed along, within, or otherwise connected to a fluid-conveying string to prevent the influx of downhole pressure and the flow of a surface fluid upward along the fluid-conveying string, and that is resistant to the effects of friction, wear, and corrosion caused by the flowing surface fluid. For example, a need exists for a fluid flow control valve comprising internal components that are covered or otherwise protected from the surface fluid flowing through the fluid flow control valve.

[0011] A need also exists for a fluid flow control valve that can be installed along, within, or otherwise connected to a fluid-conveying string to prevent the influx of downhole pressure and the flow of a surface fluid upward along the fluidconveying string, and which comprises a relatively large-diameter inner flow path and / or relatively small internal components, thereby reducing flow restrictions and / or associated pressure drops caused by the fluid flow control valve.

[0012] Embodiments usable within the scope of the present disclosure meet these needs.SUMMARY

[0013] The present disclosure is directed to a valve for controlling flow of a fluid within a fluid-conveying string extending within a wellbore. The valve comprises: a tubular body comprising a body inner surface defining a body axial bore extending through the tubular body; and an annular seat located along the body inner surface. The annular seat comprises a seat inner surface defining a seat axial bore extending through the annular seat and the seat inner surface comprises an inner sealing surface. The valve further comprises a plunger disposed and axially movable within the body axial bore and the seat axial bore. The plunger comprises: a bung comprising an outer sealing surface; and a sleeve connected to the bung. The sleeve comprises a sleeve outer surface and a sleeve inner surface. The sleeve inner surface defines a sleeve axial bore. The sleeve further comprises plurality of sleeve radial bores extending between sleeve outer surface and a sleeve inner surface. The sleeve further comprises an upper sleeve portion and a lower sleeve portion. The sleeve radial bores are located along the lower sleeve portion. The body axial bore, the seat axial bore, the sleeve axial bore, and the sleeve radial bores collectively define a fluid passage extending through the valve. The plunger is configured to move between: a closed position in which the outer sealing surface is engaged with the inner sealing surface to thereby preventthe flow of the fluid through the fluid passage in an upward direction; and an open position in which: (i) the outer sealing surface is disengaged from the inner sealing surface to thereby permit the flow of the fluid through the fluid passage in a downward direction; and (ii) the upper sleeve portion is located along the inner sealing surface.

[0014] In an embodiment, the valve may be at least one of a check valve, a float valve, a non-return valve, or a back pressure valve. In an embodiment, the fluidconveying string may be one of a drilling tubular joint string, a workover tubular joint string, and a coiled tubing string.

[0015] In an embodiment, the valve may further comprise a connector configured for connection to the fluid-conveying string. In an embodiment, the valve may comprise: an upper connector at an upper end thereof configured for connection to an upper portion of the fluid-conveying string; and a lower connector at a lower end thereof configured for connection to a lower portion of the fluidconveying string. In an embodiment, the valve may instead be configured for insertion within a fluid passage of the fluid-conveying string.

[0016] In an embodiment, the sleeve axial bore may be open at an upper end of the sleeve and closed by the bung at a lower end of the sleeve.

[0017] In an embodiment, the plunger may further comprise a flow diverter comprising an outer surface that may be sloped radially outward in the downward direction. The outer surface may be configured to direct the flow of the fluid flowing through the sleeve axial bore in a radially outward direction toward the sleeve radial bores. In an embodiment, the flow diverter may comprise a conical outer surface configured to direct the flow of the fluid flowing through the sleeve axial bore in a radially outward direction toward the sleeve radial bores. In an embodiment, the flow diverter may comprise a bowl shaped surface configured to direct the flow of the fluid flowing through the sleeve axial bore in a radially outward direction toward the sleeve radial bores.

[0018] In an embodiment, the annular seat may further comprise an elastomeric fluid seal forming a portion of the inner sealing surface. The annular seat may be an annular member that is separate and distinct from the tubular body. The annularseat may be disposed within the body axial bore. The annular seat may be connected to the body inner surface. The annular seat may comprise a seat outer surface. The annular seat may be disposed within the body axial bore such that the seat outer surface is disposed against the body inner surface. The body inner surface may comprise internal threads and the seat outer surface may comprise external threads. The internal threads and the external threads may be engaged to connect the annular seat to the body inner surface.

[0019] In an embodiment, the valve may further comprise a biasing member configured to bias the plunger toward the closed position. The biasing member may comprise a coil spring.

[0020] In an embodiment, the valve may further comprise a base disposed within the body axial bore and connected to the body inner surface. The base may comprise a plurality of base axial bores, wherein the base axial bores further define the fluid passage. The biasing member may be disposed between the base and the plunger such that the biasing member can bias the plunger toward the closed position.

[0021] In an embodiment, the aforementioned sleeve may be an upper sleeve of the plunger, and the plunger may further comprise a lower sleeve connected to the bung on an opposite side of the bung from the upper sleeve. The lower sleeve may comprise an inner surface defining a lower sleeve axial bore. The lower sleeve axial bore may be open at a lower end of the lower sleeve and closed by the bung at an upper end of the lower sleeve. The biasing member may be disposed within the lower sleeve axial bore such that the lower sleeve is disposed around the biasing member.

[0022] The present disclosure is further directed to a valve for controlling flow of a fluid within a fluid-conveying string extending within a wellbore. The valve comprises: a tubular body comprising a body axial bore extending therethrough; an annular seat comprising an inner sealing surface; and a plunger axially movable within the body axial bore. The plunger comprises: a bung comprising an outer sealing surface; and a sleeve connected to the bung. The sleeve comprises a sleeve axial bore and a plurality of sleeve radial bores. The sleevecomprises an upper sleeve portion and a lower sleeve portion. The sleeve radial bores are located along the lower sleeve portion. The plunger is configured to move between: a closed position in which the outer sealing surface is engaged with the inner sealing surface to thereby prevent flow of the fluid in an upward direction through the body axial bore, the sleeve axial bore, and the sleeve radial bores; and an open position in which: (i) the outer sealing surface is disengaged from the inner sealing surface to thereby permit the flow of the fluid in a downward direction through the body axial bore, the sleeve axial bore, and the sleeve radial bores; and (ii) the upper sleeve portion is located along the inner sealing surface.

[0023] In an embodiment, the valve may be at least one of a check valve, a float valve, a non-return valve, or a back pressure valve. In an embodiment, the fluidconveying string may be one of a drilling tubular joint string, a workover tubular joint string, and a coiled tubing string.

[0024] In an embodiment, the valve may further comprise a connector configured for connection to the fluid-conveying string. In an embodiment, the valve may comprise: an upper connector at an upper end thereof configured for connection to an upper portion of the fluid-conveying string; and a lower connector at a lower end thereof configured for connection to a lower portion of the fluidconveying string. In an embodiment, the valve may instead be configured for insertion within a fluid passage of the fluid-conveying string.

[0025] In an embodiment, the sleeve axial bore may be open at an upper end of the sleeve and closed by the bung at a lower end of the sleeve.

[0026] In an embodiment, the plunger may further comprise a flow diverter comprising an outer surface that may be sloped radially outward in the downward direction. The outer surface may be configured to direct the flow of the fluid flowing through the sleeve axial bore in a radially outward direction toward the sleeve radial bores. In an embodiment, the flow diverter may comprise a conical outer surface configured to direct the flow of the fluid flowing through the sleeve axial bore in a radially outward direction toward the sleeve radial bores. In an embodiment, the flow diverter may comprise a bowl shaped surface configured to direct the flow of the fluid flowing through the sleeve axial bore in a radially outward direction toward the sleeve radial bores.

[0027] In an embodiment, the annular seat may further comprise an elastomeric fluid seal forming a portion of the inner sealing surface. The annular seat may be an annular member that is separate and distinct from the tubular body. The annular seat may be disposed within the body axial bore. The annular seat may be connected to the body inner surface. The annular seat may comprise a seat outer surface. The annular seat may be disposed within the body axial bore such that the seat outer surface is disposed against the body inner surface. The body inner surface may comprise internal threads and the seat outer surface may comprise external threads. The internal threads and the external threads may be engaged to connect the annular seat to the body inner surface.

[0028] In an embodiment, the valve may further comprise a biasing member configured to bias the plunger toward the closed position. The biasing member may comprise a coil spring.

[0029] In an embodiment, the valve may further comprise a base disposed within the body axial bore and connected to the body inner surface. The base may comprise a plurality of base axial bores, wherein the base axial bores further define the fluid passage. The biasing member may be disposed between the base and the plunger such that the biasing member can bias the plunger toward the closed position.

[0030] In an embodiment, the aforementioned sleeve may be an upper sleeve of the plunger, and the plunger may further comprise a lower sleeve connected to thebung on an opposite side of the bung from the upper sleeve. The lower sleeve may comprise an inner surface defining a lower sleeve axial bore. The lower sleeve axial bore may be open at a lower end of the lower sleeve and closed by the bung at an upper end of the lower sleeve. The biasing member may be disposed within the lower sleeve axial bore such that the lower sleeve is disposed around the biasing member.

[0031] The present disclosure is further directed to a valve for controlling flow of a fluid within a fluid-conveying string extending within a wellbore. The valve comprises: a tubular body comprising a body axial bore extending therethrough; an annular seat comprising an inner sealing surface; and a plunger axially movable within the body axial bore. The plunger comprises: a bung comprising an outer sealing surface; and a sleeve connected to the bung. The sleeve comprises a sleeve axial bore. The plunger is configured to move between: a closed position in which the outer sealing surface is engaged with the inner sealing surface to thereby prevent flow of the fluid in an upward direction through the body axial bore and the sleeve axial bore; and an open position in which: (i) the outer sealing surface is disengaged from the inner sealing surface to thereby permit the flow of the fluid in a downward direction through the body axial bore and the sleeve axial bore; and (ii) the sleeve is located along the inner sealing surface.

[0032] In an embodiment, the valve may be at least one of a check valve, a float valve, a non-return valve, or a back pressure valve. In an embodiment, the fluidconveying string may be one of a drilling tubular joint string, a workover tubular joint string, and a coiled tubing string.

[0033] In an embodiment, the valve may further comprise a connector configured for connection to the fluid-conveying string. In an embodiment, the valve may comprise: an upper connector at an upper end thereof configured for connection to an upper portion of the fluid-conveying string; and a lower connector at a lower end thereof configured for connection to a lower portion of the fluidconveying string. In an embodiment, the valve may instead be configured for insertion within a fluid passage of the fluid-conveying string.

[0034] In an embodiment, the sleeve axial bore may be open at an upper end of the sleeve and closed by the bung at a lower end of the sleeve.

[0035] In an embodiment, the plunger may further comprise a flow diverter comprising an outer surface that may be sloped radially outward in the downward direction. The outer surface may be configured to direct the flow of the fluid flowing through the sleeve axial bore in a radially outward direction toward the sleeve radial bores. In an embodiment, the flow diverter may comprise a conical outer surface configured to direct the flow of the fluid flowing through the sleeve axial bore in a radially outward direction toward the sleeve radial bores. In an embodiment, the flow diverter may comprise a bowl shaped surface configured to direct the flow of the fluid flowing through the sleeve axial bore in a radially outward direction toward the sleeve radial bores.

[0036] In an embodiment, the annular seat may further comprise an elastomeric fluid seal forming a portion of the inner sealing surface. The annular seat may be an annular member that is separate and distinct from the tubular body. The annular seat may be disposed within the body axial bore. The annular seat may be connected to the body inner surface. The annular seat may comprise a seat outer surface. The annular seat may be disposed within the body axial bore such that the seat outer surface is disposed against the body inner surface. The body inner surface may comprise internal threads and the seat outer surface may comprise external threads. The internal threads and the external threads may be engaged to connect the annular seat to the body inner surface.

[0037] In an embodiment, the valve may further comprise a biasing member configured to bias the plunger toward the closed position. The biasing member may comprise a coil spring.

[0038] In an embodiment, the valve may further comprise a base disposed within the body axial bore and connected to the body inner surface. The base may comprise a plurality of base axial bores, wherein the base axial bores further define the fluid passage. The biasing member may be disposed between the base and the plunger such that the biasing member can bias the plunger toward the closed position.

[0039] In an embodiment, the aforementioned sleeve may be an upper sleeve of the plunger, and the plunger may further comprise a lower sleeve connected to the bung on an opposite side of the bung from the upper sleeve. The lower sleeve may comprise an inner surface defining a lower sleeve axial bore. The lower sleeve axial bore may be open at a lower end of the lower sleeve and closed by the bung at an upper end of the lower sleeve. The biasing member may be disposed within the lower sleeve axial bore such that the lower sleeve is disposed around the biasing member.

[0040] The present disclosure is further directed to a valve for controlling flow of a fluid through a fluid-conveying conduit. The valve comprises a tubular body comprising a body axial bore extending therethrough and an annular seat located along the body axial bore. The annular seat is connected to the tubular body and comprises an inner sealing surface. The valve further comprises a plunger axially movable within the body axial bore. The plunger comprises a bung comprising an outer sealing surface and a sleeve connected to the bung. The sleeve comprises a sleeve axial bore. The plunger is configured to move between: a closed position in which the outer sealing surface is engaged with the inner sealing surface to thereby prevent flow of the fluid in a first direction through the valve and thereby prevent flow of the fluid in the first direction through the fluidconveying conduit; and an open position in which: (i) the outer sealing surface is disengaged from the inner sealing surface to thereby permit flow of the fluid in a second direction through the valve and thereby permit flow of the fluid in the second direction through the fluid-conveying conduit; and (ii) the sleeve is located along the inner sealing surface thereby covering at least a portion of the inner sealing surface.

[0041] In an embodiment, the sleeve may be separated from the bung by an annular space. In the closed position of the plunger, the outer sealing surface may be engaged with the inner sealing surface to thereby prevent flow of the fluid in the first direction through the valve via the body axial bore, the sleeve axial bore, and the annular space. In the open position of the plunger, the outer sealing surface may be disengaged from the inner sealing surface to thereby permit flow of the fluid in the second direction through the valve via the body axial bore, the sleeveaxial bore, and the annular space.

[0042] In an embodiment, the sleeve may comprise an first sleeve portion and a second sleeve portion. The sleeve may further comprise a plurality of sleeve radial bores located along the second sleeve portion. The plurality of sleeve radial bores may be connected with the sleeve axial bore. In the closed position of the plunger, the outer sealing surface may be engaged with the inner sealing surface to thereby prevent flow of the fluid in the first direction through the valve via the body axial bore, the sleeve axial bore, and the sleeve radial bores. In the open position of the plunger: (i) the outer sealing surface may be disengaged from the inner sealing surface to thereby permit flow of the fluid in the second direction through the valve via the body axial bore, the sleeve axial bore, and the sleeve radial bores; and (ii) the first sleeve portion may be located along the inner sealing surface thereby covering the at least a portion of the inner sealing surface.

[0043] In an embodiment, the sleeve axial bore may be open at a first end of the sleeve and closed by the bung at a second end of the sleeve.

[0044] In an embodiment, the fluid-conveying conduit may extend within a wellbore and comprise at least one of a drilling tubular joint string, a workover tubular joint string, and a coiled tubing string. Therefore, the first direction may comprise uphole direction and the second direction may comprise downhole direction.

[0045] In an embodiment, the valve may further comprise a biasing member configured to bias the plunger toward the closed position and a support base located along the body axial bore. The support base may be connected to the tubular body. The biasing member may be disposed between the support base and the plunger such that the biasing member can bias the plunger toward the closed position.

[0046] In an embodiment, the plunger may further comprise a plunger axial bore, which may be open at a first end thereof and closed at a second end thereof. The valve may further comprise a support base located along the body axial bore, wherein the support base may be connected to the tubular body. The valve may further comprise a shaft connected to the support base, wherein the shaft may be disposed within the plunger axial bore such that the plunger can move along the shaft between the closed position and the open position.

[0047] In an embodiment, the annular seat may further comprise an elastomeric fluid seal disposed along the inner sealing surface. The sleeve may be located along the elastomeric fluid seal when the plunger is in the open position thereby covering at least a portion of the elastomeric fluid seal.

[0048] In an embodiment, the annular seat may comprise an annular member that is separate and distinct from the tubular body. The annular seat may be detachably connected to the tubular body.

[0049] The present disclosure is further directed to a valve for controlling flow of a fluid through a fluid-conveying conduit. The valve comprises a tubular body comprising a body axial bore extending therethrough, and an annular seat located along the body axial bore. The annular seat is connected to the tubular body and may comprise an inner sealing surface. The valve further comprises a plunger axially movable within the body axial bore. The plunger comprises a bung comprising an outer sealing surface and a sleeve connected to the bung. The sleeve comprises a sleeve axial bore and a plurality of sleeve radial bores. The sleeve further comprises a first sleeve portion and a second sleeve portion, wherein the sleeve radial bores are located along the second sleeve portion. The plunger is configured to move between: a closed position in which the outer sealing surface is engaged with the inner sealing surface to thereby prevent flow of the fluid in a first direction through the valve via the body axial bore, the sleeve axial bore, and the sleeve radial bores and thereby prevent flow of the fluid in the first direction through the fluid-conveying conduit; and an open position in which: (i) the outer sealing surface is disengaged from the inner sealing surface to thereby permit flow of the fluid in a second direction through the valve via the body axial bore, the sleeve axial bore, and the sleeve radial bores and thereby permit flow of the fluid in the second direction through the fluid-conveying conduit; and (ii) the first sleeve portion is located along the inner sealing surface thereby covering at least a portion of the inner sealing surface.

[0050] In an embodiment, the fluid-conveying conduit may extend within a wellbore and comprise at least one of a drilling tubular joint string, a workover tubular joint string, and a coiled tubing string. Therefore, the first direction may comprise uphole direction and the second direction may comprise downhole direction.

[0051] In an embodiment, the sleeve axial bore may be open at a first end of the sleeve and closed by the bung at a second end of the sleeve.

[0052] In an embodiment, the valve may further comprise a biasing member configured to bias the plunger toward the closed position and a support base located along the body axial bore. The support base may be connected to the tubular body. The biasing member may be disposed between the support base and the plunger such that the biasing member can bias the plunger toward the closed position.

[0053] In an embodiment, the annular seat may further comprise an elastomeric fluid seal disposed along the inner sealing surface. When the plunger is in the open position, the first sleeve portion may be located along the elastomeric fluid seal thereby covering at least a portion of the elastomeric fluid seal.

[0054] In an embodiment, the annular seat may comprise an annular member that is separate and distinct from the tubular body. The annular seat may be detachably connected to the tubular body.

[0055] The present disclosure is further directed to a valve for controlling flow of a fluid through a fluid-conveying conduit. The valve comprises a tubular body comprising a body inner surface defining a body axial bore extending through the tubular body and an annular seat located along the body inner surface. The annular seat comprises a seat inner surface defining a seat axial bore extending through the annular seat, wherein the seat inner surface comprises an inner sealing surface. The valve further comprises a plunger disposed and axially movable within the body axial bore and the seat axial bore. The plunger comprises a bung comprising an outer sealing surface and a sleeve connected to the bung. The sleeve comprises a sleeve outer surface and a sleeve inner surface, wherein the sleeve inner surface defines a sleeve axial bore. The sleeve further comprises a plurality of sleeve radial bores extending between sleeve outer surface and a sleeve inner surface. The sleeve further comprises a first sleeve portion and a second sleeve portion, wherein the sleeve radial bores are located along the second sleeve portion. The body axial bore, the seat axial bore, the sleeve axial bore, and the sleeve radial bores collectively define a fluid passage extending through the valve. The plunger is configured to move between: aclosed position in which the outer sealing surface is engaged with the inner sealing surface to thereby prevent flow of the fluid in a first direction through the fluid passage and thereby prevent flow of the fluid in the first direction through the fluid-conveying conduit; and an open position in which: (i) the outer sealing surface is disengaged from the inner sealing surface to thereby permit flow of the fluid in a second direction through the fluid passage and thereby permit flow of the fluid in the second direction through the fluid-conveying conduit; and (ii) the first sleeve portion is located along the inner sealing surface thereby covering at least a portion of the inner sealing surface.

[0056] In an embodiment, the fluid-conveying conduit may extend within a wellbore and comprise at least one of a drilling tubular joint string, a workover tubular joint string, and a coiled tubing string. Therefore, the first direction may comprise uphole direction and the second direction may comprise downhole direction.

[0057] In an embodiment, the annular seat may further comprise an elastomeric fluid seal disposed along the inner sealing surface. When the plunger is in the open position, the first sleeve portion may be located along the elastomeric fluid seal thereby covering at least a portion of the elastomeric fluid seal.

[0058] In an embodiment, the sleeve axial bore may be open at a first end of the sleeve and closed by the bung at a second end of the sleeve.

[0059] In an embodiment, the annular seat may comprise an annular member that is separate and distinct from the tubular body. The annular seat may be detachably connected to the tubular body.BRIEF DESCRIPTION OF THE DRAWINGS

[0060] In the detailed description of various embodiments usable within the scope of the present disclosure, presented below, reference is made to the accompanying drawings, in which:

[0061] FIG. 1 depicts a schematic view of a wellsite system comprising an apparatus usable within the scope of the present disclosure.

[0062] FIG. 2 depicts a schematic sectional view of an example embodiment of the apparatus shown in FIG. 1 usable within the scope of the present disclosure.

[0063] FIG. 3 depicts a schematic sectional view of the apparatus shown in FIG. 2 in a different stage of operations.

[0064] FIG. 4 shows an enlarged view of a portion of the apparatus shown in FIG. 3.

[0065] One or more embodiments are described below with reference to the listed Figures.DETAILED DESCRIPTION OF THE EMBODIMENTS

[0066] Before describing selected embodiments of the present disclosure in detail, it is to be understood that the present invention is not limited to the particular embodiments described herein. The disclosure and description herein is illustrative and explanatory of one or more presently preferred embodiments and variations thereof, and it will be appreciated by those skilled in the art that various changes in the design, organization, means of operation, structures and location, methodology, and use of mechanical equivalents may be made without departing from the spirit of the invention.

[0067] As well, it should be understood that the drawings are intended to illustrate and plainly disclose presently preferred embodiments to one of skill in the art, but are not intended to be manufacturing level drawings or renditions of final products and may include simplified conceptual views to facilitate understanding or explanation. Also, the relative size and arrangement of the components may differ from that shown and still operate within the spirit of the invention.

[0068] Moreover, it will be understood that various directions such as “upper”, “lower”,“bottom”, “top”, “left”, “right”, and so forth are made only with respect to explanation in conjunction with the drawings, and that components may be oriented differently, for instance, during transportation and manufacturing as well as operation. Because many varying and different embodiments may be made within the scope of the concept(s) herein taught, and because many modifications may be made in the embodiments described herein, it is to be understood that thedetails herein are to be interpreted as illustrative and non-limiting.

[0069] FIG. 1 is a schematic view of at least a portion of an exemplary embodiment of a wellsite system 100 according to one or more aspects of the present disclosure, representing an environment in which one or more aspects of the present disclosure may be implemented. The wellsite system 100 is depicted in relation to a wellbore 102 formed by rotary and / or directional drilling and extending from a wellsite surface 104 into a subterranean formation 106. The wellsite system 100 will be in the future, is currently, or was in the past used to facilitate recovery of oil, gas, and / or other materials that are trapped in the subterranean formation 106 via the wellbore 102. A lower portion of the wellbore 102 is shown enlarged, as compared to an upper portion of the wellbore 102 that is adjacent the wellsite surface 104. The enlargement permits a more detailed depiction of various tools, including tubulars, devices, and other objects, which are disposed within the wellbore 102.

[0070] At least a portion of the wellbore 102 may be a cased-hole wellbore 102 that comprises a casing (not shown) secured by cement (not shown). At least a portion of the wellbore 102 may also, or instead, be an open-hole wellbore 102 lacking the casing and cement. Thus, one or more aspects of the present disclosure are applicable to and / or readily adaptable for utilizing in a cased-hole portion of the wellbore 102 and an open-hole portion of the wellbore 102. It is also noted that although the wellsite system 100 is depicted as an onshore implementation, it is to be understood that the aspects described below are also generally applicable to offshore and / or subsea implementations.

[0071] The wellsite system 100 includes surface equipment 130 located at the wellsite surface 104. The wellsite system 100 also includes or is operable in conjunction with a downhole fluid-conveying string (or conduit) 120 (“fluid-conveying string”), conveyed within the wellbore 102 along the subterranean formation 106 by the surface equipment 130 from the wellsite surface 104. The surface equipment 130 may include a support structure 142 and a conveyance device or system 140 collectively operable to assemble and / or otherwise convey the fluidconveying string 120 into and within the wellbore 102.

[0072] A wellhead 134 may cap the upper (or surface) end of the wellbore 102. A plurality (e.g., a stack) of fluid control devices 132 (e.g., a Christmas tree) may be mounted on top of the wellhead 134. The fluid control devices 132 may include fluid control valves, spools, and fittings individually and / or collectively operable to direct and control the flow of fluid out of the wellbore 102. The fluid-conveying string 120 may be deployed into or retrieved from the wellbore 102 via the support structure 142 and / or the conveyance device or system 140 through the fluid control devices 132 and the wellhead 134.

[0073] The fluid-conveying string 120 may be a fluid conduit comprising an inner surface 122 defining a fluid passage 124 (z.e., an axial bore) extending longitudinally therethrough. During downhole operations, the fluid-conveying string 120 may be used to convey (z.e., pass or transfer) a surface fluid within the fluid passage 124 in a downward (z.e., downhole) direction, as indicated by arrow 126, from the wellsite surface 104 to a predetermined downhole location within the wellbore 102 to perform a downhole operation. The surface equipment 130 may further include a fluid source 144 (e.g., a fluid container, a pump, etc.) fluidly connected with the fluid passage 124 of the fluid-conveying string 120 via a fluid conduit 146, which may be fluidly connected with the fluid passage 124 via an opening at a surface end of the fluid-conveying string 120. The fluid source 144 may be operable to pump or otherwise force the surface fluid into the fluid passage 124 of the fluid-conveying string 120 via the opening of the fluidconveying string 120.

[0074] To prevent the influx of downhole pressure (z.e., back-pressure) and the flow of surface fluid, as wells as wellbore fluid located within the wellbore 102, along the fluid passage 124 in an upward (z.e., uphole) direction, as indicated by arrow 128, a fluid flow control valve 150 (“valve”) may be installed along, within, or otherwise connected to the fluid-conveying string 120. The valve 150 may be operable to control flow of the surface fluid conveyed within the fluid-conveying string 120.

[0075] The valve 150 may comprise an inner surface 152 defining a fluid passage (z.e., an axial bore) 154 configured to flow (z.e., pass, convey, or transmit) the surface fluid flowing through the fluid-conveying string 120. The valve 150 may furthercomprise a plunger 156 (e.g., a movable valve member, dart, or fluid blocking member) configured to move between an open position and a closed position. In the open position, the plunger 156 permits the surface fluid to flow through the fluid passage 154 in the downward direction 126, thereby permitting the surface fluid to flow through the fluid passage 124 of the fluid-conveying string 120 in the downward direction 126. In the closed position, the plunger 156 prevents the influx of downhole pressure within the fluid passage 154 in the upward direction 128 and the flow of the surface fluid (or the wellbore fluid) through the fluid passage 154 in the upward direction 128. The plunger 156 thereby prevents the influx of downhole pressure within the fluid passage 124 in the upward direction 128 and the flow of the surface fluid through the fluid passage 124 of the fluidconveying string 120 in the upward direction 128. The valve 150 may be referred to in the oil and gas industry as a check valve, a float valve, a non-retum valve, or a back pressure valve, among other examples.

[0076] Although the valve 150 is shown connected along the fluid-conveying string 120 between an upper portion of the fluid-conveying string 120 and a lower portion of the fluid-conveying string 120, it is to be understood that the valve 150 may instead be configured for connection to the fluid-conveying string 120 at a lower end of the fluid-conveying string 120. It is to be further understood that the valve 150 may instead be configured for connection to the fluid-conveying string 120 within the fluid passage 124 of the fluid-conveying string 120. For example, an outer surface of the valve 150 may be configured for insertion into the fluid passage 124 and be disposed against or otherwise connected to the inner surface 122 of the fluid-conveying string 120.

[0077] In an example implementation of the wellsite system 100, the fluid-conveying string 120 may be a drill string comprising a plurality of tubular joints (or drill pipes) connected end-to-end. The support structure 142 may comprise a drilling rig, and the conveyance device or system 140 may comprise a drill string assembly system (e.g., a drawworks, a top drive, rotary table, slips, tongs, etc.), which may be collectively operable to assemble the drill string and convey the drill string within the wellbore 102. The fluid source 144 may comprise a drilling fluid (or mud) source (e.g., a mud tank, mud pumps, etc.). The valve 150 may beinstalled along, within, or otherwise connected to the drill string to prevent the influx of downhole pressure and the flow of the drilling mud and / or wellbore fluid through the drill string in the upward direction 128.

[0078] In another exemplary implementation of the wellsite system 100, the fluidconveying string 120 may be a well intervention string (e.g., a workover string) comprising a plurality of tubular joints connected end-to-end. The support structure 142 may therefore comprise a well servicing rig (e.g., a workover, intervention, and completion rig) and the conveyance device or system 140 may comprise a well intervention string assembly system (e.g., a drawworks, a top drive, a snubbing unit, slips, tongs, etc.), which may be collectively operable to assemble the well intervention string and convey the well intervention string within the wellbore 102. The fluid source 144 may comprise a source (e.g., a tank, a pump, etc.) of a well servicing (e.g., workover, well-control, completion, etc.) fluid (e.g., an acid, a brine, etc.). The valve 150 may be installed along, within, or otherwise connected to the well intervention string to prevent the influx of downhole pressure and the flow of the well servicing fluid and / or wellbore fluid through the well intervention string in the upward direction 128.

[0079] In still another exemplary implementation of the wellsite system 100, the fluidconveying string 120 may be a coiled tubing string comprising a continuous length of steel tubing. The support structure 142 may comprise a vertical support structure (e.g., a mast, a derrick, or a crane, etc.) and the conveyance device or system 140 may comprise a coiled tubing string conveyance system (e.g., an injector head, a coiled tubing reel, etc.), which may be collectively operable to insert the coiled tubing string into the wellbore 102 and convey the coiled tubing string within the wellbore 102. The fluid source 144 may comprise a source (e.g., a tank, a pump, etc.) of a well servicing (e.g., workover, well-control, completion, etc.) fluid (e.g., an acid, a brine, etc.). The valve 150 may be connected to the coiled tubing string at a lower end of the coiled tubing string to prevent the influx of downhole pressure and the flow of the well servicing fluid and / or wellbore fluid through the coiled tubing string in the upward direction 128.

[0080] FIGS. 2 and 3 are schematic sectional views of an exemplary embodiment of a downhole fluid flow control valve 200 (“valve”) according to one or more aspects of the present disclosure. The valve 200 is an exemplary embodiment of the valve 150 shown in FIG. 1 and may comprise one or more structural features and modes of operation of the valve 150, as described herein. The valve 200 may be operable to control flow of a surface fluid within a fluid-conveying string 120 conveyed, installed, or otherwise disposed within a wellbore 102. As described above, the valve 200 may be installed along, within, or otherwise connected to the fluid-conveying string 120, such as a drilling tubular joint string, a working tubular joint string, or a coiled tubing string. FIG. 3 shows the valve 200 in a different stage of operations than the valve 200 shown in FIG. 2. FIG. 4 is an enlarged view of a portion of the valve 200 shown in FIG. 3.

[0081] As shown, the valve 200 may comprise a tubular body 210 having a body inner surface 212 defining a body axial bore 214 extending through the tubular body 210 between an upper end 202 of the valve 200 (or the tubular body 210) and a lower end 204 of the valve 200 (or the tubular body 210). The body axial bore 214 may form a portion of a fluid passage 206 (see FIG. 4) extending through the valve 200 between the upper end 202 of the valve 200 (or the tubular body 210) and the lower end 204 of the valve 200 (or the tubular body 210).

[0082] The tubular body 210 or another portion of the valve 200 may be configured for installation along, within, or otherwise connection to the fluid-conveying string 120. For example, the tubular body 210 or another portion of the valve 200 may comprise an upper connector 222 (or coupler) at an upper (or uphole) end 202 of the valve 200 and a lower connector 224 (or coupler) at a lower (or downhole) end 204 of the valve 200. The connectors 222, 224 may permit the valve 200 to be connected between and, thus, couple together an upper portion of the fluidconveying string 120 and a lower portion of the fluid-conveying string 120. The connectors 222, 224 may permit the valve 200 to be instead connected between and, thus, couple together the fluid-conveying string 120 and a downhole tool connected below the valve 200. For example, the upper connector 222 may be configured to connect the valve 200 to the upper portion of the fluid-conveying string 120 and the lower connector 224 may be configured to connect the valve200 to the lower portion of the fluid-conveying string 120 or a downhole tool connected below the valve 200. In an exemplary embodiment of the valve 200, the upper connector 222 may comprise female threads configured to engage corresponding male threads of the upper portion of the fluid-conveying string 120. The lower connector 224 may comprise male threads configured to engage corresponding female threads of the lower portion of the fluid-conveying string 120 or a downhole tool connected below the valve 200. In an exemplary implementation, the connectors 222, 224 may be double shouldered rotary threaded connections. Although the valve 200 is shown comprising connectors 222, 224 having female and male threads, respectively, it is to be understood that the valve 200 may be implemented with other types of connectors, such as, for example, upper male threads, lower female threads, cam and groove connectors, pin-in-slot connectors, twist-lock connectors, and spiral pin connectors.

[0083] Although the valve 200 is shown comprising connectors 222, 224 configured for connecting the valve 200 along the fluid-conveying string 120 between an upper portion of the fluid-conveying string 120 and a lower portion of the fluidconveying string 120, it is to be understood that the valve 200, including the tubular body 210, may be configured for connection to the fluid-conveying string 120 within the fluid passage 124 of the fluid-conveying string 120. For example, an outer surface 208 of the valve 200 (or the tubular body 210) may be configured for insertion into the fluid passage 124 of the fluid-conveying string 120 and be disposed against or otherwise connected to the inner surface 122 of the fluid-conveying string 120.

[0084] The valve may further comprise an annular seat 230 comprising a seat inner surface 232 (see FIG. 4) defining a seat axial bore 234 (see FIG. 4) extending through the annular seat 230. The seat inner surface 232 may comprise an inner sealing surface 236. The annular seat 230 may further comprise an elastomeric fluid seal 238 (e.g., an O-ring) (see FIG. 4) disposed along the inner sealing surface 236 or otherwise forming a portion of the inner sealing surface 236. The annular seat 230 may be or may comprise a sleeve, a ring, or another annular member located along the body inner surface 212. The annular seat 230 may be separate and distinct from the tubular body 210 and comprise a seat outer surface235 (see FIG. 4). The annular seat 230 may be disposed within the body axial bore 214 such that the seat outer surface 235 is disposed against and connected to the body inner surface 212 of the tubular body 210. For example, the body inner surface 235 may comprise internal threads and the seat outer surface 212 may comprise complementary external threads. The internal threads and the external threads may be engaged to connect the annular seat 230 to the body inner surface 212. The annular seat 230 may be retained in a predetermined position within the body axial bore 214 by a retaining member 237 (e.g., a retainer ring) engaging the body inner surface 212. Although the annular seat 230 is shown as an annular member that is separate and distinct from the tubular body 210, it is to be understood that the annular seat 230 may be integrally formed with the tubular body 210, such that the annular seat 230 is integrally connected to or otherwise integral with the tubular body 210. The seat axial bore 234 may form a portion of the main fluid passage 206 extending through the valve 200 between the upper end 202 of the valve 200 and the lower end 204 of the valve 200.

[0085] The valve 200 may comprise a plunger 240 (z.e., a movable valve member or dart) disposed and axially movable within the body axial bore 214 and the seat axial bore 234. The plunger 240 may comprise a bung 242 (z.e., a plug or stopper) having an outer sealing surface 244 and an upper sleeve 246 connected to the bung 242. The upper sleeve 246 may be connected to the bung 242 at a lower end of the upper sleeve 246. The upper sleeve 246 may comprise a sleeve outer surface 247 (see FIG. 4) and a sleeve inner surface 248 (see FIG. 4). The sleeve inner surface 248 may define an upper sleeve axial bore 250. The sleeve axial bore 250 may be open at an upper end of the upper sleeve 246 and closed by the bung 242 at the lower end of the upper sleeve 246. The upper sleeve 246 may have an upper sleeve portion 252 (see FIG. 4) located closest to the upper end of the upper sleeve 246 and a lower sleeve portion 254 (see FIG. 4) located closest to the lower end of the upper sleeve 246. The upper sleeve 246 may further comprise a plurality of lateral or otherwise radial bores (or openings) 256 extending laterally or otherwise radially outward between the sleeve outer surface 247 and the sleeve inner surface 248. The sleeve radial bores 256 may be located along the lower sleeve portion 254, wherein the upper sleeve portion 252 may not comprise any sleeve radial bores 256. The sleeve axial bore 250 and the sleeveradial bores 256 may be connected. The sleeve axial bore 250 and the sleeve radial bores 256 may define a portion of the main fluid passage 206 extending through the valve between opposing ends of the valve.

[0086] Each sleeve radial bore 256 may comprise or be defined by a sleeve inner surface 261 (see FIG. 4) that extends (or is angled) laterally, diagonally, or otherwise radially outward in the downward direction, and, thus, configured to direct the flow of the surface fluid flowing through the sleeve axial bore 250, as indicated by arrows 203, in a lateral, diagonal, or otherwise radially outward and downward direction, as indicated by the arrows 205. Therefore, the sleeve inner surface 261 promotes flow of the surface fluid in lateral, diagonal, or otherwise radially outward and downward direction such that the surface fluid flowing through the radial bores 256 does not impact the body inner surface 212 of the tubular body 210 at a right ( / .< ., perpendicular) angle or an angle that is close to a right angle (e.g., about 80 degrees), thereby reducing angle of impact of the solid particles of the surface fluid and the inner surface 212 and thereby reducing friction, wear, and other corrosive effects of the surface fluid, especially a surface fluid carrying or otherwise comprising solid particles, on the inner surface 212 of the tubular body 210. Accordingly, the sleeve radial bores 256 may be a plurality of cross-over bores, openings, or other spaces configured to direct or otherwise permit the surface fluid flowing axially through the body axial bore 214, the seat axial bore 235, and the upper sleeve axial bore 250 along an inner flow path, as indicated by arrows 203 (see FIG. 4), to flow in a radially outward and downward direction, as indicated by arrows 205 (see FIG. 4), such that the surface fluid can flow around the bung 242 while reducing the angle of impact between the surface fluid and the inner surface 212 of the tubular body 210. The surface fluid may continue to flow downwards and in a laterally, diagonally, or otherwise radially inward direction along an outer flow path, as indicated by arrows 207, 267 (see FIG. 4) around and behind the bung 242.

[0087] The plunger 240 may further comprise a flow diverter 258 configured to redirect the flow of the surface fluid flowing axially downward through the body axial bore 214, the seat axial bore 235, and the upper sleeve axial bore 250 along the inner flow path, as indicated by the arrows 203, in a radially outward directiontoward the sleeve radial bores 256, as indicated by the arrows 205. The flow diverter 258 may comprise an outer surface 259 that is sloped radially outward in the downward direction, as indicated by arrows 205 and, thus, configured to direct the flow of the surface fluid toward the sleeve radial bores 256. The flow diverter 258 may split the surface fluid flow 203 in the radially outward direction, such that the surface fluid can flow along the outer flow path around the bung 242. The flow diverter 258 may maintain laminar flow or otherwise minimize or inhibit turbulence in the fluid as the surface fluid flows along the outer surface 259 of the flow diverter 258 and is being directed in the radially outward direction toward the sleeve radial bores 256.

[0088] In an example implementation, the flow diverter 258 may be a cone or comprise a conical geometry, having a conical outer surface 259 that is sloped radially outward in the downward direction and, thus, configured to direct the flow of the surface fluid flowing through the body axial bore 214, the seat axial bore 235, and the upper sleeve axial bore 250 in the radially outward direction toward the sleeve radial bores 256. The flow diverter 258 may instead comprise a bowlshaped geometry, having a bowl-shaped outer surface 259 that is sloped radially outward in the downward direction and, thus, configured to direct the flow of the surface fluid flowing through the body axial bore 214, the seat axial bore 235, and the upper sleeve axial bore 250 in the radially outward direction toward the sleeve radial bores 256.

[0089] Although the plunger 240 is shown comprising an upper sleeve 246 that is connected to the bung 242 via a lower sleeve portion 254, it is to be understood that the plunger 240 may be implemented with an upper sleeve 246 that comprises the upper sleeve portion 252, but not the lower sleeve portion 254. In other words, the upper sleeve 246 may be implemented without the sleeve radial bores 256. In such embodiment of the plunger 240, the upper sleeve 246 may be connected to the bung 242 (and / or the flow diverter 258) by one or more axial support members 282 (see FIG. 4) extending axially between the bung 242 and the upper sleeve 246. The axial support members 282 may comprise a portion of the flow diverter 258 or another shaft, rod, or stem extending axially between and connecting the bung 242 and the upper sleeve 246. One or more radial supportmembers 284 (e.g., rods, foils, a piston with axial bores, etc.) (shown in phantom lines in FIG. 4) may extend laterally, diagonally, or otherwise radially between the axial support members 282 and the upper sleeve 246. The radial support members 284 may be azimuthally spaced apart (or comprise axial bores) to define one or more axial spaces therebetween for permitting axial flow of the surface fluid along the axial flow path 203. The upper sleeve 246 may be axially separated from the bung 242, thereby defining an annular space (or gap) 257 extending between the bung 242 and the upper sleeve 246 and around the axial support members. Thus, the annular space 257 may direct or otherwise permit the surface fluid flowing axially through the body axial bore 214, the seat axial bore 235, and the sleeve axial bore 250 along an inner flow path, as indicated by the arrows 203, to flow in a laterally, diagonally, or otherwise radially outward direction such that the surface fluid can flow around the bung 242 along an outer flow path, as indicated by the arrows 205. The annular space 257 may therefore permit flow of the surface fluid in the laterally, diagonally, or otherwise radially outward direction 205 instead of (and in the same or similar manner as) the radial bores 256.

[0090] While the valve 200 is conveyed downhole as part of, or otherwise connected to, the fluid-conveying string 120 and during downhole operations in which a surface fluid is pumped downhole through the fluid passage 124 of the fluidconveying string 120 in the downward direction 126, the plunger 240 is operable to permit the surface fluid to flow ( / .< ., pass) through the main fluid passage 206 (see FIG. 4) in the downward direction 126, thereby permitting the surface fluid to flow through the fluid passage 124 of the fluid-conveying string 120 in the downward direction 126. The plunger 240 is further operable to block or otherwise prevent the influx of downhole pressure in the upward direction 128 along the main fluid passage 206 and the flow of the surface fluid and / or a wellbore fluid located within the wellbore 102 in the upward direction 128 through the main fluid passage 206. The plunger thereby also prevents the influx of downhole pressure along the fluid passage 124 of the fluid-conveying string 120 in the upward direction 128 and the flow of the surface fluid and / or the wellbore fluid through the fluid passage 124 in the upward direction 128. Thus, the valve 200 may be or may comprise one of a check valve, a float valve, a non-return valve, or a back pressure valve.

[0091] For example, the plunger 240 is configured to move between a closed position (shown in FIG. 2), in which the plunger 240 prevents the influx of downhole pressure and the flow of the surface fluid and / or the wellbore fluid through the main fluid passage 206 of the valve 200 in the upward direction 128, and an open position (shown in FIGS. 3 and 4), in which the plunger 240 permits the flow of the surface fluid through the main fluid passage 206 of the valve 200 in the downward direction 126.

[0092] While the plunger 240 (and the valve 200) is in the closed position: (i) the outer sealing surface 244 of the bung 242 is engaged with the inner sealing surface 236 of the annular seat 230; and (ii) the lower sleeve portion 254 of the upper sleeve 246 is located within the seat axial bore 234, such that the sleeve radial bores 256 are within the seat axial bore 234 or otherwise covered by the annular seat 230, to thereby prevent the flow of the surface fluid and / or the wellbore fluid through the sleeve radial bores 256 of the main fluid passage 206 in the upward direction 128. While the sealing surface 244 of the bung 242 and the inner sealing surface 236 of the annular seat 230 are engaged, the sealing surface 244 and the inner sealing surface 236 form a metal -to-metal fluid seal that prevents or inhibits fluid flow therebetween. The elastomeric fluid seal 238 may improve the fluid seal between the sealing surface 244 and the inner sealing surface 236, such as by facilitating a bubble-tight fluid seal that prevents or inhibits fluid flow therebetween.

[0093] While the plunger 240 (and the valve 200) is in the open position: (i) the outer sealing surface 244 of the bung 242 is disengaged from the inner sealing surface 236 of the annular seat 230, thereby defining the annular space (or gap) 257 (see FIG. 4) therebetween; and (ii) the sleeve radial bores 256 are located outside of the seat axial bore 234 to uncover (or open) the sleeve radial bores 256 and thereby fluidly connecting the sleeve radial bores 256 and the body axial bore 214 via the annular space 257 to thereby permit the flow of the surface fluid through the sleeve radial bores 256 into the body axial bore 214 of the main fluid passage 206 in the downward direction 126. Furthermore, while the plunger 240 is in the open position, (iii) at least a portion of the upper sleeve portion 252 (see FIG. 4) of the upper sleeve 246 is located along (or aligned with) the innersealing surface 236 of the annular seat 230, such that the upper sleeve portion 252 covers (e.g., shields, overlays, etc.) at least a portion of the inner sealing surface 236, including the elastomeric fluid seal 238, while the fluid flows through the seat axial bore 234 and the sleeve axial bore 250. In such position, the upper sleeve portion 252 of the upper sleeve 246 may protect (e.g., isolate) at least a portion of the inner sealing surface 236, including the elastomeric fluid seal 238, from friction, wear, and other corrosive effects caused by contact of the flowing surface fluid, including any solid particles in the surface fluid, with the inner sealing surface 236, as the surface fluid flows past or otherwise along the inner sealing surface 236. In other words, the upper sleeve portion 252 of the upper sleeve 246 may direct the fast-flowing surface fluid, and any solid particles, around or otherwise past the inner sealing surface 236, including the elastomeric fluid seal 238, such that the fast-flowing surface fluid and any solid particles do not flow directly along and contact the inner sealing surface 236.

[0094] The valve 200 may further comprise a biasing member 260 configured to bias the plunger 240 toward the closed position. The biasing member 260 may comprise, for example, a coil spring or a plurality of Belleville springs. While the valve 200 is located downhole as part of, or otherwise connected to, the fluidconveying string 120 and during downhole operations in which a surface fluid is pumped downhole through the fluid passage 124 of the fluid-conveying string 120 in the downward direction 126, fluid pressure imparts a downward force on the plunger 240, overcoming an upward force imparted to the plunger 240 by the biasing member 260 and thereby moving the plunger 240 from the closed position to the open position. In the open position, the plunger 240 permits the surface fluid to flow ( / .< ., pass) through the main fluid passage 206 in the downward direction 126, thereby permitting the surface fluid to flow through the fluid passage 124 of the fluid-conveying string 120 in the downward direction 126.

[0095] The valve 200 may further comprise a base 262 disposed within the body axial bore 214 and connected to the body inner surface 212. For example, the base 262 may engage an annular shoulder 264 formed along the body inner surface 212, such that the base 262 cannot move with respect to the tubular body 210. Thebase 262 may comprise a plurality of base axial bores 266 (see FIG. 4) configured to permit the flow of the surface fluid in the downward direction 126 past the base 262, as indicated by the arrows 267 (see FIG. 4). The base axial bores 266 may thus further define the main fluid passage 206 extending through the valve 200 between opposing ends 202, 204 of the valve 200. The biasing member 260 may be disposed between the base 262 and the plunger 240, such that the biasing member 260 can bias the plunger 240 toward the closed position.

[0096] The plunger 240 may further comprise a lower sleeve 270 connected to the bung 242 on an opposite side of the bung 242 from the upper sleeve 246. The lower sleeve 270 may comprise a sleeve inner surface 272 defining a lower sleeve axial bore 274, which may be open at a lower end thereof and closed by the bung 242 at an upper end thereof. The biasing member 260 may be disposed within the lower sleeve axial bore 274, such that the lower sleeve 270 is disposed around and, therefore, covers (e.g., shields, overlays, etc.) the biasing member 260 while the surface fluid flows through the body axial bore 214. In such position, the lower sleeve 270 may protect the biasing member 260 from friction, wear, and other corrosive effects caused by contact of the surface fluid, and any solid particles in the surface fluid, with the biasing member 260, as the surface fluid and the solid particles flow past or otherwise along the biasing member 260, as indicated by the arrows 207.

[0097] The valve 200 may further comprise a shaft 280 (e.g., a rod, stem, or mandrel) connected to the base 262. At least a portion of the shaft 280 may be disposed within the sleeve axial bore 274 of the lower sleeve 270, such that the plunger 240 can move axially along the shaft 280 between the closed position and the open position. The upper sleeve 246 of the plunger 240 may slide within the seat axial bore 234 (along the seat inner surface 232 of the annular seat 230) and the lower sleeve 270 of the plunger 240 may slide along the shaft 280, whereby permitting the plunger 240 to move axially within the body axial bore 214, while maintaining the plunger 240 centered (concentric) within the body axial bore 214 or otherwise with respect to the tubular body 210.

[0098] The body axial bore 214, defined by the inner body surface 212, may comprise an increased (or larger) inner diameter 276 (see FIG. 4) along or otherwise adjacentto the plunger 240 as compared to an inner diameter 278 (see FIG. 4) above and below the plunger 240. Such increased inner diameter increases flow area around the bung 242, the lower sleeve 270, and the base 262, thereby reducing restrictions to flow and associated pressure drops that may be caused by the bung 242, the lower sleeve 270, and the base 262 as the surface fluid flows around the bung 242 and the lower sleeve 270, and past the base 262, as indicated by the arrows 205, 207, 267.

[0099] Although FIGS. 2-4 show the plunger 240 of the valve 200 comprising both the upper sleeve 246 and the lower sleeve 270, it is to be understood that the valve 200 may be implemented with a plunger 240 that comprises the upper sleeve 246, but does not comprise the lower sleeve 270. It is to be further understood that the valve 200 may instead be implemented with a plunger 240 that comprises the lower sleeve 270, but does not comprise the upper sleeve 246. Furthermore, although the valve 200 is shown comprising the shaft 280 fixedly connected to the base 262 and the plunger 240 moving (z.e., sliding) along or otherwise with respect to the shaft 280 as the plunger 240 moves between the open and closed positions. However, it is to be understood that the valve 200 may instead be implemented with the shaft 280 being fixedly connected to the plunger 240 and configured to move (z.e., slide) along or otherwise with respect to the base 262 as the plunger 240 moves between the open and closed positions.[000100] Although FIGS. 1-4 and the above description show and describe the valve 150,200 as being implemented downhole, namely, installed along, within, or otherwise connected to a downhole fluid-conveying string 120 to prevent the influx of downhole pressure and the flow of a surface fluid upward along the fluid-conveying string 120, it is to be understood that the valve 150, 200 according to one or more aspects of the present disclosure, which is resistant to the effects of friction, wear, and corrosion caused by a flowing fluid (and solid particles therein), may also or instead be implemented at the Earth’s surface. That is, the valve 150, 200 may be installed along, within, or otherwise connected to a surface fluid-conveying conduit to permit flow of a fluid in a predetermined first direction within the surface fluid-conveying conduit and to prevent or inhibit the influx of pressure and the flow of the fluid in the opposing second directionwithin the surface fluid-conveying conduit. It is to be understood that the valve 150, 200 may be used at the Earth’s surface (i.e., as part of surface equipment) not just in the oil and gas industry, but also in the chemical, water utility, and other industries. For example, the valve 150, 200 may be used during chemical production and / or refining operations or during oil and gas drilling, well stimulation (e.g., fracturing, acidizing, etc.), production, and / or refining operations.[000101] In an example implementation, the surface equipment may comprise the wellsite surface equipment 130 shown in FIG. 1, wherein the valve 150, 200 is installed along or as part of the surface fluid-conveying conduit 146. In another example implementation, the valves 150, 200 may by fluidly connected to API 6A equipment, such as the wellhead 134 and / or the well fluid control devices 132 to control flow of various wellbore fluids being pumped into or being discharged out of the wellbore 102. For example, one or more valves 150, 200 may be fluidly connected along a choke line to control wellbore fluid (e.g., drilling fluid, formation fluid, etc.) being pumped out of the wellbore 102 and / or a kill line to control kill fluid (e.g., kill-weight mud) being pumped into the wellbore 102. In still another example implementation, one or more of the valves 150, 200 may be used in well fracturing operations to control flow of a fracturing fluid or one or more ingredients of a fracturing fluid. For example, the valves 150, 200 may by connected upstream and / or downstream of a frac manifold to control flow of fracturing fluid being pumped into and / or out of the frac manifold.[000102] While various embodiments usable within the scope of the present disclosure have been described with emphasis, it should be understood that within the scope of the appended claims, the present invention can be practiced other than as specifically described herein.

Claims

CLAIMSWHAT IS CLAIMED IS:

1. A valve for controlling flow of a fluid through a fluid-conveying conduit, wherein the valve comprises:a tubular body comprising a body axial bore extending therethrough;an annular seat located along the body axial bore, wherein the annular seat is connected to the tubular body, and wherein the annular seat comprises an inner sealing surface; and a plunger axially movable within the body axial bore, wherein the plunger comprises:a bung comprising an outer sealing surface; anda sleeve connected to the bung, wherein the sleeve comprises a sleeve axial bore, and wherein the plunger is configured to move between:a closed position in which the outer sealing surface is engaged with the inner sealing surface to thereby prevent flow of the fluid in a first direction through the valve and thereby prevent flow of the fluid in the first direction through the fluid-conveying conduit; andan open position in which: (i) the outer sealing surface is disengaged from the inner sealing surface to thereby permit flow of the fluid in a second direction through the valve and thereby permit flow of the fluid in the second direction through the fluid-conveying conduit; and (ii) the sleeve is located along the inner sealing surface thereby covering at least a portion of the inner sealing surface.

2. The valve of claim 1, wherein the sleeve is separated from the bung by an annular space, and wherein:in the closed position of the plunger, the outer sealing surface is engaged with the inner sealing surface to thereby prevent flow of the fluid in the first direction through the valve via the body axial bore, the sleeve axial bore, and the annular space; andin the open position of the plunger, the outer sealing surface is disengaged from the inner sealing surface to thereby permit flow of the fluid in the second direction through the valve via the body axial bore, the sleeve axial bore, and the annular space.

3. The valve of claim 1, wherein:the sleeve comprises an first sleeve portion and a second sleeve portion;the sleeve further comprises a plurality of sleeve radial bores located along the second sleeve portion;the plurality of sleeve radial bores are connected with the sleeve axial bore;in the closed position of the plunger, the outer sealing surface is engaged with the inner sealing surface to thereby prevent flow of the fluid in the first direction through the valve via the body axial bore, the sleeve axial bore, and the sleeve radial bores; andin the open position of the plunger: (i) the outer sealing surface is disengaged from the inner sealing surface to thereby permit flow of the fluid in the second direction through the valve via the body axial bore, the sleeve axial bore, and the sleeve radial bores; and (ii) the first sleeve portion is located along the inner sealing surface thereby covering the at least a portion of the inner sealing surface.

4. The valve of claim 3, wherein the sleeve axial bore is open at a first end of the sleeve and closed by the bung at a second end of the sleeve.

5. The valve of claim 1, wherein the fluid-conveying conduit extends within a wellbore and comprises at least one of a drilling tubular joint string, a workover tubular joint string, and a coiled tubing string, wherein the first direction comprises uphole direction, and wherein the second direction comprises downhole direction.

6. The valve of claim 1, further comprising:a biasing member configured to bias the plunger toward the closed position; anda support base located along the body axial bore, wherein the support base is connected to the tubular body, and wherein the biasing member is disposed between the support base and the plunger such that the biasing member can bias the plunger toward the closed position.

7. The valve of claim 1, wherein:the plunger further comprises a plunger axial bore;the plunger axial bore is open at a first end thereof and closed at a second end thereof; and the valve further comprises:a support base located along the body axial bore, wherein the support base is connected to the tubular body; anda shaft connected to the support base, wherein the shaft is disposed within the plunger axial bore such that the plunger can move along the shaft between the closed position and the open position.

8. The valve of claim 1, wherein the annular seat further comprises an elastomeric fluid seal disposed along the inner sealing surface, and wherein the sleeve is located along the elastomeric fluid seal when the plunger is in the open position thereby covering at least a portion of the elastomeric fluid seal.

9. The valve of claim 1, wherein the annular seat comprises an annular member that is separate and distinct from the tubular body, and wherein the annular seat is detachably connected to the tubular body.

10. A valve for controlling flow of a fluid through a fluid-conveying conduit, wherein the valve comprises:a tubular body comprising a body axial bore extending therethrough;an annular seat located along the body axial bore, wherein the annular seat is connected to the tubular body, and wherein the annular seat comprises an inner sealing surface; and a plunger axially movable within the body axial bore, wherein the plunger comprises:a bung comprising an outer sealing surface; anda sleeve connected to the bung, wherein the sleeve comprises a sleeve axial bore and a plurality of sleeve radial bores, wherein the sleeve further comprises a first sleeve portion and a second sleeve portion, wherein the sleeve radial bores are located along the second sleeve portion, and wherein the plunger is configured to move between:a closed position in which the outer sealing surface is engaged with the inner sealing surface to thereby prevent flow of the fluid in a first direction through the valve via the body axial bore, the sleeve axial bore, and thesleeve radial bores and thereby prevent flow of the fluid in the first direction through the fluid-conveying conduit; andan open position in which: (i) the outer sealing surface is disengaged from the inner sealing surface to thereby permit flow of the fluid in a second direction through the valve via the body axial bore, the sleeve axial bore, and the sleeve radial bores and thereby permit flow of the fluid in the second direction through the fluid-conveying conduit; and (ii) the first sleeve portion is located along the inner sealing surface thereby covering at least a portion of the inner sealing surface.

11. The valve of claim 10, wherein the fluid-conveying conduit extends within a wellbore and comprises at least one of a drilling tubular joint string, a workover tubular joint string, and a coiled tubing string, wherein the first direction comprises uphole direction, and wherein the second direction comprises downhole direction.

12. The valve of claim 10, wherein the sleeve axial bore is open at a first end of the sleeve and closed by the bung at a second end of the sleeve.

13. The valve of claim 10, further comprising:a biasing member configured to bias the plunger toward the closed position; anda support base located along the body axial bore, wherein the support base is connected to the tubular body, and wherein the biasing member is disposed between the support base and the plunger such that the biasing member can bias the plunger toward the closed position.

14. The valve of claim 10, wherein the annular seat further comprises an elastomeric fluid seal disposed along the inner sealing surface, and wherein, when the plunger is in the open position, the first sleeve portion is located along the elastomeric fluid seal thereby covering at least a portion of the elastomeric fluid seal.

15. The valve of claim 10, wherein the annular seat comprises an annular member that is separate and distinct from the tubular body, and wherein the annular seat is detachably connected to the tubular body.

16. A valve for controlling flow of a fluid through a fluid-conveying conduit, wherein thevalve comprises:a tubular body comprising a body inner surface defining a body axial bore extending through the tubular body;an annular seat located along the body inner surface, wherein the annular seat comprises a seat inner surface defining a seat axial bore extending through the annular seat, and wherein the seat inner surface comprises an inner sealing surface;a plunger disposed and axially movable within the body axial bore and the seat axial bore, wherein the plunger comprises:a bung comprising an outer sealing surface; anda sleeve connected to the bung, wherein the sleeve comprises a sleeve outer surface and a sleeve inner surface, wherein the sleeve inner surface defines a sleeve axial bore, wherein the sleeve further comprises a plurality of sleeve radial bores extending between sleeve outer surface and a sleeve inner surface, wherein the sleeve comprises a first sleeve portion and a second sleeve portion, wherein the sleeve radial bores are located along the second sleeve portion, wherein the body axial bore, the seat axial bore, the sleeve axial bore, and the sleeve radial bores collectively define a fluid passage extending through the valve, and wherein the plunger is configured to move between:a closed position in which the outer sealing surface is engaged with the inner sealing surface to thereby prevent flow of the fluid in a first direction through the fluid passage and thereby prevent flow of the fluid in the first direction through the fluid-conveying conduit; andan open position in which: (i) the outer sealing surface is disengaged from the inner sealing surface to thereby permit flow of the fluid in a second direction through the fluid passage and thereby permit flow of the fluid in the second direction through the fluid-conveying conduit; and (ii) the first sleeve portion is located along the inner sealing surface thereby covering at least a portion of the inner sealing surface.

17. The valve of claim 16, wherein the fluid-conveying conduit extends within a wellbore and comprises at least one of a drilling tubular joint string, a workover tubular joint string, and a coiled tubing string, wherein the first direction comprises uphole direction, and wherein the second direction comprises downhole direction.

18. The valve of claim 16, wherein the annular seat further comprises an elastomeric fluid seal disposed along the inner sealing surface, and wherein, when the plunger is in the open position, the first sleeve portion is located along the elastomeric fluid seal thereby covering at least a portion of the elastomeric fluid seal.

19. The valve of claim 16, wherein the sleeve axial bore is open at a first end of the sleeve and closed by the bung at a second end of the sleeve.

20. The valve of claim 16, wherein the annular seat comprises an annular member that is separate and distinct from the tubular body, and wherein the annular seat is detachably connected to the tubular body.

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