US20210215010A1 - Downhole setting tool - Google Patents
Downhole setting tool Download PDFInfo
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- US20210215010A1 US20210215010A1 US17/146,641 US202117146641A US2021215010A1 US 20210215010 A1 US20210215010 A1 US 20210215010A1 US 202117146641 A US202117146641 A US 202117146641A US 2021215010 A1 US2021215010 A1 US 2021215010A1
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- mandrel
- hydraulic chamber
- lower cylinder
- tool
- downhole
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- 239000012530 fluid Substances 0.000 claims abstract description 35
- 238000004891 communication Methods 0.000 claims abstract description 13
- 238000000034 method Methods 0.000 claims description 18
- 230000000452 restraining effect Effects 0.000 claims description 8
- 230000004044 response Effects 0.000 claims description 5
- 239000002360 explosive Substances 0.000 claims description 4
- 230000008878 coupling Effects 0.000 claims description 2
- 238000010168 coupling process Methods 0.000 claims description 2
- 238000005859 coupling reaction Methods 0.000 claims description 2
- 239000000843 powder Substances 0.000 description 6
- 238000005474 detonation Methods 0.000 description 3
- 230000004075 alteration Effects 0.000 description 1
- 230000015572 biosynthetic process Effects 0.000 description 1
- 238000010276 construction Methods 0.000 description 1
- -1 e.g. Substances 0.000 description 1
- 230000008569 process Effects 0.000 description 1
- 238000007789 sealing Methods 0.000 description 1
- 230000035939 shock Effects 0.000 description 1
- 238000006467 substitution reaction Methods 0.000 description 1
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Classifications
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- E—FIXED CONSTRUCTIONS
- E21—EARTH OR ROCK DRILLING; MINING
- E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B23/00—Apparatus for displacing, setting, locking, releasing or removing tools, packers or the like in boreholes or wells
- E21B23/06—Apparatus for displacing, setting, locking, releasing or removing tools, packers or the like in boreholes or wells for setting packers
- E21B23/065—Apparatus for displacing, setting, locking, releasing or removing tools, packers or the like in boreholes or wells for setting packers setting tool actuated by explosion or gas generating means
Definitions
- a packer may be deployed into the well and set therein to isolate one section from another.
- a setting tool is typically employed to set the packer.
- the setting tool may include a central mandrel that pulls up on a corresponding mandrel of the packer (or other type of tool such as a plug), and a setting sleeve that pushes down on a collar or another member of a setting assembly of the packer.
- the setting tool is actuated, e.g., by detonating a charge therein, to push downward on the sleeve holding the mandrel stationary. This results in the setting assembly being axially compressed and radially expanded, and thereby setting into the wellbore.
- the setting tools are prone to failure, as they typically rely on several relatively movable pistons, rods, sleeves, etc. for movement of the setting sleeve and/or mandrel.
- Embodiments of the disclosure may provide a downhole setting tool.
- the tool includes an upper cylinder, and a piston positioned in the upper cylinder.
- a charge chamber is defined on one side of the piston within the upper cylinder, and a first hydraulic chamber is defined on an opposite side of the piston and within the upper cylinder.
- the tool also includes a mandrel coupled to the upper cylinder.
- a flow port is defined in the mandrel, the flow port being in fluid communication with the first hydraulic chamber.
- the tool further includes a lower cylinder coupled to the head of the mandrel, the mandrel and the lower cylinder defining a second hydraulic chamber within the lower cylinder, and the flow port being in fluid communication with the second hydraulic chamber.
- the lower cylinder is configured to move with respect to the mandrel when the setting tool is actuated.
- Embodiments of the disclosure may also provide a method for setting a downhole tool.
- the method includes coupling a mandrel of the downhole tool to a setting tool.
- the setting tool includes an upper cylinder, and a piston positioned in the upper cylinder.
- a charge chamber is defined on one side of the piston within the upper cylinder, and a first hydraulic chamber is defined on an opposite side of the piston and within the upper cylinder, the first hydraulic chamber having hydraulic fluid therein.
- the setting tool also includes a mandrel attached to the upper cylinder. The mandrel of the setting tool is coupled the mandrel of the downhole tool.
- the setting tool further includes a lower cylinder coupled to the mandrel, the mandrel and the lower cylinder defining a second hydraulic chamber within the lower cylinder, the second hydraulic chamber being in fluid communication with the first hydraulic chamber.
- the method further includes deploying the tool and the setting tool into a wellbore, and detonating a charge in the charge chamber of the setting tool. Detonating the charge causes a force to be applied to the piston. Applying the force to the piston causes the piston to force at least some of the hydraulic fluid to flow from the first hydraulic chamber to the second hydraulic chamber. Causing at least some of the hydraulic fluid to flow from the first hydraulic chamber to the second hydraulic chamber causes the lower cylinder to move with respect to the mandrel and to apply a setting force to the downhole tool.
- Embodiments of the disclosure also provide a downhole setting tool including an upper cylinder comprising a sub configured to contain a charge, the upper cylinder at least partially defining a first hydraulic chamber therein, a piston positioned in the first chamber and movable with respect to the upper cylinder in response to detonating the charge, and a mandrel including a head coupled to the upper cylinder and defining a flow port therein.
- the piston moving in response to the charge detonating is configured to cause hydraulic fluid to flow from the first hydraulic chamber and through the flow port.
- the mandrel also includes an extension extending from the head and configured to couple to a subjacent tool so as to apply an axially-directed force thereto.
- the setting tool also includes a lower cylinder received at least partially around the mandrel and comprising a shoulder that is sealed with the extension of the mandrel.
- the shoulder and the head of the mandrel define a second hydraulic chamber axially therebetween, the first and second hydraulic chambers being in fluid communication with one another via the flow port.
- the setting tool further includes one or more retaining members connecting the lower cylinder to the head of the mandrel. The one or more retaining members are configured to release and allow the lower cylinder to move relative to the mandrel and relative to the upper cylinder.
- FIG. 1 illustrates a side, cross-sectional view of a downhole setting tool in a run-in configuration, according to an embodiment.
- FIG. 2 illustrates a side, cross-sectional view of the downhole tool in an actuated configuration, according to an embodiment.
- FIG. 3 illustrates a flowchart of a method for setting a downhole tool (e.g., a packer, plug, etc.) in a wellbore, according to an embodiment.
- a downhole tool e.g., a packer, plug, etc.
- first and second features are formed in direct contact
- additional features may be formed interposing the first and second features, such that the first and second features may not be in direct contact.
- embodiments presented below may be combined in any combination of ways, e.g., any element from one exemplary embodiment may be used in any other exemplary embodiment, without departing from the scope of the disclosure.
- FIG. 1 illustrates a side, cross-sectional view of a downhole setting tool 100 , according to an embodiment.
- the tool 100 may be configured to connect to a subjacent tool, such as a packer, plug, etc., that is to be set into a wellbore.
- the downhole setting tool 100 may be configured to push downward on an upper cone of a downhole tool, while pulling upward on a lower cone of the downhole tool.
- the downhole tool may be provided as any of the downhole tools discussed in U.S. Pat. No. 10,408,012, which is incorporated herein by reference in its entirety, to the extent not inconsistent with the present disclosure.
- the downhole setting tool 100 may be configured to pull upward on a mandrel and press downward on a setting assembly (e.g., slips, seals, cones, etc.) that is slidably positioned around the mandrel, as commonly employed in packers, plugs, etc.
- a setting assembly e.g., slips, seals, cones, etc.
- the tool 100 may include an upper cylinder 102 and a lower cylinder 104 .
- cylinders it will be appreciated that this term, as used herein, includes geometries for the cylinders 102 , 104 that may not be precisely cylindrical.
- the cylinders 102 , 104 may include shoulders, varying diameters, or other features as described herein or otherwise called for to support the functionality of the tool 100 , while still being referred to as “cylinders”.
- the upper cylinder 102 may be formed from a plurality of members, e.g., a sleeve 106 and a sub 108 that are threaded, fastened, or otherwise connected together, end-to-end.
- the sleeve 106 may be generally hollow, and may at least partially define a first hydraulic chamber 110 therein.
- the first hydraulic chamber 110 may contain a generally incompressible hydraulic fluid, e.g., oil, therein.
- the sub 108 may provide an upper connection 109 for the tool 100 to connect to a tool string (e.g., wireline, slickline, coiled tubing, etc.), and a bore therethrough, which may define a charge chamber 112 .
- the charge chamber 112 may be configured to contain a powder charge, or any other type of explosive power source.
- the sub 108 may also include a disc bleeder valve 116 , which may be configured to vent gas in the charge chamber 112 , e.g., to avoid damage to the tool 100 upon detonation of the powder charge.
- the charge chamber 112 and the first hydraulic chamber 110 may be prevented from fluid communication therebetween by a piston 114 .
- the piston 114 may be received within the upper cylinder 102 , specifically within the sleeve 106 , and may be sealed therewith. In the run-in configuration, as shown in FIG. 1 , the piston 114 may also abut an end of the sub 108 , and may be held in place by the hydraulic fluid filling the first hydraulic chamber 110 , and/or may be pinned or otherwise temporarily restrained in position.
- the piston 114 may be configured to slide within the sleeve 106 , e.g., in response to detonation of the powder charge in the charge chamber 112 .
- a mandrel 120 may be received through the lower cylinder 104 and into the upper cylinder 102 .
- the mandrel 120 may be threaded into or otherwise fastened to the upper cylinder 102 , such that the mandrel 120 may generally not move with respect thereto during actuation.
- One or more restraining members 121 may be coupled to the lower cylindrical member 104 and to either or both of the upper cylinder 102 or (as shown) the mandrel 120 .
- the restraining members 121 may temporarily fasten the lower cylinder 104 to the mandrel 120 .
- the lower cylinder 104 may be configured to slide with respect to the mandrel 120 during actuation, but may be prevented from doing so prior to actuation by the restraining members 121 .
- the one or more restraining members 121 may be shear pins, shear screws, clips, detents, or any other member configured to release upon exertion of a predetermined amount of force.
- the mandrel 120 may include a head 122 and an extension 124 , with the head 122 defining a larger diameter than the extension 124 , as shown.
- the head 122 and the extension 124 may be integrally-formed or may be formed from two separate pieces that are connected together. Further, the head 122 may be sealed with the lower cylinder 104 by one or more seals 123 so as to prevent fluid from communicating from the first hydraulic chamber 110 around mandrel 120 .
- the extension 124 may extend through a shoulder 126 formed in the lower cylinder 104 , and may seal therewith. Moreover, the shoulder 126 may be configured to slide along the extension 124 .
- the head 122 may define an end face 128 , which may be axially-oriented, where the extension 124 meets the head 122 .
- a second hydraulic chamber 130 may be defined axially between the shoulder 126 and the end face 128 .
- the head 122 may include a flow port 132 therein, which may communicate between the first and second hydraulic chambers 110 , 130 .
- the flow port 132 may include an axial bore 134 in the head 122 extending from the first hydraulic chamber 110 , but not entirely through the head 122 .
- the flow port 132 may also include one or more radial openings 136 , which extend at least partially radially from the axial bore 134 and to an outer diameter of the head 122 , e.g., between the head 122 and the inner diameter of the lower cylinder 104 , below (to the right of, as illustrated) the seals 123 , and thus may fluidly communicate with the second hydraulic chamber 130 via the unsealed interface between the head 122 and the lower cylinder 104 .
- the tool 100 may include a mandrel adapter 140 .
- the mandrel adapter 140 may be configured to engage the mandrel of the subjacent tool and, upon actuation of the setting tool 100 , to pull upward on the mandrel of the subjacent tool, as discussed above.
- a lower end 142 of the lower cylinder 104 may be configured, upon actuation of the tool 100 , to slide over and past the mandrel adapter 140 and into engagement with the setting assembly of the subjacent tool, so as to push downwardly thereon, as discussed above.
- the mandrel adapter 140 may also provide a lower stop for the movement of the lower cylinder 104 , as will be described in greater detail below, thereby preventing the lower cylinder 104 from sliding away from the around the mandrel 120 .
- FIG. 2 illustrates a side, cross-sectional view of the tool 100 in an actuated position, that is, after actuation of the tool 100 , according to an embodiment.
- Actuation of the tool 100 may generally occur by detonating the powder charge contained in the charge chamber 112 . Detonation may expand the gas in the charge chamber 112 or otherwise apply a force on the piston 114 directed in a downhole direction (to the right in FIG. 2 ). This force causes the piston 114 to move from the position shown in FIG. 1 to that shown in FIG. 2 .
- the piston 114 moving causes the hydraulic fluid in the first hydraulic chamber 110 to flow through the flow port 132 and (e.g., directly) into the second hydraulic chamber 130 .
- the flow port 132 e.g., the radial openings 136
- the hydraulic fluid may be viscous. Accordingly, the flow port 132 may serve to slow the movement of the piston 114 , acting as a dashpot to limit shock loading of the subjacent tool.
- the restraining members 121 holding the lower cylinder 104 in place release (e.g., yield), allowing the lower cylinder 104 to slide relative to the mandrel 120 .
- the mandrel 120 is prevented from moving with respect to the upper cylinder 102 and thus the tool string via the connection with the upper cylinder 102 .
- the mandrel 120 is connected to a subjacent mandrel, e.g., via the mandrel adapter 140 .
- the subjacent mandrel may thus likewise be prevented from movement with respect to the upper cylinder 102 .
- the lower cylinder 104 is driven downhole, extending the lower end 142 thereof past the mandrel adapter 140 , e.g., into engagement with the subjacent tool (or any other structure employed to set the subjacent tool), and applying a downhole-directed force thereto.
- the shoulder 126 may engage the adapter 140 at a bottom of a downstroke of the lower cylinder 104 , such that the adapter 140 prevents the lower cylinder 104 from sliding off of the mandrel 120 .
- the combination of the pushing and pulling may cause the subjacent tool to radially expand, and thereby set into position, e.g., sealing with a surrounding tubular (e.g., casing, liner, wellbore wall, etc.).
- FIG. 3 illustrates a flowchart of a method 300 for setting a downhole tool (e.g., packer, plug, etc.), according to an embodiment.
- a downhole tool e.g., packer, plug, etc.
- the method 300 may proceed by operation of the downhole setting tool 100 discussed above, and thus is described herein with reference thereto. However, it will be appreciated that other embodiments may employ other structures. Further, although one illustrated sequence of steps is described below for the method 300 , it will be appreciated that the order may be changed, or the steps may be combined or separated into two or more steps, without departing from the scope of the present disclosure.
- the method 300 may begin by connecting a mandrel 120 of the downhole setting tool 100 to a packer, as at 302 .
- the mandrel 120 may be connected to a mandrel of the packer, but in other embodiments, the mandrel 120 may be connected to a cone or another setting tool.
- the method 300 may also include connecting an upper cylinder 102 of the downhole setting tool 100 to a tool string, as at 304 .
- the method 300 may then include running the tool string, including the setting tool 100 and the packer, into a wellbore, as at 306 .
- the downhole setting tool 100 When the packer arrives at a desired position, the downhole setting tool 100 may be actuated, as at 308 . Actuating the downhole setting tool 100 may be achieved by detonating a powder charge contained in a charge chamber 112 of the downhole setting tool 100 . Further, detonating the powder charge may drive a piston 114 in the upper cylinder 102 in a downhole direction. Driving the piston 114 in the downhole direction may force a hydraulic fluid contained in a first hydraulic chamber 110 through a flow port 132 defined in the mandrel 120 and into a second hydraulic chamber 130 . The second hydraulic chamber 130 is defined between the mandrel 120 and a lower cylinder 104 .
- Forcing fluid into the second hydraulic chamber 130 may cause one or more restraining members 121 holding the lower cylinder 104 in place relative to the upper cylinder 102 to release, and may then cause the lower cylinder 104 to move downward with respect to the mandrel 120 .
- the lower cylinder 104 may move downward into engagement with the packer or another setting tool, so as to set the packer.
- the mandrel 120 may be prevented from moving with respect to the tool string via connection to the upper cylinder 102 .
- the downward movement of lower cylinder 104 may push downward on the packer, while the mandrel 120 pulls upward on the mandrel or cone of the packer.
- a setting force e.g., a downward force, an upward force, or a combination thereof
- a setting force is applied by the setting tool 100 onto the packer, thereby radially expanding the packer, so as to set the packer in the wellbore.
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Abstract
Description
- This application claims priority to U.S. Provisional Patent Application having Ser. No. 62/960,323, which was filed on Jan. 13, 2020 and is incorporated herein by reference in its entirety.
- In the oil and gas field, a variety of downhole tools may be employed to perform various functions in the well. For example, a packer may be deployed into the well and set therein to isolate one section from another. A setting tool is typically employed to set the packer. The setting tool may include a central mandrel that pulls up on a corresponding mandrel of the packer (or other type of tool such as a plug), and a setting sleeve that pushes down on a collar or another member of a setting assembly of the packer. The setting tool is actuated, e.g., by detonating a charge therein, to push downward on the sleeve holding the mandrel stationary. This results in the setting assembly being axially compressed and radially expanded, and thereby setting into the wellbore.
- However, the setting tools are prone to failure, as they typically rely on several relatively movable pistons, rods, sleeves, etc. for movement of the setting sleeve and/or mandrel.
- Embodiments of the disclosure may provide a downhole setting tool. The tool includes an upper cylinder, and a piston positioned in the upper cylinder. A charge chamber is defined on one side of the piston within the upper cylinder, and a first hydraulic chamber is defined on an opposite side of the piston and within the upper cylinder. The tool also includes a mandrel coupled to the upper cylinder. A flow port is defined in the mandrel, the flow port being in fluid communication with the first hydraulic chamber. The tool further includes a lower cylinder coupled to the head of the mandrel, the mandrel and the lower cylinder defining a second hydraulic chamber within the lower cylinder, and the flow port being in fluid communication with the second hydraulic chamber. The lower cylinder is configured to move with respect to the mandrel when the setting tool is actuated.
- Embodiments of the disclosure may also provide a method for setting a downhole tool. The method includes coupling a mandrel of the downhole tool to a setting tool. The setting tool includes an upper cylinder, and a piston positioned in the upper cylinder. A charge chamber is defined on one side of the piston within the upper cylinder, and a first hydraulic chamber is defined on an opposite side of the piston and within the upper cylinder, the first hydraulic chamber having hydraulic fluid therein. The setting tool also includes a mandrel attached to the upper cylinder. The mandrel of the setting tool is coupled the mandrel of the downhole tool. The setting tool further includes a lower cylinder coupled to the mandrel, the mandrel and the lower cylinder defining a second hydraulic chamber within the lower cylinder, the second hydraulic chamber being in fluid communication with the first hydraulic chamber. The method further includes deploying the tool and the setting tool into a wellbore, and detonating a charge in the charge chamber of the setting tool. Detonating the charge causes a force to be applied to the piston. Applying the force to the piston causes the piston to force at least some of the hydraulic fluid to flow from the first hydraulic chamber to the second hydraulic chamber. Causing at least some of the hydraulic fluid to flow from the first hydraulic chamber to the second hydraulic chamber causes the lower cylinder to move with respect to the mandrel and to apply a setting force to the downhole tool.
- Embodiments of the disclosure also provide a downhole setting tool including an upper cylinder comprising a sub configured to contain a charge, the upper cylinder at least partially defining a first hydraulic chamber therein, a piston positioned in the first chamber and movable with respect to the upper cylinder in response to detonating the charge, and a mandrel including a head coupled to the upper cylinder and defining a flow port therein. The piston moving in response to the charge detonating is configured to cause hydraulic fluid to flow from the first hydraulic chamber and through the flow port. The mandrel also includes an extension extending from the head and configured to couple to a subjacent tool so as to apply an axially-directed force thereto. The setting tool also includes a lower cylinder received at least partially around the mandrel and comprising a shoulder that is sealed with the extension of the mandrel. The shoulder and the head of the mandrel define a second hydraulic chamber axially therebetween, the first and second hydraulic chambers being in fluid communication with one another via the flow port. The setting tool further includes one or more retaining members connecting the lower cylinder to the head of the mandrel. The one or more retaining members are configured to release and allow the lower cylinder to move relative to the mandrel and relative to the upper cylinder.
- The present disclosure may best be understood by referring to the following description and accompanying drawings that are used to illustrate some embodiments. In the drawings:
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FIG. 1 illustrates a side, cross-sectional view of a downhole setting tool in a run-in configuration, according to an embodiment. -
FIG. 2 illustrates a side, cross-sectional view of the downhole tool in an actuated configuration, according to an embodiment. -
FIG. 3 illustrates a flowchart of a method for setting a downhole tool (e.g., a packer, plug, etc.) in a wellbore, according to an embodiment. - The following disclosure describes several embodiments for implementing different features, structures, or functions of the invention. Embodiments of components, arrangements, and configurations are described below to simplify the present disclosure; however, these embodiments are provided merely as examples and are not intended to limit the scope of the invention. Additionally, the present disclosure may repeat reference characters (e.g., numerals) and/or letters in the various embodiments and across the Figures provided herein. This repetition is for the purpose of simplicity and clarity and does not in itself dictate a relationship between the various embodiments and/or configurations discussed in the Figures. Moreover, the formation of a first feature over or on a second feature in the description that follows may include embodiments in which the first and second features are formed in direct contact, and may also include embodiments in which additional features may be formed interposing the first and second features, such that the first and second features may not be in direct contact. Finally, the embodiments presented below may be combined in any combination of ways, e.g., any element from one exemplary embodiment may be used in any other exemplary embodiment, without departing from the scope of the disclosure.
- Additionally, certain terms are used throughout the following description and claims to refer to particular components. As one skilled in the art will appreciate, various entities may refer to the same component by different names, and as such, the naming convention for the elements described herein is not intended to limit the scope of the invention, unless otherwise specifically defined herein. Further, the naming convention used herein is not intended to distinguish between components that differ in name but not function. Additionally, in the following discussion and in the claims, the terms “including” and “comprising” are used in an open-ended fashion, and thus should be interpreted to mean “including, but not limited to.” All numerical values in this disclosure may be exact or approximate values unless otherwise specifically stated. Accordingly, various embodiments of the disclosure may deviate from the numbers, values, and ranges disclosed herein without departing from the intended scope. In addition, unless otherwise provided herein, “or” statements are intended to be non-exclusive; for example, the statement “A or B” should be considered to mean “A, B, or both A and B.”
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FIG. 1 illustrates a side, cross-sectional view of adownhole setting tool 100, according to an embodiment. Thetool 100 may be configured to connect to a subjacent tool, such as a packer, plug, etc., that is to be set into a wellbore. In one specific embodiment, thedownhole setting tool 100 may be configured to push downward on an upper cone of a downhole tool, while pulling upward on a lower cone of the downhole tool. In such an embodiment, the downhole tool may be provided as any of the downhole tools discussed in U.S. Pat. No. 10,408,012, which is incorporated herein by reference in its entirety, to the extent not inconsistent with the present disclosure. In other embodiments, thedownhole setting tool 100 may be configured to pull upward on a mandrel and press downward on a setting assembly (e.g., slips, seals, cones, etc.) that is slidably positioned around the mandrel, as commonly employed in packers, plugs, etc. - In an embodiment, the
tool 100 may include anupper cylinder 102 and alower cylinder 104. Although referred to as “cylinders,” it will be appreciated that this term, as used herein, includes geometries for thecylinders cylinders tool 100, while still being referred to as “cylinders”. - In at least one embodiment, the
upper cylinder 102 may be formed from a plurality of members, e.g., asleeve 106 and asub 108 that are threaded, fastened, or otherwise connected together, end-to-end. Thesleeve 106 may be generally hollow, and may at least partially define a firsthydraulic chamber 110 therein. The firsthydraulic chamber 110 may contain a generally incompressible hydraulic fluid, e.g., oil, therein. - The
sub 108 may provide anupper connection 109 for thetool 100 to connect to a tool string (e.g., wireline, slickline, coiled tubing, etc.), and a bore therethrough, which may define acharge chamber 112. Thecharge chamber 112 may be configured to contain a powder charge, or any other type of explosive power source. In some embodiments, thesub 108 may also include adisc bleeder valve 116, which may be configured to vent gas in thecharge chamber 112, e.g., to avoid damage to thetool 100 upon detonation of the powder charge. - The
charge chamber 112 and the firsthydraulic chamber 110 may be prevented from fluid communication therebetween by apiston 114. Thepiston 114 may be received within theupper cylinder 102, specifically within thesleeve 106, and may be sealed therewith. In the run-in configuration, as shown inFIG. 1 , thepiston 114 may also abut an end of thesub 108, and may be held in place by the hydraulic fluid filling the firsthydraulic chamber 110, and/or may be pinned or otherwise temporarily restrained in position. Thepiston 114 may be configured to slide within thesleeve 106, e.g., in response to detonation of the powder charge in thecharge chamber 112. - A
mandrel 120 may be received through thelower cylinder 104 and into theupper cylinder 102. For example, themandrel 120 may be threaded into or otherwise fastened to theupper cylinder 102, such that themandrel 120 may generally not move with respect thereto during actuation. One ormore restraining members 121 may be coupled to the lowercylindrical member 104 and to either or both of theupper cylinder 102 or (as shown) themandrel 120. The restrainingmembers 121 may temporarily fasten thelower cylinder 104 to themandrel 120. Accordingly, thelower cylinder 104 may be configured to slide with respect to themandrel 120 during actuation, but may be prevented from doing so prior to actuation by the restrainingmembers 121. The one ormore restraining members 121 may be shear pins, shear screws, clips, detents, or any other member configured to release upon exertion of a predetermined amount of force. - In an embodiment, the
mandrel 120 may include ahead 122 and anextension 124, with thehead 122 defining a larger diameter than theextension 124, as shown. Thehead 122 and theextension 124 may be integrally-formed or may be formed from two separate pieces that are connected together. Further, thehead 122 may be sealed with thelower cylinder 104 by one ormore seals 123 so as to prevent fluid from communicating from the firsthydraulic chamber 110 aroundmandrel 120. Theextension 124 may extend through ashoulder 126 formed in thelower cylinder 104, and may seal therewith. Moreover, theshoulder 126 may be configured to slide along theextension 124. - Further, the
head 122 may define anend face 128, which may be axially-oriented, where theextension 124 meets thehead 122. A secondhydraulic chamber 130 may be defined axially between theshoulder 126 and theend face 128. Thehead 122 may include aflow port 132 therein, which may communicate between the first and secondhydraulic chambers flow port 132 may include anaxial bore 134 in thehead 122 extending from the firsthydraulic chamber 110, but not entirely through thehead 122. Theflow port 132 may also include one or moreradial openings 136, which extend at least partially radially from theaxial bore 134 and to an outer diameter of thehead 122, e.g., between thehead 122 and the inner diameter of thelower cylinder 104, below (to the right of, as illustrated) theseals 123, and thus may fluidly communicate with the secondhydraulic chamber 130 via the unsealed interface between thehead 122 and thelower cylinder 104. - In some embodiments, the
tool 100 may include amandrel adapter 140. Themandrel adapter 140 may be configured to engage the mandrel of the subjacent tool and, upon actuation of thesetting tool 100, to pull upward on the mandrel of the subjacent tool, as discussed above. Further, alower end 142 of thelower cylinder 104 may be configured, upon actuation of thetool 100, to slide over and past themandrel adapter 140 and into engagement with the setting assembly of the subjacent tool, so as to push downwardly thereon, as discussed above. Themandrel adapter 140 may also provide a lower stop for the movement of thelower cylinder 104, as will be described in greater detail below, thereby preventing thelower cylinder 104 from sliding away from the around themandrel 120. -
FIG. 2 illustrates a side, cross-sectional view of thetool 100 in an actuated position, that is, after actuation of thetool 100, according to an embodiment. Actuation of thetool 100 may generally occur by detonating the powder charge contained in thecharge chamber 112. Detonation may expand the gas in thecharge chamber 112 or otherwise apply a force on thepiston 114 directed in a downhole direction (to the right inFIG. 2 ). This force causes thepiston 114 to move from the position shown inFIG. 1 to that shown inFIG. 2 . - The
piston 114 moving causes the hydraulic fluid in the firsthydraulic chamber 110 to flow through theflow port 132 and (e.g., directly) into the secondhydraulic chamber 130. However, theflow port 132, e.g., theradial openings 136, may be relatively small in cross-section, as shown, and the hydraulic fluid may be viscous. Accordingly, theflow port 132 may serve to slow the movement of thepiston 114, acting as a dashpot to limit shock loading of the subjacent tool. - As the fluid is forced from the first
hydraulic chamber 110 into the secondhydraulic chamber 130, the restrainingmembers 121 holding thelower cylinder 104 in place release (e.g., yield), allowing thelower cylinder 104 to slide relative to themandrel 120. This allows the volume of the secondhydraulic chamber 130 to increase, as the pressure of the hydraulic fluid filling thesecond chamber 130 under force applied by thepiston 114, drives thelower cylinder 104 away from theupper cylinder 102. - As the
lower cylinder 104 is driven downhole, themandrel 120 is prevented from moving with respect to theupper cylinder 102 and thus the tool string via the connection with theupper cylinder 102. As noted above, themandrel 120 is connected to a subjacent mandrel, e.g., via themandrel adapter 140. The subjacent mandrel may thus likewise be prevented from movement with respect to theupper cylinder 102. - The
lower cylinder 104, however, is driven downhole, extending thelower end 142 thereof past themandrel adapter 140, e.g., into engagement with the subjacent tool (or any other structure employed to set the subjacent tool), and applying a downhole-directed force thereto. In some embodiments, theshoulder 126 may engage theadapter 140 at a bottom of a downstroke of thelower cylinder 104, such that theadapter 140 prevents thelower cylinder 104 from sliding off of themandrel 120. The combination of the pushing and pulling may cause the subjacent tool to radially expand, and thereby set into position, e.g., sealing with a surrounding tubular (e.g., casing, liner, wellbore wall, etc.). -
FIG. 3 illustrates a flowchart of amethod 300 for setting a downhole tool (e.g., packer, plug, etc.), according to an embodiment. For the sake of convenience, the downhole tool will be described as a packer, but it will be appreciated that this is merely an example. Themethod 300 may proceed by operation of thedownhole setting tool 100 discussed above, and thus is described herein with reference thereto. However, it will be appreciated that other embodiments may employ other structures. Further, although one illustrated sequence of steps is described below for themethod 300, it will be appreciated that the order may be changed, or the steps may be combined or separated into two or more steps, without departing from the scope of the present disclosure. - The
method 300 may begin by connecting amandrel 120 of thedownhole setting tool 100 to a packer, as at 302. In some embodiments, themandrel 120 may be connected to a mandrel of the packer, but in other embodiments, themandrel 120 may be connected to a cone or another setting tool. Themethod 300 may also include connecting anupper cylinder 102 of thedownhole setting tool 100 to a tool string, as at 304. Themethod 300 may then include running the tool string, including thesetting tool 100 and the packer, into a wellbore, as at 306. - When the packer arrives at a desired position, the
downhole setting tool 100 may be actuated, as at 308. Actuating thedownhole setting tool 100 may be achieved by detonating a powder charge contained in acharge chamber 112 of thedownhole setting tool 100. Further, detonating the powder charge may drive apiston 114 in theupper cylinder 102 in a downhole direction. Driving thepiston 114 in the downhole direction may force a hydraulic fluid contained in a firsthydraulic chamber 110 through aflow port 132 defined in themandrel 120 and into a secondhydraulic chamber 130. The secondhydraulic chamber 130 is defined between themandrel 120 and alower cylinder 104. Forcing fluid into the secondhydraulic chamber 130 may cause one ormore restraining members 121 holding thelower cylinder 104 in place relative to theupper cylinder 102 to release, and may then cause thelower cylinder 104 to move downward with respect to themandrel 120. - The
lower cylinder 104 may move downward into engagement with the packer or another setting tool, so as to set the packer. Themandrel 120 may be prevented from moving with respect to the tool string via connection to theupper cylinder 102. Thus, the downward movement oflower cylinder 104 may push downward on the packer, while themandrel 120 pulls upward on the mandrel or cone of the packer. As a result, a setting force (e.g., a downward force, an upward force, or a combination thereof) is applied by thesetting tool 100 onto the packer, thereby radially expanding the packer, so as to set the packer in the wellbore. - The foregoing has outlined features of several embodiments so that those skilled in the art may better understand the present disclosure. Those skilled in the art should appreciate that they may readily use the present disclosure as a basis for designing or modifying other processes and structures for carrying out the same purposes and/or achieving the same advantages of the embodiments introduced herein. Those skilled in the art should also realize that such equivalent constructions do not depart from the spirit and scope of the present disclosure, and that they may make various changes, substitutions, and alterations herein without departing from the spirit and scope of the present disclosure.
Claims (20)
Priority Applications (1)
Application Number | Priority Date | Filing Date | Title |
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US17/146,641 US20210215010A1 (en) | 2020-01-13 | 2021-01-12 | Downhole setting tool |
Applications Claiming Priority (2)
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US202062960323P | 2020-01-13 | 2020-01-13 | |
US17/146,641 US20210215010A1 (en) | 2020-01-13 | 2021-01-12 | Downhole setting tool |
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Publication Number | Publication Date |
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US20210215010A1 true US20210215010A1 (en) | 2021-07-15 |
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US17/146,641 Abandoned US20210215010A1 (en) | 2020-01-13 | 2021-01-12 | Downhole setting tool |
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US (1) | US20210215010A1 (en) |
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2021
- 2021-01-12 US US17/146,641 patent/US20210215010A1/en not_active Abandoned
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