Ball seat release device comprising a sliding shear sleeve

Abstract

The present invention provides, in one aspect, a tee release apparatus. According to this embodiment, the tee release apparatus includes a shear sleeve having a pocket and a tee body slidingly engaged within the shear sleeve, the tee body configured to move from a first linear position to a second linear position. The tee body further includes a longitudinal fluid passage, a tee located in the longitudinal fluid passage, one or more first fluid bypass ports coupling the longitudinal fluid passage and an exterior of the tee body, the one or more first fluid bypass ports located on a first side of the tee, and one or more second fluid bypass ports coupling the longitudinal fluid passage and the exterior of the tee body, the one or more second fluid bypass ports located on a second, opposite side of the tee.

Description

[0001] Cross-references to related applications

[0002] This application claims priority to U.S. Application Serial No. 17 / 131,442, filed December 22, 2020, entitled “BALL SEAT RELEASE APPARATUSINCLUDING SLIDING SHEAR SLEEVE”, which is jointly assigned with this application and is incorporated herein by reference in its entirety. Background Technology

[0003] In conventional practice, drilling an oil or gas well involves creating a wellbore that passes through numerous underground formations. For a variety of reasons, it is preferable to seal each formation the well passes through. For example, it is important to prevent formation fluids, gases, or materials from undesirably entering the wellbore from the formation, or wellbore fluids from undesirably entering the formation. Furthermore, it is generally desirable to isolate producing formations from each other and from non-producing formations.

[0004] Therefore, traditional well architectures typically include casing installed within the wellbore. In addition to providing a sealing function, the casing provides wellbore stability to counteract formation geomechanical forces such as compressive forces, seismic forces, and tectonic forces, thus preventing wellbore wall collapse. The casing is typically secured within the wellbore by a cement layer that fills the annular space between the outer surface of the casing and the wellbore wall. For example, once the casing string is in the desired position in the well, cement grout is pumped through the inside of the casing, around the lower end of the casing, and upwards into the annular space. After the annular space around the casing is fully filled with cement grout, the grout is allowed to harden, thereby supporting the casing and forming a substantially watertight barrier.

[0005] In standard practice, wellbore is drilled in intervals, with casing installed in each interval before drilling the next. Therefore, each subsequent casing string placed in the wellbore typically has a reduced outer diameter compared to the previously installed casing string. Specifically, the casing to be installed in a lower wellbore interval must pass through the previously installed casing string in an upper wellbore interval. In one approach, each casing string extends downhole from the surface such that only the lower portion of each casing string is adjacent to the wellbore wall. Alternatively, the wellbore casing string may comprise one or more liner strings that do not extend to the surface of the wellbore but typically extend downwards from near the bottom end of the previously installed casing string into the uncased portion of the wellbore. In this installation, the liner string can be set or suspended from a liner hanger positioned between the downhole end of the previously installed casing string and the uphole end of the liner string. Attached Figure Description

[0006] The following description now refers to the accompanying drawings, in which:

[0007] Figure 1A well system designed, manufactured, and operated according to this disclosure is shown;

[0008] Figure 2 A ball seat release device designed, manufactured, and operated according to this disclosure is shown; and

[0009] Figures 3 to 7 It shows Figure 2 The ball seat release device is shown in various operating states. Detailed Implementation

[0010] Downhole equipment is typically installed / started hydraulically. Pressure is generated by closing the inner diameter (“ID”) of the tubing string and pumping the closed volume until the start-up pressure of the downhole equipment is reached. For liner hanger installations, a setting ball is typically used to close the run-in tool ID, and pressure is applied inside the drill string to set the hanger and release the run-in tool.

[0011] In some applications, it is necessary to rebuild circulation after setting the liner hanger, especially when using expandable liner hangers. This requires removing and / or bypassing the ball. Typical hydraulic starting tools would require high pressure to release the ball to open the tubing ID. This pressure could cause a pressure shock to the formation when released below the down-feeding tool, potentially damaging the formation. The liner hanger designed, manufactured, and operated according to this disclosure employs a soft ball seat release device, which allows the flow path to be rebuilt without exceeding the normal circulation pressure.

[0012] First refer to Figure 1 This illustration shows a well system 100 designed, manufactured, and operated according to this disclosure. In one embodiment, the well system 100 employs a ball-and-socket release device (e.g., soft release) 190, also designed, manufactured, and operated according to this disclosure. In the well system 100, a semi-submersible platform 110 is centered above a subsea oil and gas formation 112 located below the seabed 114. A subsea pipeline 116 extends from the deck 118 of the platform 110 to the wellhead equipment 120, including a blowout preventer 122. The platform 110 has a lifting device 124, a derrick 126, a moving trolley 128, a hook 130, and a swivel 132 for raising and lowering downhole transport vehicles 140 (including, but not limited to, tubing strings, working tubing strings, etc.).

[0013] Wellbore 150 has been drilled through various formations, including formation 112. Casing string 155 is secured within the upper portion of wellbore 150 by cement 160. The term "casing" is used herein to refer to a string operable to be positioned within the wellbore, for example, to provide wellbore stability. Casing may be of the type known to those skilled in the art as "liner" and may be made of any material, such as steel or composite materials. Casing may be a connecting string or a continuous string. Extending downhole from casing string 155 into the lower portion of wellbore 150 is liner string 170, which includes a liner hanger 172 and a liner top 174 at its upper end.

[0014] In the illustrated embodiment, a ball-mounted release device (e.g., soft release) 190 is coupled to the downhole transport vehicle 140 and the run-in tool 180. According to this disclosure, the ball-mounted release device 190 allows for the reconstruction of the flow path below the run-in tool 180, for example, without removing the run-in tool 180 from the wellbore 150, and without exceeding the normal circulation pressure. Therefore, the flow path can be reconstructed without causing pressure shocks to the formation.

[0015] although Figure 1 A liner string 170 installed in an inclined wellbore is depicted, but those skilled in the art will understand that this system is equally applicable to wellbores with other orientations, including vertical, horizontal, and skewed wellbores. Therefore, those skilled in the art will understand that the use of directional terms such as above, below, upper, lower, upward, downward, above well, and below well is related to the illustrative embodiments depicted in the accompanying drawings, with the upward direction pointing towards the top of the corresponding drawing, the downward direction towards the bottom of the corresponding drawing, the above well direction towards the well surface, and the below well direction towards the well toe. Furthermore, even... Figure 1 While the system is described for offshore operations, those skilled in the art should understand that it is equally applicable to onshore operations.

[0016] Turn Figure 2 A cross-sectional view of a ball-and-socket release device 200 designed, manufactured, and operated according to this disclosure is shown. In the illustrated embodiment, the ball-and-socket release device 200 has been lowered downhole by a running tool 270. In the illustrated embodiment, the ball-and-socket release device 200 and the running tool 270 are positioned within a liner hanger 280, a jumper 290, and a liner string 295. Those skilled in the art will understand that the opposite end of the liner hanger 280 will be coupled to the casing string such that the liner hanger 280 anchors and seals the liner string 295 to the casing string.

[0017] In the illustrated embodiment, the down-running tool 270 includes a tool string 272 extending upward toward the wellbore from a surface facing the wellbore. In the illustrated embodiment, the down-running tool 270 further includes a chuck 274 and a chuck support 276. As shown, the chuck 274 may have a chuck profile that engages a corresponding profile in the bottom end of the casing hanger 280. Therefore, as the down-running tool 270 moves downhole and the chuck profile of the chuck 274 engages with the profile in the casing hanger 280, the chuck 274 will remain fixed while the casing hanger 280 is set together with the casing string.

[0018] exist Figure 2 In the illustrated embodiment, the ball seat release device 200 includes a shear sleeve 210. In one or more embodiments (e.g., including...), Figure 2 In the illustrated embodiment, the shear sleeve 210 includes a first shoulder 212 and a second shoulder 214. In the illustrated embodiment, the first shoulder 212 is an surface shoulder, and the second shoulder 214 is a downhole shoulder. According to one embodiment, the first shoulder 212 may engage with another feature in the ball seat release device 200 (e.g., shoulder 252 of the ball seat body 230), while the second shoulder 214 may engage with shoulder 292 in the bridging connector 290. Therefore, in Figure 2 In one embodiment, the shear sleeve 210 is a sliding shear sleeve that is operable to slide (e.g., slide downhole in one embodiment) until the second shoulder 214 engages with the shoulder 292.

[0019] In the illustrated embodiment, the shear sleeve 210 further includes a first concave pocket 216 formed along at least a portion of its inner surface. In one or more embodiments, the first concave pocket 216 is a fluid bypass concave pocket. According to one or more embodiments, the first concave pocket 216 includes a width (W). The width (W) can vary considerably and remains within the range of this disclosure. However, in one or more embodiments, the width (W) is in the range of about 4 cm to about 20 cm. In one or more other embodiments, the width (W) is in the range of about 6 cm to about 16 cm, and in one or more other embodiments, the width (W) is in the range of about 8 cm to about 10 cm. Figure 2 In the illustrated embodiment, the shear sleeve 210 further includes a locking latch feature 220. The locking latch feature 220 may include many different locking features and remains within the scope of this disclosure. However, the locking latch feature 220 in… Figure 2 In the embodiment, a retaining ring is used.

[0020] like Figure 2The ball seat device 200 shown further includes a ball seat body 230 slidably engaged within a shear sleeve 210. In one or more embodiments, the ball seat body 230 is configured to move relative to the shear sleeve 210 from a first linear position to a second linear position. In some embodiments, the first linear position is a first uphole linear position, and the second linear position is a second downhole linear position. However, other embodiments exist in which this orientation is reversed.

[0021] exist Figure 2 In the illustrated embodiment, the ball seat 230 and the shear sleeve 210 are releasably connected using a shear feature 225. In one embodiment, the shear feature 225 is a shear pin located in the shear sleeve 210 and engaging with the ball seat 230. However, other shear features 225 are also within the scope of this disclosure.

[0022] In one or more embodiments, the ball seat body 230 includes a longitudinal fluid passage 235 and a ball seat 240 located within the longitudinal fluid passage 235. As those skilled in the art will understand, the ball seat 240 is configured to engage with a drop ball or plug such that the drop ball or plug can abut against the ball seat 240. With the drop ball or plug abutting against the ball seat 240, the operator of the ball seat device 200 can pressurize the drop ball or plug to set the liner hanger 280 and fix the liner post relative to the sleeve post.

[0023] In one or more embodiments, the ball seat 230 may additionally include one or more first fluid bypass ports 245 connecting the longitudinal fluid passage 235 and the exterior of the ball seat 230. In the illustrated embodiment, one or more first fluid bypass ports 245 are located on a first side of the ball seat 240. For example, in some embodiments, one or more first fluid bypass ports 245 may be located on the uphole side of the ball seat 240. In one or more embodiments, the ball seat 230 may additionally include one or more second fluid bypass ports 250 connecting the longitudinal fluid passage 235 and the exterior of the ball seat 230. In the illustrated embodiment, one or more second fluid bypass ports 250 are located on a second side of the ball seat 240. For example, in some embodiments, one or more second fluid bypass ports 250 may be located on the downhole side of the ball seat 240.

[0024] According to one or more embodiments, one or more first fluid bypass ports 245 and one or more second fluid bypass ports 250 may be separated by a distance (D). The distance (D) can vary considerably and remains within the range of this disclosure. However, in one or more embodiments, the distance (D) is in the range of about 8 cm to about 20 cm. In one or more other embodiments, the distance (D) is in the range of about 10 cm to about 13 cm. In some other embodiments, the distance (D) is greater than the width (W) of the first recess 216.

[0025] In some embodiments, the outer diameter (d) of the ball seat 230 may vary along its length. For example, in Figure 2 In one embodiment, the ball seat 230 has a first outer diameter (d1) near one or more first fluid bypass ports 245 and a second smaller outer diameter (d2) near one or more second fluid bypass ports 250. The specific values ​​of the first outer diameter (d1) and the second smaller outer diameter (d2) can vary considerably and remain within the scope of this disclosure.

[0026] In one or more embodiments, the ball seat 230 includes a shoulder 252 that engages with a first shoulder 212 in the shear sleeve 210. In this embodiment, once the shear feature 225 has been sheared, the ball seat 230 can continue to slide relative to the shear sleeve 210 until the shoulder 252 engages with the first shoulder 212. At this point, the ball seat 230 will be in a second linear position.

[0027] In the illustrated embodiment, the ball seat 230 further includes a second recess 255 positioned along a portion of its outer surface. In at least one embodiment, the second recess 255 is configured to align with the locking latch feature 220. Thus, when properly positioned, the locking latch feature 220 is configured to retract radially into the second recess 255 to lock the ball seat 230 and the shear sleeve 210 relative to each other. This locking can occur, for example, when the ball seat 230 is in a second linear position.

[0028] exist Figure 2 The ball seat release device 200 shown in the embodiment further includes a first circumferential seal 260 located between the shear sleeve 210 and the ball seat body 230. In one embodiment, the first circumferential seal 260 is positioned near and above one or more first fluid bypass ports 245. Figure 2 The ball seat release device 200 shown in the embodiments may additionally include a second circumferential seal 262 located between the shear sleeve 210 and the ball seat body 230. In one embodiment, the second circumferential seal 262 is positioned near and downhole of one or more first fluid bypass ports 245, but above wellhead of one or more second fluid bypass ports 250. Figure 2 The ball seat release device 200 shown in the embodiments may additionally include a third circumferential seal 264 located between the shear sleeve 210 and the ball seat body 230. In one embodiment, the third circumferential seal 264 is positioned near one or more second fluid bypass ports 250 and downhole.

[0029] exist Figure 2In one embodiment of the operation of the ball seat release device 200, when the ball seat body 230 is in the first linear position, one or more first fluid bypass ports 245 are not radially aligned with the first concave pocket 216, but when the ball seat body 230 is in the first linear position, one or more second fluid bypass ports 250 are radially aligned with the first concave pocket 216. Additionally, in Figure 2 In this embodiment of the operation of the ball seat release device 200, when the ball seat body 230 is in the second linear position, one or more first fluid bypass ports 245 are radially aligned with the first concave pocket 216, but when the ball seat body 230 is in the second linear position, one or more second fluid bypass ports 250 are not radially aligned with the first concave pocket 216. However, in other embodiments, when the ball seat body 230 is in the second linear position, one or more second fluid bypass ports 250 are radially aligned with the first concave pocket 216. This configuration allows one or more first fluid bypass ports 245, the first concave pocket 216, and one or more second fluid bypass ports 250 to provide a fluid flow path around a drop ball or plug that can engage with the ball seat 240 when the ball seat body 230 is in the second linear position, but to close the fluid flow path when the ball seat body 230 is in the first linear position.

[0030] Now turning Figures 3 to 7 Various partial sectional views are shown of the ball seat release device 300 in different operating states within the liner hanger 280, bridging joint 290, and liner column 295. The ball seat release device 300 is similar in many respects to... Figure 2 The ball seat release device 200 is shown. Therefore, similar reference numerals have been used to illustrate the similarities between the two (if they are not identical). The ball seat release device 300 is in... Figure 3 The diagram shows the device in the drilling operation state. Therefore, the ball seat release device 300 is connected to the down-feed tool 270. Furthermore, the shearing feature 225 secures the shear sleeve 210 to the ball seat body 230. Therefore, the ball seat body 230 is held in a first linear position relative to the shear sleeve 210. Figure 3 In this embodiment, the first linear position is the wellhead linear position. Therefore, the fluid bypass path passing through one or more first fluid bypass ports 245, the first concave pocket 216, and one or more second fluid bypass ports 250 is closed.

[0031] Turn Figure 4 This shows the effect after deploying the drop ball or cork 410 using the drop tool 270. Figure 3The ball seat release device 300. In the illustrated embodiment, the drop ball or plug 410 abuts against the ball seat 240. With the drop ball or plug 410 abutting against the ball seat 240, the down-running tool 270 and the ball seat release device 300 can undergo one or more pressure cycles. In this embodiment, the pressure cycle sets the liner hanger 280, for example by driving a cone that radially expands the liner hanger 280 to engage with the wellhead casing string. At this stage, the liner hanger 280 secures the liner string 295 to the casing string. At this stage, the shear sleeve 210 and the ball seat body 230 remain in their respective first linear positions (e.g., first wellhead position).

[0032] Turn Figure 5 This illustrates the process after the weight is seated onto the ball seat release device 300 via the lowering tool 270. Figure 4 The ball seat release device. As shown, the down-running tool 270 pushes the entire ball seat release device 300 downhole until the shoulder 214 on the shear sleeve 210 engages with the shoulder 292 on the bridging joint 290. This prevents the shear sleeve 210 from moving further downhole. Thus, the shear sleeve 210 is operable from a first linear position (e.g., Figure 4 The position shown in the figure) is moved to the second linear position (e.g., Figure 5 (as shown in the diagram). At this stage, the shear sleeve 210 is in its second linear position, but the ball seat 230 remains in its first linear position.

[0033] Turn Figure 6 This illustrates the process after the weight is continuously seated onto the ball seat release device 300 via the lowering tool. Figure 5 The ball seat release device 300. As the shear sleeve 210 can no longer move further, the ball seat body 230 continues to move downhole, thereby shearing the shearing feature 225. At this stage, the ball seat body 230 is able to move relative to the shear sleeve 210. Therefore, as the ball seat body 230 continues to move downhole, the shoulder 252 of the ball seat body 230 engages the shoulder 212 of the shear sleeve 210. At this stage, the shear sleeve 210 and the ball seat body 230 are in their respective second linear positions (e.g., second surface positions). Figure 6 In the illustrated embodiment, the locking latch feature 220 has been radially retracted into the second concave pocket 255 to lock the ball seat 230 and the shear sleeve 210 relative to each other. For example, as shown, this locking can occur when the ball seat 230 is in the second linear position.

[0034] Turn Figure 7 This illustrates the process after a fluid (e.g., a low-pressure fluid) is pumped downwards into the insertion tool 270. Figure 6The ball seat release device 300. As shown, fluid can bypass the drop ball or plug 410 via a flow path 710. For example, with the ball seat 230 in the second linear position, fluid can bypass the drop ball or plug 410 by exiting the ball seat 230 via one or more first bypass ports 245, traversing along the first concave pocket 216, and then re-entering the ball seat 230 via one or more second bypass ports 250. In this embodiment, the drop ball or plug 410 remains against the ball seat 240, and therefore fluid flow cannot reach the entire ID of the tool; however, the flow path 710 is reconstructed in the absence of pressure impact on the formation.

[0035] The aspects disclosed in this article include:

[0036] A. A ball seat release device comprising: 1) a shear sleeve having a recess positioned along a portion of its inner surface; 2) a ball seat body slidably engaged within the shear sleeve, the ball seat body configured to move relative to the shear sleeve from a first linear position to a second linear position, and further wherein a shearing feature releasably connects the ball seat body to the shear sleeve, the ball seat body comprising: a) a longitudinal fluid channel; b) a ball seat located within the longitudinal fluid channel; c) one or more first fluid bypass ports connecting the longitudinal fluid channel and the exterior of the ball seat body, the one or more first fluid bypass ports being located on a first side of the ball seat; and d) one or more second fluid bypass ports connecting the longitudinal fluid channel and the exterior of the ball seat body, the one or more second fluid bypass ports being located on a second opposite side of the ball seat.

[0037] B. A well system comprising: 1) a casing string secured within a wellbore extending through one or more subsurface formations; 2) a liner hanger and a liner string suspended at and near the downhole end of the casing string; and 3) a ball seat release device coupled to a downhole end of a downhole tool and positioned within at least a portion of the liner hanger or the liner string, the ball seat release device comprising: a) a shear sleeve having a recess positioned along a portion of its inner surface; and b) a ball seat body slidably engaged within the shear sleeve, the ball seat body configured relative to the shear sleeve from the downhole end of the casing string. A linear position moves to a second linear position, and further, wherein the shearing feature releasably connects the ball seat body to the shearing sleeve, the ball seat body comprising: i) a longitudinal fluid channel; ii) a ball seat located in the longitudinal fluid channel; iii) one or more first fluid bypass ports connecting the longitudinal fluid channel and the exterior of the ball seat body, the one or more first fluid bypass ports being located on a first side of the ball seat; and iv) one or more second fluid bypass ports connecting the longitudinal fluid channel and the exterior of the ball seat body, the one or more second fluid bypass ports being located on a second opposite side of the ball seat.

[0038] C. A method for completing a well system, the method comprising: 1) deploying a liner hanger and a liner string onto a casing string using a running-in tool, wherein a ball seat release device is coupled near the downhole end of the running-in tool, the ball seat release device comprising: a) a shear sleeve having a recess positioned along a portion of its inner surface; and b) a ball seat body slidably engaged within the shear sleeve, the ball seat body configured to move relative to the shear sleeve from a first linear position to a second linear position, and further wherein a shear feature releasably engages the ball seat body with the shear sleeve, the ball seat body comprising: i) a longitudinal fluid passage; ii) a ball seat located within the longitudinal fluid passage; iii) one or more first fluid bypass ports coupled to the longitudinal fluid passage. To the outside of the fluid passage and the ball seat body, the one or more first fluid bypass ports are located on a first side of the ball seat; and iv) one or more second fluid bypass ports connecting the longitudinal fluid passage and the outside of the ball seat body, the one or more second fluid bypass ports being located on a second opposite side of the ball seat: 2) positioning the liner hanger near the downhole end of the casing string; 3) placing a drop ball or plug inside the casing string, the drop ball or plug abutting against the ball seat; and 4) pressing the drop ball or plug abutting against the ball seat to set the liner hanger and fix the liner string relative to the casing string, and then moving the downhole tool to move the ball seat body from a first linear position to a second linear position and providing a downhole fluid path for the ball seat release device.

[0039] Aspects A, B, and C may have one or more of the following additional combinations of elements: Element 1: wherein the shear sleeve includes a locking latch feature. Element 2: wherein the concave pocket is a first concave pocket, and further, wherein the ball seat body includes a second concave pocket positioned along a portion of its outer surface, the locking latch feature being configured to retract radially into the second concave pocket when the ball seat body is in a second linear position to lock the ball seat body and the shear sleeve relative to each other. Element 3: wherein the locking latch feature is a snap ring. Element 4: wherein the concave pocket, one or more first fluid bypass ports, and one or more second fluid bypass ports are configured to provide a fluid flow path around a drop ball or plug that can engage with the ball seat when the ball seat body is in the second linear position. Element 51: wherein the distance (D) between one or more first fluid bypass ports and one or more second fluid bypass ports is greater than the width (W) of the concave pocket. Element 6: wherein the ball seat body has a first outer diameter (d1) near one or more first fluid bypass ports and a second smaller outer diameter (d2) near one or more second fluid bypass ports. Element 7: Wherein, when the ball seat is in the first linear position, one or more first fluid bypass ports are not radially aligned with the concave bag; however, when the ball seat is in the first linear position, one or more second fluid bypass ports are radially aligned with the concave bag; and when the ball seat is in the second linear position, one or more first fluid bypass ports are radially aligned with the concave bag; however, when the ball seat is in the second linear position, one or more second fluid bypass ports are not radially aligned with the concave bag. Element 8: Wherein, the shear sleeve is a sliding shear sleeve. Element 9: Further includes: a first circumferential seal located between the shear sleeve and the ball seat, near and above the one or more first fluid bypass ports; a second circumferential seal located between the shear sleeve and the ball seat, near and below the one or more first bypass ports; and a third circumferential seal located between the shear sleeve and the ball seat, near and below the one or more second fluid bypass ports. Element 10: Moving the downhole tool to move the ball seat body from a first linear position to a second linear position includes: moving the shear sleeve and the ball seat body downhole until the shoulder of the shear sleeve engages with the shoulder of the bridging joint, the shear sleeve and the ball seat body being linearly connected to each other via a shearing feature; and continuing to move the ball seat body downhole until the shearing feature shears and allows the ball seat body to move from the first linear position to the second linear position. Element 11: Continuing to move the ball seat body downhole until the shearing feature shears and allows the ball seat body to move from the first linear position to the second linear position includes aligning one or more first fluid bypass ports with a concave pocket.

[0040] Those skilled in the art to which this application pertains will understand that other and additional additions, deletions, substitutions, and modifications can be made to the described embodiments.

Claims

1. A ball seat release device, comprising: A shearing sleeve having a recessed pocket positioned along a portion of its inner surface, the shearing sleeve further comprising a second shoulder, the second shoulder being a downhole shoulder configured to engage with a shoulder in a bridging joint, the shearing sleeve being configured to slide within the bridging joint; as well as A ball seat body slidably engages within the shear sleeve, the ball seat body being configured to move relative to the shear sleeve from a first linear position to a second linear position, wherein a shearing feature releasably connects the ball seat body to the shear sleeve, the ball seat body comprising: Longitudinal fluid channel; A ball seat is located in the longitudinal fluid channel; One or more first fluid bypass ports connecting the longitudinal fluid channel and the exterior of the ball seat, the one or more first fluid bypass ports being located on a first side of the ball seat; and One or more second fluid bypass ports are connected to the longitudinal fluid channel and the exterior of the ball seat, the one or more second fluid bypass ports being located on a second opposite side of the ball seat.

2. The ball seat release device according to claim 1, wherein the shear sleeve includes a locking latch feature.

3. The ball seat release device of claim 2, wherein the recess is a first recess, wherein the ball seat body includes a second recess positioned along a portion of its outer surface, and the locking buckle feature is configured to retract radially into the second recess when the ball seat body is in the second linear position to lock the ball seat body and the shear sleeve relative to each other.

4. The ball seat release device according to claim 2, wherein the locking buckle feature is a retaining ring.

5. The ball seat release device of claim 1, wherein the concave pocket, the one or more first fluid bypass ports, and the one or more second fluid bypass ports are configured to provide a fluid flow path around a drop ball or plug engaged with the ball seat when the ball seat body is in the second linear position.

6. The ball seat release device according to claim 5, wherein the distance between the one or more first fluid bypass ports and the one or more second fluid bypass ports is greater than the width of the concave bag.

7. The ball seat release device according to claim 6, wherein the ball seat body has a first outer diameter near the one or more first fluid bypass ports and a second smaller outer diameter near the one or more second fluid bypass ports.

8. The ball seat release device according to claim 7, wherein when the ball seat body is in the first linear position, the one or more first fluid bypass ports are not radially aligned with the concave bag, but when the ball seat body is in the first linear position, the one or more second fluid bypass ports are radially aligned with the concave bag, and when the ball seat body is in the second linear position, the one or more first fluid bypass ports are radially aligned with the concave bag, but when the ball seat body is in the second linear position, the one or more second fluid bypass ports are not radially aligned with the concave bag.

9. The ball seat release device according to claim 1, wherein the shear sleeve is a sliding shear sleeve.

10. The ball seat release device according to claim 1, further comprising: The first circumferential seal is located between the shear sleeve and the ball seat, near the one or more first fluid bypass ports and above the well. The second circumferential seal is located between the shear sleeve and the ball seat, near the one or more first bypass ports and downhole; And a third circumferential seal, located between the shear sleeve and the ball seat, near the one or more second fluid bypass ports and downhole.

11. A well system comprising: A casing string, which is fixed inside a wellbore that extends through one or more underground formations; A casing hanger and a casing string, which are suspended at and close to the downhole end of the casing string; and A ball seat release device, connected to the vicinity of the downhole end of the running tool and positioned within at least a portion of the liner hanger or the liner string, the ball seat release device comprising: A shearing sleeve having a recessed pocket positioned along a portion of its inner surface, the shearing sleeve further comprising a second shoulder, the second shoulder being a downhole shoulder configured to engage with a shoulder in a bridging joint, the shearing sleeve being configured to slide within the bridging joint; and A ball seat body slidably engages within the shear sleeve, the ball seat body being configured to move relative to the shear sleeve from a first linear position to a second linear position, wherein a shearing feature releasably connects the ball seat body to the shear sleeve, the ball seat body comprising: Longitudinal fluid channel; A ball seat is located in the longitudinal fluid channel; One or more first fluid bypass ports connecting the longitudinal fluid channel and the exterior of the ball seat, the one or more first fluid bypass ports being located on a first side of the ball seat; and One or more second fluid bypass ports are connected to the longitudinal fluid channel and the exterior of the ball seat, the one or more second fluid bypass ports being located on a second opposite side of the ball seat.

12. The well system of claim 11, wherein the shear sleeve includes a locking latch feature.

13. The well system of claim 12, wherein the recess is a first recess, wherein the ball seat body includes a second recess positioned along a portion of its outer surface, the locking latch feature being configured to retract radially into the second recess when the ball seat body is in the second linear position to lock the ball seat body and the shear sleeve relative to each other.

14. The well system of claim 11, wherein the concave bag, the one or more first fluid bypass ports, and the one or more second fluid bypass ports are configured to provide a fluid flow path around a drop ball or plug engaged with the ball seat when the ball seat body is in the second linear position.

15. The well system of claim 14, wherein the distance between the one or more first fluid bypass ports and the one or more second fluid bypass ports is greater than the width of the concave pocket.

16. The well system of claim 15, wherein the ball seat has a first outer diameter near the one or more first fluid bypass ports and a second smaller outer diameter near the one or more second fluid bypass ports.

17. The well system of claim 16, wherein when the ball seat is in the first linear position, the one or more first fluid bypass ports are not radially aligned with the concave pocket, but when the ball seat is in the first linear position, the one or more second fluid bypass ports are radially aligned with the concave pocket, and when the ball seat is in the second linear position, the one or more first fluid bypass ports are radially aligned with the concave pocket, but when the ball seat is in the second linear position, the one or more second fluid bypass ports are not radially aligned with the concave pocket.

18. A method for completing a well system, comprising: The casing hanger and casing string are deployed within the casing string using a running tool, wherein a ball seat release device is connected near the downhole end of the running tool, the ball seat release device comprising: A shearing sleeve having a recessed pocket positioned along a portion of its inner surface, the shearing sleeve further comprising a second shoulder, the second shoulder being a downhole shoulder configured to engage with a shoulder in a bridging joint, the shearing sleeve being configured to slide within the bridging joint; and A ball seat body slidably engages within the shear sleeve, the ball seat body being configured to move relative to the shear sleeve from a first linear position to a second linear position, wherein a shearing feature releasably connects the ball seat body to the shear sleeve, the ball seat body comprising: Longitudinal fluid channel; A ball seat is located in the longitudinal fluid channel; One or more first fluid bypass ports connecting the longitudinal fluid channel and the exterior of the ball seat, the one or more first fluid bypass ports being located on a first side of the ball seat; and One or more second fluid bypass ports are connected to the longitudinal fluid channel and the exterior of the ball seat, the one or more second fluid bypass ports being located on a second opposite side of the ball seat; Position the liner hanger near the bottom end of the casing string; A drop ball or plug is placed inside the sleeve post, with the drop ball or plug abutting against the ball seat; and Pressing the ball or plug against the ball seat to set the liner hanger and fix the liner string relative to the casing string, and then moving the downhole tool to move the ball seat body from the first linear position to the second linear position, and providing a downhole fluid path for the ball seat release device.

19. The method of claim 18, wherein moving the downhole tool to the bottom to move the ball seat from the first linear position to the second linear position comprises: The shearing sleeve and the ball seat are moved downhole until the second shoulder of the shearing sleeve engages with the shoulder of the bridging joint, and the shearing sleeve and the ball seat are linearly connected to each other via the shearing feature; as well as Continue moving the ball seat downhole until the shearing feature shears and allows the ball seat to move from the first linear position to the second linear position.

20. The method of claim 19, wherein continuing to move the ball seat downhole until the shearing feature shears and allowing the ball seat to move from the first linear position to the second linear position comprises aligning the one or more first fluid bypass ports with the concave bag.

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