Patent Application
20230167704
In the resource recovery and fluid sequestration industries, plugs are often set in a borehole in order to perform downhole operations. In various plug systems, the plug is set via a rotation of the plug once it is at its target location downhole. Setting multiple plugs can require multiple trips downhole, which is both time-consuming and expensive. Attempts to set two or more plugs in a single trip is hindered by rigid connection between plugs. Thus, once a lower plug is set, the plugs above it are prevented from being able to rotate to set itself in the borehole. There is therefore a need to be able to set multiple plugs downhole in a single trip that allows flexibility of rotation between the plugs.
Disclosed herein is a method of performing an operation in a borehole. A ball is seated at a seat member in a flow passage of an inner sleeve, the inner sleeve disposed at a first position within an outer sleeve in a locked configuration of a plug. A fluid pressure at the ball moves the inner sleeve from the first position to a second position within the outer sleeve to place the plug in an unlocked configuration. The seat member is moved radially outward via the fluid pressure at the ball to open the flow passage with the inner sleeve at the second position.
Also disclosed herein is a downhole device. The downhole device includes an outer sleeve defining a bore therethrough, an inner sleeve disposed within the bore and axially movable with respect to the outer sleeve between a first position and a second position, the inner sleeve defining a flow passage, and a seat member in the flow passage for seating a ball when the inner sleeve is at the first position. A fluid pressure on the ball moves the inner sleeve from the first position to the second position, moves the seat member radially outward out of the flow passage when the inner sleeve is at the second position, and pushes the ball out of the flow passage.
The following descriptions should not be considered limiting in any way. With reference to the accompanying drawings, like elements are numbered alike:
A detailed description of one or more embodiments of the disclosed apparatus and method are presented herein by way of exemplification and not limitation with reference to the Figures.
Referring to
The retrieving head 202 is coupled to the top end 205 of the ball valve 206. The first lock 204 is attached to the top end 205 of the ball valve 206. The first lock 204 and the top end 205 of the ball valve 206 are disposed within the retrieving head 202. A bottom end 207 of the ball valve 206 is coupled to a top end of the plug 208. Actuation of the ball valve 206 (Le., opening and/or closing the ball valve 206) is affected by a limited rotation of a top end 205 of the ball valve 206 and the bottom end 207 of the ball valve, the bottom end 207 including a bottom sub (see bottom sub 1302 of
The first lock 204 and the second lock 222 can each be in either a locked configuration or an unlocked configuration. When the first lock 204 is in a locked configuration, the sub-assemblies of first plug assembly 116 are rigidly connected to each other. The plug assembly as a whole can be rotated within the borehole. When the first lock 204 is in an unlocked configuration, the retrieving head 202 is free to move axially with respect to the ball valve 206. When the second lock 222 is in a locked configuration, a mandrel of the plug 208 and a wall-engaging component of the plug 208 are rigidly connected to each other and can be rotated as a unit. When the second lock 222 is in an unlocked configuration, the mandrel of the plug 208 and the wall-engaging component of the plug 208 are in a configuration that allows them to rotate independently of each other.
The first plug assembly 116 is conveyed into the borehole with the first lock 204 and the second lock 222 both in the locked configuration. A ball 230 is dropped into the string 102 from the surface location 108 and is allowed to fall through the bore 215. When the ball lands at the first lock 204, an increase of a first fluid pressure behind the ball 230 cause the first lock 204 to release (i.e., move from a locked configuration to an unlocked configuration). As the ball 230 lands at the plug 208, an increase of a second fluid pressure behind the ball 230 causes the second lock 222 to release (i.e., move from a locked configuration to an unlocked configuration).
The ball 230 is made of an elastically deformable material. Thus, the ball 230 can be deformed or be compressed from its original (or unstressed) shape by applying a compressive force to it. Once the compressive force is removed, the ball 230 returns to its original shape. The ball 230 experiences elastic deformation as it activates the first lock 204 and the second lock 222. The amount of compressive deformation applied on the ball 230 as it traverses the first lock 204 and the second lock 222 is within a range of elasticity of the ball 230.
The ball valve 206 includes a clutch mechanism 224 on its outer surface. The clutch mechanism 224 can be engaged by applying a set down force via the retrieving head 202. Removing the set down force disengages the clutch. in the disengaged state, the clutch is free to rotate separately from the ball valve 206. The ball valve 206 is connected to the mandrel of the plug 208 and the wall-engaging component of the plug 208. When the clutch is in the disengaged position, the lower end of the ball valve 206 and attached mandrel of the plug 208 are free to rotate with respect to the wall-engaged component of the plug 208. When the clutch mechanism 224 is engaged, the bottom end 207 of the ball valve 206 becomes rigidly coupled to the wall-engaging component of the plug 208. Thus, the clutch mechanism 224 can be engaged to allow a torque to be applied at the ball valve 206, mandrel and wall-engaging component. The top end 205 of the ball valve 206 can be rotated with respect to the bottom end 207 of the ball valve 206, thereby effecting actuation of the ball valve 206.
The retrieving head 202 includes a sleeve 225 that extends axially over a portion of the ball valve 206. When the first lock 204 is in an unlocked configuration, the retrieving head 202 is free to move axially with respect to the ball valve 206. The clutch mechanism 224 can then be engaged or coupled to the ball valve 206 by moving the retrieving head 202 axially with respect to the ball valve 206 to push the sleeve 225 against the clutch mechanism 224. When the clutch mechanism 224 is engaged, the bottom end 207 of the ball valve 206, the mandrel of the plug and the wall-engaging components of the plug are rigidly coupled together. The clutch mechanism 224, the bottom end 207 of the ball valve 206, the mandrel of the plug and the wall-engaging components of the plug are therefore rotationally stationary in the borehole as the plug 208 is set in the borehole. The top end 205 of the ball valve 206 remains free to rotate when the clutch mechanism 224 is engaged.
A shear member 520 secures the ball seat 506 within the lock housing 502 at a first location. The shear member 520 can be a shear pin or shear screw or other shear device, in various embodiments. In an embodiment, the ball seat 506 include a first hole 516 on its outer surface. A second hole 518 is located on an interior surface of the lock housing 502. In the locked configuration, the ball seat 506 is secured at a first location in the lock housing 502 at which the first hole 516 and the second hole 518 are axially aligned. The shear member 520 resides within the first hole 516 and the second hole 518 to secure the ball seat 506 within the lock housing 502 at the first location.
The lock mandrel 504 extends along the longitudinal axis 508 from a first mandrel end 522 to a second mandrel end 524. In the locked configuration, the ball seat 506 is at a first seat location and the lock mandrel is at a first mandrel location. At the first mandrel location, the second mandrel end 524 is disposed within the bore 215 of the lock housing 502 at the first housing end 510 with the remainder of the lock mandrel 504 residing outside of the bore 215. A retainer 526 is coupled to the first housing end 510 and traps the second mandrel end 524 within the bore 215. The second mandrel end 524 includes a ridge 528 on its outer surface. In the locked configuration, the ridge 528 is seated at a receiving portion 530 of the ball seat 506. The retainer 526 and the receiving portion 530 of the ball seat 506 reside on opposite sides of the ridge 528 and maintain the ridge 528 and, by extension, the lock mandrel 504 in a stationary position with respect to the lock housing 502. A snap ring 532 is wrapped around the exterior surface of the receiving portion 530 of the ball seat 506 while the first lock 204 is in the locked configuration. The snap ring 532 resides partially in a groove 534 formed in an inner surface of the lock housing 502. A portion of the snap ring 532 lies against the ridge 528 of the lock mandrel 504 to prevent axial motion of the lock mandrel 504.
As shown in
The inner sleeve 804 includes a dog slot 814 extending radially through the body of the inner sleeve 804. A seat member such as a dog 816 is disposed in the dog slot 814. An outer surface of the inner sleeve 804 includes a recess 818. The inner sleeve 804 has a first outer diameter and the recess 818 has a second outer diameter that is less than the first outer diameter. The recess 818 extends around the circumference of the inner sleeve 804. When the key slot 808 is not axially aligned with the recess 818 of the inner sleeve 804, the outer surface of the inner sleeve 804 prevents the key 810 from collapsing radially inward. When the dog slot 814 is not axially aligned with the profile 812, the inner surface of the outer sleeve 802 prevents outward motion of the dog 816 out of the dog slot 814. The inner sleeve 804 can move within the outer sleeve 802 to place the key slot 808 in axial alignment with the recess 818 and the dog slot 814 in axial alignment with the profile 812.
Referring back to
A torque clutch 1308 is disposed around an outer surface of the bottom sub 1302 uphole of the torque lock nut 1310. The torque clutch 1308 is biased away from the flanged end 1306. A key 1315 extends through the torque clutch 1308 and into a hole 1314 in the outer surface of the bottom sub 1302 to keep the torque clutch 1308 rotationally locked to the bottom sub 1302. In various embodiments, a spring 1316 can be used to bias a spring retainer 1318 of the torque clutch 1308 away from the flanged end 1306. The sleeve 225 is shown uphole of the torque clutch 1308.
Once the torque clutch 1308 is disengaged from the torque lock nut 1310, the bottom sub 1302 is free to rotate independently of the torque lock nut 1310. With the ball valve 206 in either of the closed or open configuration, the torque clutch 1308 can be axially reengaged to the torque lock nut 1310 to allow torque against the bottom sub 1302, thereby allowing the closed or open configuration of the ball valve.
Set forth below are some embodiments of the foregoing disclosure:
Embodiment 1. A method of performing an operation in a borehole. The method includes seating a ball at a seat member in a flow passage of an inner sleeve, the inner sleeve disposed at a first position within an outer sleeve in a locked configuration of a plug, moving, via fluid pressure at the ball, the inner sleeve from the first position to a second position within the outer sleeve to place the plug in an unlocked configuration, and moving the seat member radially outward via the fluid pressure at the ball to open the flow passage with the inner sleeve at the second position.
Embodiment 2. The method of any prior embodiment, wherein the outer sleeve includes a key slot therein and a key disposed in the key slot and the inner sleeve includes a recess on its outer surface, further comprising moving the inner sleeve to an intermediate position between the first position and the second position to axially align the key slot with the recess to allow the key to collapse into the recess.
Embodiment 3. The method of any prior embodiment, further comprising rotating the plug with the key in the recess.
Embodiment 4. The method of any prior embodiment, wherein the inner sleeve maintains the key radially outward when the inner sleeve is in the first position.
Embodiment 5. The method of any prior embodiment, wherein the seat member is a dog in a dog slot of the inner sleeve.
Embodiment 6. The method of any prior embodiment, wherein the outer sleeve includes a profile on its inner surface, further comprising moving the inner sleeve to the second position to axially align the dog slot with the profile to allow the dog to move radially outward into the profile to open the flow passage.
Embodiment 7. The method of any prior embodiment, wherein the outer sleeve maintains the dog radially inwards when the inner sleeve is in either the first position or an intermediate position.
Embodiment 8. The method of any prior embodiment, further comprising forcing the ball out of the inner sleeve via the fluid pressure when the flow passage is open.
Embodiment 9. A downhole device. The downhole device includes an outer sleeve defining a bore therethrough, an inner sleeve disposed within the bore and axially movable with respect to the outer sleeve between a first position and a second position, the inner sleeve defining a flow passage, and a seat member in the flow passage for seating a ball when the inner sleeve is at the first position and wherein a fluid pressure on the ball moves the inner sleeve from the first position to the second position, moves the seat member radially outward out of the flow passage when the inner sleeve is at the second position, and pushes the ball out of the flow passage.
Embodiment 10. The downhole device of any prior embodiment, wherein the outer sleeve includes a key slot therein and a key disposed in the key slot and the inner sleeve includes a recess on its outer surface, wherein the key slot is axially aligned with the recess when the inner sleeve is at an intermediate position between the first position and the second position to allow the key to collapse into the recess.
Embodiment 11. The downhole device of any prior embodiment, further comprising a plug that is free to rotate when the key is in the recess.
Embodiment 12. The downhole device of any prior embodiment, wherein the inner sleeve maintains the key radially outward when the inner sleeve is in the first position.
Embodiment 13. The downhole device of any prior embodiment, wherein the seat member is a dog in a dog slot of the inner sleeve.
Embodiment 14. The downhole device of any prior embodiment, wherein the outer sleeve includes a profile on its inner surface, wherein the dog slot is axially aligned with the profile with the inner sleeve is in the second position, thereby allowing the dog to move radially outward into the profile to open the flow passage.
Embodiment 15. The downhole device of any prior embodiment, wherein the outer sleeve maintains the dog radially inwards when the inner sleeve is in either the first position or an intermediate position.
The use of the terms “a” and “an” and “the” and similar referents in the context of describing the invention (especially in the context of the following claims) are to be construed to cover both the singular and the plural, unless otherwise indicated herein or clearly contradicted by context. Further, it should be noted that the terms “first,” “second,” and the like herein do not denote any order, quantity, or importance, but rather are used to distinguish one element from another. The terms “about”, “substantially” and “generally” are intended to include the degree of error associated with measurement of the particular quantity based upon the equipment available at the time of filing the application. For example, “about” and/or “substantially” and/or “generally” can include a range of ±8% or 5%, or 2% of a given value.
The teachings of the present disclosure may be used in a variety of well operations. These operations may involve using one or more treatment agents to treat a formation, the fluids resident in a formation, a wellbore, and/or equipment in the wellbore, such as production tubing. The treatment agents may be in the form of liquids, gases, solids, semi-solids, and mixtures thereof. Illustrative treatment agents include, but are not limited to, fracturing fluids, acids, steam, water, brine, anti-corrosion agents, cement, permeability modifiers, drilling muds, emulsifiers, demulsifiers, tracers, flow improvers etc. Illustrative well operations include, but are not limited to, hydraulic fracturing, stimulation, tracer injection, cleaning, acidizing, steam injection, water flooding, cementing, etc.
While the invention has been described with reference to an exemplary embodiment or embodiments, it will be understood by those skilled in the art that various changes may be made and equivalents may be substituted for elements thereof without departing from the scope of the invention. In addition, many modifications may be made to adapt a particular situation or material to the teachings of the invention without departing from the essential scope thereof. Therefore, it is intended that the invention not be limited to the particular embodiment disclosed as the best mode contemplated for carrying out this invention, but that the invention will include all embodiments falling within the scope of the claims. Also, in the drawings and the description, there have been disclosed exemplary embodiments of the invention and, although specific terms may have been employed, they are unless otherwise stated used in a generic and descriptive sense only and not for purposes of limitation, the scope of the invention therefore not being so limited.
