The present disclosure relates to downhole force setting apparatus. In particular, the present disclosure relates to valves which can be adjusted to provide a plurality of forces.
During the course of well testing operations, various downhole tools can be used, such as samplers and packers. A packer is used to provide a seal between the outside of the production tubing and the inside of the casing, liner, or wellbore wall. Packers isolate zones by packing off between the inside of the casing, or open hole, and outside the tubing. Closing off the space between the casing and tubing directs oil and gas up to the surface through the tubing. Most packers have a locking mechanism that is unlocked once downhole to activate the packer and to ensure the packer is not set or activated while it is running in and out of the wellbore. Samplers utilize a triggering mechanism to capture reservoir fluids in its chamber. The triggering mechanism can be a rupture disk initiated by a certain applied annular pressure, which causes the rupture disk to burst and allows fluid to flow through the passageway.
In order to describe the manner in which the above-recited and other advantages and features of the disclosure can be obtained, a more particular description of the principles briefly described above will be rendered by reference to specific embodiments thereof which are illustrated in the appended drawings. Understanding that these drawings depict only exemplary embodiments of the disclosure and are not therefore to be considered to be limiting of its scope, the principles herein are described and explained with additional specificity and detail through the use of the accompanying drawings in which:
Various embodiments of the disclosure are discussed in detail below. While specific implementations are discussed, it should be understood that this is done for illustration purposes only. A person skilled in the relevant art will recognize that other components and configurations may be used without parting from the spirit and scope of the disclosure. Additional features and advantages of the disclosure will be set forth in the description which follows, and in part will be obvious from the description, or can be learned by practice of the herein disclosed principles. The features and advantages of the disclosure can be realized and obtained by means of the instruments and combinations particularly pointed out in the appended claims. These and other features of the disclosure will become more fully apparent from the following description and appended claims, or can be learned by the practice of the principles set forth herein.
Disclosed herein is a downhole force setting apparatus which may be located within the wall of a sampler assembly, packer, or other downhole tool that utilizes downhole force for activation. The downhole force setting apparatus can have multiple configurations, from generating a smaller force and gradually increasing or decreasing the force generated, as desired. The force setting device includes a valve, such as a rotary valve, which selectively covers and uncovers one or more ports to permit entry of fluid from the borehole into a settable device, such as a packer. The valve may be actuated to uncover and cover the one or more ports based on a predetermined detected downhole property, such as pressure. Upon uncovering one or more ports, and in particular, as more ports are uncovered, additional fluid is permitted into the settable device, thereby increasing the force generated. For example, a packer may be set by actuating the locking mechanism via the force generated.
While the exemplary operating environment depicted in
The plurality of ports 204 can correspond to a plurality of pistons. The ports 204 are configured to allow fluid to flow into the ports 204 into and through the pistons connected to the ports 204. The valve 206 also includes a low pressure port 208 through which fluid can flow. The low pressure port 208 has a diameter larger than the diameters of the plurality of ports 204. Accordingly, the fluid flowing through the plurality of ports 204 flows with a greater velocity than the fluid flowing through the low pressure port 208.
The valve 206 may be provided in various shapes and sizes. For example, the valve 206 may include an elongated portion 210 which can have ends 212 that extend substantially perpendicularly from the elongated portion 210. The valve 206 may be rotatable to cover one or more ports 204. For example, the valve 206 can have an elongated body with the ends extending to create a “hook” shape and rotatable such that the ends can cover or uncover one or more of the plurality of ports 204. Fluid, such as high pressurized oil, from the tubing or annulus or a fluid reservoir that is a part of the tool itself, may flow from the plurality of pistons and be discharged through the plurality of ports 204 on the valve manifold 202. In some examples, fluid can be restricted by covering one or more ports 204 with the valve 206. An electric motor can rotate the valve 206, which can be biased in one direction. In other examples, the valve 206 can translate or rotate in two or more directions. High pressurized oil flows through the pistons and out of the ports away from the rotary valve 206. As illustrated in
The valve housing section 312 and a mandrel 318 can define an annular region inside the sampler assembly 300 in which one or more samplers 302 may be disposed. The samplers 302 can receive and store fluid for sampling either within the sampling assembly 300 or when retrieved at the surface. The valve housing section 312 of the body 304 can form a sample port 320, which permits fluid communication from outside the sample assembly 300, for example to receive fluid from the well. The fluid can flow from the sample port 320 to one or more of the samplers 302 through pistons 324 and fluid passages 326. In the illustrated example, nine samplers 302 are positioned in the annular region. In some examples, more or less than nine samplers 302 may be implemented.
A rupture disk 316 initially isolates the fluid chamber section 308 from the air chamber 314. The fluid chamber section 308 captures reservoir fluids. In some examples, more than one rupture disk 316 may be used for a discrete triggering event. In some examples, rupture disks 316 may be ruptured when exposed to predetermined forces. When a pressure differential between the outside well zone and the air chamber section 314 reaches a predetermined level, the rupture disk 316 ruptures, thus permitting fluid to flow from the fluid chamber section 308 through the air chamber section 314 into the sample chamber section 310.
According to some examples, the sampler assembly 300 can be disposed in the wellbore, with the samplers 302 closed to prevent fluid from entering the samplers 302. Once the sampler assembly 300 has been deployed to a desired location, an elevated fluid pressure may be applied to the sampler assembly 300 that is above the threshold pressure needed to rupture the rupture disk 316. Once the rupture disk 316 is ruptured, the fluid is communicated to a longitudinal conduit 322, which in turn is communicated through the pistons 324 and fluid passages 326 to the respective samplers 302. The fluid, under elevated annular fluid pressure, when communicated to the samplers 302 actuates a sampler activation mechanism in each of the samplers 302 to open up respective valves corresponding to ports to allow fluid in the carrier inner bore to flow into the samplers 302. Before the rupture disk 316 is ruptured, the longitudinal conduit 322, pistons 324, and fluid passages 326 may be filled with air, aqueous or an oligeanous fluid or any other suitable fluid.
As illustrated in
For example, the valve 206 on the downhole force setting apparatus 200 is actuatable to open the ports 320 to enable fluids to flow into the samplers 302. The downhole force setting apparatus 200 is adjustable to generate different forces as discussed above to rupture disks 316 in the sampler assembly 300. For example, as the valve 206 uncovers more ports 204, the fluid flows at a greater velocity and generates a greater force which can cause the rupture disk 316 coinciding with a set of samplers 302 to rupture and cause fluid to flow into those samplers 302. The valve 206 can cover and/or uncover a predetermined number of ports 204 to control the fluid to flow at a predetermined velocity and generates a predetermined force to rupture a predetermined rupture disk 316 coinciding with a desired set of samplers 302. In at least one example, each individual port 204 on the downhole force setting apparatus 200 can be connected to a different rupture disk 316 (i.e., set of samplers). Once ruptured, fluid flows through the longitudinal conduit 322 and the pistons 324 shift, allowing the fluid to flow through the fluid passage 326 and into the samplers 302.
Fluid flow through the fluid ports 404 is initially blocked by the presence of the downhole force setting apparatus 200. The actuating pistons 412 move a locking mechanism out of the way so that packer 400 can be set and can move locking mechanism back so the packer 400 is unset. The locking mechanism is includes the valve 206 and the actuating sleeve 414. The downhole force setting apparatus 200 can provide a predetermined force, as discussed above, to the packer elements by rotating or selectively covering and uncovering the ports 404. The valve 206 on the downhole force setting apparatus 200 in a closed configuration blocks the fluid ports 404, such that fluid is provided to the packer elements such that the packer 400 is unset. Selectively setting and unsetting the packer can be done with a pressure sensor on a controller to sense a pressure pulse in order to activate the packer 400. In some examples, this can be done by an automatic setting. For example, when the pressure is a particular predetermined pressure downhole, such as about 500 psi, a certain number of ports 204 are exposed on the apparatus 200 to activate the packer 400. When the packer 400 is at low hydrostatic pressure, enough force can be generated to compress the packer 400 and then swell it out against the walls of the wellbore. This is done by exposing a greater number of ports 204 to increase the force from the fluid flowing across the downhole force setting apparatus 200. In other examples, more ports 204 can be covered such that more fluid flows through the low pressure port 208 and less fluid flows through the ports 204, and the force from the fluid flowing across the downhole force setting apparatus 200 can be decreased to the desired level. Accordingly, the downhole force setting apparatus 200 can adjust the amount of force from the fluid flowing therethrough to any desired level of a plurality of levels. The pressurized fluid then adds pressure to the pistons 412 to actuate the pistons 412. A hydraulic line can lead to the actuating pistons 412, which can convey hydraulic fluid to the packer 400 to expand the packer 400.
In some examples, the hydrostatically operated downhole force setting apparatus 200 can be adjusted to permit fluid to flow at a greater velocity from one portion of the downhole force setting apparatus 200 and a lower velocity on an opposing side of the downhole force setting apparatus 200. The hydrostatic pressure from the fluid applies a force to the sealing element to move it to its expanded position. The actuating pistons 412 can be mounted between the sealing element and mandrel 402. A locking mechanism can be used for the actuating mechanism, where the locking mechanism is responsive to a predetermined force. For example, force from fluid under wellbore hydrostatic pressure can bear upon the pressure receiving area 408 of the actuating pistons 412 and urge the pistons 412 to move axially upwardly. A downhole force setting apparatus 200 can compress the packer 400 axially to cause it to expand radially and become set.
In some examples, an actuating sleeve 414 also surrounds the central mandrel 402 below the ring. The actuating sleeve 414 can set the packer element that is correspondingly positioned on the radial exterior of the central mandrel 402. During setting of the packer assembly 400, the actuating sleeve 414 may remain stationary with respect to the central mandrel 402. The downhole force setting apparatus 200 can move the actuating sleeve axially. This movement of the actuating sleeve 414 can shear screws and permit fluid to flow through the fluid communication ports 404, which unlocks the actuating pistons 412 from engagement with the central mandrel 402. As movement of the actuating sleeve 414 unblocks the fluid ports 404, hydrostatic fluid pressure present within the wellbore 104 is then transmitted through the ports 404 and enters the pressure receiving area 408.
Referring to
At block 502, the downhole force setting apparatus 200 is deployed with a downhole tool in a wellbore. The downhole force setting apparatus 200 can be deployed within a sampler assembly 300 or a packer assembly 400. The downhole force setting apparatus 200 is used to apply a more accurate force to the elements of the downhole tool that is deployed within. The force applied to the elements of the downhole hole depends on the hydrostatic changes from well to well or changes in hydrostatic pressure from within the same well.
At block 504, the valve is translated to cover one or more ports of the valve manifold. The translation depends on the pressure downhole which is communicated using an acoustic system or pressure profile. The pressure downhole can be sensed by a pressure sensor on a controller. For example, a pressure pulse is sent up and a measurement of the annulus pressure is sent up, which is then used to determine how to control the valve. The pressure can also be pre-programmable and set up automatically.
At block 506, fluid is permitted to flow across the valve manifold. High pressurized fluid is transmitted through the valve and surrounds the valve when the ports are covered. The more pistons that are covered the less force is applied. If all ports are covered by the valve, then no force is generated. The force can be adjusted in as many increments as there are ports on the valve manifold. The ports can go to a single staged piston or multiple pistons to function a downhole tool.
While the foregoing is directed to embodiments of the present disclosure, other and further embodiments of the disclosure may be devised without departing from the basic scope thereof, and the scope thereof is determined by the claims that follow. Those skilled in the art, having the benefit of this disclosure, will appreciate numerous modifications and variations therefrom. It is intended that the appended claims cover all such modifications and variations as fall within the true spirit and scope of this present disclosure.
Filing Document | Filing Date | Country | Kind |
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PCT/US2019/055315 | 10/9/2019 | WO |