Patent Application
20250116274
In the resource recovery and fluid sequestration industries, a drill string is used to create a borehole in an earth formation. A drill bit at a downhole end of the drill string rotates, thereby creating cuttings. A drilling fluid or drilling mud is circulated through the drill string to exit into the borehole at a downhole end. The drilling fluid then flows uphole through an annulus to remove the cuttings from the borehole. Before being sent downhole, the drilling fluid can be treated with additives. Additives have a certain level of coarseness. The coarser the additive, the more they can wear on the drilling equipment. Therefore, it is generally desirable to have additives be as fine as possible. Accordingly, there is a need for a system and method for shearing the additives in the drilling fluid prior to circulation of the drilling fluid downhole.
Disclosed herein is a method for shearing a fluid. A disk of a turbine is rotated at a selected speed. The fluid flows across a surface of the disk to shear the fluid. The fluid is expelled from the turbine at a fluid outlet of the turbine.
Also disclosed herein is a system for shearing a fluid. The system includes a turbine having a rotational axis, a fluid inlet for receiving the fluid, a disk rotatable about the rotational axis at a selected speed, wherein the disk shears the fluid as the fluid moves across a surface of the disk, and a fluid outlet at a circumferential location of the turbine for expelling the fluid from the turbine.
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
A drilling fluid circulation system 116 includes a fluid storage device 118 that stores the drilling fluid 114 at the surface location 110 and an injection pipe 120 that extends from the fluid storage device 118 to a top end of the drill string 106. The injection pipe 120 includes a pump 122 for pumping the drilling fluid 114 from the fluid storage device 118 into the drill string 106. The drilling fluid 114 flow downhole through a central bore of the drill string 106 to exit into the borehole 102 at the drill bit 112. The drilling fluid 114 then flows to the surface through an annulus 124 between the drill string 106 and a wall 126 of the borehole 102. At the surface location 110. the drilling fluid 114 returns to the fluid storage device 118 via a return pipe 128.
The drill string 106 is an example of a work string suitable for use in the borehole 102. The methods disclosed herein are not limited to use with a drill string 106 and can be used with other types of work strings.
Additives can be included in the drilling fluid. The additives can be grains that can come in varying sizes, such as large and coarse or small and fine. A fluid shearing device 130 can be used to shear the drilling fluid (i.e., to break up the additives in the drilling fluid from coarse particles to fine particles). In one embodiment, the fluid shearing device 130 can be located in the injection pipe 120. In another embodiment, the fluid shearing device 130 can be located at a location that is independent of the drilling fluid circulation system 116 and can be used to shear the drilling fluid before the drilling fluid is placed in the fluid storage device 118.
The at least two disks 306 impart a radially outward velocity on the drilling fluid 114 that is in the gap 310 by dragging the drilling fluid along their surfaces as the at least two disks 306 rotate. Fluid particles along a boundary layer of the fluid at the surfaces of the at least two disks 306 travels at a first velocity while fluid particles away from the surfaces travel at a second velocity. The difference in these velocities produces a shear stress within the drilling fluid 114. The shear stress is imparted to the additive particles, causing the additive particles to break up, disintegrate, or change from a having a first coarseness (e.g., coarse) to a second coarseness (e.g., fine). At the circumference of the at least two disks 306, the fluid exits the gap 310 and leaves the turbine 202 via the fluid outlet 320. The speed of rotation of the at least two disks 306 can affect the degree of shearing that occurs in the fluid. In various embodiments, the disks are rotated at a selected speed such as, for example. about 20,000 rotations per minute.
The fluid is sheared based on various forces. For example, due to the high velocity of rotation of the disk, the fluid and its additive particles are flung by the disk against the housing at high speeds, thereby shearing the fluid. Also, due to the width of the gap between the disks, the fluid has high internal friction between a boundary layer of the fluid and a layer away from the disks. This internal friction causes viscous bonding of the fluid to breaking, thereby shearing the fluid.
The fluid that is sheared by the methods disclosed herein is describes as a drilling fluid. In various embodiments. the fluid is any fluid that includes two or more components. A first component can be a first fluid, and a second component can be a second fluid or an additive or additive particle. In various embodiments, the fluid can be any type of fluid including. but not limited to, a drilling fluid, a frac fluid, a drill-in fluid, a packer fluid.
Set forth below are some embodiments of the foregoing disclosure:
Embodiment 1. A method for shearing a fluid. A disk of a turbine is rotated at a selected speed. The fluid flows across a surface of the disk to shear the fluid. The fluid is expelled from the turbine at a fluid outlet of the turbine.
Embodiment 2. The method of any prior embodiment, wherein the disk includes at least two disks.
Embodiment 3. The method of any prior embodiment, further including flowing the fluid into the turbine along a rotational axis of the turbine, wherein rotating the disk imparts a radially outward velocity to the fluid.
Embodiment 4. The method of any prior embodiment, wherein the fluid has an additive particle, further including shearing the fluid by dragging the particle along the surface of the disk via rotation of the disk to disintegrate the additive particle.
Embodiment 5. The method of any prior embodiment, further including injecting the fluid expelled from the turbine into one of: (i) a storage device; and (ii) a drill string.
Embodiment 6. The method of any prior embodiment, wherein the fluid includes an additive particle and the turbine includes a first turbine and a second turbine, the first turbine includes a first set of disks defining a first gap having a first separation distance and the second turbine includes a second set of disks defining a second gap having a second separation distance less than the first separation distance, further including injecting the fluid into the first turbine to obtain a first level of coarseness of the additive particle and injecting the fluid from the first turbine into the second turbine obtain a second level of coarseness of the additive particle.
Embodiment 7. The method of any prior embodiment, wherein the fluid is one of: (i) a drilling fluid, (ii) a frac fluid, (iii) a drill-in fluid. and (iv) a packer fluid.
Embodiment 8. A system for shearing a fluid. The system includes a turbine having a rotational axis, a fluid inlet for receiving the fluid, a disk rotatable about the rotational axis at a selected speed, wherein the disk shears the fluid as the fluid moves across a surface of the disk, and a fluid outlet at a circumferential location of the turbine for expelling the fluid from the turbine.
Embodiment 9. The system of any prior embodiment, wherein the disk includes at least two disks.
Embodiment 10. The system of any prior embodiment, wherein the disk is configured to impart a radially outward velocity to the fluid.
Embodiment 11. The system of any prior embodiment, wherein the fluid is a drilling fluid having an additive particle, further including shearing the drilling fluid by dragging the additive particle along the surface of the disk via rotation of the disk to disintegrate the additive particle.
Embodiment 12. The system of any prior embodiment, wherein the fluid outlet is configured to transfer the fluid from the turbine into one of: (i) a storage device; and (ii) a drill string.
Embodiment 13. The system of any prior embodiment, wherein the turbine includes a first turbine and a second turbine, the first turbine includes a first set of disks defining a first gap having a first separation distance and the second turbine includes a second set of disks defining a second gap having a second separation distance less than the first separation distance, and a fluid transfer line between a fluid outlet at the circumferential location of the first turbine to an inlet along the rotational axis of the second turbine.
Embodiment 14. The system of any prior embodiment, wherein the fluid includes an additive particle and rotation of the first set of disks obtains a first level of coarseness of the additive particle and rotation of the second set of disks injecting the fluid from the first turbine into the second turbine obtain a second level of coarseness of the additive particle.
Embodiment 15. The system of any prior embodiment, wherein the fluid includes at least a first component including a first fluid and second component, the second component includes one of: (i) a second fluid; and (ii) an additive particle.
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% 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 borehole, and/or equipment in the borehole, 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.
