Patent ID: 12215556

DETAILED DESCRIPTION

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 toFIG.1, a downhole system100is shown in an illustrative embodiment. The downhole system100includes a string102extending through a borehole104in a formation106from a surface location. In various embodiments, the string102can be a pipe string, a conveyance string, a pumping string, a snubbing string, a drill string, etc. The string102include a drill bit or milling device108at a bottom end110. A downhole tool112is attached to the bottom end110of the string102above the milling device108via a release device114and is conveyed downhole with the string102. In various embodiments, the downhole tool112can be a whipstock, a packer, a screen, a downhole pump, etc. The whipstock includes an angled surface116for diverting a path of the string102. The string102can be conveyed into the borehole104to a desired location. Once the string102is at the desired location, the whipstock is secured to a wall of the borehole104via an anchor118. Rotating the string102with the whipstock anchored in place causes the release device114to shear, thereby allowing the string102to separate from the whipstock. Once separated from the whipstock, the string102can be moved downward, allowing the whipstock to divert the path of the string102to form a secondary borehole.

The string102can include an additional device120for performing other downhole actions. For example, the additional device120can be one or more sensors for measuring a downhole parameter during conveyance of the string102through the borehole104. In another embodiment, the additional device120can be a scraping tool for scraping and/or cleaning the borehole104during conveyance of the string102through the borehole104. In another embodiment, the additional device120can be a pump for pumping or circulating fluid through the string102. The pump can be disposed within the string or disposed at a surface location. The fluid can be pumped through the string102during conveyance of the string102to the desired location or once the downhole tool112has been secured at the desired location. Once the downhole tool112has been secured in borehole, tension. compression and/or a cycling between tension and compression can be applied along a longitudinal axis of the string102.

FIG.2shows a perspective view200of the release device114, in an illustrative embodiment. In the embodiment ofFIG.2, the release device is a bolt202. The bolt202is shown with respect to a string coordinate system205to show a relative orientation of the bolt202with respect to the string102. The string coordinate system205includes a longitudinal string axis (z-axis) oriented along a longitudinal axis of the string102and a radial axis (r-axis) extending radially away from the longitudinal axis. A circumferential axis (θ axis) shows a direction of rotation of the string102.

When attaching the downhole tool112to the string102, a longitudinal bolt axis204is aligned or substantially aligned with the radial axis of the string102. The bolt202is in the general shape of a cylinder that includes a first shank206and a second shank208separated by a shear region210. A transverse cross-section of the bolt202can be circular or can be in the shape of an oval or ellipse, with a major axis of the ellipse aligned with the longitudinal axis of the string102.

The shear region210includes one or more anisotropic shear members212. The anisotropic shear members212have a structure with a first shear axis S1having a first resistance to shear and a second shear axis S2having a second resistance to shear. The second resistance to shear is less than the first resistance to shear. When the bolt202is used to couple the downhole tool112to the string102, the first shear axis S1is aligned with the longitudinal axis of the string102and the second shear axis S2is aligned with the θ axis of the string102.

A shear member212can have a body that extends along a member axis that lies within a transverse plane of the bolt202(i.e., a plane transverse to the longitudinal bolt axis204) and oriented along the first shear axis S1. In an illustrative embodiment, the body of the shear member212can be in the form of a cylinder having its cylinder axis (i.e., longitudinal axis of the cylinder) lying within the transverse plane of the bolt202. As referred to herein, a cross-section perpendicular to the cylinder axis can have any shape, such as circular, oval, square (a four-sided cylinder), hexagonal (a hexagonal cylinder), octagonal, etc.

FIG.3shows a side view300of the bolt202from a location looking along a longitudinal axis of the string102. The first shank206is the innermost shank and is coupled to the string102. The second shank208is the outermost shank and is coupled to the downhole tool112. For each shear member212a first location on a circumferential side of the cylinder connects to a first gap surface214of the first shank206and a second location on the circumferential side of the cylinder diametrically opposite the first location connects to a second gap surface216of the second shank208. A first beam218extends between the first location of the circumferential side of the cylinder to the first gap surface214to mechanically connect the shear member212to the first shank206. Similarly, a second beam220extends between the second location of the circumferential side of the cylinder and the second gap surface216to mechanically connect the shear member212to the second shank208.

A rotation of the string102is shown by torque arrow224. A reaction torque due to the downhole tool112being anchored in the borehole104is shown by reaction arrow226. As these torques are applied, the shear member212rotates (as indicated by shear rotation arrows228), thereby rupturing the first beam218and/or the second beam220. Thus, the first shank206is separated from the second shank208via the rotation of the string102, thereby releasing the downhole tool112from the string102.

Forces applied along the longitudinal axis of the string (i.e., via movement of the string102through the borehole) do not cause this rotation but instead are applied along the first shear axis S1of the shear members212. The shear resistance along the first shear axis S1allows highs forces to be applied in this direction.

FIG.4shows a side view400of the bolt202as seen at a location along the longitudinal axis of the bolt202, in another embodiment. The bolt202includes the first shank206and the second shank208. Thin rectangular parallelepiped structures402a,402b, and402care disposed within the shear region substantially parallel to the gap surfaces of the first shank206and second shank208. Although three rectangular parallelepiped structures402a,402b, and402care shown for illustrative purposes, in other embodiments, any plurality of rectangular parallelepiped structures can be within the shear region. A cross-section of the rectangular parallelepiped structures402a,402b, and402cshows rectangles having a long axis L and a short axis D. A first rectangle can be joined to a second or adjacent rectangle by a connecting beam404a,404b,404c,404dat adjacent ends of their long axes. Rotating the string102ruptures one or more of the connecting beams404a,404b,404cand404d, thereby releasing the downhole tool112from the string102.

FIG.5shows a flowchart500of a method for performing an operation downhole. In box502, a downhole tool is coupled to a string via a release device. The release device shear member has a first shear axis that has a first shear resistance and a second shear axis having a second shear resistance less than the first shear resistance. The first shear axis is aligned with a longitudinal axis of the string and the second shear axis is aligned with a circumferential axis of the string. In box504, the string is moved through a borehole to place the downhole tool at a selected location of the borehole. In box506, the downhole tool is secured within the borehole. In box508, the string is rotated to create a force along the second shear axis that ruptures the shear member, thereby releasing the release device and separating the downhole tool from the string.

In various embodiments, the bolt can be made of a carbon fiber, steel, a Nickel alloy, bronze, or copper.

Set forth below are some embodiments of the foregoing disclosure:

Embodiment 1. A method of performing an operation downhole. A downhole tool is coupled to a string via a release device, the release device including a shear member therein having a first shear axis that has a first shear resistance and a second shear axis having a second shear resistance less than the first shear resistance, wherein the first shear axis is aligned with a longitudinal axis of the string and the second shear axis is aligned with a circumferential axis of the string. The string is conveyed through a borehole to place the downhole tool at a selected location of the borehole. The downhole tool is secured within the borehole. The string is rotated to release the release device.

Embodiment 2. The method of any prior embodiment, wherein the shear member further includes a bolt having a longitudinal bolt axis, the bolt includes a first shank and a second shank separated by a shear region, wherein the shear region includes the shear member therein.

Embodiment 3. The method of any prior embodiment, wherein the shear member includes a body having a member axis oriented within a transverse plane of the bolt and aligned with the longitudinal axis of the string.

Embodiment 4. The method of any prior embodiment, wherein the body is coupled to a first gap surface of the first shank at a first location along a circumferential side of the body and to a second gap surface of the second shank at a second location along the circumferential side of the body diametrically opposite the first location.

Embodiment 5. The method of any prior embodiment, further including a first beam at the first location extending along the member axis and a second beam at the second location extending along the member axis.

Embodiment 6. The method of any prior embodiment, further including rotating the string to separate the shear member from at least one of the first gap surface and the second gap surface.

Embodiment 7. The method of any prior embodiment, further including performing at least one of: (i) measuring a downhole parameter while conveying the string to the selected location; (ii) scraping the borehole while conveying the string to the selected location; (iii) cleaning the borehole while conveying the string to the selected location; (iv) pumping a fluid through the string; (v) applying a compression along the string with the downhole tool secured within the borehole; and (vi) applying a tension along the string with the downhole tool secured within the borehole.

Embodiment 8. A downhole system includes a string, a downhole tool, and a release device configured to couple the downhole tool to the string, the release device including a shear member therein having a first shear axis that has a first shear resistance and a second shear axis having a second shear resistance less than the first shear resistance, wherein the first shear axis is aligned with a longitudinal axis of the string and the second shear axis is aligned with a circumferential axis of the string.

Embodiment 9. The system of any prior embodiment, wherein the release device further includes a bolt having a longitudinal bolt axis, the bolt comprising a first shank and a second shank separated by a shear region, wherein the shear region includes the shear member therein.

Embodiment 10. The system of any prior embodiment, wherein the shear member includes a body having a member axis oriented within a transverse plane of the release device and aligned with the longitudinal axis of the string.

Embodiment 11. The system of any prior embodiment, wherein the body is coupled to a first gap surface of the first shank at a first location along a circumferential side of the body and to a second gap surface of the second shank at a second location along the circumferential side of the body diametrically opposite the first location.

Embodiment 12. The system of any prior embodiment, further including a first beam at the first location extending along the member axis and a second beam at the second location extending along the member axis.

Embodiment 13. The system of any prior embodiment, wherein the shear member is configured to separate from at least one of the first gap surface and the second gap surface upon a rotation of the string.

Embodiment 14. The system of any prior embodiment, wherein the shear member includes a plurality of rectangular parallelepiped structures parallel to a first gap surface of the first shank and a second gap surface of the second shank.

Embodiment 15. The system of any prior embodiment, wherein a transverse cross-section of the release device is in a shape of one of: (i) a circle; (ii) an ellipse; (iii) an oval; (iv) a square; (v) a hexagon; and (vi) an octagon.

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 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.