BLADE FLOW PDC BITS

Abstract

An apparatus that includes one or more flow channels and method for fabricating such flow channels. The apparatus includes a body and one or more blades extending from one end of the body. Each blade includes a leading section, a trailing section, a face section extending from one end of the leading section to an end of the trailing section, and at least one flow channel extending from the leading edge section to the trailing edge section.

Description

RELATED APPLICATIONS

The present application is a non-provisional application of and claims priority under 35 U.S.C. §119 to U.S. Provisional Application No. 61/709,070, entitled “Blade Flow PDC Bits” and filed on Oct. 2, 2012, the entirety of which is incorporated by reference herein.

The present application is related to U.S. Non-Provisional Patent Application No. ______, entitled “Flow Through Gauge For Drill Bit” and filed on Sep. ______, 2013, and U.S. Non-Provisional Patent Application No.

, entitled “Machined High Angle Nozzle Sockets For Steel Body Bits” and filed on Sep. ______, 2013, both of which are hereby incorporated by reference herein.

BACKGROUND

This invention relates generally to drill bits and/or other downhole tools. More particularly, this invention relates to drill bits that include one or more flow management channels formed within one or more blade sections of the drill bits and/or other downhole tools.

FIG. 1 shows a perspective view of a drill bit 100 in accordance with the prior art. Referring to FIG. 1, the drill bit 100 includes a bit body 110 that is coupled to a shank 115 and is designed to rotate in a counter-clockwise direction 190. The shank 115 includes a threaded connection 116 at one end 120. The threaded connection 116 couples to a drill string (not shown) or some other equipment that is coupled to the drill string. The threaded connection 116 is shown to be positioned on the exterior surface of the one end 120. This positioning assumes that the drill bit 100 is coupled to a corresponding threaded connection located on the interior surface of a drill string (not shown). However, the threaded connection 116 at the one end 120 is alternatively positioned on the interior surface of the one end 120 if the corresponding threaded connection of the drill string (not shown) is positioned on its exterior surface in other exemplary embodiments. A bore (not shown) is formed longitudinally through the shank 115 and the bit body 110 for communicating drilling fluid from within the drill string to a drill bit face 111 via one or more nozzles 114 during drilling operations.

The bit body 110 includes a plurality of gauge sections 150 and a plurality of blades 130 extending from the drill bit face 111 of the bit body 110 towards the threaded connection 116, where each blade 130 extends to and terminates at a respective gauge section 150. The blade 130 and the respective gauge section 150 are formed as a single component, but are formed separately in certain drill bits 100. The drill bit face 111 is positioned at one end of the bit body 110 furthest away from the shank 115. The plurality of blades 130 form the cutting surface of the drill bit 100. One or more of these plurality of blades 130 are either coupled to the bit body 110 or are integrally formed with the bit body 110. The gauge sections 150 are positioned at an end of the bit body 110 adjacent the shank 115. The gauge section 150 includes one or more gauge cutters (not shown) in certain drill bits 100. The gauge sections 150 typically define and hold the full hole diameter of the drilled hole.

Each of the blades 130 include a blade leading edge section 132, a blade face section 134, and a blade trailing edge section 136. The blade face section 134 extends from a longitudinal end of the blade trailing edge section 136 to a longitudinal end of the blade leading edge section 132. The blade leading edge section 132 faces in the direction of rotation 190, while the blade trailing edge section 136 faces in the opposite direction of rotation 190. A junk slot 122 is formed between each consecutive blade 130, which allows for cuttings and drilling fluid to return to the surface of the wellbore (not shown) once the drilling fluid is discharged from the nozzles 114. A plurality of cutters 140 are coupled to each of the blades 130 and extend outwardly from the surface of the blades 130 to cut through earth formations when the drill bit 100 is rotated during drilling. One type of cutter 140 used within the drill bit 100 is a PDC cutter; however other types of cutters are contemplated as being used within the drill bit 100. The cutters 140 and portions of the bit body 110 deform the earth formation by scraping and/or shearing depending upon the type of drill bit 100. Although one embodiment of the drill bit 100 has been described, other drill bit embodiments and/or other downhole tools that include one or more blades 130, which are known to people having ordinary skill in the art, are applicable to exemplary embodiments of the present invention.

During drilling of a borehole, the drill bit 100 rotates to cut through an earth formation to form a wellbore therein. This cutting is typically performed through scraping and/or shearing action according to certain drill bits 100, but is performed through other means based upon the type of drill bit used. Drilling fluid (not shown) exits the drill bit 100 through one or more nozzles 114 and facilitates the removal of the cuttings from the borehole wall back towards the surface. The blades 130 typically are formed as solid blades which direct the fluid flow from the one or more nozzles 114 directly up the open face areas and up the respective junk slots 122. This solid blade design may cause entrainment of the cuttings, heat build up within the blades, potential for cuttings to build up upon the surfaces of the blade, and/or efficiency reduction of the blade dynamics.

BRIEF DESCRIPTION OF THE DRAWINGS

The foregoing and other features and aspects of the invention will be best understood with reference to the following description of certain exemplary embodiments of the invention, when read in conjunction with the accompanying drawings, wherein:

FIG. 1 shows a perspective view of a drill bit in accordance with the prior art;

FIG. 2 shows a perspective view of a drill bit including one or more flow channels in a blade section of the drill bit in accordance with an exemplary embodiment of the present invention;

FIG. 3 shows a schematic view of the one or more flow channels in the blade section of the drill bit of FIG. 2 in accordance with an exemplary embodiment of the present invention;

FIG. 4 shows a perspective view of a drill bit including one or more flow channels in a blade section of the drill bit in accordance with an exemplary embodiment of the present invention;

FIG. 5 shows a schematic view of the one or more flow channels in the blade section of the drill bit of FIG. 4 in accordance with an exemplary embodiment of the present invention;

FIG. 6 shows a perspective view of a drill bit including one or more flow channels in a blade section of the drill bit in accordance with an exemplary embodiment of the present invention; and

FIG. 7 shows a schematic view of the one or more flow channels in the blade section of the drill bit of FIG. 6 in accordance with an exemplary embodiment of the present invention.

The drawings illustrate only exemplary embodiments of the invention and are therefore not to be considered limiting of its scope, as the invention may admit to other equally effective embodiments.

DETAILED DESCRIPTION OF THE INVENTION

This invention relates generally to drill bits and/or other downhole tools. More particularly, this invention relates to drill bits that include one or more flow management channels formed within one or more blade sections of the drill bits and/or other downhole tools. Although the description provided below is related to a fixed cutter bit, exemplary embodiments of the invention relate to any downhole tool having one or more blade sections, such as, but not limited to, steel body or matrix PDC bits, impregnated bits, and other fixed cutter bits.

According to exemplary embodiments of the present invention, one or more inlet holes are deployed on a blade leading edge section of a blade section of a bit. Further, one or more outlet holes are deployed on one or more of the blade trailing edge section, where one or more outlet holes are fluidly coupled to at least one inlet hole from within the blade. The outlet hole and the corresponding inlet hole form a fluid channel extending therebetween. The fluid channels are deployed to allow fluid to flow beneath a blade face section of the blade section to provide cooling to the blade face section. These fluid channels are deployed at an upward angle, either linearly or curve-shaped, in certain exemplary embodiments, to facilitate the movement of entrained cuttings and drilling fluid in the uphole direction. However, in other exemplary embodiments, one or more fluid channels are deployed in a horizontal direction or a downward angle.

FIG. 2 shows a perspective view of a drill bit 200 including one or more flow channels 360 in a blade section 230 of the drill bit 200 in accordance with an exemplary embodiment of the present invention. FIG. 3 shows a schematic view of the one or more flow channels 360 in the blade section 230 of the drill bit 200 in accordance with an exemplary embodiment of the present invention. Referring to FIGS. 2 and 3, the drill bit 200 is similar to drill bit 100 (FIG. 1) and includes a bit body 210 that is coupled to a shank 215. The drill bit 200 is designed to rotate in a counter-clockwise direction 290. The shank 215 includes a threaded connection (not shown) at one end (not shown). This threaded connection is similar to threaded connection 116 (FIG. 1). The threaded connection couples to a drill string (not shown) or some other equipment that is coupled to the drill string. A bore (not shown) is formed longitudinally through the shank and the bit body 210 for communicating drilling fluid from within the drill string to a drill bit face 211 via one or more nozzles 214 during drilling operations.

The bit body 210 includes a plurality of gauge sections 250 and a plurality of blades 230, or blade sections, extending from the drill bit face 211 of the bit body 210 towards the shank 215, where each blade 230 extends to and terminates at a respective gauge section 250. The blade 230 and the respective gauge section 250 are formed as a single component, but are formed separately in other drill bits. The drill bit face 211 is positioned at one end of the bit body 210 furthest away from the shank 215. The plurality of blades 230 form the cutting surface of the drill bit 200. One or more of these plurality of blades 230 are either coupled to the bit body 210 or are integrally formed with the bit body 210. The gauge sections 250 are positioned at an end of the bit body 210 adjacent the shank 215. The gauge section 250 includes one or more gauge cutters (not shown) in certain exemplary embodiments of drill bits. The gauge sections 250 typically define and hold the full hole diameter of the drilled hole.

Each of the blades 230, or blade sections, include a blade leading edge section 232, a blade face section 234, and a blade trailing edge section 236. The blade face section 234 extends from a longitudinal end of the blade trailing edge section 236 to a longitudinal end of the blade leading edge section 232 and forms a front surface of the blade section 230. The blade leading edge section 232 faces in the direction of rotation 290, while the blade trailing edge section 236 faces in the opposite direction of rotation 290. A junk slot 222 is formed between each consecutive blade 230, which allows for cuttings and drilling fluid to return to the surface of the wellbore (not shown) once the drilling fluid is discharged from the nozzles 214. A plurality of cutters 240 are coupled to each of the blades 230 and extend outwardly from the surface of the blades 230 to cut through earth formations when the drill bit 200 is rotated during drilling. One type of cutter 240 used within the drill bit 200 is a PDC cutter; however, other types of cutters are contemplated as being used within the drill bit 200. The cutters 240 and portions of the bit body 210 deform the earth formation by scraping and/or shearing depending upon the type of drill bit 200.

According to some exemplary embodiments, as shown in FIGS. 2 and 3, one or more inlet holes 270 are formed within the blade leading edge section 232 and one or more outlet holes 275 are formed within the blade trailing edge section 236. The flow channel 360 extends from an inlet hole 270 to at least one corresponding outlet hole 275. Hence, the drilling fluid and/or cuttings enter into the flow channel 360 through the inlet hole 270 and exits through the outlet hole 275. The fluid flowing through this flow channel 360 facilitates cooling of at least the blade section 230 and also reduces erosion of the blade section 230. Although the inlet holes 270 and the outlet holes 275 are illustrated as being round-shaped, one or more of these holes 270, 275 are shaped differently, for example, rectangular-shaped, crescent-shaped, or oval-shaped. In some exemplary embodiments, one inlet hole 270 corresponds to and is in fluid communication with a single outlet hole 275. However, in other exemplary embodiments, one inlet hole 270 corresponds to and is in fluid communication with a plurality of outlet holes 275. Also, in certain exemplary embodiments, one or more outlet holes 275 are shaped and/or dimensioned differently than the corresponding inlet hole 270. For example, the outlet hole 275 is sized larger, in perimeter or diameter, than the corresponding inlet hole 270 in certain exemplary embodiments. This feature reduces plugging within the flow channel 360 and/or reduces the velocity of the fluid and cuttings through the flow channel 360. In certain exemplary embodiments, at least one flow channel 360 is directed in an upward angle from the inlet hole 270 to the outlet hole 275. In other exemplary embodiments, the flow channel 360 is directed substantially horizontally or in a downward direction towards the bottom of the borehole (not shown). According to some exemplary embodiments, one or more flow channels 360 are formed substantially linearly from the inlet hole 270 to the outlet hole 275, while in other exemplary embodiments, one or more flow channels 360 are formed non-linearly, for example, curved-shaped. In certain exemplary embodiments, one or more outlet holes 275 are positioned to direct the flow of fluids and cuttings from the flow channel 360 towards desired areas of the cutting structure. In certain exemplary embodiments, the inlet holes 270 and/or the outlet holes 275 are strategically positioned relative to the fluid flow from specific nozzles 214 to better manage the overall flow through the blade sections 230 of the bit 200. Further, according to certain exemplary embodiments, the flow channels 360 and/or the holes 270, 275 are treated with an appropriate anti-balling coating, or nitriding, to reduce the likelihood of bit balling and the plugging of flow channels 360 and/or holes 270, 275.

FIG. 4 shows a perspective view of a drill bit 400 including one or more flow channels 560 in a blade section 430 of the drill bit 400 in accordance with an exemplary embodiment of the present invention. FIG. 5 shows a schematic view of the one or more flow channels 560 in the blade section 430 of the drill bit 400 in accordance with an exemplary embodiment of the present invention. Referring to FIGS. 4 and 5, the drill bit 400 is similar to drill bit 200 (FIG. 2). However, blade section 430 is different from blade section 230 (FIG. 2) in that the shape of the inlet holes 470, the outlet holes 475, and the flow channels 560 is different than the shape of the inlet holes 270 (FIG. 2), the outlet holes 275 (FIG. 2), and flow channels 360 (FIG. 3). Each of the blades 430, as described above with respect to drill bit 200 (FIG. 2), include a blade leading edge section 432, a blade face section 434, and a blade trailing edge section 436. The blade face section 434 extends from a longitudinal end of the blade trailing edge section 436 to a longitudinal end of the blade leading edge section 432 and forms a front surface of the blade section 430. The blade leading edge section 432 faces in the direction of rotation 490 of the drill bit 400, while the blade trailing edge section 436 faces in the opposite direction of rotation 490.

According to some exemplary embodiments, as shown in FIGS. 4 and 5, one or more inlet holes 470 are formed within the blade leading edge section 432 and one or more outlet holes 475 are formed within the blade trailing edge section 436. The flow channel 560 extends from an inlet hole 470 to at least one corresponding outlet hole 475. Hence, the drilling fluid and/or cuttings enter into the flow channel 560 through the inlet hole 470 and exits through the outlet hole 475. The fluid flowing through this flow channel 560 facilitates cooling of at least the blade section 430 and also reduces erosion of the blade section 430. Although the inlet holes 470 and the outlet holes 475 are illustrated as being rectangular-shaped, one or more of these holes 470, 475 are shaped differently, for example, round-shaped, crescent-shaped, or oval-shaped. In some exemplary embodiments, one inlet hole 470 corresponds to and is in fluid communication with a single outlet hole 475. However, in other exemplary embodiments, one inlet hole 470 corresponds to and is in fluid communication with a plurality of outlet holes 475. Also, in certain exemplary embodiments, one or more outlet holes 475 is shaped and/or dimensioned differently than the corresponding inlet hole 470. For example, the outlet hole 475 is sized larger, in perimeter or diameter, than the corresponding inlet hole 470 in certain exemplary embodiments. This feature reduces plugging within the flow channel 560 and/or reduces the velocity of the fluid and cuttings through the flow channel 560. In certain exemplary embodiments, at least one flow channel 560 is directed in an upward angle from the inlet hole 470 to the outlet hole 475. In other exemplary embodiments, the flow channel 560 is directed substantially horizontally or in a downward direction towards the bottom of the borehole (not shown). According to some exemplary embodiments, one or more flow channels 560 are formed substantially linearly from the inlet hole 470 to the outlet hole 475, while in other exemplary embodiments, one or more flow channels 560 are formed non-linearly, for example, curved-shaped. In certain exemplary embodiments, one or more outlet holes 475 are positioned to direct the flow of fluids and cuttings from the flow channel 560 towards desired areas of the cutting structure. In certain exemplary embodiments, the inlet holes 470 and/or the outlet holes 475 are strategically positioned relative to the fluid flow from specific nozzles 414, similar to nozzle 214 (FIG. 2), to better manage the overall flow through the blade sections 430 of the bit 400. Further, according to certain exemplary embodiments, the flow channels 560 and/or the holes 470, 475 are treated with an appropriate anti-balling coating, or nitriding, to reduce the likelihood of bit balling and the plugging of flow channels 560 and/or holes 470, 475.

FIG. 6 shows a perspective view of a drill bit 600 including one or more flow channels 760 in a blade section 630 of the drill bit 600 in accordance with an exemplary embodiment of the present invention. FIG. 7 shows a schematic view of the one or more flow channels 760 in the blade section 630 of the drill bit 600 in accordance with an exemplary embodiment of the present invention. Referring to FIGS. 6 and 7, the drill bit 600 is similar to drill bit 200 (FIG. 2). However, blade section 630 is different from blade section 230 (FIG. 2) in that the shape of the inlet holes 670, the outlet holes 675, and the flow channels 760 is different than the shape of the inlet holes 270 (FIG. 2), the outlet holes 275 (FIG. 2), and flow channels 360 (FIG. 3). Each of the blades 630, as described above with respect to drill bit 200 (FIG. 2), include a blade leading edge section 632, a blade face section 634, and a blade trailing edge section 636. The blade face section 634 extends from a longitudinal end of the blade trailing edge section 636 to a longitudinal end of the blade leading edge section 632 and forms a front surface of the blade section 630. The blade leading edge section 632 faces in the direction of rotation 690 of the drill bit 600, while the blade trailing edge section 636 faces in the opposite direction of rotation 690.

According to some exemplary embodiments, as shown in FIGS. 6 and 7, one or more inlet holes 670 are formed within the blade leading edge section 632 and one or more outlet holes 675 are formed within the blade trailing edge section 636. The flow channel 760 extends from an inlet hole 670 to at least one corresponding outlet hole 675. Hence, the drilling fluid and/or cuttings enter into the flow channel 760 through the inlet hole 670 and exits through the outlet hole 675. The fluid flowing through this flow channel 760 facilitates cooling of at least the blade section 630 and also reduces erosion of the blade section 630. Although the inlet holes 670 and the outlet holes 675 are illustrated as being crescent-shaped, one or more of these holes 670, 675 are shaped differently, for example, round-shaped, rectangular-shaped, or oval-shaped. According to this exemplary embodiment, and which may be featured in other exemplary embodiments, the holes 670, 675 are curved along arcs to better match the rotation of the bit. This feature is accomplished, according to some exemplary embodiments, by milling the holes from the backside and would involve the previously mentioned larger diameter on the blade trailing edge section 636 than the blade leading edge section 632. In some exemplary embodiments, one inlet hole 670 corresponds to and is in fluid communication with a single outlet hole 675. However, in other exemplary embodiments, one inlet hole 670 corresponds to and is in fluid communication with a plurality of outlet holes 675. Also, in certain exemplary embodiments, one or more outlet holes 675 are shaped and/or dimensioned differently than the corresponding inlet hole 670. For example, the outlet hole 675 is sized larger, in perimeter or diameter, than the corresponding inlet hole 670 in certain exemplary embodiments. This feature reduces plugging within the flow channel 760 and/or reduces the velocity of the fluid and cuttings through the flow channel 760. In certain exemplary embodiments, at least one flow channel 760 is directed in an upward angle from the inlet hole 670 to the outlet hole 675. In other exemplary embodiments, the flow channel 760 is directed substantially horizontally or in a downward direction towards the bottom of the borehole (not shown). According to some exemplary embodiments, one or more flow channels 760 are formed substantially linearly from the inlet hole 670 to the outlet hole 675, while in other exemplary embodiments, one or more flow channels 760 are formed non-linearly, for example, curved-shaped. In certain exemplary embodiments, one or more outlet holes 675 are positioned to direct the flow of fluids and cuttings from the flow channel 760 towards desired areas of the cutting structure. In certain exemplary embodiments, the inlet holes 670 and/or the outlet holes 675 are strategically positioned relative to the fluid flow from specific nozzles 614, similar to nozzle 214 (FIG. 2), to better manage the overall flow through the blade sections 630 of the bit 600. Further, according to certain exemplary embodiments, the flow channels 760 and/or the holes 670, 675 are treated with an appropriate anti-balling coating, or nitriding, to reduce the likelihood of bit balling and the plugging of flow channels 760 and/or holes 670, 675.

Exemplary embodiments of this invention allow for better cooling, cleaning, and flow management of the flow around the cutters and blades of the drill bit. It allows for the guidance of fluid flow in the uphole direction to better clean the bit. It employs anti-balling technology as an exemplary embodiment to keep the holes and flow channels clean. It directs fluid towards the cutters of a trailing blade in a new and unique way. It improves cuttings entrainment and overall fluid dynamics of the bit. It can be employed with traditional jet nozzles and/or lateral, or high angle, jet nozzles. It also is combinable with one or more “Flow Through” gauge features as disclosed within U.S. Non-Provisional Patent Application No. ______, entitled “Flow Through Gauge For Drill Bit” and filed on Sep. ______, 2013, and/or one or more “High Angle Nozzle” feature as disclosed, or similarly disclosed, within U.S. Non-Provisional Patent Application No. ______, entitled “Machined High Angle Nozzle Sockets For Steel Body Bits” and filed on Sep. ______, 2013, both of which have previously been hereby incorporated by reference herein.

According to certain exemplary embodiments, there are a plurality of inlet holes, and hence a plurality of flow channels, extending through at least one blade. Further, according to certain exemplary embodiments, there are a plurality of inlet holes, and hence a plurality of flow channels, extending through each of the blades. According to some of the exemplary embodiments, at least one outlet hole is positioned at a different elevation than a corresponding inlet hole when the tool is vertically oriented, such as when it is in a vertically oriented borehole. Further, according to some of the exemplary embodiments, each of the inlet holes and each of the outlet holes are dimensioned to less than nine square inches. Further, according to some of the exemplary embodiments, at least one of the inlet holes and/or at least one of the outlet holes are dimensioned to less than nine square inches.

Although the invention has been described with reference to specific embodiments, these descriptions are not meant to be construed in a limiting sense. Various modifications of the disclosed embodiments, as well as alternative embodiments of the invention will become apparent to persons skilled in the art upon reference to the description of the invention. It should be appreciated by those skilled in the art that the conception and the specific embodiments disclosed may be readily utilized as a basis for modifying or designing other structures for carrying out the same purposes of the invention. It should also be realized by those skilled in the art that such equivalent constructions do not depart from the spirit and scope of the invention as set forth in the appended claims. It is therefore, contemplated that the claims will cover any such modifications or embodiments that fall within the scope of the invention.

Claims

1. A downhole tool, comprising:

a body;

one or more blades extending from one end of the body towards a second end of the body, each blade comprising: a leading edge section; a trailing edge section; and a face section extending from a longitudinal end of the leading edge section to a longitudinal end of the trailing edge section,

wherein at least one flow channel is formed in at least one blade, the at least one flow channel extending from the leading edge section to the trailing edge section.

2. The downhole tool of claim 1, wherein the leading edge section comprises at least one inlet opening, the trailing edge section comprises at least one outlet opening, and the flow channel is formed extending from the inlet opening to at least one outlet opening.

3. The downhole tool of claim 2, wherein the flow channel is oriented at an upward angle.

4. The downhole tool of claim 2, wherein the at least one outlet opening is dimensioned larger than the corresponding inlet opening.

5. The downhole tool of claim 2, wherein at least one inlet opening is fluidly communicable with at least two corresponding outlet openings.

6. The downhole tool of claim 2, wherein the at least one flow channel comprises a plurality of flow channels, a first flow channel being parallel to a second flow channel.

7. The downhole tool of claim 2, wherein the shape of the at least one inlet opening is selected from the group consisting of circular-shaped, oval-shaped, crescent-shaped, and rectangular-shaped.

8. The downhole tool of claim 7, wherein the shape of at least one outlet opening is selected from the group consisting of circular-shaped, oval-shaped, crescent-shaped, and rectangular-shaped.

9. The downhole tool of claim 8, wherein the flow channel is curve-shaped.

10. The downhole tool of claim 8, wherein the flow channel is substantially linear.

11. The downhole tool of claim 8, wherein the cross-sectional area of at least one flow channel varies.

12. The downhole tool of claim 1, wherein the flow channel is curve-shaped.

13. The downhole tool of claim 1, wherein the flow channel is substantially linear.

14. The downhole tool of claim 1, wherein the cross-sectional area of at least one flow channel varies.

15. The downhole tool of claim 1, wherein at least a portion of the flowpath comprises an anti-balling coating.

16. A blade section of a downhole tool, comprising:

a leading edge section;

a trailing edge section; and

a face section extending from one end of the leading edge section to one end of the trailing edge section,

wherein at least one flow channel is formed within the blade section extending from the leading edge section to the trailing edge section and beneath the face section.

17. The blade section of claim 16, wherein the leading edge section comprises at least one inlet opening, the trailing edge section comprises at least one outlet opening, and the flow channel is formed extending from the inlet opening to the at least one outlet opening.

18. The blade section of claim 17, wherein the flow channel is oriented at an upward angle.

19. The blade section of claim 17, wherein the at least one outlet opening is dimensioned larger than the corresponding inlet opening.

20. The blade section of claim 17, wherein at least one inlet opening is fluidly communicable with at least two corresponding outlet openings.

21. The blade section of claim 17, wherein the at least one flow channel comprises a plurality of flow channels, a first flow channel being parallel to a second flow channel.

22. The blade section of claim 17, wherein the shape of the at least one inlet opening is selected from the group consisting of circular-shaped, oval-shaped, crescent-shaped, and rectangular-shaped.

23. The blade section of claim 17, wherein the shape of at least one outlet opening is selected from the group consisting of circular-shaped, oval-shaped, crescent-shaped, and rectangular-shaped.

24. The blade section of claim 16, wherein the flow channel is curved.

25. The blade section of claim 16, wherein at least a portion of the flowpath comprises an anti-balling coating.

26. A method of fabricating one or more flow channels in a downhole tool, the method comprising:

obtaining a downhole tool, comprising: a body; one or more blades extending from one end of the body, the plurality of blades forming a cutting surface, each blade comprising: a leading edge section; a trailing edge section; and a face section extending from a longitudinal end of the leading edge section to a longitudinal end of the trailing edge section, wherein at least one flow channel is formed in at least one blade, the at least one flow channel extending from the leading edge section to the trailing edge section.

forming at least one flow channel in at least one blade, the flow channel extending from the leading edge section to the trailing edge section.

27. The method of claim 26, wherein forming at least one flow channel in the blade comprises:

forming at least one inlet opening in the leading edge section;

forming at least one outlet opening in the trailing edge section; and

forming the flow channel to extend from the at least one inlet opening to the at least one outlet opening.

28. The method of claim 27, wherein the flow channel is oriented at an upward angle.

29. The method of claim 27, wherein at least one outlet opening is dimensioned larger than the corresponding inlet opening.

30. The method of claim 27, wherein the flow channel is curved.

31. The method of claim 27, wherein the shape of the at least one inlet opening is selected from the group consisting of circular-shaped, oval-shaped, crescent-shaped, and rectangular-shaped.

32. The method of claim 27, wherein the shape of at least one outlet opening is selected from the group consisting of circular-shaped, oval-shaped, crescent-shaped, and rectangular-shaped.

33. The method of claim 26, wherein at least a portion of the flowpath comprises an anti-balling coating.