Fluid ports on blades of earth-boring rotary tools for hydraulic impact and related methods

Abstract

An earth-boring tool includes a bit body, at least one blade with at least one cutting element, and at least one outlet disposed on or adjacent to the blade on a cone, nose, or shoulder and configured to discharge drilling fluid at a tilt angle of about 25° to about 90°. An earth-boring tool also includes multiple blades with cutting elements on rotationally leading surfaces and outlets on formation-facing surfaces. The outlets are configured to discharge drilling fluid to impact the formation in front of cutting elements of a rotationally trailing blade.

Description

[0001] FLUID PORTS ON BLADES OF EARTH-BORING ROTARY TOOLS FOR HYDRAULIC IMPACT AND RELATED METHODS

[0002] PRIORITY CLAIM

[0003] This application claims the benefit of the filing date of United States Provisional Patent Application Serial No. 63 / 756,458, filed February 10, 2025, for "Fluid Ports On Blades of Earth-Boring Rotary Tools For Hydraulic Impact and Related Methods,’’ the disclosure of which is hereby incorporated herein in its entirety by this reference.

[0004] TECHNICAL FIELD

[0005] Embodiments of the present disclosure relate to earth-boring rotary tools having tool bodies with blades thereon and fluid ports on exterior surfaces of blades for hydraulic impact on the adj acent formation surfaces, and to related methods of manufacturing and using such drill bits.

[0006] BACKGROUND

[0007] Wellbore drilling operations may involve the use of an earth-boring tool at the end of a long string of pipe commonly referred to as a drill string. An earth-boring tool may be used for drilling through formations, such as rock, dirt, sand, tar, etc. Rotary drill bits are commonly used for drilling bore holes or wells in earth formations. Rotary drill bits include two rimary configurations. One configuration is the roller cone bit, which typically includes three roller cones mounted on support legs that extend from a bit body. Each roller cone is configured to spin or rotate on a support leg. Cutting teeth typically are provided on the outer surfaces of each roller cone for cutting rock and other earth formations. The cutting teeth often are coated with an abrasive super hard (“hardfacing”) material. Such materials often include tungsten carbide particles dispersed throughout a metal alloy matrix material. Alternatively, receptacles are provided on the outer surfaces of each roller cone into which hardmetal inserts are secured to form the cutting elements. The roller cone drill bit may be placed in a bore hole such that the roller cones are adjacent the earth formation to be drilled. As the drill bit is rotated, the roller cones roll across the surface of the formation, the cutting teeth crushing the underlying formation.

[0008] A second configuration of a rotary drill bit is the fixed-cutter bit (often referred to as a “drag” bit), which typically includes a plurality of cutting elements secured to a faceregion of a bit body. Generally, the cutting elements of a fixed-cutter type drill bit have either a disk shape or a substantially cylindrical shape. A hard, super-abrasive material, such as mutually bonded particles of polycrystalline diamond, may be provided on a substantially circular end surface of each cutting element to provide a cutting surface. Such cutting elements are often referred to as “polycrystalline diamond compact” (PDC) cutters. Typically, the cutting elements are fabricated separately from the bit body and secured within pockets formed in the outer surface of the bit body. A bonding material such as an adhesive or, more typically, a braze alloy may be used to secure the cutting elements to the bit body. The fixed-cutter drill bit may be placed in a bore hole such that the cutting elements are adj acent to the earth formation to be drilled. As the drill bit is rotated, the cutting elements scrape across and shear away the surface of the underlying formation.

[0009] A fluid may be supplied into the wellbore during the wellbore drilling operation. The fluid may be used to cool and / or clean the earth-boring tool and / or related cutting elements. For example, the fluid may cool the earth-boring tool and cany' cuttings and debris away from the earth-boring tool.

[0010] SUMMARY

[0011] According to one aspect of disclosure, an earth-boring tool includes a bit body, at least one blade on the bit body having at least one cutting element, and at least one outlet disposed on or adjacent to the at least one blade in a cone region, a nose region, or a shoulder region of the earth-boring tool. The at least one outlet is configured to discharge a drilling fluid at a tilt angle of about 25° to about 90°.

[0012] According to another aspect of the disclosure, a method of forming an earth-boring tool is provided. The method includes forming a bit body and providing a first blade and a second blade on the bit body. The first blade is disposed rotationally in front of the second blade. At least one cutting element is provided on the second blade, and at least one outlet is provided on or adjacent to the first blade. The at least one outlet is configured to discharge a drilling fluid rotationally in front of the at least one cutting element of the second blade.BRIEF DESCRIPTION OF THE DRAWINGS

[0013] For a detailed understanding of the disclosure, reference should be made to the following detailed description, taken in conjunction with the accompanying drawings, in which like elements have generally been designated with like numerals, and wherein:

[0014] FIG. 1 A illustrates a partial front perspective view of an earth-boring tool in accordance with embodiments of the disclosure;

[0015] FIG. IB illustrates a first partial side perspective view of the earth-boring tool of FIG 1A;

[0016] FIG. 1C illustrates a second partial side perspective view of the earth-boring tool of FIG. 1A;

[0017] FIG. 2A is a perspective view of another earth-boring tool in accordance with embodiments of the disclosure;

[0018] FIG. 2B is a top plan view of the earth-boring tool of FIG. 2 A;

[0019] FIG. 2C is a side plan view' of the earth-boring tool of FIG. 2A;

[0020] FIG. 2D is a side cross-sectional view of the earth-boring tool of FIG. 2A;

[0021] FIG. 2E is a perspective view of an earth-boring tool in accordance with embodiments of the disclosure;

[0022] FIG. 3A is an exposure profile of cutting elements on an earth-boring tool in accordance with embodiments of the disclosure;

[0023] FIG. 3B is the exposure profile of FIG. 3 A with the cutting elements removed; and FIG. 3C is an enlarged view of the exposure profile of FIG. 3B with an exemplary fluid passageway.

[0024] FIG. 4 is an exposure profile of an earth-boring tool with the cutting elements removed showing fluid passageways in accordance with embodiments of the disclosure.

[0025] FIG. 5 is a perspective view of atop portion of a blank for creating fluid passageways in an earth boring tool according to embodiments of the disclosure.

[0026] FIG. 6 is a graph showing exemplary' fluid velocities in front of cutters of different blades an earth-boring tool.

[0027] FIG. 7 is a flow diagram illustrating an example method of drilling a wellbore using an earth-boring tool in accordance with embodiments of the disclosure.MODE(S) FOR CARRYING OUT THE INVENTION

[0028] The illustrations presented herein are not actual views of any particular apparatus, system, or method, but are merely idealized representations, which are employed to describe embodiments of the invention.

[0029] As used herein, the term “earth-boring tool” means and includes any ty pe of bit or tool used for drilling during the formation or enlargement of a wellbore in a subterranean formation. For example, earth-boring tools include fixed-cutter bits, roller cone bits, percussion bits, core bits, eccentric bits, bi-center bits, reamers, mills, drag bits, hybrid bits (e.g., rolling components in combination with fixed cutting elements), and other drilling bits and tools known in the art.

[0030] As used herein, the term “outlet” refers to any opening in the body of the drill bit in fluid communication with a source of drilling fluid and adapted to discharge that fluid into the borehole. As used herein, the term “port” refers to an outlet in the body of the drill bit that is not adapted to receive any additional attached piece or part to discharge the fluid. As used herein, the term “nozzle receptacle” refers to an outlet adapted (e.g., threaded) to receive a nozzle adapted to control or direct fluid flow out of the outlet. As used herein, the term “nozzle” or “nozzle insert” refers to any apparatus, tool, or part that is adapted to attach to the drill bit via a nozzle receptacle.

[0031] As used herein, the term “about” or “approximately” in reference to a numerical value for a particular parameter is inclusive of the numerical value and a degree of variance from the numerical value that one of ordinary skill in the art would understand is within acceptable tolerances for the particular parameter. For example, “about” or “approximately” in reference to a numerical value may include additional numerical values within a range of from 90.0 percent to 110.0 percent of the numerical value, such as within a range of from 95.0 percent to 105.0 percent of the numerical value, within a range of from 97.5 percent to 102.5 percent of the numerical value, within a range of from 99.0 percent to 101.0 percent of the numerical value, within a range of from 99.5 percent to 100.5 percent of the numerical value, or within a range of from 99.9 percent to 100.1 percent of the numerical value.

[0032] As used herein, terms such as “ahead” and “behind” are used in reference to a direction of movement of the associated element. For example, as a drill string moves into a borehole the bottom of the borehole is ahead of the elements of the drill string and the surface is behind the elements of the drill string. In another example, in relation to a cuttingelement on a rotating earth-boring tool a portion of the formation that has not yet been contacted by the cutting element is ahead of the cutting element whereas a portion of the formation that has already been contacted by the cutting element is behind the cutting element.

[0033] As used herein, the terms “leading” and “trailing” are used in reference to the direction of rotation of the drill bit. For example, the cutting elements are located on a leading edge of a blade when the cutting elements are on an edge of the blade that faces toward the direction of rotation. Similarly, on a drill bit with multiple blades, each blade is both a “leading” blade relative to a blade behind it and a “trailing” blade relative to a blade ahead of it.

[0034] As used herein, relational terms, such as “first,” “second,” “top.” “bottom,” etc., are generally used for clarity and convenience in understanding the disclosure and accompanying drawings and do not connote or depend on any specific preference, orientation, or order, except where the context clearly indicates otherwise.

[0035] As used herein, the term “and / or” means and includes any and all combinations of one or more of the associated listed items.

[0036] As used herein, the terms “vertical” and “lateral” refer to the orientations as depicted in the figures.

[0037] An earth-boring tool according to embodiments of the disclosure is shown in FIGS. 1A-1C. The earth-boring tool is a fixed-cutter type rotary drill bit 100. which includes a bit body 114 having radially protruding and longitudinally extending blades 102 thereon. The bit body 114 may be secured to a steel shank 118, which is used to couple the drill bit 100 to the end of a drill string. The bit body 114 of the drill bit 100 may be formed from steel. Alternatively, the bit body 114 may be formed from a particle-matrix composite material. Such materials include hard particles randomly dispersed throughout a matrix material (often referred to as a “binder” material). Such bit bodies 114 typically are formed by embedding a steel blank in a volume of particulate carbide material (e.g., tungsten carbide, titanium carbide, tantalum carbide, etc.) within a graphite mold and infiltrating the particulate carbide material with a matrix material, such as a copper alloy. Drill bits that have a bit body formed from such a particle-matrix composite material may exhibit increased erosion and wear resistance, but lower strength and toughness relative to drill bits having steel bit bodies.The blades 102 have a rotationally leading surface 120, a rotationally trailing surface 122 opposite the leading surface 120, and a radially outer formation-facing surface 124. As is known in the industry, the bit body 114 includes different regions referred to as the cone region 128, the nose region 130, the shoulder region 132, and the gage region. Fluid courses 112 are defined between the blades 102. A longitudinal bore 116 extends through the steel shank and partially through the bit body 114, and fluid passageways extend through the bit body 114 between the longitudinal bore 116 and fluid flow ports 110 located in the bit body 114 within the fluid courses 112 to discharge fluid to cool the drill bit 100 and to entrain and remove cuttings and debris from the wellbore.

[0038] A plurality of cutting elements 104 are secured to each of the blades 102 close to the junction between the leading surface 120 and the formation-facing surface 124. The cutting elements 104 may be, for example, poly crystalline diamond compact (PDC) cutting elements, which have a diamond table disposed on a cemented tungsten carbide substrate. Each cutting element 104 may be secured to the blade 102 within a cutting pocket formed in the blade 102, such as through welding, soldering, brazing, etc.

[0039] In accordance with embodiments of the present disclosure, one or more outlets (e.g., fluid impact ports 108) may be provided on one or more of the blades 102. Fluid passageways 126 may also extend between the outlets (e.g., fluid impact ports 108) and the longitudinal bore 116 to provide fluid communication therebetween. In accordance with embodiments of the present disclosure, fluid impact ports 108 are located and configured to discharge pressurized fluid against the adjacent formation surfaces at relatively high pressure to weaken and / or erode the material of the formation during drilling and assist in the cutting action performed by the cutting elements 104.

[0040] Another earth-boring tool according to embodiments of the disclosure is shown in FIGS. 2A to 2D. The earth-boring tool 200 and its components may be similar to the earthboring tool 100 discussed above in connection with FIGS. 1 A to 1C. The earth-boring tool is a fixed-cutter type rotary drill bit 200, which includes a bit body 214 having radially protruding and longitudinally extending blades 202 thereon. The bit body 214 may be secured to a steel shank 218. which is used to couple the drill bit 200 to the end of a drill string. The bit body 214 of the drill bit 200 may be formed from steel or from a particlematrix composite material. The bit body 214 may be formed as discussed above regarding bit body 114.The blades 202 have a rotationally leading surface 220, a rotationally trailing surface 222 opposite the leading surface 220, and a radially outer formation-facing surface 224. As is known in the industry, the bit body 214 includes different regions referred to as the cone region 228, the nose region 230, the shoulder region 232, and the gage region. Fluid courses 212 are defined between the blades 202. A longitudinal bore 216 extends through the steel shank and partially through the bit body 214, and fluid passageways extend through the bit body 214 between the longitudinal bore 216 and fluid flow ports 210 located in the bit body 214 within the fluid courses 212 to discharge fluid to cool the drill bit 200 and to entrain and remove cuttings and debris from the wellbore.

[0041] A plurality of cutting elements 204 are secured to each of the blades 202 close to the junction between the leading surface 220 and the formation-facing surface 224. The cutting elements 204 may be, for example, polycrystalline diamond compact (PDC) cutting elements, which have a diamond table disposed on a cemented tungsten carbide substrate. Each cutting element 204 may be secured to the blade within a cutting pocket formed in the blade 202, such as through welding, soldering, brazing, etc.

[0042] In accordance with embodiments of the present disclosure, one or more outlets (e.g., fluid impact ports 208) may be provided on or adjacent to one or more of the blades 202. Fluid passageways 226 may extend between the outlets (e.g., fluid impact ports 208) and the longitudinal bore 216 to provide fluid communication therebetween. In accordance with embodiments of the present disclosure, fluid impact ports 208 are located and configured to discharge pressurized fluid against the adjacent formation surfaces at relatively high pressure to weaken and / or erode the material of the formation during drilling and assist in the cutting action performed by the cutting elements 204.

[0043] During drilling operations, the drill bit 100, 200 is positioned at the bottom of a wellbore and rotated about a longitudinal axis while drilling fluid is pumped down the drill string to the longitudinal bore 116, 216 and through internal fluid passageways 126, 226 to fluid impact ports 108, 208 and fluid flow ports 110, 210. When the drill bit 100, 200 rotates, the cutting face 106, 206 of the cutting elements 104, 204 may contact the earth formation and remove material. The material removed by the cutting face 106. 206 may then be removed through the fluid courses 112, 212. In the industry, the portion of the fluid courses 112, 212 in a gage region of the drill bit 100, 200 are commonly referred to as junk slots. The drill bit 100, 200 includes fluid flow ports 110, 210 that may introduce fluid, such as water or drilling mud, into the area around the blades 102, 202 to aid in removingthe sheared material and other debris from the area around the blades 102, 202 and / or to cool the cutting elements 104, 204 and the blade 102, 202 to increase the efficiency of the dull bit 100, 200.

[0044] As the tool rotates, each blade 102, 202 is ahead of one other blade 102, 202 and behind another blade 102, 202, in relation to the direction of rotation. A leading surface 120, 220 of the blades 102, 202 includes the cutting elements 104, 204, and a trailing surface 122, 222 of the blade faces away from the direction of motion and toward a leading surface 120, 220 of a following blade 102, 202. In various embodiments, the fluid impact ports 108, 208 on or adjacent to a given blade are configured to discharge fluid, which impacts the formation at a point in front of and relatively close to a cutting element 104. 204 on the blade behind the blade on which the fluid impact port 108, 208 is located. For example, a fluid impact port 108, 208 on or adjacent to a first blade is at a radial position that corresponds with a radial position of a cutting element 104, 204 on a second blade that is rotationally behind the first blade. The impact of the fluid on the formation surface is intended to weaken that part of the formation just prior to being impacted by the cutting element 104, 204 on the following blade.

[0045] In some embodiments, the fluid impact ports 108, 208 are located on the formationfacing surface 124, 224 of the blade 102, 202. For example, the blade 102, 202 may comprise a raised protruding portion 217 that extends the formation facing surface 124, 224 in a direction rotationally behind a remainder of the blade 102, 202. The raised protruding portion 217 of one blade 102, 202 may extend partially into and / or be aligned with one of the fluid courses 112, 212 in front of a rotationally trailing blade 102, 202. In some embodiments, the fluid impact ports 108 may be placed on or adjacent to the trailing surface 122, 222 of the blade 102, 202, or at the intersection between the formation-facing surface 124, 224 and the trailing surface 122, 222 of the blade 102, 202. The fluid impact ports 108, 208 on different blades 102, 202 may be located at about the same radial position relative to a central axis of the drill bit 100, 200. In some embodiments, fluid impact ports 108, 208 on different blades 102, 202 may be located at different radial positions relative to the central axis of the drill bit 100, 200. In some embodiments, the fluid impact ports 108, 208 may be located within one or more fluid courses 112, 212.

[0046] The fluid may enter the wellbore through the fluid impact ports 108, 208 and fluid flow ports 110, 210 during drilling. The fluid impact ports 108, 208 and fluid flow ports 110, 210 may be coupled to a pressurized fluid supplied through the drill string. Thepressure of the fluid in the borehole may be controlled through the pressure of the fluid being supplied through the drill string and the fluid impact ports 108. 208 and fluid flow ports 110, 210. Reducing the distance between the fluid impact ports 108, 208 and a formation may facilitate weakening the material of the formation by infiltrating pores in the formation material with the fluid. In some embodiments, the fluid impact ports 108, 208 are configured to concentrate fluid flowing through the fluid impact ports 108, 208 through a jetting effect that may increase a pressure of the fluid contacting the formation and may weaken the material of the formation. For example, a formation’s bulk strength may increase at greater depths due to a confining pressure. Delivering a high-pressure fluid directly onto the formation may locally weaken the bulk strength of the formation and cuttings, which may increase the amount of material removed, depth of cut, and / or rate of penetration of the associated drill bit 100, 200. In various embodiments, the pressure delivered to the drill bit 100 may be from about 200 psi to about 2,000 psi as measured at the inlet and outlet. The fluid can impact the rock from about 100 psi to about 1,000 psi at velocities from about 100 ft / s to about 500 ft / s. The fluid may be drilling mud with a weight varying from about 7 ppg and about 15 ppg using, for example, 1 to 8 nozzles and 1 to 3 ports.

[0047] The fluid impact ports 108, 208 of the drill bit 100, 200 may be deployed on or adjacent to a formation-facing surface 124, 224 of the blade 102, 202 on the cone 128, 228, a nose 130, 230, and / or a shoulder 132, 232 region of the drill bit 100, 200. Positioning the fluid impact ports 108, 208 on the blades 102, 202 rotationally in front of one or more of the cutting elements 104, 204 may facilitate reducing the strength of the formation immediately rotationally ahead of the cutting elements 104, 204 of the drill bit 100, 200 during a drilling operation. The position of the fluid impact ports 108, 208 and / or the direction of fluid flow from the fluid impact ports 108, 208 may be such that fluid impact ports 108, 208 on or adjacent to one blade 102, 202 may be directed at the portion of the formation directly ahead of the cutting elements 104, 204 and cutting faces 106, 206 on the blade 102, 202 behind, in terms of direction of rotation, which may result in an increased depth of cut, or rate of penetration. Although only a few fluid impact ports 108, 208 are show n in FIGS. 1 A to 1 C and 2A to 2D, it would be understood by persons of skill in the art that fluid impact ports 108, 208 may be positioned on or adjacent to additional blades 102, 202 up to and including all blades 102, 202, and that more than one fluid impact port 108, 208 may be placed on or adjacent to any given blade 102, 202. In someembodiments, the number of fluid impact ports 108, 208 on a or adjacent to a blade 102, 202 matches the number of cutting elements 104, 204 on the same or a rotationally trailing blade 102, 202.

[0048] The internal fluid passageways 126, 226, fluid impact ports 108, 208, and fluid flow ports 110, 210 may have a variety7of shapes and sizes depending on their location and purpose. The internal fluid passageways 126, 226 may have a consistent diameter or may¬ be widened and / or narrowed in parts to direct and control the flow. By way of non-limiting example, an internal fluid passageway 126, 226 leading to a fluid impact port 108, 208 may have a frustoconical shape that is narrowest at the fluid impact port 108, 208 in order to enhance impact damage. The fluid impact ports may have a diameter ranging from about 0.125” to about 0.5”, or about 0.25”.

[0049] In various embodiments, such as shown in FIG. 2E, the drill bit 100, 200 may include outlets that comprise nozzle receptacles 234 adapted to receive nozzles 236. The nozzle receptacles 234 may be machined into the drill bit body 214 (e.g., drilled and / or threaded) or may be formed into the drill bit body 214 when it is manufactured (e.g, during casting). The shape of the nozzles 236 may be varied based on their position and / or intended functions. In various embodiments, nozzles 236 may be designed to provide a high-impact stream capable of weakening a formation. Conversely, nozzles 236 may be designed to provide a high flow for purposes of cooling and cleaning the drill bit 100, 200. The nozzles 236 may be provided in a variety of types, shapes, sizes, and dimensions, such as are known in the art. The nozzles 236 may have a fixed or adjustable flow path / direction. The nozzles 236 may be recessed into the bit body 114, 214 (e.g., on the blade 102, 202) such that distal ends of the nozzles 236 are approximately flush with the adjoining surface of the bit body 114, 214, may be below the adjoining surface of the bit body 114, 214, or may extend outward beyond the surface of the bit body 114, 214. The location of the distal ends of the nozzles 236 relative to the adjoining surface of the bit body 114, 214 may depend on the nozzles’ 236 placements on the bit body 114, 214 and the intended impact targets. By way of non-limiting example, the nozzles 236 may have an outlet diameter ranging from about 0.125” to about 0.5”, or about 0.25”. Though a single nozzle is shown in FIG. 2E, multiple nozzle receptacles 234 and nozzles 236 may be incorporated on a drill bit 200.

[0050] In various embodiments, the disclosed drill bit 100, 200 and fluid impact port 108 provide improved drilling efficiency by increasing the amount and rate of materialremoved, depth of cut, and / or rate of penetration of a drill bit 100, 200. The improved efficiency may also contribute to increased effective life of the drill bit 100, 200 and its cutting elements 104, 204.

[0051] FIG. 3A is an exposure profile of cutting elements on an earth-boring tool in accordance with embodiments of the disclosure, and FIG. 3B is the exposure profile of FIG. 3A with the cutting elements removed. In FIGS. 3A and 3B, an exposure profile for an earth-boring tool may be for a drill bit 300. The drill bit 300 may be similar to the drill bit 200, 100 previously described. The drill bit 300 comprises a plurality of blades 302a-302g (referred to collectively as blades 302) and a plurality of cutting elements 304a-l -304g-5 (referred to collectively as cutting elements 304). In FIGS. 3A and 3B, an exposure profile 340 for a drill bit 300 is shown based on superimposing positions of each of the cutting elements 304 on each of the blades 302 into a single profile. The exposure profile 340 is based on the positions of the tips of each of the cutting elements 304, and generally represents a profile created by the drill bit 300 into a formation.

[0052] For example, the drill bit 300 may comprise a drill bit body 314 with seven blades 302a-302g. A profile of each of the seven blades 302a-302g are supenmposed on one another in FIGS. 3A and 3B. A first blade 302a may comprise cutting elements 304a-l, 304a-2, 304a-3, 304a-4, 304a-5, 304a-6, and 304a-7, which are positioned on the blade 302a in the positions shown in FIG. 3A. A second blade 302b may comprise cutting elements 304b-l, 304b-2, 304b-3, 304b-4, 304b-5, and 304b-6. which are positioned on the blade 302b in the positions shown in FIG. 3A. A third blade 302c may comprise cutting elements 304c-l, 304c-2, 304c-3, 304c-4, 304c-5, 304c-6, and 304c-7, which are positioned on the blade 302c in the positions shown in FIG. 3 A. A fourth blade 302d may comprise cutting elements 304d-l, 304d-2, 304d-3, 304d-4. 304d-5, and 304d-6, which are positioned on the blade 302d in the positions shown in FIG. 3A. A fifth blade 302e may comprise cutting elements 304e-l, 304e-2, 304e-3, 304e-4, 304e-5, 304e-6, and 304e-7, which are positioned on the blade 302e in the positions shown in FIG. 3A. A sixth blade 302f may comprise cutting elements 304f-l, 304f-2, 304f-3, 304f-4, and 304f-5, which are positioned on the blade 302f in the positions shown in FIG. 3A. A seventh blade 302g may comprise cutting elements 304g-l, 304g-2, 304g-3, 304g-4, and 304g-5, which are positioned on the blade 302g in the positions shown in FIG. 3A.

[0053] The tips of the cutting elements 304 define the exposure profile 340 of the drill bit 300. FIG. 3B shows the exposure profile 340 of the drill bit 300 w ithout the cuttingelements for clarity. FIG. 3C is an enlarged view of the exposure profile of FIG. 3B with an exemplary fluid passageway. Similar to drill bits 100. 200 described previously, drill bit 300 comprises one or more fluid passageways 326 that extend from a longitudinal bore (not shown, but similar to longitudinal bores 116, 216 in drill bits 100, 200) to an outlet (e.g., fluid impact port 308) disposed on a formation-facing surface 324 of the blades 302.

[0054] FIG. 3C shows the outlet of the fluid impact port 308 being flush or even with the formation-facing surface 324. However, the outlet may be formed such that the outlet of the fluid impact port 308 is formed below the formation-facing surface 324 (e g., within a depression formed in the formation-facing surface 324) or may be formed above the formation-facing surface 324 (e.g., on a protrusion formed in the formation-facing surface 324). When the outlet is a nozzle receptacle and a nozzle is received therein, a distal end of the nozzle may be positioned to be below, even with, or above the surrounding formation-facing surface 324. The fluid impact port 308 or distal end of the nozzle may be spaced apart from the exposure profde 340 such that the fluid impact port 308 or distal end of the nozzle does not directly impact the formation during a drilling operation. In some embodiments, the fluid impact port 308 or distal end of the nozzle may be positioned from a location that is even with the surrounding formation-facing surface 324 to a location below the exposure profile 340 of the drill bit 300.

[0055] A distance between the fluid impact port 308 or distal end of the nozzle and the exposure profile 340 of the drill bit may be defined by a minimum distance between a central exit point 309 of the fluid impact port 308 or distal end of the nozzle and the exposure profile 340, as indicated by distance 342 in FIG. 3C. In some embodiments, the minimum distance 342 between the central exit point 309 of the fluid impact port 308 or distal end of the nozzle and the exposure profile 340 is 0.5 inches or less. In some embodiments, the minimum distance 342 between the central exit point 309 of the fluid impact port 308 or distal end of the nozzle and the exposure profile 340 is 0.35 inches or less. In some embodiments, the minimum distance 342 between the central exit point 309 of the fluid impact port 308 or distal end of the nozzle and the exposure profile 340 is about 0.25 inches to about 0.35 inches.

[0056] A distance between the fluid impact port 308 or distal end of the nozzle and the exposure profile 340 of the drill bit may also be defined by a distance betw een a central exit point 309 of the fluid impact port 308 or distal end of the nozzle and the exposure profile 340 taken along a central axis of the fluid passageway 326, as indicated bydistance 344 in FIG. 3C. In some embodiments, the distance 344 between the central exit point 309 of the fluid impact port 308 or distal end of the nozzle and the exposure profile 340 is 0.5 inches or less. In some embodiments, the distance 344 between the central exit point 309 of the fluid impact port 308 or distal end of the nozzle and the exposure profile 340 is 0.35 inches or less. In some embodiments, the distance 344 between the central exit point 309 of the fluid impact port 308 or distal end of the nozzle and the exposure profile 340 is about 0.28 inches to about 0.35 inches.

[0057] A distance between the fluid impact port 308 or distal end of the nozzle and the exposure profile 340 of the drill bit may also be defined by an absolute minimum distance between the fluid impact port 308 or distal end of the nozzle and the exposure profile 340, as indicated by distance 346 in FIG. 3C. In some embodiments, the distance 346 between the central exit point 309 of the fluid impact port 308 or distal end of the nozzle and the exposure profile 340 is 0.5 inches or less. In some embodiments, the distance 346 between the central exit point 309 of the fluid impact port 308 or distal end of the nozzle and the exposure profile 340 is 0.35 inches or less. In some embodiments, the distance 346 between the central exit point 309 of the fluid impact port 308 or distal end of the nozzle and the exposure profile 340 is about 0.2 inches to about 0.3 inches.

[0058] FIG. 4 is an exposure profile of an earth-boring tool with the cutting elements removed showing distal end portions of fluid passageways in accordance with embodiments of the disclosure. In some embodiments, an earth-boring tool (e.g.. drill bit 400) may be configured with outlets (e.g., fluid flow ports 410) positioned to maintain high-velocity, radially directed flow along cutter leading edges and into fluid courses to improve removal of cuttings and to improve cooling. In FIG. 4 an exposure profile of a drill bit 400 is shown that comprises blades 402 forming a formation-facing surface 424 and an exposure profile 440 based on cutting elements (not shown) disposed on the blades 402. End portions of exemplary fluid passageways 426 are schematically shown on the exposure profile of the drill bit 400 show n in FIG. 4.

[0059] At a distal end of the fluid passageways 426, a fluid flow port 410 is formed on an outer surface of the drill bit 400. In this embodiment, the fluid flow ports 410 are shown at positions below the formation-facing surface 424, such as being positioned within a fluid course (e.g., a fluid course 112, 212 (FIGS. 1A-2E)). However, the fluid flow ports 410 may be formed at other positions such as on one or more of the blades 402 (e.g., on arotationally trailing surface (e.g., 112, 222 in FIGS. 1A-2E) and / or on a raised protruding portion (e.g.. 217 in FIGS. 2A-2E) of the blades 402).

[0060] The end portion of the fluid passageways 426 and the fluid flow ports 410 may be configured such that a fluid flow pattern 413 emitted from the fluid flow ports 410 is emitted generally in the direction indicated by arrows 452a, 452b. The directions of the fluid flow patterns 413 may be oriented at a relatively high tilt angle. The tilt angle may be defined herein as an angle between the direction of the fluid flow pattern, and a direction perpendicular to a tangent of the formation-facing surface 424 intersecting with the direction of the fluid flow pattern 413. As shown in FIG. 4, atilt angle 456a of the fluid flow pattern 413 is based on the direction of the flow pattern indicated by arrow 452a and a direction perpendicular to the tangent of the formation-facing surface 424 indicated by arrow 454a. Similarly, a tilt angle 456b of another fluid flow pattern 413 is based on the direction of the flow pattern indicated by arrow 452b and a direction perpendicular to the tangent of the formation-facing surface 424 indicated by arrow 454b.

[0061] The relatively high tilt angles 456a, 456b of the fluid flow ports 410 are oriented such that the fluid flow patterns skim the rock formation surface and flow relatively parallel to faces of the cutting elements. In this manner, a higher velocity of fluid can be maintained within the fluid courses (e.g., fluid courses 112, 212 (FIGS. 1A-2E)) to enhance transport of cuttings and increase cooling efficiency. In some examples, the tilt angles 456a, 456b may be from about 25° to about 70°. In some examples, the title angles 456a, 456b may be from about 35° to about 70°. In some embodiments, such as where the fluid flow ports 410 are formed on a rotationally trailing surface of blade 402 and / or on a raised protruding portion (e.g., raised protruding portion 217), the tilt angles 456a, 456b may be from about 456a, 456b may be from about 25° to about 90°.

[0062] To form the fluid passageways 426 such that the fluid flow ports 410 have a relatively high tilt angle may require complex passage routing from the longitudinal bore (e.g., longitudinal bore 116, 216 (FIGS. 1 A-2E) to the fluid flow ports 410. To form the drill bit 400 with such fluid passageways 426, manufacturing techniques such as those described in U.S. Patent Application No. 19 / 441,565. which was filed on January 6, 2026. may be used. The contents of U.S. Patent Application No. 19 / 441,565 are hereby incorporated by reference in their entirety.

[0063] For example, an additive manufacturing process may be used to form a blank for casting the drill bit as described above. FIG. 5 is a perspective view of a top portion of ablank 560 for creating fluid passageways in an earth boring tool according to embodiments of the disclosure. The blank 560 may comprise a bore displacement 562 (only atop portion of which is shown in FIG. 5) which corresponds to a distal end of a longitudinal bore (e.g., longitudinal bore 116, 216 (FIGS. 1A-2E)) of the drill bit. One or more main passageway displacements 564 may extend from the bore displacement 562, and one or more fluid passageway displacements 566 may extend from each of the main passageway displacements in a plurality of different directions 552. The main passageway displacements 564 and fluid passageway displacements 566 may correspond to fluid passageways (e.g., fluid passageways 426 (FIG. 4)) in a drill bit. As shown in FIG. 5, at least one of the main passagew ay displacements 564 and fluid passageway displacements 566 is formed with a complex geometry. That is, at least one of the main passageway displacements 564 and fluid passageway displacements 566 is formed with a curved profde (e.g., does not extend in a single, straight direction). The complex geometry of the at least one of the main passageway displacements 564 and fluid passagew ay displacements 566 may facilitate the formation of the relatively high tilt angle of the fluid flow ports (e.g., fluid flow ports 410 (FIG. 4)) of the drill bit when the blank 560 is used to form the drill bit.

[0064] As mentioned above, by utilizing fluid flow7ports with high tilt angles, the fluid flow ports may facilitate the removal of cuttings through the fluid courses and may increase cooling efficiency. By using fluid flow ports with a high tilt angle, the flow from fluid flow ports is directed through the fluid courses of the drill bit substantially parallel to cutting faces of cutting elements of the drill bit. FIG. 6 is a graph showing exemplary fluid velocities in front of 30 different cutters of one or more blades an earth-boring tool when utilizing fluid flow ports having high tilt angles. As shown in FIG. 6, the fluid flow ports with a high tilt angle may maintain a fluid velocity around or above about 10 ft / s in front of almost all of the cutters of a drill bit. Furthermore, the velocity of the fluid may be maintained above 80 ft / s in front of about half of the cutters. This fluid velocity in front of the cutters may help remove cuttings from in front of the cutters through the fluid courses and may increase cooling efficiency of the fluid.

[0065] FIG. 7 illustrates an example method 700 of drilling a wellbore with an earth-boring tool configured to direct drilling fluid in a manner that weakens a rock formation adjacent to the earth-boring tool and / or promotes transport of cuttings and cooling / cleaning in the vicinity7of cutting elements. In some embodiments, the method 700 is performed using anearth-boring tool of the type described herein (e.g., the tools shown in FIGS. 1 A-4), which may include one or more blades with cutting elements thereon and one or more outlets in fluid communication with internal passageways supplying drilling fluid.

[0066] Act 702 of method 700 includes providing an earth-boring tool (e.g., drill bits 100, 200, 300, 400) having a bit body, at least one blade extending from the bit body, and at least one cutting element on the at least one blade, and further having at least one fluid course positioned rotationally in front of the at least one cutting element (e.g., located angularly ahead of the cutting element with respect to an intended direction of rotation during drilling).

[0067] In some embodiments, the earth-boring tool provided in act 702 includes at least one outlet (including, for example, a port, a nozzle receptacle, and / or a nozzle insert) disposed on or adjacent to the at least one blade and in fluid communication with one or more internal fluid passageways. Without limitation, the outlet may be positioned within a fluid course adjacent to the at least one blade or on a blade surface such as on a formationfacing surface, on a rotationally trailing surface, and / or on a raised protruding portion of the blade that extends rotationally behind a remainder of the blade, depending on the desired flow direction and packaging constraints. The outlet may be located in a cone region, nose region, and / or shoulder region of the earth-boring tool (for example, depending on whether flow is intended to service a particular radial band of cutting elements). The outlets may be positioned such that the drilling fluid discharged from the outlet flows rotationally in front of the at least one cutting element.

[0068] Act 704 of method 700 includes rotating the earth-boring tool about a central axis in a direction of rotation during drilling such that the at least one cutting element engages a formation. As the tool rotates, the at least one outlet positioned in front of the cutting element (relative to the direction of rotation) presents a flow path for drilling fluid to enter a region that the cutting element is about to enter.

[0069] Act 706 of method 700 includes pumping drilling fluid through the earth-boring tool and discharging at least a portion of the drilling fluid from the at least one outlet disposed on or adjacent to the at least one blade to flow along the flow path. In some embodiments, the outlet is oriented such that the discharged drilling fluid exits at a relatively high tilt angle, which may be defined as an angle between (i) a direction of the emitted fluid flow pattern and (ii) a direction perpendicular to a tangent of a formationfacing surface intersecting the emitted fluid flow pattern. In some examples, the tilt angle isfrom about 25° to about 90°. In some examples, the tilt angle is from about 35° to about 90°. In some examples the tilt angle is from about 35° to about 70°. In some embodiments, the outlet is oriented such that the discharged drilling fluid impacts a rock formation to weaken a rock formation in front of the cutting element.

[0070] In operation, a relatively high tilt angle may be selected such that discharged drilling fluid skims a formation-facing region and / or flows substantially parallel to faces of cutting elements through the fluid course, thereby maintaining higher fluid velocity within the fluid course to enhance transport of cuttings and increase cooling / cleaning efficiency. In some non-limiting examples, the outlet orientation and / or internal passageway routing may be configured to maintain elevated drilling-fluid velocities in front of multiple cutters during drilling, which may assist in removing cuttings from in front of cutters through the fluid courses and improving cooling efficiency.

[0071] In some embodiments, discharging the drilling fluid in act 706 includes discharging through a nozzle positioned within a nozzle receptacle formed in the bit body and / or blade, where the nozzle may be selected to provide a desired flow pattern (e.g., higher flow for cooling / cleaning) and may be recessed, flush, or protruding relative to an adjoining surface depending on placement and intended function. The outlet and associated internal passageways may have any suitable geometry (including, in some embodiments, complex / curved routing) to achieve the desired discharge location and tilt angle while maintaining structural integrity of the bit body and blades.

[0072] In some embodiments, the outlet used in act 706 is positioned at a radial position selected to correspond to a radial position of a cutting element (or a group of cutting elements) such that discharged drilling fluid preferentially ser ices a target radial group of cutting elements by flowing into the fluid course in front of the corresponding cutting elements. The outlets may be positioned to maintain high-velocity, radially directed flow along cutter leading edges and into fluid courses to improve removal of cuttings and cooling.

[0073] In some implementations of method 700, the earth-boring tool provided in act 702 includes one or more outlets configured as impact outlets (sometimes referred to herein as fluid impact ports (e g., fluid impact ports 108, 208)) that, during act 706, discharge drilling fluid in a jet directed to impact the rock formation at an impact point that is in front of (i.e., rotationally ahead of) at least one cutting element with respect to the direction of rotation of act 704. In these implementations, the jet can locally erode, fracture, or otherwiseweaken the formation immediately before engagement by the cutting element, thereby facilitating cutting and / or improving drilling efficiency. The impact outlets may be disposed on a formation-facing surface of a blade, on or adjacent to a blade surface, within a blade-adjacent feature that communicates with an internal passageway, and / or at another location suitable to achieve the desired impact point ahead of the cutting element (for example, as illustrated and described in connection with the exposure-profile and outletplacement examples in other figures).

[0074] In such impact-jet implementations, the orientation, exit geometry, and placement of the outlet can be selected so that the jet maintains sufficient coherence and momentum to reach the formation at the intended impact point and within a desired standoff distance from the cutter engagement region. For example, the outlet may include a nozzle and / or nozzle receptacle and may be positioned at a radial location corresponding to a radial position of a target cutting element (or group of cutting elements) so that the jet impacts a formation region that the cutting element is about to contact. In some embodiments, impact outlets may be used in combination with high-tilt-angle outlets described above — e.g., one subset of outlets directs drilling fluid along one or more fluid courses for cuttings transport and cooling / cleaning, while another subset directs one or more jets to impact and weaken formation ahead of one or more cutting elements — such that both hydraulic functions are provided during the same drilling operation. In this manner, the drilling fluid may be used to impact and weaken a rock formation in front of the cutting element and / or to convey cuttings generated by the cutting element away from the cutting region through the fluid course.

[0075] The acts shown in FIG. 7 are illustrative and may be modified in order, combined, subdivided, repeated, or performed with additional acts in a manner consistent with the present disclosure. For example, one or more outlets and / or nozzles may be used on a given blade and / or at different radial positions, and the earth-boring tool may include multiple blades with corresponding fluid courses such that multiple cutters are serviced by corresponding high-tilt-angle discharge streams.

[0076] The technologies described herein are not limited to the specific embodiments discussed above. For example, the high tilt angle fluid flow ports (e.g., fluid flow ports 410) may be configured as nozzle receptacles to receive nozzles therein for directing the fluid in a desired spray pattern. In some embodiments, high tilt angle fluid flow ports(e.g., fluid flow ports 410 (FIG. 4)) may be used in combination with fluid impact ports (e.g., fluid impact ports 108. 208, 308 (FIGS. 1A-3C)) on a drill bit.

[0077] Non-limiting example embodiments of the present disclosure may include:

[0078] Embodiment 1. An earth-boring tool comprising a bit body, at least one blade on the bit body comprising at least one cutting element, and at least one outlet disposed on or adj acent to the at least one blade in a cone region, a nose region, or a shoulder region of the earth-boring tool, the at least one outlet being configured to discharge a drilling fluid at a tilt angle of about 25° to about 90°.

[0079] Embodiment 2. The earth-boring tool of Embodiment 1, wherein the at least one blade comprises a rotationally trailing surface, and wherein the at least one outlet is disposed on or adjacent to the rotationally trailing surface.

[0080] Embodiment 3. The earth-boring tool of Embodiment 1, wherein the at least one blade comprises a raised protruding portion that extends rotationally behind a remainder of the at least one blade, and wherein the at least one outlet is disposed on or adjacent to the raised protruding portion.

[0081] Embodiment 4. The earth-boring tool of Embodiment 1, wherein the at least one outlet is formed in a fluid course adjacent to the at least one blade.

[0082] Embodiment 5. The earth-boring tool of any one of Embodiments 1 to 4, further comprising a fluid impact port disposed at a radial position on the bit body corresponding to a radial position of the at least one cutting element disposed on a rotationally leading surface of the at least one blade such that a drilling fluid impacts a formation at a point rotationally in front of the at least one cutting element.

[0083] Embodiment 6. The earth-boring tool of and one of Embodiments 1 to 5, wherein the at least one outlet comprises a plurality of outlets on or adjacent to the at least one blade.

[0084] Embodiment 7. The earth-boring tool of any one of Embodiments 1 to 6, wherein the at least one outlet comprises at least one nozzle receptacle, and wherein the earthboring tool further comprises at least one nozzle attached to the at least one nozzle receptacle in the at least one blade.

[0085] Embodiment 8. A method of forming an earth-boring tool comprising forming a bit body, providing a first blade and a second blade on the bit body with the first blade being disposed rotationally in front of the second blade, providing at least one cutting element on the second blade, and providing at least one outlet on or adjacent to the first blade, the atleast one outlet being configured to discharge a drilling fluid rotationally in front of the at least one cutting element of the second blade and substantially parallel to a cutting face of the at least one cutting element.

[0086] Embodiment 9. The method of Embodiment 8, wherein providing at least one outlet on or adj acent to the first blade further comprises providing at least one fluid impact port on or adj acent to the first blade configured to discharge the drilling fluid to impact a formation at a point rotationally in front of the at least one cutting element of the second blade.

[0087] Embodiment 10. The method of Embodiment 9, wherein providing the at least one fluid impact port on or adjacent to the first blade comprises providing a plurality of fluid impact ports on or adjacent to the first blade; providing at least one cutting element on the second blade comprises providing a plurality of cutting elements on the second blade; and each of the plurality of fluid impact ports is positioned on or adjacent to the first blade and is configured to discharge the drilling fluid to impact a formation at a point rotationally in front of one of the plurality’ of cutting elements of the second blade.

[0088] Embodiment 11. The method of any one of Embodiments 8 to 10, wherein providing at least one outlet on or adjacent to the first blade further comprises providing at least one nozzle receptacle and at least one nozzle attached to the nozzle receptacle at the at least one outlet.

[0089] Embodiment 12. The method of any one of Embodiments 8 to 11, wherein providing at least one outlet on or adjacent to the first blade comprises providing at least one fluid flow port on or adjacent to the first blade configured to discharge a drilling fluid into a fluid course between the first blade and the second blade.

[0090] Embodiment 13. The method of Embodiment 12, wherein the providing the at least one fluid flow port comprises forming the at least one fluid flow port to discharge the drilling fluid at a tilt angle of about 25° to about 90°.

[0091] Embodiment 14. The method of Embodiment 12 or 13, wherein the providing the at least one fluid flow port comprises forming the at least one fluid flow port in the fluid course between the first blade and the second blade.

[0092] Embodiment 15. The method of claim 12, wherein providing the at least one fluid flow port comprises forming a fluid passagew ay betw een a longitudinal bore of the earthboring tool and the at least one fluid flow port, and wherein the fluid passageway has a curved profile.Embodiment 16. An earth-boring tool comprising a bit body, a plurality of blades on the bit body, each blade comprising a rotationally leading surface having a plurality of cutting elements thereon and a formation-facing surface, and a plurality of outlets positioned on or adjacent to the formation-facing surface of each blade, the plurality of outlets being configured to discharge a drilling fluid that impacts a formation at a point rotationally in front of the plurality of cutting elements of a respective rotationally trailing blade of the plurality of blades.

[0093] Embodiment 17. The earth-boring tool of Embodiment 16, wherein the plurality of outlets further comprises at least one fluid impact port.

[0094] Embodiment 18. The earth-boring tool of Embodiment 17 or 16, wherein the plurality of cutting elements defines an exposure profile of the earth-boring tool, and wherein a minimum distance between a central exit point of the at least one fluid impact port and the exposure profile is less than 0.5 inches.

[0095] Embodiment 19. The earth-boring tool of any one of Embodiments 16 to 18, wherein the plurality of outlets further comprises at least one nozzle receptacle, and wherein at least one nozzle is attached to the at least one nozzle receptacle.

[0096] Embodiment 20. The earth-boring tool of Embodiment 19, wherein the plurality of cutting elements defines an exposure profile of the earth-boring tool, and wherein a distance between a distal end of the at least one nozzle and the exposure profile is less than 0.5 inches.

[0097] Embodiment 21. The earth-boring tool of any one of Embodiments 16 to 20, wherein the plurality of outlets is positioned at about a same radial position relative to a central axis of the earth-boring tool.

[0098] Embodiment 22. A method of drilling a wellbore, comprising providing an earthboring tool comprising a bit body and at least one blade extending from the bit body, the at least one blade cartying at least one cutting element, and the earth-boring tool further comprising at least one fluid course positioned in front of the at least one cutting element; rotating the earth-boring tool about a central axis in a direction of rotation; and pumping drilling fluid through the earth-boring tool and discharging at least a portion of the drilling fluid from at least one outlet disposed on or adjacent to the at least one blade, wherein the at least one outlet is oriented to discharge the drilling fluid at a tilt angle from about 25 degrees to about 90 degrees, such that the discharged drilling fluid flows along the at least one fluid course in front of the at least one cutting element during drilling.Embodiment 23. The method of Embodiment 22, wherein the at least one outlet is disposed in a cone region, a nose region, or a shoulder region of the earth-boring tool.

[0099] Embodiment 24. The method of Embodiment 22 or 23, wherein the at least one outlet is disposed on or adjacent to a rotationally trailing surface of the at least one blade, and wherein the at least a portion of the drilling fluid discharged from the at least one outlet flows along the at least one fluid course.

[0100] Embodiment 25. The method of any one of Embodiments 22 to 24. wherein discharging at least the portion of the drilling fluid from the at least one outlet comprises discharging the drilling fluid through a nozzle positioned within a nozzle receptacle formed in the bit body or the at least one blade.

[0101] Embodiment 26. The method of any one of Embodiments 22 to 25, wherein the at least one outlet is positioned at a radial position corresponding to a radial position of the at least one cutting element.

[0102] The embodiments of the disclosure described above and illustrated in the accompanying drawings do not limit the scope of the disclosure, which is encompassed by the scope of the appended claims and their legal equivalents. Any equivalent embodiments are within the scope of this disclosure. Indeed, various modifications of the disclosure, in addition to those show n and described herein, such as alternate useful combinations of the elements described, will become apparent to those skilled in the art from the description. Such modifications and embodiments also fall within the scope of the appended claims and equivalents.

Claims

CLAIMSWhat is claimed is:

1. An earth-boring tool, comprising:a bit body;at least one blade on the bit body comprising at least one cutting element; andat least one outlet disposed on or adjacent to the at least one blade in a cone region, a nose region, or a shoulder region of the earth-boring tool, and the at least one outlet being configured to discharge a drilling fluid at a tilt angle of about 25° to about 90°.

2. The earth-boring tool of claim 1, wherein the at least one blade comprises a rotationally trailing surface, and wherein the at least one outlet is disposed on or adjacent to the rotationally trailing surface.

3. The earth-boring tool of claim 1, wherein the at least one blade comprises a raised protruding portion that extends rotationally behind a remainder of the at least one blade, and wherein the at least one outlet is disposed on or adjacent to the raised protruding portion.

4. The earth-boring tool of claim 1, wherein the at least one outlet is formed in a fluid course adj acent to the at least one blade.

5. The earth-boring tool of claim 1, further comprising a fluid impact port disposed at a radial position on the bit body corresponding to a radial position of the at least one cutting element disposed on a rotationally leading surface of the at least one blade such that a drilling fluid impacts a formation at a point rotationally in front of the at least one cutting element.

6. The earth-boring tool of claim 1, wherein the at least one outlet comprises a plurality of outlets on or adjacent to the at least one blade.

7. The earth-boring tool of claim 1, wherein the at least one outlet comprises at least one nozzle receptacle, and wherein the earth-boring tool further comprises at least one nozzle attached to the at least one nozzle receptacle in the at least one blade.

8. A method of forming an earth-boring tool, comprising:forming a bit body;providing a first blade and a second blade on the bit body, the first blade being disposed rotationally in front of the second blade;providing at least one cutting element on the second blade; andproviding at least one outlet on or adjacent to the first blade, the at least one outlet being configured to discharge a drilling fluid rotationally in front of the at least one cutting element of the second blade and substantially parallel to a cutting face of the at least one cutting element.

9. The method of claim 8, wherein providing at least one outlet on or adjacent to the first blade further comprises providing at least one fluid impact port on or adjacent to the first blade configured to discharge the drilling fluid to impact a formation at a point rotationally in front of the at least one cutting element of the second blade.

10. The method of claim 9, wherein:providing the at least one fluid impact port on or adjacent to the first blade comprises providing a plurality of fluid impact ports on or adjacent to the first blade; providing at least one cutting element on the second blade comprises providing a plurality of cutting elements on the second blade; andeach of the plurality of fluid impact ports is positioned on or adjacent to the first blade and is configured to discharge the drilling fluid to impact a formation at a point rotationally in front of one of the plurality7of cutting elements of the second blade.

11. The method of claim 8, wherein providing at least one outlet on or adjacent to the first blade further comprises providing at least one nozzle receptacle and at least one nozzle attached to the nozzle receptacle at the at least one outlet.

12. The method of claim 8, wherein providing at least one outlet on or adjacent to the first blade comprises providing at least one fluid flow port on or adjacent to the first blade configured to discharge a drilling fluid into a fluid course between the first blade and the second blade.

13. The method of claim 12, wherein the providing the at least one fluid flow port comprises forming the at least one fluid flow port to discharge the drilling fluid at a tilt angle of about 25° to about 90°.

14. The method of claim 12, wherein the providing the at least one fluid flow port comprises forming the at least one fluid flow port in the fluid course between the first blade and the second blade.

15. The method of claim 12, wherein providing the at least one fluid flow port comprises forming a fluid passageway between a longitudinal bore of the earth-boring tool and the at least one fluid flow port, and wherein the fluid passageway has a curved profile.

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