Patent Publication Number: US-8122980-B2

Title: Rotary drag bit with pointed cutting elements

Description:
BACKGROUND OF THE INVENTION 
     1. Field 
     This invention relates to drill bits, specifically drill bit assemblies for use in oil, gas and geothermal drilling. More particularly, the invention relates to cutting elements in rotary drag bits comprised of a carbide substrate with a non-planar interface and an abrasion resistant layer of super hard material affixed thereto using a high pressure high temperature press apparatus. Such cutting elements typically comprise a super hard material layer or layers formed under high temperature and pressure conditions usually in a press apparatus designed to create such conditions, cemented to a carbide substrate containing a metal binder or catalyst such as cobalt. 
     2. Relevant Technology 
     A cutting element or insert is normally fabricated by placing a cemented carbide substrate into a container or cartridge with a layer of diamond crystals or grains loaded into the cartridge adjacent one fact of the substrate. A number of such cartridges are typically loaded into a reaction cell and placed in the high-pressure/high-temperature (HPHT) apparatus. The substrates and adjacent diamond crystal layers are then compressed under HPHT conditions which promotes a sintering of the diamond grains to form the polycrystalline diamond structure. As a result, the diamond grains become mutually bonded to form a diamond layer over the substrate interface. 
     Such cutting elements are often subjected to intense forces, torques, vibration, high temperatures and temperature differentials during operation. As a result, stresses within the structure may begin to form. Drag bits for example may exhibit stresses aggravated by drilling anomalies during well boring operations such as bit whirl or bounce often resulting in spalling, delamination or fracture of the super hard abrasive layer or the substrate thereby reducing or eliminating the cutting elements efficacy and decreasing overall drill bit wear life. The super hard material layer of a cutting element sometimes delaminates from the carbide substrate after the sintering process as well as during percussive and abrasive use. Damage typically found in drag bits may be a result of shear failures, although non-shear modes of failure are not uncommon. The interface between the super hard material layer and substrate is particularly susceptible to non-shear failure modes due to inherent residual stresses. 
     U.S. Pat. No. 6,332,503 by Pessier et al, which is herein incorporated by reference for all that it contains, discloses an array of chisel-shaped cutting elements are mounted to the face of a fixed cutter bit. Each cutting element has a crest and an axis which is inclined relative to the borehole bottom. The chisel-shaped cutting elements may be arranged on a selected portion of the bit, such as the center of the bit, or across the entire cutting surface. In addition, the crest on the cutting elements may be oriented generally parallel or perpendicular to the borehole bottom. 
     U.S. Pat. No. 6,408,959 by Bertagnolli et al., which is herein incorporated by reference for all that it contains, discloses a cutting element, insert or compact which is provided for use with drills used in the drilling and boring of subterranean formations. 
     U.S. Pat. No. 6,484,826 by Anderson et al., which is herein incorporated by reference for all that it contains, discloses enhanced inserts formed having a cylindrical grip and a protrusion extending from the grip. 
     U.S. Pat. No. 5,848,657 by Flood et al, which is herein incorporated by reference for all that it contains, discloses domed polycrystalline diamond cutting element wherein a hemispherical diamond layer is bonded to a tungsten carbide substrate, commonly referred to as a tungsten carbide stud. Broadly, the inventive cutting element includes a metal carbide stud having a proximal end adapted to be placed into a drill bit and a distal end portion. A layer of cutting polycrystalline abrasive material disposed over said distal end portion such that an annulus of metal carbide adjacent and above said drill bit is not covered by said abrasive material layer. 
     U.S. Pat. No. 4,109,737 by Bovenkerk which is herein incorporated by reference for all that it contains, discloses a rotary bit for rock drilling comprising a plurality of cutting elements mounted by interence-fit in recesses in the crown of the drill bit. Each cutting element comprises an elongated pin with a thin layer of polycrystalline diamond bonded to the free end of the pin. 
     US Patent Application Serial No. 2001/0004946 by Jensen, although now abandoned, is herein incorporated by reference for all that it discloses. Jensen teaches that a cutting element or insert with improved wear characteristics while maximizing the manufacturability and cost effectiveness of the insert. This insert employs a superabrasive diamond layer of increased depth and by making use of a diamond layer surface that is generally convex. 
     BRIEF SUMMARY OF THE INVENTION 
     In one aspect of the present invention, a rotary drag bit has a bit body intermediate a shank and a working surface, the working surface having a plurality of blades converging at a center of the working surface and diverging towards a gauge of the working surface. At least one blade has a cutting element with a carbide substrate bonded to a diamond working end with a pointed geometry; the diamond working end having a central axis which intersects an apex of the pointed geometry; wherein the axis is oriented within a 15 degree rake angle. 
     In some embodiments, the rotary drag bit, has a bit body intermediate a shank and a working surface, the working surface having a cutting element with a carbide substrate bonded to a diamond working end with a pointed geometry; the diamond working end having a central axis which intersects an apex of the pointed geometry; wherein the axis is oriented within a 15 degree rake angle. 
     In some embodiments, the rake angle may be negative and in other embodiments, the axis may be substantially parallel with the shank portion of the bit. The cutting element may be attached to a cone portion a nose portion, a flank portion and/or a gauge portion of at least one blade. Each blade may comprise a cutting element with a pointed geometry. 
     The pointed geometry may comprise 0.050 to 0.200 inch radius and may comprise a thickness of at least 0.100 inches. The diamond working end may be processed in a high temperature high pressure press. The diamond working end may be cleaned in vacuum and sealed in a can by melting a sealant disk within the can prior to processing in the high temperature high pressure press. A stop off also within the can may control a flow of the melting disk. The diamond working end may comprise infiltrated diamond. In some embodiments, the diamond working end may comprise a metal catalyst concentration of less than 5 percent by volume. The diamond working end may be bonded to the carbide substrate at an interface comprising a flat normal to the axis of the cutting element. A surface of the diamond working end may be electrically insulating. The diamond working end may comprise an average diamond grain size of 1 to 100 microns. The diamond working end may comprise a characteristic of being capable of withstanding greater than 80 joules in a drop test with carbide targets 
     The rotary drag bit may further comprise a jack element with a distal end extending beyond the working face. In other embodiments, another cutting element attached to the at least one blade may comprises a flat diamond working end. The cutting element with the flat diamond working end may precede or trail behind the cutting element with the pointed geometry in the direction of the drill bit&#39;s rotation. The cutting element with the pointed geometry may be in electric communication with downhole instrumentation, such as a sensor, actuator, piezoelectric device, transducer, magnetostrictive device, or a combination thereof. 
    
    
     
       BRIEF DESCRIPTION OF THE DRAWINGS 
         FIG. 1  is a perspective diagram of an embodiment of a drill string suspended in a bore hole. 
         FIG. 2  is a side perspective diagram of an embodiment of a drill bit. 
         FIG. 3  is a cross-sectional diagram of an embodiment of a cutting element. 
         FIG. 3   a  is a cross-sectional diagram of another embodiment of a cutting element. 
         FIG. 3   b  is a cross-sectional diagram of another embodiment of a cutting element. 
         FIG. 3   c  is a cross-sectional diagram of another embodiment of a cutting element. 
         FIG. 3   d  is a cross-sectional diagram of another embodiment of a cutting element. 
         FIG. 4  is a cross-sectional diagram of an embodiment of an assembly for HPHT processing. 
         FIG. 5  is a cross-sectional diagram of another embodiment of a cutting element 
         FIG. 5   a  is a cross-sectional diagram of another embodiment of a cutting element. 
         FIG. 5   b  is a cross-sectional diagram of another embodiment of a cutting element. 
         FIG. 6  is a diagram of an embodiment of test results. 
         FIG. 7   a  is a cross-sectional diagram of another embodiment of a cutting element. 
         FIG. 7   b  is a cross-sectional diagram of another embodiment of a cutting element. 
         FIG. 7   c  is a cross-sectional diagram of another embodiment of a cutting element. 
         FIG. 7   d  is a cross-sectional diagram of another embodiment of a cutting element. 
         FIG. 7   e  is a cross-sectional diagram of another embodiment of a cutting element. 
         FIG. 7   f  is a cross-sectional diagram of another embodiment of a cutting element. 
         FIG. 7   g  is a cross-sectional diagram of another embodiment of a cutting element. 
         FIG. 7   h  is a cross-sectional diagram of another embodiment of a cutting element. 
         FIG. 8  is a cross-sectional diagram of an embodiment of a drill bit. 
         FIG. 9  is a perspective diagram of another embodiment of a drill bit. 
         FIG. 9   a  is a perspective diagram of another embodiment of a drill bit. 
         FIG. 10  is a method of an embodiment for fabricating a drill bit. 
     
    
    
     DETAILED DESCRIPTION OF THE INVENTION AND THE PREFERRED EMBODIMENT 
     Referring now to the figures,  FIG. 1  is a cross-sectional diagram of an embodiment of a drill string  100  suspended by a derrick  101 . A bottom hole assembly  102  is located at the bottom of a bore hole  103  and comprises a rotary drag bit  104 . As the drill bit  104  rotates down hole the drill string  100  advances farther into the earth. The drill string  100  may penetrate soft or hard subterranean formations  105 . 
       FIG. 2  discloses a drill bit  104  of the present invention. The drill bit  104  comprises a shank  200  which is adapted for connection to a down hole tool string such as drill string comprising drill pipe, drill collars, heavy weight pipe, reamers, jars, and/or subs. In some embodiments coiled tubing or other types of tool string may be used. The drill bit  104  of the present invention is intended for deep oil and gas drilling, although any type of drilling application is anticipated such as horizontal drilling, geothermal drilling, mining, exploration, on and off-shore drilling, directional drilling, water well drilling and any combination thereof. The bit body  201  is attached to the shank  200  and comprises an end which forms a working face  202 . Several blades  203  extend outwardly from the bit body  201 , each of which may comprise a plurality of cutting elements  208  which may have a pointed geometry  700 . A drill bit  104  most suitable for the present invention may have at least three blades  203 ; preferably the drill bit  104  will have between three and seven blades  203 . The blades  203  collectively form an inverted conical region  205 . Each blade  203  may have a cone portion  253 , a nose portion  206 , a flank portion  207 , and a gauge portion  204 . Cutting elements  208  may be arrayed along any portion of the blades  203 , including the cone portion  253 , nose portion  206 , flank portion  207 , and gauge portion  204 . A plurality of nozzles  209  are fitted into recesses  210  formed in the working face  202 . Each nozzle  209  may be oriented such that a jet of drilling mud ejected from the nozzles  209  engages the formation before or after the cutting elements  208 . The jets of drilling mud may also be used to clean cuttings away from drill bit  104 . In some embodiments, the jets may be used to create a sucking effect to remove drill bit cuttings adjacent the cutting elements  208  by creating a low pressure region within their vicinities. 
     The pointed cutting elements are believed to increase the ratio of formation removed upon each rotation of the drill bit to the amount of diamond worn off of the cutting element per rotation of the drill bit over the traditional flat shearing cutters of the prior art. Generally the traditional flat shearing cutters of the prior art will remove 0.010 inch per rotation of a Sierra White Granite wheel on a VTL test with 4200-4700 pounds loaded to the shearing element with the granite wheel. The granite removed with the traditional flat shearing cutter is generally in a powder form. With the same parameters, the pointed cutting elements with a 0.150 thick diamond and with a 0.090 to 0.100 inch radius apex positioned substantially at a zero rake removed over 0.200 inches per rotation in the form of chunks. 
       FIGS. 3 through 3   b  disclose the cutting element  208  in contact with a subterranean formation  105  wherein the axis  304  is oriented within a 15 degree rake angle  303 . The rake angle  303  may be positive as shown in  FIG. 3 , negative as shown in  FIG. 3   a , or it may comprises a zero rake as shown in  FIG. 3   b . Cutting element in the gauge portion, flank portion, nose portion, or cone portion of the blades may have a negative rake, positive rake, or zero rake. The positive rake may be between positive 15 degrees and approaching a zero rake, while the negative rake may also be between negative 15 degrees and approaching a zero rake. In some embodiments, the substrate may be brazed to a larger carbide piece  351 . This may be advantageous since it may be cheaper to bond the small substrate to the diamond working end in the press. The larger carbide piece may then be brazed, bonded, or press fit into the bit blade. The bit blade may be made of carbide or steel. 
       FIG. 3   c  discloses an embodiment of a cutting element  208  with a pointed diamond working end preceding another cutting element  350  with a flat diamond working end  360 .  FIG. 3   d  discloses the cutting element  208  trailing behind the other cutting element  360 . 
       FIG. 4  is a cross-sectional diagram of an embodiment for a high pressure high temperature (HPHT) processing assembly  400  comprising a can  401  with a cap  402 . At least a portion of the can  401  may comprise niobium, a niobium alloy, a niobium mixture, another suitable material, or combinations thereof. At least a portion of the cap  402  may comprise a metal or metal alloy. 
     A can such as the can of  FIG. 4  may be placed in a cube adapted to be placed in a chamber of a high temperature high pressure apparatus. Prior to placement in a high temperature high pressure chamber the assembly may be placed in a heated vacuum chamber to remove the impurities from the assembly. The chamber may be heated to 1000 degrees long enough to vent the impurities that may be bonded to superhard particles such as diamond which may be disposed within the can. The impurities may be oxides or other substances from the air that may readily bond with the superhard particles. After a reasonable venting time to ensure that the particles are clean, the temperature in the chamber may increase to melt a sealant  410  located within the can adjacent the lids  412 ,  408 . As the temperature is lowered the sealant solidifies and seals the assembly. After the assembly has been sealed it may undergo HPHT processing producing a cutting element with an infiltrated diamond working end and a metal catalyst concentration of less than 5 percent by volume which may allow the surface of the diamond working end to be electrically insulating. 
     The assembly  400  comprises a can  401  with an opening  403  and a substrate  300  lying adjacent a plurality of super hard particles  406  grain size of 1 to 100 microns. The super hard particles  406  may be selected from the group consisting of diamond, polycrystalline diamond, thermally stable products, polycrystalline diamond depleted of its catalyst, polycrystalline diamond having nonmetallic catalyst, cubic boron nitride, cubic boron nitride depleted of its catalyst, or combinations thereof. The substrate  300  may comprise a hard metal such as carbide, tungsten-carbide, or other cemented metal carbides. Preferably, the substrate  300  comprises a hardness of at least 58 HRc. 
     A stop off  407  may be placed within the opening  403  of the can  401  in-between the substrate  300  and a first lid  408 . The stop off  407  may comprise a material selected from the group consisting of a solder/braze stop, a mask, a tape, a plate, and sealant flow control, boron nitride, a non-wettable material or a combination thereof. In one embodiment the stop off  407  may comprise a disk of material that corresponds with the opening of the can  401 . A gap  409  between 0.005 to 0.050 inches may exist between the stop off  407  and the can  401 . The gap  409  may support the outflow of contamination while being small enough size to prevent the flow of a sealant  410  into the mixture  404 . Various alterations of the current configuration may include but should not be limited to; applying a stop off  407  to the first lid  408  or can by coating, etching, brushing, dipping, spraying, silk screening painting, plating, baking, and chemical or physical vapor deposition techniques. The stop off  407  may in one embodiment be placed on any part of the assembly  400  where it may be desirable to inhibit the flow of the liquefied sealant  410 . 
     The first lid  408  may comprise niobium or a niobium alloy to provide a substrate that allows good capillary movement of the sealant  410 . After the first lid  408  is installed within the can, the walls  411  of the can  401  may be folded over the first lid  408 . A second lid  412  may then be placed on top of the folded walls  401 . The second lid  412  may comprise a material selected from the group consisting of a metal or metal alloy. The metal may provide a better bonding surface for the sealant  410  and allow for a strong bond between the lids  408 ,  412 , can  401  and a cap  402 . Following the second lid  412  a metal or metal alloy cap  402  may be placed on the can  401 . 
     Now referring to  FIG. 5 , the substrate  300  comprises a tapered surface  500  starting from a cylindrical rim  504  of the substrate and ending at an elevated, flatted, central region  501  formed in the substrate. The diamond working end  506  comprises a substantially pointed geometry  520  with a sharp apex  502  comprising a radius of 0.050 to 0.125 inches. In some embodiments, the radius may be 0.900 to 0.110 inches. It is believed that the apex  502  is adapted to distribute impact forces across the flatted region  501 , which may help prevent the diamond working end  506  from chipping or breaking. The diamond working end  506  may comprise a thickness  508  of 0.100 to 0.500 inches from the apex to the flatted region  501  or non-planar interface, preferably from 0.125 to 0.275 inches. The diamond working end  506  and the substrate  300  may comprise a total thickness  507  of 0.200 to 0.700 inches from the apex  502  to a base  503  of the substrate  300 . The sharp apex  502  may allow the drill bit to more easily cleave rock or other formations. 
     The pointed geometry  520  of the diamond working end  506  may comprise a side which forms a 35 to 55 degree angle  555  with a central axis  304  of the cutting element  208 , though the angle  555  may preferably be substantially 45 degrees. The included angle may be a 90 degree angle, although in some embodiments, the included angle is 85 to 95 degrees. 
     The pointed geometry  520  may also comprise a convex side or a concave side. The tapered surface of the substrate may incorporate nodules  509  at the interface between the diamond working end  506  and the substrate  300 , which may provide more surface area on the substrate  300  to provide a stronger interface. The tapered surface may also incorporate grooves, dimples, protrusions, reverse dimples, or combinations thereof. The tapered surface may be convex, as in the current embodiment, though the tapered surface may be concave. 
     Comparing  FIGS. 5 and 5   b , the advantages of having a pointed apex  502  as opposed to a blunt apex  505  may be seen.  FIG. 5  is representation of a pointed geometry  520  which was made by the inventors of the present invention, which has a 0.094 inch radius apex and a 0.150 inch thickness from the apex to the non-planar interface.  FIG. 5   b  is a representation of another geometry also made by the same inventors comprising a 0.160 inch radius apex and 0.200 inch thickness from the apex to the non-planar geometry. The cutting elements were compared to each other in a drop test performed at Novatek International, Inc. located in Provo, Utah. Using an Instron Dynatup 9250G drop test machine, the cutting elements were secured in a recess in the base of the machine burying the substrate  300  portions of the cutting elements and leaving the diamond working ends  506  exposed. The base of the machine was reinforced from beneath with a solid steel pillar to make the structure more rigid so that most of the impact force was felt in the diamond working end  506  rather than being dampened. The target  510  comprising tungsten carbide 16% cobalt grade mounted in steel backed by a 19 kilogram weight was raised to the needed height required to generate the desired potential force, then dropped normally onto the cutting element. Each cutting element was tested at a starting 5 joules, if the elements withstood joules they were retested with a new carbide target  510  at an increased increment of 10 joules the cutting element failed. The pointed apex  502  of  FIG. 5  surprisingly required about 5 times more joules to break than the thicker geometry of  FIG. 5   b.    
     It is believed that the sharper geometry of  FIG. 5  penetrated deeper into the tungsten carbide target  510 , thereby allowing more surface area of the diamond working ends  506  to absorb the energy from the falling target by beneficially buttressing the penetrated portion of the diamond working ends  506  effectively converting bending and shear loading of the substrate into a more beneficial compressive force drastically increasing the load carrying capabilities of the diamond working ends  506 . On the other hand it is believed that since the embodiment of  FIG. 5   b  is blunter the apex hardly penetrated into the tungsten carbide target  510  thereby providing little buttress support to the substrate and caused the diamond working ends  506  to fail in shear/bending at a much lower load with larger surface area using the same grade of diamond and carbide. The average embodiment of  FIG. 5  broke at about 130 joules while the average geometry of  FIG. 5   b  broke at about 24 joules. It is believed that since the load was distributed across a greater surface area in the embodiment of  FIG. 5  it was capable of withstanding a greater impact than that of the thicker embodiment of  FIG. 5   b.    
     Surprisingly, in the embodiment of  FIG. 5 , when the super hard pointed geometry  520  finally broke, the crack initiation point  550  was below the radius of the apex. This is believed to result from the tungsten carbide target  510  pressurizing the flanks of the pointed geometry  520  in the penetrated portion, which results in the greater hydrostatic stress loading in the pointed geometry  520 . It is also believed that since the radius was still intact after the break, that the pointed geometry  520  will still be able to withstand high amounts of impact, thereby prolonging the useful life of the of the pointed geometry even after chipping. 
       FIG. 6  illustrates the results of the tests performed by Novatek, International, Inc. As can be seen, three different types of pointed insert geometries were tested. This first type of geometry is disclosed in  FIG. 5   a  which comprises a 0.035 inch super hard geometry  525  and an apex with a 0.094 inch radius  526 . This type of geometry broke in the 8 to 15 joules range. The blunt geometry  527  with the radius  528  of 0.160 inches and a thickness of 0.200, which the inventors believed would outperform the other geometries broke, in the 20-25 joule range. The pointed geometry  520  with the 0.094 thickness and the 0.150 inch thickness broke at about 130 joules. The impact force measured when the super hard geometry  525  with the 0.160 inch radius broke was 75 kilo-newtons. Although the Instron drop test machine was only calibrated to measure up to 88 kilo-newtons, which the pointed geometry  520  exceeded when it broke, the inventors were able to extrapolate that the pointed geometry  520  probably experienced about 105 kilo-newtons when it broke. 
     As can be seen, super hard material  506  having the feature of being thicker than 0.100 inches or having the feature of a 0.075 to 0.125 inch radius is not enough to achieve the diamond working end or super hard geometry  525  optimal impact resistance, but it is synergistic to combine these two features. In the prior art, it was believed that a sharp radius of 0.075 to 0.125 inches of a super hard material such as diamond would break if the apex were too sharp, thus rounded and semispherical geometries are commercially used today. 
     The performance of the present invention is not presently found in commercially available products or in the prior art. Inserts tested between 5 and 20 joules have been acceptable in most commercial applications, but not suitable for drilling very hard rock formations 
       FIGS. 7   a  through  7   g  disclose various possible embodiments comprising different combinations of tapered surface  500  and pointed geometries  700 .  FIG. 7   a  illustrates the pointed geometry with a concave side  750  and a continuous convex substrate geometry  751  at the interface  500 .  FIG. 7   b  comprises an embodiment of a thicker super hard material  752  from the apex to the non-planar interface, while still maintaining this radius of 0.075 to 0.125 inches at the apex.  FIG. 7   c  illustrates grooves  763  formed in the substrate to increase the strength of interface.  FIG. 7   d  illustrates a slightly concave geometry at the interface  753  with concave sides.  FIG. 7   e  discloses slightly convex sides  754  of the pointed geometry  700  while still maintaining the 0.075 to 0.125 inch radius.  FIG. 7   f  discloses a flat sided pointed geometry  755 .  FIG. 7   g  discloses concave and convex portions  757 ,  756  of the substrate with a generally flatted central portion. 
     Now referring to  FIG. 7   h , the diamond working end  761  may comprise a convex surface comprising different general angles at a lower portion  758 , a middle portion  759  and an upper portion  760  with respect to the central axis  762  of the tool. The lower portion  758  of the side surface may be angled at substantially 25 to 33 degrees from the central axis, the middle portion  759 , which may make up a majority of the convex surface, may be angled at substantially 33 to 40 degrees from the central axis, and the upper portion  760  of the side surface may be angled at about 40 to 50 degrees from the central axis. 
       FIG. 8  discloses an embodiment of the drill bit  104  with a jack element  800 . The jack element  800  comprises a hard surface of a least 63 HRc. The hard surface may be attached to the distal end  801  of the jack element  800 , but it may also be attached to any portion of the jack element  800 . In some embodiments, the jack element  800  is made of the material of at least 63 HRc. In the preferred embodiment, the jack element  800  comprises tungsten carbide with polycrystalline diamond bonded to its distal end  801 . In some embodiments, the distal end  801  of the jack element  800  comprises a diamond or cubic boron nitride surface. The diamond may be selected from group consisting of polycrystalline diamond, natural diamond, synthetic diamond, vapor deposited diamond, silicon bonded diamond, cobalt bonded diamond, thermally stable diamond, polycrystalline diamond with a cobalt concentration of 1 to 40 weight percent, infiltrated diamond, layered diamond, polished diamond, course diamond, fine diamond or combinations thereof. In some embodiments, the jack element  800  is made primarily from a cemented carbide with a binder concentration of 1 to 40 weight percent, preferably of cobalt. The working face  202  of the drill bit  104  may be made of a steel, a matrix, or a carbide as well. The cutting elements  208  or distal end  801  of the jack element  800  may also be made out of hardened steel or may comprise a coating of chromium, titanium, aluminum or combinations thereof. 
     One long standing problem in the industry is that cutting elements  208 , such as diamond cutting elements, chip or wear in hard formations  105  when the drill bit  104  is used too aggressively. To minimize cutting element  208  damage, the drillers will reduce the rotational speed of the bit  104 , but all too often, a hard formation  105  is encountered before it is detected and before the driller has time to react. The jack element  800  may limit the depth of cut that the drill bit  104  may achieve per rotation in hard formations  105  because the jack element  800  actually jacks the drill bit  104  thereby slowing its penetration in the unforeseen hard formations  105 . If the formation  105  is soft, the formation  105  may not be able to resist the weight on bit (WOB) loaded to the jack element  800  and a minimal amount of jacking may take place. But in hard formations  105 , the formation  105  may be able to resist the jack element  800 , thereby lifting the drill bit  104  as the cutting elements  208  remove a volume of the formation during each rotation. As the drill bit  104  rotates and more volume is removed by the cutting elements  208  and drilling mud, less WOB will be loaded to the cutting elements  208  and more WOB will be loaded to the jack element  800 . Depending on the hardness of the formation  105 , enough WOB will be focused immediately in front of the jack element  800  such that the hard formation  105  will compressively fail, weakening the hardness of the formation and allowing the cutting elements  208  to remove an increased volume with a minimal amount of damage. 
     In some embodiments of the present invention, at least one of the cutting elements with a pointed geometry may be in electrical communication with downhole instrumentation. The instrumentation may be a transducer, a piezoelectric device, a magnetostrictive device, or a combination thereof. The transducer may be able to record the bit vibrations or acoustic signals downhole which may aid in identifying formation density, formation type, compressive strength of the formation, elasticity of the formation, stringers, or a combination thereof. 
       FIG. 9  discloses a drill bit  900  typically used in water well drilling.  FIG. 9   a  discloses a drill bit  901  typically used in subterranean, horizontal drilling. These bits  900 ,  901 , and other bits, may be consistent with the present invention. 
       FIG. 10  is a method  1000  of an embodiment for preparing a cutting element  208  for a drill bit  104 . The method  1000  may include the steps of providing  1001  an assembly  400  comprising a can with an opening and constituents disposed within the opening, a stop off positioned atop the constituents, a first and second lid positioned atop the constituents, a meltable sealant positioned intermediate the second lid and a cap covering the opening; heating  1002  the assembly  400  to a cleansing temperature for a first period of time; further heating  1003  the assembly  400  to a sealing temperature for a second period of time. In one embodiment the assembly  400  may be heated to the cleansing temperature in a vacuum and then brought back to atmospheric pressure in an inert gas. The assembly  400  may then be brought to the sealing temperature while in an inert gas. This may create a more stable assembly  400  because the internal pressure of the assembly  400  may be the same as the pressure out side of the assembly  400 . This type of assembly  400  may also be less prone to leaks and contamination during HPHT processing and transportation to the processing site. The assembly may then be placed in a cube adapted to be placed in a chamber of a high pressure high temperature apparatus  1004  where it may undergo the HPHT process  1005 . Completing the HPHT process, the newly formed cutting element  208  may be subject to grinding to remove unwanted material  1006 . The cutting element  208  may then be brazed or welded  1007  into position on the drill bit  104 . 
     Whereas the present invention has been described in particular relation to the drawings attached hereto, it should be understood that other and further modifications apart from those shown or suggested herein, may be made within the scope and spirit of the present invention.