|Número de publicación||US20060260845 A1|
|Tipo de publicación||Solicitud|
|Número de solicitud||US 11/382,571|
|Fecha de publicación||23 Nov 2006|
|Fecha de presentación||10 May 2006|
|Fecha de prioridad||17 May 2005|
|Número de publicación||11382571, 382571, US 2006/0260845 A1, US 2006/260845 A1, US 20060260845 A1, US 20060260845A1, US 2006260845 A1, US 2006260845A1, US-A1-20060260845, US-A1-2006260845, US2006/0260845A1, US2006/260845A1, US20060260845 A1, US20060260845A1, US2006260845 A1, US2006260845A1|
|Cesionario original||Johnson Simon C|
|Exportar cita||BiBTeX, EndNote, RefMan|
|Citada por (11), Clasificaciones (11), Eventos legales (1)|
|Enlaces externos: USPTO, Cesión de USPTO, Espacenet|
This invention relates to a rotary drill bit that is vibrationally stable, and in particular to a rotary drill bit suitable for use in the formation of subterranean well bores.
The cost of drilling a borehole in the subsurface formations of the Earth is dependent on the length of time taken to drill the borehole to the desired depth. The time spent drilling is in turn determined by the rate of penetration and the number of times the drill bit has to be changed in order to achieve the target depth.
A known form of drill bit for use in the formation of subterranean well bores comprises a bit body having formed thereon a series of upstanding blades. Each blade is provided with a series of cutting elements. The cutting elements each typically comprise a substrate of, for example, tungsten carbide to which is bonded a table of a superhard material, for example in the form of polycrystalline diamond. Between the blades are formed flow channels to which drilling fluid is supplied in use, the drilling fluid serving to clean and cool the cutting elements and to carry away material removed by the drill bit.
In use, the drill bit is rotated about its axis while an axially directed load is applied thereto. As a result, material is gouged, scraped or abraded from the formation in which the bore hole is being formed, the material being carried away, as hereinbefore described, by the drilling fluid.
The cutting elements naturally wear away in use due to the varying abrasive nature of the subsurface rock formations. In practice however, the expected economic life of the known drill bits is often degraded due to the cutters being chipped or broken.
In these cases, the known drill bits are known to suffer from literal and torsional vibrations, and these vibrations cause the known drill bit to deviate from its desired smooth path through the formation. This results in the application of large loadings to the cutting elements mounted on the bit which may cause damage thereto, which results in greatly accelerated degradation of the cutting elements. This is particularly apparent when drilling rock formations with bits of relatively large diameter. Obviously this is undesirable and it is an object of the invention to provide a drill bit of improved stability.
According to the present invention there is provided a drill bit comprising a bit body having a plurality of upstanding main blades formed thereon, the blades having a plurality cutting elements mounted thereon, the blades being shaped such that a cutting profile of the bit includes a nose portion, an inner cone region located radially inwards of the nose portion and an outer region located radially outwards of the nose portion, the bit further comprising at least one additional blade, the additional blade carrying cutters located radially inwards of the outer region, but being substantially free of cutters located in the outer region.
Such an arrangement is advantageous in that the number of cutters located in the cone region, relative to the number of cutters on the outer region, can be increased, and these additional cutters create a restoring force to prevent the drill bit moving off its center of rotation while drilling. This can be used to achieve an improvement in bit stability, reducing lateral vibration thereof.
The outer regions of the additional blades are conveniently of increased blade height as compared to the outer regions of the main blades. As a result, during drilling, the outer regions of the additional blades can bear against the surface of the formation being drilled, thereby limiting the depth of cut achievable by the cutting elements, and this can be used to limit lateral and torsional vibration.
Although applicable to drill bits of relatively small diameter, the invention is particularly applicable to large diameter drill bits, for example bits of diameter falling within the range of approximately 12¼″ to 26″.
The cutting elements preferably comprise polycrystalline diamond compact cutters, but other arrangements are possible, for example the cutting elements could comprise diamond crystals, or polycrystalline diamonds, mounted upon or embedded in the blades.
The outer surface of the outer regions of the additional blades may be rendered of improved resistance to wear. This could be achieved for example by mounting suitably shaped and positioned, non-cutting, polycrystalline diamond compact elements thereon. Alternatively, or additionally, a hard facing material coating may be applied thereto.
The invention will further be described, by way of example, with reference to the accompanying drawings.
Referring first to
Referring to FIGS. 2 to 5 there is shown a drill bit comprising a bit body 10 having a front face 12 and a connection region 14 designed to allow the bit to be connected to other downhole components, in use, to allow the bit to be driven for rotation about its centerline 16 and to allow an axially directed load to be applied thereto.
Mounted on the bit body 10 are a number of upstanding main blades 18, the main blades 18 upstanding from the front face 12 of the bit body 10. The main blades 18 include a first plurality of blades 18a which extend from the center line 16, of the bit to the gauge region 20 thereof, and a second plurality of blades 18b which stop short of the center line 16, of the bit. These upstanding main blades 18 may be integrally formed on the bit body, or alternately, may be formed separately and later attached to the bit body 10. The gauge regions 20 of the main blades 18 are of substantially uniform gauge length, the gauge regions 20 all being located at the same axial position on the bit.
As can be seen most clearly in
The main blades 18 each carry a series of cutting elements 28. Each cutting element 28 is in the form of a polycrystalline diamond compact comprising a table of polycrystalline diamond which is bonded to a substrate of less hard material, typically tungsten carbide. The cutting elements 28 are located on parts of the blades 18 in the cone region 24, at the nose portion 22 and in the outer region 26.
Back-up cutting elements 28a are provided immediately behind, and at the same general radial position as at least some of the cutting elements 28, in a known manner.
In addition to the main blades 18, the bit body 10 is further provided with a plurality of additional blades 30. As illustrated, each additional blade 30 is located immediately behind an associated one of the main blades 18 b, the additional blades 30 being substantially equally spaced apart around the bit body 10. Each additional blade 30 includes a part located in the cone region 24, a part located at the nose portion 22 and a part located in the outer region 26, and includes a gauge region aligned with the gauge regions 20 of the main blades 18.
Between the main blades 18 a, 18 b and the additional blades 30 are formed a series of flow channels 32 to which drilling fluid is supplied, in use, through passages (not shown) located internally of the bit and through nozzles 34. The fluid serves to clean and cool the cutting elements, and also serves to carry away from the bit formation material which, in use, is removed by the cutting elements.
Like the main blades 18, the additional blades 30 are also adapted to carry a series of cutting elements 28. The cutting elements 28 carried by the additional blades 30 are located radially inwards of the outer region 26, being located only in the cone region 24 and the nose portion 22, while the outer region 26 is free of cutting elements 28. The provision of the cutters 28 only in the cone region 24 and nose portion 22 of the additional blades 30 serves to enhance the stability of the bit. This is because, in order to reduce lateral vibrations, it is important for the lateral forces generated by the cutting elements to be balanced. Where the bit is of large diameter, as in the arrangement illustrated, this is usually difficult as the torque generated by the radially outer cutting elements is high compared to the torque generated by the inner cutting elements. The location of the cutting elements on the additional blades 30 only at relatively small radial distances from the axis enables this part of the bit to carry a disproportionately large number of cutting elements, and thereby allows such balancing to be achieved more easily.
The parts of the additional blades 30 in the outer regions 26 are, as mentioned hereinbefore, devoid of cutters, and will be referred to hereinafter as cutter devoid surfaces 36. In addition to being devoid of cutters, the cutter devoid surfaces are designed to be of larger blade height than the corresponding parts of the main blades 18 with the result that engagement of the cutter devoid surfaces 36 with the formation
being drilled, in use, limits the depth of cut achievable by the bit. In use, the bit is located downhole and is driven for rotation about its axis 16. An axially directed load sometimes referred to as weight-on-bit is applied to the bit. The combination of the rotary motion and the weight-on-bit causes the cutters 28 to gouge, scrape or abrade material from the formation, thereby extending the borehole. Changes in the applied weight-on-bit or changes in the formation being drilled can give rise to changes in the depth of cut and this, in turn, can cause torsional vibrations to occur. With the bit described hereinbefore, the maximum depth of cut is limited by the engagement of the cutter devoid surfaces 36 with the formation being drilled. As a result, variations in depth of cut are reduced and the severity of torsional vibrations can be limited, or the initiation of such vibrations can be avoided.
As the cutter devoid surfaces 36 wilt in use, bear against the formation being drilled, at least for some of the time, the surfaces 36 may be subject to wear. In order to limit such wear, a wear resistant coating may be applied thereto. Alternatively, a series of wear resistant inserts, for example in the form of suitably shaped polycrystalline diamond compacts, may be mounted upon the surfaces 36.
It will be appreciated that a range of modifications and alterations may be made to the arrangements described hereinbefore without departing from the scope of the invention. For example, rather than using polycrystalline diamond compacts as the cutting elements, it may be possible to use diamond crystals or polycrystalline diamond mounted upon or embedded in the blades 18, 30. Further, alternative means may be used to render the cutter devoid surfaces of good wear resistance. A further possibility may be to shape the cutter devoid surfaces so as to match the actual shape of the bottom hole surface created by the cutter elements 28, at the desired rate of penetration. As a result, the full surface area of each cutter devoid surface can be arranged to engage the formation being drilled.
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.
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|Clasificación de EE.UU.||175/331|
|Clasificación internacional||E21B10/08, E21B10/42, E21B10/43, E21B10/54|
|Clasificación cooperativa||E21B10/54, E21B10/42, E21B10/43|
|Clasificación europea||E21B10/54, E21B10/42, E21B10/43|
|14 Jun 2006||AS||Assignment|
Owner name: REEDHYCALOG UK LIMITED, UNITED KINGDOM
Free format text: ASSIGNMENT OF ASSIGNORS INTEREST;ASSIGNOR:JOHNSON, SIMON;REEL/FRAME:017780/0430
Effective date: 20060609