• 专利附录
  • 专利说明
  • 权利要求
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    • 专利摘要:
    ROTARY DRILLING EQUIPMENT AND PISTON ASSEMBLY FOR USE WITH A DIRECTIONAL SECTION OF A DIRECTIONAL ROTATING DRILLING EQUIPMENT. Approximately, directional drilling includes a control system inside a cylindrical housing connected to a drill bit having radially extendable pistons. A piston-acting fluid seeps out of the housing and through a fluid measurement set that directs the fluid to fluid channels in the drill hole leading to the respective pistons. The control system controls the fluid measurement set to selectively allow fluid to flow through the fluid channels to the pistons and exit through a hole in each fluid canister. The flow of selective fluid causes the pistons in the drill bit to temporarily extend in the opposite direction to a desired well drilling deviation, thereby deflecting it from the center line of the drilled hole. The fluid measurement set has the ability to stabilize, direct and change TFA within the drill bit by moving a support member within the fluid measurement set. The control system and the drill bit are (...).
    公开号:BR112013005716B1
    申请号:R112013005716-5
    申请日:2011-09-09
    公开日:2020-07-07
    发明作者:Jeffery CLAUSEN；Jonathan Ryan Prill
    申请人:National Oilwell Varco, L.P.；
    IPC主号:
    专利说明:

    Field of the Invention
    [0001] The present invention relates to systems and devices for directional drilling of holes, in general, and, in particular, for oil and gas wells. Foundations
    [0002] The directional rotary systems (RSS) currently used in oil and gas wells within subsurface formations typically use tools that operate above the drill bit, as completely independent and controlled tools from the surface. These tools are used to direct a drill string in a desired direction other than vertical, or another desired when drilling the well, for example, by means of target pads or reaction members that exert lateral forces against the well drilling wall. , to deflect the drill bit from the well's center line. Most of these conventional systems are complex and expensive, and have limited uptime due to the limitations of the battery and electronics. They also require that the entire tool be transported from the pit location to a repair and maintenance facility when parts of the tool break. Most of the designs currently used require large pressure drops across the tool for the tools to work well. Currently, there is no easily separable interface between the RSS control systems and the interface reaction members with the formation that allow directional control directly on the drill.
    [0003] There are two main categories of directional rotary drilling systems used for directional drilling. In point-the-bit drilling systems, the orientation of the drill bit is modified in relation to the center line of the drill string to achieve a desired deviation in the well drilling. In “push-the-bit” systems, a lateral or secondary force is applied to the drill string (typically, at a point at a certain height above the drill bit), thereby deflecting the drill locally off the axis of drilling the well to achieve a desired deviation.
    [0004] The directional rotary systems (RSS) currently used to focus targeted drilling of tools seated above the drill bit push the bit with constant force several feet above the bit, or point the bit to direct the bit in the desired direction . Push-the-bit systems are simpler and more robust, but they have limitations due to the fact that the lateral force applied is several feet from the drill, thus requiring the application of comparatively greater forces to deflect the drill. Basic physics informs us that the lateral force necessary to induce a given deflection of the drill (and thus a given change of direction) increases with the increase in the distance between the lateral force and the drill.
    [0005] Examples of prior art RSS systems can be found in U.S. Patents 4,690,229 (Raney); 5,265,682 (Russell et al.); 5,513,713 (Groves); 5,520,255 (Barr et al.); 5,553,678 (Barr et al.); 5,582,260 (Murer et al.); 5,706,905 (Barr); 5,778,992 (Fuller); 5,803,185 (Barr et al.); 5,971,085 (Colebrook); 6,279,670 (Eddison et al.); 6,439,318 (Eddison et al.); 7,413,413,034 (Kirkhope et al.); 7,287,605 (Van Steenwyk et al.); 7,306,060 (Krueger et al.); 7,810,585 (Downton); and 7,931,098 (Aronstam et al.), and in the International Registration Application PCT / US2008 / 068100 (Downton), published in the form of International Publication WO 2009/002996 Al.
    [0006] The RSS designs currently used, typically, demand large pressure drops along the drill, thus limiting the hydraulic capacity in a given well, due to the increased requirements regarding horsepower for the circulation of the drill. drilling fluid throughout the apparatus. Point-the-bit systems can offer performance advantages when compared to push-the-bit systems, but require complex and expensive drill bit designs; moreover, they can be prone to stability problems when drilling the well, making them less consistent and more difficult to control, especially when drilling along soft formations.
    [0007] A push-the-bit system typically requires the use of a sub filter working above the tool to keep debris out of critical areas of the device. If large debris (for example, rocks) or a large amount of lost rolling material (for example, drilling fluid) is allowed to enter the valve arrangements in current push-the-bit tool designs, the result will be , typically, valve failure. However, sub filters are also prone to problems; if lost rolling stock or rocks enter and obstruct a sub filter, it may be necessary to remove (or “maneuver”) the well bore column to clean the filter.
    [0008] For the reasons mentioned above, there is a need for directional rotary drilling systems of the push-the-bit type and devices that can deflect the drill bit to a desired extent by applying less lateral forces to the drill column than those of the systems conventional push-the-bit type, and at the same time produce a lower pressure drop across the tool than that which occurs using known systems. There is also a need for steerable rotary drilling systems of the push-the-bit type and devices that can operate reliably without the need to be used in conjunction with the sub filters.
    [0009] Push-the-bit RSS projects currently in use typically incorporate an integral control RSS system, or a device to control the operation of the RSS tool. In this way, it is necessary to disconnect the entire RSS device from the drilling column and replace it with a new one whenever you want to change the drill size. This results in cost increases and lost time, associated with drill changes. Thus, there is also a need for push-the-bit RSS projects, in which the RSS control device can be easily separated from the targeting mechanism and can be used with multiple size drill bits.
    [00010] There is also an additional need for push-the-bit RSS systems and a device that can be selectively operated, either in a first directional drilling mode, or in a second mode, in which the mechanism The steering gear is turned off for the purpose of straight, non-deflected drilling. This ability to select the operating mode increases the life of the device as well as the time between tool changes in the field. Furthermore, there is a need for these systems and devices to use a modular design according to the field; allowing the control system and the propulsion system components to be exchanged in the field, thus providing greater reliability and flexibility for the operator in the field and at a lower cost. Brief Summary
    [00011] In general terms, the present invention teaches embodiments of the push-the-bit directional rotary drilling rig (alternatively, called RSS tool) comprising a drill bit having a cutting structure, a drive mechanism (or “steering section”) to laterally deflect the cutting structure by applying lateral force to the drill bit, and a control set to actuate the drill's drive mechanism. As used in this publication, the term “drill bit” should be understood to include both the cutting structure and the steering section, the cutting structure being connected to the lower end of the steering section. The cutting structure can be permanently connected or integrated with the steering section, or it can be detachable from the steering section.
    [00012] The direction section of the drill bit houses one or more pistons, each having a radial stroke. The pistons are typically (but not necessarily) evenly spaced around the circumference of the drill, and adapted to extend radially outwardly from the main body of the steering section. In some embodiments, the pistons are adapted for direct contact with the wall of a well bore, into a subsurface formation. In other embodiments, a reaction member (alternatively called a reaction block) can be provided for each piston, with the outer surfaces of the reaction members seated in a circular pattern, generally corresponding to the diameter (that is, the caliber) drilling well and the drill bit cutting structure. Each reaction member is mounted in the steering section so that it extends over at least a portion of the outer face of the associated piston, so that when a given piston is extended, it reacts against the internal surface of its reaction member. The outer surface of the reaction member, in turn, reacts against the well drilling wall, so that a lateral force, induced by the piston extension, will push or deflect the drill cutting structure in a direction away from the piston extended, in the direction of the opposite side of the well drilling. The reaction members are mounted on the steering section in a non-rigid or resilient manner, so that they can be deflected out of relation to the steering section, to induce a lateral displacement of the cutting structure in relation to the drilling of the well when a given piston is actuated. The pistons can be deflected in the direction of retracted positions within the steering section, for example, by using springs.
    [00013] The steering section is formed with one or more fluid channels, corresponding, in number, to the number of pistons; and each extending between the end radially into a corresponding piston, to a fluid inlet at an upper end of the steering section, so that a piston-actuated fluid (such as drilling mud) can enter any channel of fluid given, to actuate the corresponding piston. The fluid channels typically continue downward beyond the piston to allow fluid to escape into the well bore through drill jet terminals.
    [00014] The RSS tool control set is arranged inside a housing, the lower end of which connects with the upper end of the end of the targeting section. A piston-actuated fluid, such as drilling mud, flows down through the housing and around the steering section. The lower end of the control assembly fits and acts on a fluid measurement set, to direct the piston actuating fluid to one (or more) of the pistons, through corresponding fluid channels in the steering section.
    [00015] In one embodiment of the RSS tool, the fluid measurement assembly generally comprises an upper glove member generally cylindrical, having an upper flange and a fluid measurement slot, or opening in the glove below flange. The fluid measurement set further comprises a lower sleeve, having a central diameter and defining the required number of fluid inlets; each fluid inlet being opened to the central diameter by means of an associated recess, in an upper region of the lower sleeve. The bottom sleeve is mounted on or integrated with the top end of the steering section. The upper sleeve may be arranged within the diameter of the lower sleeve, with the slot in the upper sleeve generally in the same height as the recesses of the lower sleeve. The control assembly is adapted to fit and to rotate the upper sleeve into the lower sleeve, so that the piston actuating fluid will flow from the housing into the upper sleeve, and then be directed through the slot in the upper sleeve, into a recess with which the slot is aligned, and thus into the corresponding fluid inlet, and down into the corresponding fluid channel in the direction section to act (ie , to extend radially) the corresponding piston.
    [00016] The housing and drill bit will rotate with the drill string, but the control set is adapted to control the rotation of the upper sleeve in relation to the housing. To use the device to deflect or deflect a well bore in a specific direction, the control assembly controls the rotation of the upper sleeve to keep it in a desired angular orientation in relation to the well bore, regardless of the rotation of the well column. drilling. In this operating mode, the fluid measurement gap in the upper sleeve remains oriented in a selected direction in relation to the ground, that is, opposite the direction in which you want to deviate the well drilling. When the lower sleeve rotates below and in relation to the upper sleeve, the piston actuating fluid will be directed, sequentially, into each of the fluid inlets, thus acting each piston to exert a force against the drilling wall of the well, pushing and deflecting, in this way, the cutting structure of the drill, in the opposite direction in relation to the drilling of the well. With each momentary alignment of the fluid measuring gap in the upper sleeve with one of the fluid inlets, the fluid will flow into the fluid inlet and actuate the corresponding piston to deflect the cutting structure in the desired lateral direction (that is, in the direction of the drilling side of the well opposite the driven piston). In this way, with each rotation of the drilling column, the cutting structure will be subjected to a number of momentary pulses, corresponding to the number of fluid and piston inlets.
    [00017] In a variant of the embodiment, the upper and lower gloves are adapted and provided so that the upper sleeve is axially movable in relation to the lower sleeve, from a top position that allows the fluid to flow into all fluid inlets, simultaneously, to an intermediate position that allows the fluid to drain only one fluid inlet at a time, and to a lower position, preventing the fluid from flowing into the fluid inlets (in which case all the fluid simply continues to flow down to the cutting structure, through a central void or channel in the steering section).
    [00018] In another embodiment of the RSS tool, the fluid measurement set comprises an upper plate that can be rotated coaxially (via the control assembly) above the lower plate fixed and incorporated into the upper end of the section targeting; with the bottom plate attached defining the required number of fluid inlets, which are arranged in a circular pattern concentric with the longitudinal axis (ie the center line) of the steering section, and aligned with the corresponding fluid channels in the section targeting. The upper and lower plates are preferably made of tungsten carbide or other wear-resistant material. The upper plate has a single fluid measurement opening, extending through it, offset by a radial distance, generally corresponding to the radius of the fluid inlets on the fixed lower plate. When the tool housing and drill bit rotate with the drill string, the control assembly controls the rotation of the top plate to keep it in a desired angular orientation in relation to the well bore, regardless of the rotation of the drill string. drilling.
    [00019] The upper rotating plate is immediately above and parallel to the lower fixed plate, so that when the flow measurement opening on the upper plate is aligned with one of the fluid inlets on the fixed lower plate, the piston actuating fluid can flow through the fluid measurement opening on the upper plate and the fluid inlet aligned on the fixed lower plate and into the corresponding fluid channel in the steering section. This fluid can cause the corresponding piston to extend radially outwards from the steering section, so that it reacts against its reaction member (or reacts directly against the drilling of the well), thus driving and deflecting the drill's cutting structure in the opposite direction.
    [00020] Preferably, the targeting section of the drill bit can be disassembled from the control assembly (for example, by means of a conventional threaded pin-and-box connection) with the rotating top plate incorporated into the control assembly. This facilitates the assembly of components in the field, to complete the RSS tool at the location of the drilling rig, and facilitates quick changes of the drill bit at the location of the rig, either to use a different cutting structure or to serve the section. direction, without having to remove the drill string control assembly.
    [00021] To drive the cutting structure in a desired direction in relation to the well drilling, the control set is configured to keep the fluid metering opening oriented in a direction opposite to the desired direction of the impulse (that is, the direction deflection). The drill bit is rotated inside the well bore, while the top plate remains non-rotating in relation to the well bore. With each rotation of the drill bit, the fluid measurement opening on the top plate will pass over and momentarily align with each of the fluid inlets on the attached bottom plate. In this way, when an actuator fluid is introduced into the interior of a tool housing above the top plate, the fluid, in turn, will flow into each fluid channel during each rotation of the drill string.
    [00022] With each momentary alignment of the fluid measurement opening of the upper plate with one of the fluid inlets, the fluid will flow into that fluid inlet and the corresponding piston will act to drive (ie, deflect) the cutting structure in the desired lateral direction (that is, in the direction of the well drilling side opposite the actuated piston). In this way, with each rotation of the drilling column, the cutting structure is subjected to a number of momentary impulses, corresponding to the number of fluid and piston inlets.
    [00023] Through the control set, the direction in which the cutting structure is propelled can be modified, by the rotating upper plate, to give a different fixed orientation in relation to the drilling of the well. However, when you want to use the tool for straight-line drilling (that is, not offset), the tool can be placed in a straight-line drilling mode (as discussed further below).
    [00024] When having a lateral force applied directly on the drill bit, close to the cutting structure, instead of a substantial distance above the bit as in conventional push-the-bit systems, the drill's directing ability is improved, and the force required to drive the bit is reduced. Minor lateral forces on the drill, with a drill that is kept in line with the rest of the stabilized drill string, also increase stability and improve repeatability in smooth formations. The term “repeatability”, as used in this patent specification, should be understood as in the directional drilling industry, denoting the ability to repeatedly achieve a consistent curve radius (or “gain rate”) for the trajectory of drilling a well in a given subsurface formation, regardless of the strength of the formation. The greater the magnitude of the force applied against a well wall by a piston in a push-the-bit drilling system, the greater the tendency of the piston to penetrate softer formations and to reduce the curvature of the path of the well drilling (when compared to the effect of similar forces in harder formations). In this way, this tendency, in softer formations, will be reduced, due to the smaller piston forces required for an equal efficiency when using push-the-bit systems, according to the present invention.
    [00025] The push-the-bit rotatable directional drilling systems and the apparatus according to the present invention can have a modular design, so that any of the various components (for example, pistons, reaction members, assembly control components, and control set components) can be modified in the field during drill changes. As noted earlier, another advantageous feature of the device is that the upper rotating plate (or sleeve) of the fluid measurement set can be deactivated, so that the tool drills in a straight line when a deviation from the well drilling is not required, promoting , thus, a longer battery life (for example, for the battery powered set of the control set components) and, thus, extending the time during which the tool can operate without changing the batteries.
    [00026] The control set for the directional rotary drilling rig, according to this publication, can be of any functionally suitable type. As a non-limiting example, the control set may be similar to, or adapted from, a fluid-actuated control set of the type according to the vertical drilling system published in International Patent Application PCT / US2009 / 040983 ( published as WO 2009/151786). In other embodiments, the control assembly can rotate the upper rotating plate or sleeve, using, for example, an electric motor or opposite turbines. Brief Description of Drawings
    [00027] Modes of implementation according to this publication will now be described with reference to the attached Figures, in which the identical reference numbers denote equal parts, and in which:
    [00028] Figure 1 is an isometric view of a first embodiment of the rotary drilling rig, according to the present publication, with pistons with deflecting drills, adapted for direct contact with a well drilling wall.
    [00029] Figure 2 is a longitudinal cross section along a first variant of the rotary drilling rig in figure 1, in which the fluid measurement set comprises a rotating upper sleeve and a fixed lower sleeve.
    [00030] Figure 2A is an enlarged view of a detail of the fluid measurement set in figure 2.
    [00031] Figures 3A, 3B, and 3C are isometric, transversal and side views, respectively, of the upper rotating sleeve of the apparatus of figure 2.
    [00032] Figures 4A, 4B, and 4C are isometric, cross-sectional, and side views, respectively, of the lower glove attached to the apparatus of figure 2.
    [00033] Figure 5 is a cross section along the apparatus of figure 2, showing a fluid measurement slot in a rotating upper sleeve, aligned with a fluid inlet in the fixed lower sleeve, to allow the fluid to flow in. corresponding fluid channel in the drill bit and showing the corresponding extended piston.
    [00034] Figure 6 is a partial isometric longitudinal section along the middle region of the apparatus in Figure 2, showing the rotating upper sleeve, lower sleeve fixed with fluid inlets, and fluid channels in the targeting section.
    [00035] Figure 7 is a bottom view of the apparatus in Figure 2, showing the drill bit and piston housings, with an extended piston with a deflecting drill.
    [00036] Figure 8A is a cross section through a variant of the sleeve assembly shown in figures 2-6, with the upper sleeve rotating in an upper position, in which the piston actuating fluid flows in all channels of fluid.
    [00037] Figure 8B is a cross section through the sleeve assembly of figure 8A, illustrating the piston actuating fluid inside the fluid inlets.
    [00038] Figure 9A is a cross section along a variant of the sleeve assembly of figure 8A, with the upper sleeve rotating in an intermediate position, in which the piston actuating fluid flows only into a fluid inlet.
    [00039] Figure 9B is a cross-section through the sleeve assembly of figure 9A, illustrating the flow of the piston actuating fluid into the fluid inlet aligned with the slit in the upper rotating sleeve.
    [00040] Figure 10A is a cross section through a sleeve assembly variant of figure 8A, with the upper sleeve rotating in a lower position, in which the actuating fluid cannot flow into any of the fluid inlets.
    [00041] Figure 10B is a cross-section through the sleeve assembly of figure 10A, illustrating the fluid flow to the blocked fluid inlets.
    [00042] Figure 11 is a longitudinal cross-section similar to figure 2, showing the rotary drilling rig in operation, inside a well bore, with a piston radially extended and exerting a force to deflect the drill against one side of the drilling the well.
    [00043] Figure 12 is a longitudinal cross section along a second embodiment of the rotary drilling rig of figure 1, with a resiliently mounted reaction member, associated with each piston, and in which the fluid measurement set comprises a rotating upper plate and a fixed lower plate.
    [00044] Figure 12A is a plan view of the upper rotating plate of the fluid measurement set of figure 12.
    [00045] Figure 12B is a plan view of the bottom plate attached to the fluid measurement set of figure 12.
    [00046] Figure 13 is a cross-section through the apparatus in Figure 12, illustrating the fluid measurement opening in the upper rotating plate, aligned with a fluid inlet, by means of the upper plate fixed inside the drill bit. and correspondingly showing the extended drill deflector piston.
    [00047] Figure 14A is an isometric view of the steering section of the apparatus of figure 12, with a flexible reaction member mounted on the steering section in association with each piston.
    [00048] Figure 14B is an end view of the apparatus in figure 14A, showing the upper and lower plates of the fluid measurement set, the piston housings, and resiliently mounted flexible reaction members.
    [00049] Figure 14C is a side view of the apparatus of figure 14A, with a piston actuated and deflecting its associated flexible reaction member.
    [00050] Figure 14D is a longitudinal cross section along the apparatus of figure 14A, with a piston actuated and deflecting its associated flexible reaction member.
    [00051] Figure 15A is an isometric view of the steering section of the apparatus of figure 12, with an articulated reaction member mounted on the steering section, in association with each piston.
    [00052] Figure 15B is an end view of the apparatus of figure 15 A, showing the upper and lower plates of the piston actuator mechanism, the piston housings and the articulated reaction members.
    [00053] Figure 15C is a side view of the device of figure 15A, with a piston actuated and deflecting its associated articulated reaction member.
    [00054] Figure 15D is a longitudinal cross section along the apparatus of figure 15 A, with a piston actuated and deflecting its associated articulated reaction member.
    [00055] Figure 16A is an isometric view of a variant of the targeting section of the device in figure 12, with the fluid measurement set incorporating a glove set as in figures 2-6.
    [00056] Figure 16B is an end view of the apparatus of Figure 16A, showing the upper and lower sleeves of the piston actuating mechanism, the piston housings, and the resiliently assembled reaction members.
    [00057] Figure 16C is a side view of the device in Figure 16A, with a piston actuated and deflecting its associated articulated reaction member.
    [00058] Figure 16D is a longitudinal cross section along the apparatus of figure 16A, with a piston actuated and deflecting its associated articulated reaction member.
    [00059] Figure 17A is a cross section along an embodiment of a piston assembly, according to the present publication, shown in a retracted position.
    [00060] Figure 17B is a cross section along the piston assembly of figure 17A, shown and an extended position (and with the request spring not shown for the sake of clarity of the illustration).
    [00061] Figure 18A is a side view of the piston assembly of figures 17A and 17B, shown in a stowed position.
    [00062] Figure 18B is a side view of the piston assemblies in figures 17A and 17B, shown in an extended position.
    [00063] Figure 19A is an isometric view of the piston assembly of figures 17 A - 18B, shown in a stowed position.
    [00064] Figure 19B is an isometric view of the piston assembly of figures 17A - 18B, shown in an extended position.
    [00065] Figure 20A is an isometric view of the external member of the piston assembly of figures 17A - 19B.
    [00066] Figure 20B is an isometric view of the inner member of the piston assembly of figures 17 A - 19B.
    [00067] Figure 21 is an isometric view of the piston assembly request spring of figures 17A - 19B.
    [00068] Figure 22 is a cross-sectional section along the direction section of the drilling rig in figure 2, incorporating piston assemblies according to figures 17A - 21. Detailed Description
    [00069] Figures 1 and 2 illustrate (in isometric and transversal view, respectively) a directional rotary drilling rig (or "RSS tool") 100 according to a first embodiment. The RSS tool 100 comprises a cylindrical housing 10, which encloses a control set 50; and a drill bit 20. An annular space 12 is formed around the control assembly 50 within the housing 10, so that the drilling fluid flowing into the housing 10 flows downward through an annular space 12 into the direction of the drill bit 20. The drill bit 20 comprises a steering section 80 connected with the lower end of the housing 10, and a cutting structure 90 connected with the lower end of the steering section 80 so that it can be rotated with the same. The steering section 80 is preferably formed or provided with means to facilitate removal of the housing 10, such as drill key notches 15. The cutting structure 90 can be of any suitable type (for example, a compact drill bit). polycrystalline diamond, or a tapered roller type drill) and the cutting structure 90 is not part of the broader embodiments of the apparatus according to the present invention.
    [00070] The steering section 80 has one or more fluid channels 30 extending downwards from the upper end of the steering section 80. As can be seen in figure 2, the steering section 80 also has an axial channel center 22, to transport the drilling fluid to the cutting structure 90, from where the drilling fluid can come out under pressure by means of jets 24 (to improve the efficiency of the cutting structure 90 when it drills into the formation materials subsurface). Each fluid channel 30 leads to a radially inner end of a corresponding piston 40, extendable radially outwardly from the steering section 80, in response to pressure from an actuating fluid flowing under pressure along the fluid channel 30. Typically, each fluid channel 30 extends beyond its corresponding piston 40 to a drill jet terminal 34, which allows fluid to drain and bleed fluid pressure.
    [00071] The steering section 80 defines and incorporates a plurality of piston housings 28 projecting outwardly, from the steering section 80 (whose main body typically has a matched diameter or close to that of the housing 10). The radial displacement of each piston 40 is preferably restricted by any suitable means (indicated, as examples in figure 12, in the form of a transverse pin 41 passing through an opening 43 in piston 40 and secured within the piston housing 28, on each side of piston 40). This specific feature is by way of example only, and those skilled in the art will note that other means of restricting piston displacement can be readily devised, without departing from the scope of this publication. The pistons 40 are also preferably provided with suitable request means (such as, by way of non-limiting example, the request springs) taking the request pistons 40 to a retracted position within their respective piston housings 28.
    [00072] In a typical case, the piston actuating fluid will be a portion of the drilling fluid, diverted from the flowing fluid seeping through axial channel 22 to the cutting structure 90. However, the piston actuating fluid can, alternatively, be a fluid other than and / or from a source other than that of the flowing drilling fluid flows into the cutting structure 90.
    [00073] The RSS 100 tool incorporates a fluid measurement set, which in the embodiment shown in figure 2 comprises an upper sleeve 110, which can be rotated by means of the control set 50 inside, and in relation to lower sleeve 120, which, in turn, is attached to, or integrated with, the upper end of the steering section 80. As can be best seen in figures 2A, 3A, 3B, and 3C, the upper rotating sleeve 110 has a diameter 114 extending through cylindrical section 116, extending downwards below an upper annular flange 112. The cylindrical section 116 has a fluid measurement opening shown in the form of a vertical slit 118. As can be seen in the figures 2A, 4A, 4B, and 4C, the fixed bottom sleeve 120 has a diameter 121 and a number of fluid inlets 122 geometrically arranged to correspond to fluid channels 30 in the steering section 80. In the illustrated embodiments, the inlets in fluid 122 are arranged in a circular pattern centered around the longitudinal axis CLRSS of the RSS 100 tool.
    [00074] The recesses 124 are formed within an upper region of the lower sleeve 120, to provide fluid communication between each fluid inlet 122 and diameter 121. Thus, and as best seen in figures 2A and 6, when the section cylindrical 116 of the upper sleeve 110 is disposed within the diameter 121 of the lower sleeve 120, with the fluid measuring slot 118 aligned with a given recess 124 in a lower sleeve 120, the diameter 114 of the upper sleeve 110 will be in fluid communication with the corresponding fluid channel 30 in direction section 80, through slot 118, recess 124 and fluid inlet 122. As can be seen in figure 5, the resulting flow of the actuating fluid under pressure within the corresponding fluid channel 30 , results in the actuation and extension radially out of the corresponding piston (indicated in figure 5 by reference number 40A to denote an actuated piston).
    [00075] The assembly and operation of the fluid measurement set described above can also be understood with reference to figure 6. The control set 50 is provided with a means of fitting the measuring set to rotate the upper sleeve 110; and it can take any functionally effective form. As a non-limiting example, the means of fitting the measuring set is shown in figures 2, 2A, and 6 comprising a mast 52 operatively connected at its upper end with the control set 50, and connected at its lower end with a cylindrical head 54 having an upper end plate 53 with one or more fluid openings 53A. The cylindrical head 54 is concentrically connected by its lower end 54L to the flange 112 of the upper sleeve 110, so that the upper sleeve 110 rotates in relation to the lower sleeve 120 when the mast 52 is rotated by the control set 50. A fluid 70, flowing down into an annular space 12 surrounding the control assembly 50 within the housing 10, it flows through the fluid openings 53 A in the upper end plate 53 of the head 54 into the cylindrical cavity 55 within the head 54, and, then, into the diameter 114 of the upper sleeve 110. A portion of the fluid 70 is deflected, through the slot 118 in the cylindrical section 116 of the upper sleeve 110, into the fluid inlet 120 aligned at that moment with the slot 118, and then into the corresponding fluid channel 30 to actuate the corresponding piston 40. The remainder of the fluid 70 flows into the main axial channel 22 in the steering section 80, for delivery to the cutting structure 90.
    [00076] Figure 7 is a bottom view of drill bit 20, showing cutting structure 90 with cutting elements or teeth 92, drill jets 24, pistons 40, and piston housings 28. In figure 13, a piston, marked 40A, is shown in its actuated position, extending radially outwardly from its piston housing 28.
    [00077] Figure 8A illustrates a variant of the glove assembly shown in figures 2 and 6 and related drawings. The upper sleeve 210 in figure 8A is generally similar to the upper sleeve 110 in figures 3A-3C, with a flange 212 and a diameter 214 similar to that of flange 112 and a diameter 114 on the upper sleeve 110, except that it has a cylindrical section 216 larger than the cylindrical section 116 of the upper sleeve 110. The cylindrical section 216 has a fluid measuring slot 218, similar to the fluid measuring slot 118 of the cylindrical section 116, located in a lower region of the cylindrical section 216. The bottom sleeve 220 of figure 8A is generally similar to the bottom sleeve 120 of figures 4A-4C, with fluid inlets 222 below those corresponding to recesses 224 (similar to fluid inlets 122 and recesses 24 in the sleeve bottom 120) formed inside the lower body 225, having a diameter 221 analogous to the diameter 121 of the lower sleeve 120, plus a cover plate 226 extending across the top of the lower body 25 and having a central opening for receiving the cylindrical section 216 of the upper sleeve 210.
    [00078] As can be understood with reference to figures 8A and 8B, when the upper sleeve 210 is in an upper position in relation to the lower sleeve 220, with the cylindrical section 216 suspended at least partially from the recesses 224 in the lower sleeve 220, the portions of the fluid 70 that flow into the diameter 214 in the upper sleeve 210 and the diameter 221 in the lower sleeve 220 will be diverted directly into all the recesses 224 and fluid inlets 222, to actuate all the pistons 40. In this mode of operation, the actuated pistons serve to centralize and stabilize the drill bit 20, when drilling a section not deviated from the well drilling. This can be particularly beneficial and advantageous when drilling a section in a straight line, but not vertical from the well drilling, and or when one wishes to maximize the total flow area (TFA) in the drill (TFA being defined as the total area of all nozzles or jets through which the fluid can flow out of the bit). The highest TFA will be when the upper sleeve 210 is in its highest position, in which the fluid can flow into all of the fluid channels 30. This is because the fluid will be able to flow out of all the drill jet terminals 34 connecting with the fluid channels 30, in addition to draining out of all the drill jets 24 in the cutting structure 90. On the other hand, the TFA will be lower when the upper sleeve 210 is in its lowest position (as shown in figures 10A and 10B), in which the fluid flowing into all the fluid channels 30 is blocked, and the fluid can only come out of the tool through the jets of the drill 24.
    [00079] Drill bit stabilization with all pistons extended may also be desirable during "straight" drilling to mitigate "drill bit spinning", which can result in poor well drilling quality when perforates along soft formations.
    [00080] Figures 9A and 9B illustrate a situation where the upper sleeve 210 is in an intermediate position with respect to the lower sleeve 220, with the cylindrical section 216 extending below the cover plate 226, to allow the fluid to drain diameter 214 through its fluid measuring slot 218. In this operating mode, fluid 70 will be diverted into a recess 224 aligned with slot 218, and then into the corresponding fluid inlet 222 to act the corresponding piston 40; this is essentially the same for the glove assembly shown in figure 2A.
    [00081] Figures 10A and 10B illustrate the situation where the upper sleeve 210 is in a lower position in relation to the lower sleeve 220, with the slot 218 arranged below the recesses 224, so that the fluid cannot enter any of the recesses 224 and fluid inlets 222. In this operating mode, all fluid 70 will flow directly to the cutting structure 90, without deviations. This may be desirable for straight-line drilling through comparatively stable subsoil materials with a lower TFA in the drill.
    [00082] To operate a fluid measurement set incorporating upper and lower sleeves 210 and 220, as in figures 8A-10B, the control assembly 50 will incorporate or be provided with a means for suspending and lowering the upper sleeve 210, in addition to a rotating upper glove 210. Those skilled in the art will appreciate that various means for axially displacing the upper glove 210 in relation to the lower glove 220 can be designed, according to the technologies already known, and the present invention is not limited to the use of any of these means in particular.
    [00083] Figure 11 illustrates an RSS 100 tool, like the one in figure 2, operating inside a WB well drilling. In this view, a portion 70A of fluid 70 and an annular space 12 of the RSS 100 have been deflected into an “active” fluid channel 30A in the targeting section 80, through the fluid measurement slot 118 in the upper rotating sleeve 110 of the fluid measurement set. The flow of the fluid under pressure, into the fluid channel 30A, acts the corresponding piston 40A, causing the actuated piston 40A to extend radially outwards, from the steering section 80 and in a reaction contact with the wall drilling the well WB, in a region of contact X, thus exerting a transverse force against the steering section 80, deflecting the cutting structure 90 in the direction away from the contact region WX, by a deflection D; the lateral deviation of the axial axis CLRSS of the RSS 100 tool deflected in relation to the axis CLWB of the well WB. The contact region WX, for a given fixed orientation of the upper sleeve 110 and its fluid measurement slot 118 in relation to the well drilling WB, will not be a specific fixed point, or region on the well drilling wall; on the contrary, it will move as the drilling progresses further and further into the ground. However, for an operating mode providing only the actuation of a single piston 40 at any given time, the contact region WX will always correspond to the angular position of the fluid 118 measurement slot.
    [00084] As long as the tool 100 continues to rotate, the flow of the actuating fluid 70A into the active fluid channel 30A will be blocked, thus relieving the hydraulic force of the acting piston 40A, which will then be retracted inwards. from the body of the steering section 80. Posterior rotation of the tool 100 will cause the actuating fluid to flow into the next fluid channel 30 in the steering section 80, thereby acting and extending the next piston 40 in sequence, and exerting another transverse force in the WX contact region of the WB well drilling.
    [00085] Thus, for each rotation of tool 100, a deflection force of the transverse drill will be exerted against drilling the well WB in the contact region WX for the same number of times as the number of fluid channels 30 in the steering section 80, thus maintaining an effectively constant deflection D of the cutting structure 90 in a constant transverse direction in relation to the drilling of the well WB. As a result of this deflection, the angular orientation of the WB well drilling will gradually change, creating a curved section in the WB well drilling.
    [00086] When a desired degree of curvature of the well or deviation has been reached and it is desirable to drill a non-deviated section of the well, the operation of the control set 50 is adjusted to rotate the upper sleeve 110 so that the measurement slot fluid 118 is in a neutral position, between a pair of adjacent recesses 124 in the bottom sleeve 120, so that fluid 70 cannot be diverted into any of the fluid inlets 122 in the bottom sleeve 120. The control set 50 (or a means of fitting the associated measuring set) is then either detached from the upper sleeve 110, leaving the upper sleeve 110 free to rotate with the lower sleeve 120 and the steering section 80, or, alternatively, it is actuated to rotate at the same rate as the tool 100, thus maintaining, in any case, the slot 118 in a neutral position in relation to the lower sleeve 120, so that the fluid cannot flow to any of the pistons 40. The operations drilling they can then be continued without any transverse force acting to deflect the cutting structure 90.
    [00087] In a variant of the embodiments in which the fluid measurement set includes an axially movable upper sleeve 210 and a lower sleeve 220, as shown in figures 8A-10B, the transition to non-bypass drilling operations is carried out by displacement of the upper sleeve 210 (by means of the control set 50) both to its upper position and to its lower position in relation to the lower sleeve 220, as desired or appropriate, in view of operational considerations. The flow of fluid to the flow channels 30 will then be prevented, regardless of whether the upper sleeve 210 continues to rotate with respect to the lower sleeve 220.
    [00088] Figure 12 illustrates an RSS 200 tool, according to an alternative embodiment, in which the fluid measurement set comprises an upper rotating plate 60 and a lower plate 35, fixed to or formed integrally within the upper end of a modified steering section 280. The bottom plate 35 has one or more fluid inlets 32 analogous to the fluid inlets 122 of the lower sleeve 120, shown in figures 2 and 6 (and elsewhere in the text). In the illustrated embodiment, and as shown in figure 12B, fluid inlets 32 are arranged in a circular pattern around the CLRSS centerline of the RSS 200 tool. The top plate 60 can be rotated, relative to housing 10, around an axis of rotation coinciding with the CLRSS centerline. As shown in figure 12A, the upper plate 60 has a fluid measurement orifice 62 deflected from the CLRSS center line by a radius, corresponding to the radius of the circle of the fluid inlets 32, formed on the fixed lower plate 35. The upper plate 60 also has a central opening 63 to allow the fluid to flow down into the axial channel 22 of the steering section 80; and the bottom plate 35 has a central opening 33 for the same purpose.
    [00089] The fluid measurement set shown in figures 12, 12A, and 12B works in essentially the same way as previously described in relation to the RSS tool embodiments, having a fluid measurement set incorporating an upper sleeve 110 (or 210) and a lower sleeve 120 (or 220). The upper plate 60 is rotated by the control assembly 50 (for example, by means of a head 54 as previously described) in order to maintain the fluid measurement orifice 62 in a fixed orientation with respect to drilling the well WB, regardless of rotation of the housing 10 and the steering section 80. When the housing 10 and the steering section 80 rotate in relation to the drilling of the well WB, the fluid measurement hole 62 in the upper plate 60 comes into alignment with each of the fluid 32 in the lower plate 35, in sequence, thus allowing a portion of the fluid flowing from the annular space 12, through the fluid openings 53A in the upper end plate 53 of the head 54, to be diverted into each channel flow rate 30 in sequence, and causing the corresponding pistons 40 to be radially extended in sequence, thereby inducing a deviation in the orientation of the WB well described.
    [00090] Figure 13 is a cross-sectional view along the housing 10 just above the upper rotating plate 60, showing the bypass hole 62 in the upper plate 60 and, in dashed lines, the fluid inlets 32 (four in total in the embodiment) illustrated) on the bottom plate 35, arranged below the upper plate 60. Figure 13 also illustrates the pistons 40 and their corresponding piston housings 28 (four in total, corresponding to the number of fluid inlets 32) and, below the same, the cutting structure 90 with the drill bit tooth 92. Figure 13 illustrates the alignment of the fluid measurement hole 62, of the upper plate 60, with one of the fluid inlets 32 in the lower plate 35, resulting in a extending radially outward from a corresponding 40A actuated piston.
    [00091] To carry the RSS 200 tool for non-deviated drilling operations, the control set 50 is used to rotate the upper plate 60 to a neutral position in relation to the lower plate, so that the fluid measurement hole 62 do not align with any of the fluid inlets 32 on the bottom plate 35, and the top plate 60 is then rotated at the same rate as the steering section 80, to keep the fluid measurement orifice 62 in neutral position relative to to the bottom plate 35.
    [00092] In an alternative embodiment of the apparatus (not shown), the upper plate 60 can be selectively displaced axially upwards and away from the lower plate 35, thus allowing the fluid to flow into all channels of fluid 30 and causing all pistons 40 to extend outwards. This results in the fact that equal transverse forces are exerted around the entire perimeter of the steering section 80, causing the cutting structure 90 to effectively drill in line straight, without deviations, and still stabilizing the cutting structure 90 inside the drilling of well WB, similarly to the cases of the previously described embodiments, incorporating the upper and lower gloves 210 and 220, when the upper sleeve 210 is in its upper position in relation to the lower sleeve 220. The control system 50 can be deactivated or put into hibernation mode, when the upper plate 60 and the lower plate 35 are not counted, saving thus, improving battery life and wear and tear on control system components.
    [00093] In one embodiment, the control assembly 50 comprises an electronically controlled positive displacement (PD) motor that rotates the upper plate 60 (or the upper sleeve 110 or 210); however, the control set 50 is not limited to this or any other type of mechanism in particular.
    [00094] Rotary directional drilling systems, in accordance with this publication, can be readily adapted to facilitate the exchange of large cycling pistons during drill changes. This ability to change pistons independently of the control system, in a design that provides an interface that can be changed in the field, makes the system more compact, easier to put into service, more versatile, and more reliable than systems conventional steerable. The RSS tools, according to this publication, will also allow multiple different sizes and types of drill bits and / or pistons to be used, together with the same control system without having to change anything other than the steering system and / or the cutting structure. This means that the system can be used to drill 12 1/4 ”(311 mm) wells, for well drilling, for example, and subsequently can be used to drill 8 3/4” (222 mm) wells , when drilling the well, without changing the size of the control system housing, thereby saving and requiring less equipment.
    [00095] The system can also be adapted to allow the use of the drill bit separately from the control system. Optionally, the control set can have a modular design, to control not only drill bits, but also other drilling tools that can make it beneficial to use the upper rotary plate (or sleeve) of the tool to perform useful tasks.
    [00096] Figures 14A, 14B, 14C, and 14D illustrate a targeting section 280, of the RSS tool according to the embodiment shown in figure 12. Targeting section 280 is substantially similar to targeting section 80 , described with reference to figure 12, and the same reference numbers are used for the components common to both embodiments. The steering section 280 is shown, as a non-limiting example, with an upper pin end 16 for threaded connection purposes with the lower end of housing 10, and with a lower housing end 17, for the threaded connection with the upper end of the cutting structure 90. The steering section 280 is distinct from the steering section 80 shown in figure 2 by the provision of flexible reaction pads 240, each of which has an upper end resiliently mounted on the main body of the steering section 280, and a free lower end 241, which extends over a corresponding piston housing 28. In the illustrated embodiment, the resilient assembly of the flexible reaction pads 240 in the body of the steering section 280 is accomplished by having the upper ends of the reaction pads 240 formed integrally with the circular band 242, arranged within an annular groove 243 extending around the circumference of the steering section 280, at a point below the end of pin 16. However, this is by way of example only. Those skilled in the art will note that other ways to resiliently mount the upper ends of the reaction pads 240 in the steering section 280 can be readily designed; and, the present publication is not limited to the use of any specific means or method of assembly of the reaction pads 240.
    [00097] As can best be seen with reference to the upper portion of figure 14D, when a given piston 40 is in its retracted position, the free lower end 241 of its associated flexible reaction block 240 will preferably be level or almost flush with the outer surface of the associated piston housing 28. However, when a piston is actuated (as illustrated by the actuated piston 40A in the lower portion of figure 14D), it will deflect the free lower end 241 of the associated reaction block (indicated by reference number 240A of figure 14D) radially outward. The deflected flexible reaction block 240A will thus be pushed towards, and against the well drilling wall, resulting in the steering section 280 and the cutting structure 90 being pushed in the radially opposite direction. When the actuated piston 40A retracts into its piston housing 28, the free lower end of reaction block 240A will bounce elastically to its unsolicited state and position.
    [00098] Figures 15A, 15B, 15C, and 15D illustrate the targeting section 380 of an RSS tool according to an alternative embodiment. The targeting section 380 is substantially similar to the targeting section 80 described with reference to figure 12, and the same reference numbers are used for components common to both embodiments. The steering section 380 is distinguished from the steering section 80 by the provision of articulated reaction pads 340, each of which extends over a corresponding housing piston 28, in which the reaction block 340 is mounted at one or more points of pivot 342, so as to be pivoting around the pivot axis substantially parallel to the longitudinal axis of the steering section 380. The pivot points 342 are located, preferably, on the guiding edges of the articulated reaction pads 340 (the term “edge orientation ”refers to the direction of rotation of the tool).
    [00099] As can be best seen with reference to the upper portion of figure 15D, when a given piston 40 is in its retracted position, its associated articulated reaction block 340 will preferably be level or almost level with the surface of the associated piston housing 28. However, when the piston is actuated (as illustrated by the actuated piston 40A, in the lower portion of figure 15D), it will push out its corresponding articulated reaction block 340A, causing the pad 340A to pivot around its articulation point (s) 342 and is deflected out towards the well drilling wall, as can be seen in figures 15C and 15D. This results in pushing the steering section 380 and the cutting structure 90 in the radially opposite direction. When the actuated piston 40A retracts into its piston housing 28, the deflected articulated reaction block 340A can be returned to its original position, aided, where appropriate, by suitable means of request.
    [000100] Figures 16A, 16B, 16C, and 16D illustrate a variant 280-1 of the steering section 280 shown in figures 14A, 14B, 14C, el4D, only with the difference that the fluid measurement set in the targeting 280-1 incorporates lower and upper gloves 110 and 120, as in figures 3A-3C and 4A-4C, instead of upper and lower plates 60 and 35, as in targeting section 280. Components and features that do not have numbers reference figures in figures 16A, 16B, 16C, and 16D correspond to similar components and characteristics, shown and referenced in figures 14A, 14B, 14C, and 14D. Those skilled in the art will also note that the steering section 380 shown in figures 15A, 15B, 15C, and 15D can be equally adapted.
    [000101] RSS tools, in accordance with this publication, may use pistons with any functionality suitable for the type and construction, and the publication is not limited to the use of any specific type of piston described or illustrated here. Figures 12, 14D, 15D, and 16D, for example, show one-piece, or unitary pistons 40. Figures 17A to 21 illustrate an embodiment of an alternative piston assembly 140, comprising an outer (or higher) member 150, an internal (or lower) member 160, and, in preferred embodiments, a request spring 170. In this description of piston assembly 140 and its constituent elements, the adjectives “internal” and “external” are used in with respect to the center line of a steering section 80, together with which the piston 140 is installed; that is, the inner member 160 will be arranged radially into the outer member 150, while the outer member 150 is radially extending outwardly from the targeting section 80 (and away from the inner member 160). However, for convenience of describing these components, the adjectives "upper" and "lower" can be used interchangeably as "external" and "internal", respectively, in correspondence with the graphic representation of these elements in figures 17A to 21.
    [000102] As shown in the specific details of figures 17A and 17B, the outer member 150 of the piston assembly 140 has a cylindrical side wall 152 with an upper end 152U closed by a cover member 151, and an open lower end 152L. The upper (or outer) surface 151A of the cover member 151 can optionally be contoured, as shown in figures 17A, 17B, 18A, and 18B, to conform to the effective diameter of the cutting structure 90, mounted in the section direction 80, in embodiments that intend to direct the contact of the piston with the well drilling wall, without intervening reaction members. The embodiment of the external member 150, shown in figures 17A and 17B, is adapted to receive the upper end of the request spring 170 (in a manner that will be described below), and for this purpose it is formed with a cylindrical boss 153 projecting upwards coaxially from the cover member 151 and having an internally threaded open bottom cavity 154. An annular space with open bottom 155 is thus formed between the boss 153 and the side wall 152 of the outer member 150.
    [000103] Extending downwards, from the cylindrical sidewall 152, there are a pair of spaced, curved and diametrically opposed sidewall extensions 156, each having a lower portion 157, formed with the shoulder projecting circumferentially, or stop element 157A, at each circumferential end of the lower portion 157. Each extension of the sidewall 156 can thus be described as assuming the general shape of an inverted “T”, being a pair of diametrically opposite openings of the sidewall 156A formed between the two side wall extensions 156.
    [000104] The inner member 160 of the piston assembly 140 has a cylindrical side wall 161 having an upper end 160U and a lower end 160L, and enclosing a cylindrical cavity 165 that is opened at each end. A pair of diametrically opposed pin openings 162 are formed along the side wall 161, to receive the retaining pin 145, to secure the inner member 160 in, and within the targeting section 80, so that the position of the inner member 160 in relation to the steering section 80 is fixed radially. A pair of diametrically opposed fluid openings 168 (semicircular or semioval, in the illustrated embodiment) is formed within the side wall 161 of the inner member 160, intersecting the lower end 160L of the inner member 160 and at right angles to the pin openings. retainer 162, in order to be, in general, aligned with the corresponding fluid channels 30, when piston 40 is installed in the steering section 80, to allow the passage of the drilling fluid downwards, beyond the internal member 160, and into a corresponding drill jet 34 in the steering section 80. As best seen in figure 17B, and for the purposes to be described below, an annular groove 169 is formed around cavity 165 at the lower end 160U of the inner member 160. In the illustrated embodiment, the annular groove 169 is discontinuous, being interrupted by the fluid openings 168.
    [000105] Extending upward from the cylindrical sidewall 161, there are a pair of spaced, curved and diametrically opposed sidewall extensions 163, each having an upper portion 164, formed to define a shoulder projecting circumferentially , or stop member 164A, at each circumferential end in the upper portion 164. Each extension of sidewall 163 can thus be described as having the general shape of a T, a pair of diametrically opposed openings of sidewall 163A formed between the two side wall extensions 163. Together, the lugs 157A and 164A thus serve as means of limiting displacement, defining the maximum radial stroke of the outer member 150 of the piston assembly 140.
    [000106] As can be better understood with reference to figures 18A, 18B, 19A, and 19B, the outer member 150 and the inner member 160 can be assembled by means of the lateral insertion of the sidewall extensions, of the upper portions 163 of the member 160, inside the side wall openings 156A of the outer member 150, so that the outer member 150 and the inner member 160 are in coaxial alignment. The outer member 150 is axially movable in relation to the inner member 160 (that is, radially in relation to the steering section 80), the axial movement out of the outer member 150 being limited by the contact of the lugs 157A on the outer member 150, against the lugs 164A on the inner member 160, as shown in figures 17B, 18B, and 19B.
    [000107] The request spring 170, shown in the isometric view of figure 21, comprises a cylindrical side wall 173, having an upper end 173U and a lower end 173L, and defining a cylindrical inner chamber 174. The upper end 173U of the side wall 173 is formed or provided with an annular flange projecting inward 171, and a lower end 173L of the side wall 173 is formed or provided with an annular lip protruding outward 179. A helical slit 175 is formed along the wall lateral 173 so that the side wall 173 takes the form of a helical spring, the helical slit 175 having an upper end adjacent to the annular flange 171 and a lower end adjacent to the annular lip 179. A pair of diametrically opposite openings of the retaining pin 172 is formed along the side wall 173, to receive a retaining pin 145, when the request spring 170 is mounted with the inner member 160 of the piston 140 and installed in a steering section 80 (as described later). In the illustrated embodiment of spring 170, the lower terminal of the helical slot 175 coincides with one of the openings of the retaining pin 172, but this is for simple convenience and not for any essential reason of functionality. A pair of diametrically opposite openings of fluid 168 (semicircular or semioval in the illustrated embodiment) are formed within the side wall 173, intersecting the lower end 173L of the side wall 173 and at right angles to the openings of the retaining pin 172, of in order to be, in general, aligned with the fluid openings 168 in the side wall 161 of the inner member 160 when the loading spring 170 is mounted with the inner member 160.
    [000108] The assembly of piston assembly 140 can be better understood with reference to figures 17A, 17B, and 22. The first stage of assembly is the insertion of the request spring 170 upwards and into the cavity 165 of the member inner 160, so that the annular lip 179 in the request spring 170 is fitted so that it is retained within the annular groove 169 at the lower end 160L of the inner member 160. The next step is the assembly of the subassembly of the inner member 160 and the load spring 170 with outer member 150, inserting the upper end of load spring 170 into the lower end of outer member 150, so that the flange 171 of load spring 170 is disposed within annular space 155 in the outer member 150. A generally cylindrical spacer 180 having an annular flange projecting inward 180A at its lower end is then positioned on and around the cylindrical boss 153, and a screw of the cover 182 is inserted upwards, through the opening in the spacer 180, and threaded into the threaded cavity 154 in the boss 153; thereby securing the spacer 180 and the upper end of the request spring 170 to the outer member 150.
    [000109] Assembled in this way, piston 140 incorporates a request spring 170 with its upper (outer) end securely retained within the outer member 150, and with its lower (inner) end securely retained by the inner member 160. In this way, when an actuating fluid from the piston flows out into the associated fluid channel 30 in the steering section 80, the fluid will flow into the piston 140 and exert pressure against the cover member 151 of the outer member 150, in order to overcome the deflection force of the request spring 170, and to extend the outer member 150 radially outwards, from the steering section 80. When the fluid pressure is released, the request spring 170 returns the outer member 150 to its stowed position, as shown in figures 17A and 18A. The magnitude of the deflection force provided by the request spring 170 can be adjusted by adjusting the axial position of the cover screw 182, and / or using spacers 180 of different axial lengths.
    [000110] The assembled piston (s) 140 can then be assembled (s) within the steering section 80, as shown in figure 22. The retaining pins 145 are inserted through the transverse openings in the steering section 80 and through the retaining pin openings 162 and 172 in the inner member 160 and in the request spring 170, respectively, thereby securing the inner member 160 and the lower end of the request spring 170 against the radial movement relative to the steering section 80.
    [000111] The specific configuration of the request spring 170, shown in the Figures, and the specific means used to mount the request spring 170 on the outer member 150 and on the inner member 160, are for example only. Those skilled in the art will note that alternative configurations and mounting means can be designed, according to the techniques already known; and, it is intended that these alternative configurations and mounting means fall within the scope of this publication.
    [000112] Piston assembly 140 provides significant benefits and advantages when compared to existing piston designs. The design of the piston assembly 140 facilitates a long stroke of the piston within a comparatively short piston assembly, with a high mechanical return force provided by the integrated request spring 170. This piston assembly is also less prone to debris that leads to pistons to be trapped within the steering section or to limit the piston stroke when it operates in environments with dirty fluids. It also allows a pre-loaded piston spring assembly to be mounted and secured in place, within the steering section, using a simple pin, without the need to pre-load the spring, during insertion into a steering section , making the piston assembly easier to use or replace.
    [000113] Those skilled in the art will readily note that various modifications to the embodiments taught by this publication can be designed without departing from the teachings and scope of this publication, including modifications using structures or materials equivalent to those designed or developed . In particular, it should be understood that the present publication is not intended to be limited to any of the described or illustrated embodiments, and that the replacement of a variant of a claimed element, without resulting in any substantial change in the operation, will not represent a departure from the scope of this publication. It should also be noted that the different teachings of the embodiments described and discussed here can be used separately or in any suitable combination, to produce different embodiments, providing the desired results.
    [000114] Those skilled in the art will also note that the components of the published embodiments, which are described or illustrated here as unitary components, can also be constructed from multiple subcomponents, without any material effect on function or function. operation, unless the context clearly requires these components to be of a unitary construction. Similarly, components described or illustrated as assembled from multiple subcomponents can be provided as unitary components, unless the context requires otherwise.
    [000115] In this patent document, any form of the word “understand” must be understood in its non-limiting sense, to indicate that whatever item that follows this word is included, but that items that are not specifically mentioned are not excluded. A reference to an element by the indefinite article "one" does not exclude the possibility that more than one of this element is present, unless the context clearly requires that there is one and only one of this element.
    [000116] Regardless of the use of any form of the terms “connect”, “fit”, “couple”, “affix”, or other terms that describe an interaction between elements, it is not intended to limit this interaction to a direct interaction between the elements in question, and may also include indirect interaction between the elements, for example, through a secondary or intermediate structure.
    [000117] Relational terms such as "parallel", "perpendicular", "coincident", "intersecting", "equal", "coaxial", and "equidistant" should not be understood as denoting or requiring absolute mathematical or geometric precision. Accordingly, these terms are to be understood as denoting or requiring only substantial precision (for example, "substantially parallel to") unless the context clearly requires otherwise.
    [000118] Whenever used in this document the terms "typical" and "typically" should be interpreted in the sense of representative or common or practical use, and should not be understood as implying essentiality or invariability.
    [000119] In this patent document, certain components of the published RSS tool embodiments are described using adjectives such as "upper" and "lower". These terms are used to establish a convenient frame of reference to facilitate explanation and to improve the reader's understanding of spatial relationships and the relative locations of the various elements and characteristics of the components in question. The use of these terms should not be interpreted as implying that they will be technically applicable in all applications and practical uses of the RSS tools, in accordance with this publication, or that these sub-tools must be used in spatial guidelines that are strictly consistent. with the adjectives indicated above. For example, according to this publication, RSS tools can be used for drilling horizontal or angularly oriented wells. To be more certain, in this way, the adjectives "upper" and "lower", when used with reference to an RSS tool, must be understood in the sense of "towards the upper (or lower) end of the drilling column", regardless of what the actual spatial orientation of the RSS tool and the drilling column may be, in a given use, in practice. The appropriate and intended interpretation of the adjectives "internal", "external", "superior", and "inferior" for the specific purposes of the illustrated piston assemblies and their components will be clear from the corresponding portions of the Detailed Description.
    权利要求:
    Claims (10)
    [0001]
    1. A steerable rotary drilling rig (100, 200) having a longitudinal axis, comprising: a control assembly (50) disposed within a housing (10) having a lower end; a targeting section (80, 280, 280-1, 380) having a central channel, an upper end coupled to the lower end of the housing (10), a lower end opposite the upper end, and a plurality of circumferentially spaced fluid channels (30) arranged around the central channel (22), with each fluid channel (30) extending axially from the upper end; a plurality of radially extendable pistons (40) housed in the steering section (80, 280, 280-1, 380); where the central channel (22) extends axially from the upper end of the steering section (80, 280, 280-1, 380) and is configured to flow the drilling fluid through the steering section (80, 280, 280-1, 380); where each of the fluid channels (30) extends from the upper end of the steering section (80, 280, 280-1, 380) to one of the pistons (40), and where each piston (40) is configured to move radially outward in response to the drilling fluid supplied by the corresponding fluid channel (30); and a fluid measurement set configured to selectively measure the flow of drilling fluid within one or more of the fluid channels (30) in the steering section (80, 280, 280-1, 380), characterized by the fact that : the fluid measurement set comprises: a lower sleeve (120, 220) coupled to the upper end of the steering section (80, 280, 280-1, 380), where the lower sleeve (120, 220) has 2IÁ a central hole (121, 221) and a plurality of circumferentially spaced entries (122, 222) arranged around the central hole (121, 221), where the central hole (121, 221) of the lower sleeve (120, 220) is in fluid communication with the central channel (22) of the steering section (80, 280, 280 -1, 380); and, an upper sleeve (110, 210) coupled to the control assembly (50) and rotatably arranged within the central hole (121, 221) of the lower sleeve (120, 220), wherein the upper sleeve (110, 210) includes a central hole (114, 214) and a fluid measurement opening (118, 218); and, the control assembly (50) is configured to rotate the upper sleeve (110, 210) in relation to the lower sleeve (120, 220) to place the fluid measurement opening (118, 218) of the upper sleeve (110, 210) in fluid communication with each fluid inlet (122, 222) of the lower sleeve (120, 220) in sequence.
    [0002]
    2. Directional rotary drilling rig (100, 200) according to claim 1, characterized in that the control set (50) is configured to move the upper sleeve (110, 210) axially in relation to the lower sleeve ( 120, 220) between: (a) an upper position allowing the drilling fluid to flow into all fluid inlets (122, 222) of the lower sleeve (120, 220) simultaneously; (b) an intermediate position allowing drilling fluid to flow only into one fluid inlet (122, 222) of the lower sleeve (120, 220) at a time; and (c) a lower position preventing drilling fluid from flowing into any of the fluid inlets (122, 222) of the lower sleeve (120, 220).
    [0003]
    3. Directional rotary drilling rig (100, 200) according to claim 1, characterized in that it additionally comprises a plurality of reaction blocks (240, 340) coupled to the steering section (80, 280, 280-1, 380), in which a reaction block (240, 340) is provided for each piston (40); wherein each piston (40) is configured to deflect the corresponding reaction block (240, 340) radially out of the steering section (80, 280, 280-1, 380) in response to the flow of drilling fluid through the channel corresponding fluid (30).
    [0004]
    4. Directional rotary drilling rig (100, 200) according to claim 3, characterized in that the reaction block (240) comprises a flexible member resiliently mounted in the steering section (80, 280, 280-1, 380) .
    [0005]
    5. Directional rotary drilling rig (100, 200) according to claim 3, characterized in that the reaction block (340) comprises a pivotally articulated member coupled to the steering section (80, 280, 280-1, 380) and configured to pivot around an articulated axis oriented parallel to the longitudinal axis of the steering section (80, 280, 280-1, 380).
    [0006]
    6. Directional rotary drilling rig (100, 200) according to claim 1, characterized in that it additionally comprises a request medium (170) for each piston (40), in which each request medium (170) is configured to request the corresponding piston to a radially retracted position within the steering section (80, 280, 280-1, 380) when the drilling fluid flow to the piston (40) ceases.
    [0007]
    7. Directional rotary drilling rig (100, 200) according to claim 1, characterized in that at least one of the pistons (40) comprises: an internal member (160) mounted on the steering section (80, 280, 280 -1, 380) and radially fixed in relation to it; and an outer member (150) movably coupled to the inner member (160) and configured to move radially in relation to the inner member (160) and the steering section (80, 280, 280-1, 380); and displacement limiting means to restrict the radial course of the outer member (150) in relation to the inner member (160) and the steering section (80, 280, 280-1, 380).
    [0008]
    Steerable rotary drilling rig (100, 200) according to claim 7, characterized in that the displacement limiting device comprises a plurality of first stop elements (157A) formed on the outer member (150) and a plurality of second stop elements (164A) formed on the inner member (160), wherein the first and second stop elements (157A, 164A) are configured and arranged so that each first stop element (157A) reacts against one of the second stop elements (164A) when the travel of the external member (150) reaches a pre-established limit.
    [0009]
    Directional rotary drilling rig (100, 200) according to claim 7, characterized in that at least one of the pistons (40) additionally comprises request means (170) for retracting the external member (150) inwardly the steering section (80, 280, 280-1, 380) when the flow of drilling fluid to the piston (40) ceases.
    [0010]
    10. Directional rotary drilling rig (100, 200) according to claim 1, characterized in that the lower end of the steering section (80, 280, 280-1, 380) comprises a cutting structure (90) rotatable with it.
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    同族专利:
    公开号 | 公开日
    US9016400B2|2015-04-28|
    AU2011301169A1|2013-03-28|
    AU2011301169A2|2013-08-01|
    EP2614209A4|2014-11-26|
    BR112013005716A2|2016-05-03|
    CN103221626A|2013-07-24|
    ES2623911T3|2017-07-12|
    RU2540761C2|2015-02-10|
    EP2614209B1|2017-03-15|
    MX2013002663A|2013-09-06|
    US20120061148A1|2012-03-15|
    CA2810266A1|2012-03-15|
    WO2012031353A1|2012-03-15|
    CA2810266C|2016-05-03|
    EP2614209A1|2013-07-17|
    AU2011301169B2|2016-11-10|
    CN103221626B|2015-07-15|
    RU2013111959A|2014-10-20|
    PL2614209T3|2017-07-31|
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    法律状态:
    2018-12-26| B06F| Objections, documents and/or translations needed after an examination request according art. 34 industrial property law|
    2019-08-06| B06U| Preliminary requirement: requests with searches performed by other patent offices: suspension of the patent application procedure|
    2020-02-04| B07A| Technical examination (opinion): publication of technical examination (opinion)|
    2020-05-12| B09A| Decision: intention to grant|
    2020-07-07| B16A| Patent or certificate of addition of invention granted|Free format text: PRAZO DE VALIDADE: 20 (VINTE) ANOS CONTADOS A PARTIR DE 09/09/2011, OBSERVADAS AS CONDICOES LEGAIS. |
    优先权:
    申请号 | 申请日 | 专利标题
    US38124310P| true| 2010-09-09|2010-09-09|
    US61/381243|2010-09-09|
    US41009910P| true| 2010-11-04|2010-11-04|
    US61/410099|2010-11-04|
    PCT/CA2011/001006|WO2012031353A1|2010-09-09|2011-09-09|Downhole rotary drilling apparatus with formation-interfacing members and control system|
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