WO2014107232A2 - Appareil de forage guidé rotatif de type push-the-bit avec filtre de fluide autonettoyant - Google Patents

Appareil de forage guidé rotatif de type push-the-bit avec filtre de fluide autonettoyant Download PDF

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Publication number
WO2014107232A2
WO2014107232A2 PCT/US2013/069985 US2013069985W WO2014107232A2 WO 2014107232 A2 WO2014107232 A2 WO 2014107232A2 US 2013069985 W US2013069985 W US 2013069985W WO 2014107232 A2 WO2014107232 A2 WO 2014107232A2
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WO
WIPO (PCT)
Prior art keywords
fluid
component
steering section
central
sleeve
Prior art date
Legal status (The legal status is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the status listed.)
Ceased
Application number
PCT/US2013/069985
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English (en)
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WO2014107232A9 (fr
WO2014107232A3 (fr
Inventor
Jeffery Ronald Clausen
Jonathan Ryan Prill
Current Assignee (The listed assignees may be inaccurate. Google has not performed a legal analysis and makes no representation or warranty as to the accuracy of the list.)
National Oilwell Varco LP
Original Assignee
National Oilwell Varco LP
Priority date (The priority date is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the date listed.)
Filing date
Publication date
Priority claimed from US13/733,703 external-priority patent/US8869916B2/en
Application filed by National Oilwell Varco LP filed Critical National Oilwell Varco LP
Publication of WO2014107232A2 publication Critical patent/WO2014107232A2/fr
Publication of WO2014107232A3 publication Critical patent/WO2014107232A3/fr
Publication of WO2014107232A9 publication Critical patent/WO2014107232A9/fr
Anticipated expiration legal-status Critical
Ceased legal-status Critical Current

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Classifications

    • E—FIXED CONSTRUCTIONS
    • E21—EARTH OR ROCK DRILLING; MINING
    • E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B4/00—Drives for drilling, used in the borehole
    • E21B4/02—Fluid rotary type drives
    • E—FIXED CONSTRUCTIONS
    • E21—EARTH OR ROCK DRILLING; MINING
    • E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B17/00—Drilling rods or pipes; Flexible drill strings; Kellies; Drill collars; Sucker rods; Cables; Casings; Tubings
    • E21B17/10—Wear protectors; Centralising devices, e.g. stabilisers
    • E21B17/1014—Flexible or expansible centering means, e.g. with pistons pressing against the wall of the well
    • E—FIXED CONSTRUCTIONS
    • E21—EARTH OR ROCK DRILLING; MINING
    • E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B23/00—Apparatus for displacing, setting, locking, releasing or removing tools, packers or the like in boreholes or wells
    • E21B23/04—Apparatus for displacing, setting, locking, releasing or removing tools, packers or the like in boreholes or wells operated by fluid means, e.g. actuated by explosion
    • E21B23/0421—Apparatus for displacing, setting, locking, releasing or removing tools, packers or the like in boreholes or wells operated by fluid means, e.g. actuated by explosion using multiple hydraulically interconnected pistons
    • E—FIXED CONSTRUCTIONS
    • E21—EARTH OR ROCK DRILLING; MINING
    • E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B23/00—Apparatus for displacing, setting, locking, releasing or removing tools, packers or the like in boreholes or wells
    • E21B23/04—Apparatus for displacing, setting, locking, releasing or removing tools, packers or the like in boreholes or wells operated by fluid means, e.g. actuated by explosion
    • E21B23/0422—Apparatus for displacing, setting, locking, releasing or removing tools, packers or the like in boreholes or wells operated by fluid means, e.g. actuated by explosion characterised by radial pistons
    • E—FIXED CONSTRUCTIONS
    • E21—EARTH OR ROCK DRILLING; MINING
    • E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B7/00—Special methods or apparatus for drilling
    • E21B7/04—Directional drilling
    • E21B7/06—Deflecting the direction of boreholes
    • E21B7/064—Deflecting the direction of boreholes specially adapted drill bits therefor
    • E—FIXED CONSTRUCTIONS
    • E21—EARTH OR ROCK DRILLING; MINING
    • E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B7/00—Special methods or apparatus for drilling
    • E21B7/04—Directional drilling
    • E21B7/06—Deflecting the direction of boreholes
    • E21B7/068—Deflecting the direction of boreholes drilled by a down-hole drilling motor

Definitions

  • the present disclosure relates generally to systems and apparatus for directional drilling of wellbores, particularly for oil and gas wells.
  • Rotary steerable systems currently used in drilling oil and gas wells into subsurface formations commonly use tools that operate above the drill bit as completely independent tools controlled from the surface. These tools are used to steer the drill string in a desired direction away from a vertical or other wellbore orientation, such as by means of steering pads or reaction members that exert lateral forces against the wellbore wall to deflect the drill bit relative to wellbore centerline.
  • Most of these conventional systems are complex and expensive, and have limited run times due to battery and electronic limitations. They also require the entire tool to be transported from the well site to a repair and maintenance facility when parts of the tool break down. In addition, most conventional designs require large pressure drops across the tool for the tools to work well.
  • Rotary steerable systems currently used for directional drilling focus on tools positioned uphole of the drill bit that either push the bit with a constant force several feet above the bit, or point the bit in order to steer the bit in the desired direction.
  • Push-the-bit systems are simpler and more robust, but have limitations due to the applied side force being several feet from the bit and thus requiring the application of comparatively large forces to deflect the bit.
  • the side force necessary to induce a given bit deflection (and, therefore, a given change in bit direction) increase as the distance between the side force and the bit increases.
  • Point-the-bit systems may offer performance advantages over push-the-bit systems, but they require complex and expensive drill bit designs; moreover, they can be prone to bit stability problems in the wellbore, making them less consistent and harder to control, especially when drilling through soft formations.
  • a push-the-bit system typically requires the use of a filter sub run above the tool to keep debris out of critical areas of the apparatus. Should large debris (e.g., rocks) or large quantities of lost circulation material (e.g., drilling fluid) be allowed to enter the valve arrangements in current push-the-bit tool designs, valve failure is typically the result.
  • filter subs are also prone to problems; should lost circulation material or rocks enter and plug up a filter sub, it may be necessary to remove (or "trip") the drill string and bit from the wellbore in order to clean out the filter.
  • Push-the-bit RSS designs currently in use typically incorporate an integral RSS control system or apparatus for controlling the operation of the RSS tool. It is therefore necessary to disconnect the entire RSS apparatus from the drill string and replace it with a new one whenever it is desired to change bit sizes. This results in increased costs and lost time associated with bit changes. Accordingly, there is also a need in the art for push-the-bit RSS designs in which the RSS control apparatus is easily separable from the steering mechanism and can be used with multiple drill bit sizes.
  • the drilling apparatus comprises a control assembly disposed within a cylindrical housing.
  • the drilling apparatus comprises a steering section having a central axis, a first end coupled to the housing, a second end, a central channel extending axially from the first end, and a fluid channel extending axially from the first end and radially-spaced from the central channel.
  • the central channel is configured to flow drilling fluid through the steering section to a cutting structure.
  • the drilling apparatus comprises a piston housed in the steering section. The fluid channel in the steering section extends to the piston and is configured to flow drilling fluid to the piston.
  • the control assembly is configured to move the first component relative to the second component to control the flow of drilling fluid through the fluid port into the fluid inlet of the second component.
  • the drilling apparatus comprises a filter module disposed in the housing and configured to filter the drilling fluid passing through the fluid port of the first component into the fluid inlet of the second component.
  • the drilling apparatus comprises a cylindrical housing.
  • the drilling apparatus comprises a control assembly disposed in the housing.
  • the drilling apparatus comprises a steering section having a central axis, an upper end coupled to a lower end of the housing, a lower end, a central channel extending axially from the upper end, and a plurality of circumferentially-spaced fluid channels disposed about the central channel and extending axially from the upper end of the steering section.
  • the central channel is configured to flow drilling fluid through the steering section to a cutting structure.
  • the drilling apparatus comprises a plurality of pistons housed in the steering section.
  • the method comprises (b) flowing drilling fluid through the central bore of the upper sleeve and the central bore of the lower sleeve into a central channel of a steering section coupled to a lower end of the housing. Further, the method comprises (c) diverting a first portion of the drilling fluid flowing through the fluid-metering opening of the upper sleeve and a first of the fluid inlets of the lower sleeve into a first fluid channel of the steering section during (b). Still further, the method comprises (d) filtering the first portion of the drilling fluid to remove at least some solids particles from the drilling fluid. Moreover, the method comprises (e) flowing the first portion of drilling fluid through the first fluid channel to a first piston housed in the steering section after (d). The method also comprises (f) moving the first piston radially outward from the steering section during (e).
  • the steering section is formed with one or more fluid channels, corresponding in number to the number of pistons, and each extending between the radially-inward end of a corresponding piston to a fluid inlet at the upper end of the steering section, such that a piston-actuating fluid (e.g., drilling mud) can enter any given fluid channel to actuate the corresponding piston.
  • a piston-actuating fluid e.g., drilling mud
  • the fluid channels continue downward past the pistons to allow fluid to exit into the wellbore through terminal bit jets.
  • the fluid-metering assembly comprises a generally cylindrical upper sleeve member having an upper flange and a fluid-metering slot or opening in the sleeve below the flange.
  • the fluid-metering assembly also comprises a lower sleeve having a center bore and defining the required number of fluid inlets, with each fluid inlet being open to the center bore via an associated recess in an upper region of the lower sleeve.
  • the lower sleeve is mounted to or integral with the upper end of the steering section.
  • the upper and lower sleeves are adapted and proportioned such that the upper sleeve is axially movable relative to the lower sleeve, between an upper position permitting fluid to flow into all fluid inlets simultaneously, an intermediate position permitting fluid flow into only one fluid inlet at a time, and a lower position preventing fluid flow into any of the fluid inlets (in which case all of the fluid simply continues to flow downward to the cutting structure through a central bore or channel in the steering section).
  • leakage of fluid to the pistons, if any is generally insufficient to activate the pads even though the upper sleeve may be spinning.
  • fluid flow to the pistons is much less when the slot in the rotating upper sleeve is not aligned with the hole in the fixed lower sleeve.
  • grooved slots can be provided in the top face of the fixed lower sleeve to increase the minimum constant flow to the piston chambers regardless of the position of the rotating upper sleeve.
  • the fluid-metering assembly comprises an upper plate that is coaxially rotatable (by means of the control assembly) above a fixed lower plate incorporated into the upper end of the steering section, with the fixed lower plate defining the required number of fluid inlets, which are arrayed in a circular pattern concentric with the longitudinal axis (i.e., centerline) of the steering section, and aligned with corresponding fluid channels in the steering section.
  • the upper and lower plates are preferably made from tungsten carbide or another wear-resistant material.
  • the upper plate has a single fluid-metering opening extending through it, offset a radial distance generally corresponding to the radius of the fluid inlets in the fixed lower plate.
  • the rotating upper plate lies immediately above and parallel to the fixed lower plate, such that when the fluid-metering opening in the upper plate is aligned with a given fluid inlet in the fixed lower plate, piston-actuating fluid flows through the fluid-metering opening in the upper plate and the aligned fluid inlet in the fixed lower plate, and into the corresponding fluid channel in the steering section.
  • This fluid flow causes the corresponding piston to extend radially outward from the steering section such that it reacts against its reaction member (or reacts directly against the wellbore), thereby pushing and deflecting the cutting structure of the bit in the opposite direction.
  • the steering section of the drill bit is preferably releasably or removably connected to the control assembly (e.g., via a conventional pin-and-box threaded connection), with the rotating upper plate being incorporated into the control assembly.
  • This facilitates field assembly of the components to complete the RSS tool at the drilling rig site, and facilitates quick drill bit changes at the rig site, either to use a different cutting structure, or to service the steering section, without having to remove the control assembly from the drill string.
  • the control assembly is set to keep the fluid-metering opening oriented in the direction opposite to the desired pushing direction (i.e., direction of deflection).
  • the drill bit is rotated within the wellbore, while the upper plate is non-rotating relative to the wellbore. With each rotation of the drill bit, the fluid-metering opening in the upper plate will pass over and be momentarily aligned with each of the fluid inlets in the fixed lower plate. Accordingly, when an actuating fluid is introduced into the interior of the tool housing above the upper plate, fluid flows into each fluid channel in turn during each rotation of the drill string.
  • the direction in which the cutting structure is pushed can be changed by rotating the upper plate to give it a different fixed orientation relative to the wellbore.
  • the tool can be put into a straight-drilling mode.
  • bit steerability is enhanced, and the force needed to push the bit is reduced.
  • the term "repeatability” is understood as denoting the ability to repeatably achieve a consistent curve radius (or "build rate") for the trajectory of a wellbore in a given subsurface formation, independent of the strength of the formation.
  • the greater the magnitude of the force applied against the wall of a wellbore by a piston in a push-the-bit drilling system the greater will be the tendency for the piston to cut into softer formations and reduce the curvature of the trajectory of the wellbore (as compared to the effect of similar forces in harder formations). Accordingly, this tendency in softer formations is reduced by virtue of the lower piston forces required for equal effectiveness when using push-the-bit systems in accordance with embodiments described herein.
  • Push-the-bit rotary steerable drilling systems and apparatus in accordance with the principles described herein can be of modular design, such that any of the various components (e.g., pistons, reaction members, control assembly, and control assembly components) may be changed out in the field during bit changes.
  • the rotating upper plate (or sleeve) of the fluid- metering assembly can be deactivated such that the tool will drill straight when deviation of the wellbore is not required, thereby promoting longer battery life (e.g., for battery-powered control assembly components) and extending the length of time that the tool can operate without changing batteries.
  • Embodiments of rotary steerable drilling apparatus described herein having fluid- metering assemblies incorporating upper and lower sleeves may include a generally cylindrical filter module coaxially mounted between the lower end of the control assembly and the upper sleeve of the fluid-metering assembly, such that the filter module rotates with the control assembly and the upper sleeve.
  • the filter module has a fluid passage, preferably but not necessarily in the form of a cylindrical bore, extending between an upper end in fluid communication with the annular space between the control assembly and the cylindrical housing of the apparatus, and a lower end in fluid communication with the bore of the upper sleeve of the fluid- metering assembly.
  • the filter module is axially movable within the housing (along with the control assembly), with an upper portion of the cylindrical outer surface of the main body of the filter module having a close tolerance tight fit within the bore of the housing, allowing passage of only very small particles. Adjacent a lower portion of the filter module body, the bore of the housing is increased in diameter, forming an annular space (or "filter annulus") between the cylindrical outer surface of the filter module body and the housing bore.
  • Fluid ports are provided through the cylindrical wall of the filter module body, and one or more filter elements are provided within the fluid passage of the filter module to cover the fluid ports.
  • the fluid passage is a cylindrical bore
  • the filter element is a cylindrical screen fitted against the cylindrical bore so as to cover all of the fluid ports.
  • the preloaded filter module accommodates significant misalignment during initial make-up of the bit pin with the box of the tool housing.
  • the filter module moves upward until the upper and lower sleeves of the fluid-metering assembly become concentric as the pin continues to make up to the housing box.
  • the spring or other preload means ensures that the upper sleeve is pushed into its properly seated position prior to initiation of fluid flow or rotation of the rotating sleeve. This arrangement reduces the risk of component damage during the procedure of stabbing the bit / lower sleeve assembly into the housing / upper sleeve assembly.
  • the operator could activate all of the pistons so that the cutting elements on the outer faces of the pistons (or on associated piston pads) will engage the wellbore to establish (or reestablish) a wellbore diameter equal to or greater than the as-new bit diameter.
  • Embodiments described herein comprise a combination of features and advantages intended to address various shortcomings associated with certain prior devices, systems, and methods.
  • the foregoing has outlined rather broadly the features and technical advantages of the invention in order that the detailed description of the invention that follows may be better understood.
  • the various characteristics described above, as well as other features, will be readily apparent to those skilled in the art upon reading the following detailed description, and by referring to the accompanying drawings. It should be appreciated by those skilled in the art that the specific embodiments disclosed may be readily utilized as a basis for modifying or designing other structures for carrying out the same purposes of the invention. It should also be realized by those skilled in the art that such equivalent constructions do not depart from the spirit and scope of the invention as set forth in the appended claims.
  • FIGURE 1 is an isometric view of an embodiment of a rotary drilling apparatus in accordance with the principles described herein, with bit-deflecting pistons adapted for direct contact with the wall of a wellbore.
  • FIGURE 2 is a longitudinal cross-section through a first variant of the rotary drilling apparatus in FIG. 1, in which the fluid- metering assembly comprises a rotating upper sleeve and a fixed lower sleeve.
  • FIGURE 2 A is an enlarged detail of the fluid-metering assembly in FIG. 2.
  • FIGURES 3A, 3B, and 3C are isometric, cross-sectional, and side views, respectively, of the rotating upper sleeve of the rotary drilling apparatus in FIG. 2.
  • FIGURE 6 is an isometric partial longitudinal section through a medial region of the rotary drilling apparatus in FIG. 2, showing the rotating upper sleeve, fixed lower sleeve with fluid inlets, and fluid channels in the steering section.
  • FIGURE 7 is a bottom view of the rotary drilling apparatus of FIG. 2, showing the drill bit and piston housings, with one bit-deflecting piston extended.
  • FIGURE 9A is a cross-section through the variant sleeve assembly in FIG. 8A, with the rotating upper sleeve in an intermediate position in which piston-actuating fluid flows only into one fluid inlet.
  • FIGURE 9B is a transverse cross-section through the sleeve assembly in FIG. 9A, illustrating flow of piston-actuating fluid into the fluid inlet aligned with the slot in the rotating upper sleeve.
  • FIGURE 13 is a transverse cross-section through the rotary drilling apparatus in FIG. 12, illustrating the fluid-metering opening in the rotating upper plate aligned with a fluid inlet through the fixed upper plate into the drill bit, and showing the corresponding bit-deflecting piston extended.
  • FIGURE 15A is an isometric view of the steering section of the rotary drilling apparatus in FIG. 12, with a hinged reaction member mounted to the steering section in association with each piston.
  • FIGURE 16C is a side view of the apparatus in FIG. 16A, with one piston actuated and deflecting its associated flexible reaction member.
  • FIGURE 17B is a cross-section through the piston assembly in FIG. 17A, shown in an extended position (and with the biasing spring not shown for clarity of illustration).
  • FIGURE 18B is a side view of the piston assembly in FIGS. 17A and 17B, shown in an extended position.
  • FIGURE 19A is an isometric view of the piston assembly in FIGS. 17A-18B, shown in a retracted position.
  • FIGURE 20A is an isometric view of the outer member of the piston assembly in FIGS. 17A-19B.
  • FIGURE 20B is an isometric view of the inner member of the piston assembly in FIGS. 17A-19B.
  • FIGURE 21 is an isometric view of the biasing spring of the piston assembly in FIGS. 17A-19B.
  • FIGURE 22 is a transverse cross-section through the steering section of the rotary drilling apparatus in FIG. 2, incorporating piston assemblies in accordance with FIGS. 17A- 21.
  • FIGURE 23 is a longitudinal cross-section through a first embodiment of the apparatus incorporating a filter module.
  • FIGURE 24A is an enlarged detail of the upper and lower sleeves of the fluid- metering assembly in the embodiment shown in FIG. 23.
  • FIGURE 24B is a transverse cross-section through the sleeve assembly in FIG. 24A, taken through the radial slot in the upper sleeve and the radial recesses in the lower sleeve.
  • FIGURE 25 is an isometric view of the sleeve assembly shown in FIGS. 24A and 24B.
  • FIGURES 25A and 25B are isometric views, respectively, of the upper and lower sleeves shown in FIGS. 24A, 24B, and 25.
  • FIGURE 26 is a longitudinal cross-section through a second embodiment of the apparatus incorporating a filter module.
  • FIGURE 27A is an enlarged detail of the upper and lower sleeves of the fluid- metering assembly in the embodiment shown in FIG. 26.
  • FIGURE 27B is a transverse cross-section through the sleeve assembly in FIG. 27A, taken through the radial slot in the upper sleeve and the radial recesses in the lower sleeve.
  • FIGURE 28 is an isometric view of the sleeve assembly shown in FIGS. 27A and 27B.
  • FIGURES 28A and 28B are isometric views, respectively, of the upper and lower sleeves shown in FIGS. 27A, 27B, and 28.
  • FIGURE 30 is an isometric view of an embodiment of a bit-deflecting piston in accordance with the principles described herein incorporating auxiliary cutting elements.
  • FIGS. 1 and 2 illustrate (in isometric and cross-sectional views, respectively) a rotary steerable drilling apparatus (or "RSS tool") 100 in accordance with a first embodiment.
  • RSS tool 100 includes a cylindrical outer housing 10 enclosing a control assembly 50 and a drill bit 20.
  • An annular space 12 is radially disposed between control assembly 50 and housing 10, such that drilling fluid flowing into housing 10 will flow downward through annular space 12 toward drill bit 20.
  • Drill bit 20 includes a steering section 80 connected to the lower end of housing 10, and a cutting structure 90 connected to the lower end of steering section 80 so as to be rotatable therewith.
  • Steering section 80 is preferably formed or provided with means for facilitating removal from housing 10, such as bit breaker slots 15.
  • cutting structure 90 can be any suitable type of cutting structure (for example, a polycrystalline diamond compact bit or a roller-cone-style bit).
  • Steering section 80 has one or more fluid channels 30 extending downward from the upper end of steering section 80. As seen in FIG. 2, steering section 80 also has a central axial channel 22 for conveying drilling fluid to cutting structure 90, where the drilling fluid can exit under pressure through jets 24 in the face of cutting structure 90 to enhance the effectiveness of cutting structure 90 as it drills into subsurface formation.
  • Each fluid channel 30 leads to the radially inner end of a corresponding piston 40 extendable radially outward from steering section 80 in response to pressure from an actuating fluid flowing under pressure through fluid channel 30.
  • each fluid channel 30 extends axially beyond its corresponding piston 40 to a terminal bit jet 34, which allows for fluid drainage and for bleeding off of fluid pressure.
  • the piston-actuating fluid is a portion of the drilling fluid diverted from the fluid flowing through axial channel 22 to cutting structure 90.
  • the piston-actuating fluid could alternatively be a fluid different from and/or from a different source than the drilling fluid flowing to cutting structure 90.
  • Recesses 124 are formed in an upper region of lower sleeve 120 to provide fluid communication between each fluid inlet 122 and bore 121. Accordingly, as best shown in FIGS. 2A and 6, when cylindrical section 116 of upper sleeve 110 is disposed within bore 121 of lower sleeve 120, with fluid-metering slot 118 aligned with a given recess 124 in lower sleeve 120, bore 114 of upper sleeve 110 will be in fluid communication with the corresponding fluid channel 30 in steering section 80, via slot 118, recess 124, and fluid inlet 122. As may be seen in FIG. 5, the resultant flow of actuating fluid under pressure within the corresponding fluid channel 30 results in actuation and radially-outward extension of the corresponding piston (indicated in FIG. 5 by reference numeral 40A to denote an actuated piston).
  • Control assembly 50 is provided with metering assembly engagement means for rotating upper sleeve 110, and this could take any functionally effective form.
  • the metering assembly engagement means is shown in FIGS. 2, 2A, and 6 as comprising a shaft 52 operably connected at its upper end to control assembly 50, and connected at its lower end to a cylindrical yoke 54 having an upper end plate 53 with one or more fluid openings 53A.
  • FIGS. 8A is generally similar to lower sleeve 120 in FIGS. 4A-4C, with fluid inlets 222 below corresponding recesses 224 (similar to fluid inlets 122 and recesses 24 in lower sleeve 120) formed into a lower body 225 having a bore 221 analogous to bore 121 in lower sleeve 120, plus a cap plate 226 extending across the top of lower body 25 and having a central opening for receiving cylindrical section 216 of upper sleeve 210.
  • control assembly 50 incorporates or is provided with means for raising and lowering upper sleeve 210 in addition to rotating upper sleeve 210.
  • any suitable means known in the art e.g., a motor
  • FIGS. 14A, 14B, 14C, and 14D illustrate the steering section 280 of an RSS tool in accordance with the embodiment shown in FIG. 12.
  • Steering section 280 is substantially similar to steering section 80 described with reference to FIG. 12, and like reference numbers are used for components common to both embodiments.
  • Steering section 280 is shown by way of non-limiting example with an upper pin end 16 for purposes of threaded connection to the lower end of housing 10, and with a lower box end 17 for threaded connection to the upper end of cutting structure 90.
  • Steering section 280 is distinguished from steering section 80 shown in FIG.
  • flexible reaction pads 240 each of which has an upper end resiliently mounted to the main body of steering section 280 and a free lower end 241 which extends over a corresponding piston housing 28.
  • the resilient mounting of flexible reaction pads 240 to the body of steering section 280 is accomplished by having the upper ends of reaction pads 240 formed integrally with a circular band 242 disposed within an annular groove 243 extending around the circumference of steering section 280 at a point below pin end 16.
  • this is by way of example only. Persons skilled in the art will appreciate that other ways of resiliently mounting the upper ends of reaction pads 240 to steering section 280 may be readily devised, and the present disclosure is not limited to the use of any particular means or method of mounting reaction pads 240.
  • 17A and 17B is adapted to receive the upper end of biasing spring 170 (in a manner to be described later herein), and for that purpose is formed with a cylindrical boss 153 projecting coaxially downward from cap member 151 and having an open-bottomed and internally-threaded cavity 154.
  • An open-bottomed annular space 155 is thus formed between boss 153 and sidewall 152 of outer member 150.
  • a generally cylindrical spacer 180 having an inward-projecting annular flange 180A at its lower end is then positioned over and around cylindrical boss 153, and a cap screw 182 is inserted upward through the opening in spacer 180 and threaded into threaded cavity 154 in boss 153, thus securing spacer 180 and the upper end of biasing spring 170 to outer member 150.
  • Recesses 658 are formed into an upper region of lower sleeve 650 to provide fluid communication between each fluid inlet 656 and bore 660. Accordingly, and as best seen in FIG. 27A, when cylindrical section 604 of upper sleeve 600 is disposed within bore 660 of lower sleeve 650, with fluid entry port 606 aligned with a given recess 658 in lower sleeve 650, bore 605 of upper sleeve 600 will be in fluid communication with the corresponding fluid channel 30 in steering section 80, via fluid entry port 606, recess 658, and fluid inlet 656.
  • RSS tool 450 is otherwise similar to the operation of RSS tool 400 as previously described, with fluid entering fluid annulus 425 entering the fluid-metering assembly through fluid entry port 606 in upper sleeve 600.

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  • Engineering & Computer Science (AREA)
  • Life Sciences & Earth Sciences (AREA)
  • Geology (AREA)
  • Mining & Mineral Resources (AREA)
  • Physics & Mathematics (AREA)
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  • General Life Sciences & Earth Sciences (AREA)
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  • Earth Drilling (AREA)

Abstract

La présente invention concerne un appareil de forage guidé comprenant un système de commande à l'intérieur d'un logement cylindrique raccordé à un trépan présentant des pistons radialement extensibles. Un ensemble de mesure de fluide dirige un fluide d'actionnement de piston dans des conduites hydrauliques menant aux pistons respectifs. Le système de commande commande l'ensemble de mesure de fluide pour faire s'écouler le fluide jusqu'aux pistons sélectionnés, entraînant l'extension temporaire des pistons actionnés dans la direction opposée jusqu'à la déviation de trou de forage souhaitée, pliant ainsi le trépan à distance de la ligne centrale du trou de forage. Un élément supérieur dans l'ensemble de mesure de fluide peut être déplacé pour stabiliser, guider et changer la surface d'écoulement totale (TFA) à l'intérieur du trépan. Le système de commande et le trépan sont raccordés de façon à faciliter le retrait pour modifier la section de guidage du trépan et à couper la configuration de structure ou le calibre simultanément. L'appareil peut comprendre un module de filtre de fluide fixé au système de commande. Les pistons peuvent comprendre des éléments de découpe auxiliaires pour assurer la capacité d'alésage à proximité du trépan.
PCT/US2013/069985 2013-01-03 2013-11-14 Appareil de forage guidé rotatif de type push-the-bit avec filtre de fluide autonettoyant Ceased WO2014107232A2 (fr)

Applications Claiming Priority (2)

Application Number Priority Date Filing Date Title
US13/733,703 2013-01-03
US13/733,703 US8869916B2 (en) 2010-09-09 2013-01-03 Rotary steerable push-the-bit drilling apparatus with self-cleaning fluid filter

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WO2019045718A1 (fr) 2017-08-31 2019-03-07 Halliburton Energy Services, Inc. Ensemble de poussée de trépan en fond de trou avec alésoir
WO2019125533A1 (fr) * 2017-12-21 2019-06-27 Halliburton Energy Services, Inc. Système et procédé de commande de plaques réglables destinés à être utilisés dans des ensembles de forage directionnel de fond de trou
CN114382408A (zh) * 2020-10-16 2022-04-22 中石化石油工程技术服务有限公司 导向钻井装置
US11365586B2 (en) * 2017-12-29 2022-06-21 Halliburton Energy Services, Inc. Steering system for use with a drill string
CN116838261A (zh) * 2023-07-10 2023-10-03 河南理工大学 穿层钻孔环供流自清堵分体式孔底抽采消喷钻具

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GB9503830D0 (en) * 1995-02-25 1995-04-19 Camco Drilling Group Ltd "Improvements in or relating to steerable rotary drilling systems"
US6840336B2 (en) * 2001-06-05 2005-01-11 Schlumberger Technology Corporation Drilling tool with non-rotating sleeve
US7287605B2 (en) * 2004-11-02 2007-10-30 Scientific Drilling International Steerable drilling apparatus having a differential displacement side-force exerting mechanism

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WO2019045718A1 (fr) 2017-08-31 2019-03-07 Halliburton Energy Services, Inc. Ensemble de poussée de trépan en fond de trou avec alésoir
EP3615761B1 (fr) * 2017-08-31 2025-07-09 Halliburton Energy Services, Inc. Ensemble de poussée de trépan en fond de trou avec alésoir
WO2019125533A1 (fr) * 2017-12-21 2019-06-27 Halliburton Energy Services, Inc. Système et procédé de commande de plaques réglables destinés à être utilisés dans des ensembles de forage directionnel de fond de trou
US10731416B2 (en) 2017-12-21 2020-08-04 Halliburton Energy Services, Inc. System and method to control adjustable pads for use in downhole directional drilling assemblies
US11365586B2 (en) * 2017-12-29 2022-06-21 Halliburton Energy Services, Inc. Steering system for use with a drill string
GB2581747B (en) * 2017-12-29 2023-02-08 Halliburton Energy Services Inc Steering system for use with a drill string
CN114382408A (zh) * 2020-10-16 2022-04-22 中石化石油工程技术服务有限公司 导向钻井装置
US12252986B2 (en) 2020-10-16 2025-03-18 China Petroleum & Chemical Corporation Steerable drilling device
CN116838261A (zh) * 2023-07-10 2023-10-03 河南理工大学 穿层钻孔环供流自清堵分体式孔底抽采消喷钻具

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