WO2024067533A1 - Appareil formant garniture d'étanchéité pendant le forage et dispositif de forage à circulation inverse - Google Patents

Appareil formant garniture d'étanchéité pendant le forage et dispositif de forage à circulation inverse Download PDF

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Publication number
WO2024067533A1
WO2024067533A1 PCT/CN2023/121302 CN2023121302W WO2024067533A1 WO 2024067533 A1 WO2024067533 A1 WO 2024067533A1 CN 2023121302 W CN2023121302 W CN 2023121302W WO 2024067533 A1 WO2024067533 A1 WO 2024067533A1
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WO
WIPO (PCT)
Prior art keywords
drilling
rubber
transmission structure
rubber cylinder
tube
Prior art date
Application number
PCT/CN2023/121302
Other languages
English (en)
Chinese (zh)
Inventor
邓虎
范黎明
李枝林
周长虹
韩雄
唐贵
张�林
庞东晓
蒋杰
廖兵
杨超
Original Assignee
中国石油天然气集团有限公司
中国石油集团川庆钻探工程有限公司
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
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Application filed by 中国石油天然气集团有限公司, 中国石油集团川庆钻探工程有限公司 filed Critical 中国石油天然气集团有限公司
Publication of WO2024067533A1 publication Critical patent/WO2024067533A1/fr

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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
    • E21B33/00—Sealing or packing boreholes or wells
    • E21B33/10—Sealing or packing boreholes or wells in the borehole
    • E21B33/12—Packers; Plugs
    • 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
    • E21B33/00—Sealing or packing boreholes or wells
    • E21B33/10—Sealing or packing boreholes or wells in the borehole
    • E21B33/12—Packers; Plugs
    • E21B33/127—Packers; Plugs with inflatable sleeve
    • 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
    • E21B33/00—Sealing or packing boreholes or wells
    • E21B33/10—Sealing or packing boreholes or wells in the borehole
    • E21B33/12—Packers; Plugs
    • E21B33/128—Packers; Plugs with a member expanded radially by axial pressure

Definitions

  • the present invention relates to the field of drilling (exploration) engineering technology, and is particularly applicable to the field of oil and gas drilling technology, as well as to the field of rock and soil drilling technology such as geological minerals and mine rescue, and in particular, to a drilling isolation device and reverse circulation drilling equipment.
  • the number of horizontal wells and the length of horizontal sections have increased significantly, and the narrow pressure window problem and wellbore purification problem in the process of horizontal well drilling have become more and more prominent.
  • the circulating medium circulates only in the drill pipe, which can effectively avoid the fluctuation of bottom hole ECD, maintain the stability of the annular pressure gradient, and improve the rock carrying capacity of the circulating medium, which is conducive to drilling in a narrow density window and extending the length of the horizontal section.
  • Reverse circulation drilling technology uses a unique double-tube drill bit (also called double-wall drill bit).
  • the drilling fluid and cuttings are returned to the surface through the inner tube channel of the double-tube drill bit, which makes this technology have great advantages that cannot be matched by conventional positive circulation: there is no erosion on the well wall, which can avoid erosion instability of the well wall, especially when circulating at a large displacement; it can greatly save circulating media (gas, mud) and ground equipment, thereby reducing energy consumption and costs, and reducing site occupation area; the sand removal efficiency is high, and the bottom of the well is clean and sand-free, which can effectively control well leakage.
  • it reduces the comprehensive cost caused by the complexity of well leakage, and also shortens the additional drilling cycle caused by the complexity of well leakage; on the other hand, it solves the environmental problems caused by the complexity of well leakage.
  • Reverse circulation drilling uses a unique concentric double-tube drill bit (double-wall drill bit). During the drilling process, how the drilling fluid (including cuttings) at the bottom of the well can smoothly enter the inner tube channel of the drill bit and return to the surface is the key to the successful implementation of reverse circulation drilling. Using annular isolation to implement forced circulation is one of the means to establish reverse circulation.
  • An object of the present invention is to provide a drilling isolation device to solve the technical problems that the current isolation device cannot achieve drilling isolation during drilling, the deformation of the rubber cartridge packer is uncontrollable, the drill is easily stuck, and the rubber cartridge structure is not strong enough.
  • Another object of the present invention is to provide a reverse circulation drilling device to solve the technical problem that the circulation is easily failed during reverse circulation drilling, resulting in the inability of the circulating fluid to smoothly carry out the cuttings, causing the inability to continue drilling.
  • the present invention provides a drilling-while-packing device, at least one rubber-tube packer, which comprises a rubber tube, a frame and two rubber-tube seats, wherein the two rubber-tube seats are arranged opposite to each other and at intervals; the two ends of the rubber tube are connected to the two rubber-tube seats, and the rubber tube can be deformed under compression; the two ends of the frame are connected to the two rubber-tube seats and are located in the rubber tube, and the radial dimensions of the two ends of the frame are smaller than the radial dimensions of the middle thereof to form a first expansion form; an upper transmission structure is connected to the upper drilling tool and the uppermost rubber-tube seat; a lower transmission structure is connected to the lower drilling tool and the lowermost rubber-tube seat, and the lower transmission structure is connected to the upper transmission structure
  • the two arms are connected and can move relative to each other along the axial direction of the wellbore; wherein, in the drilling state, the upper transmission structure moves downward along the axial direction of the wellbore relative to the lower transmission structure,
  • the present invention also provides a reverse circulation drilling equipment, including the above-mentioned isolation-while-drilling device, and the reverse circulation drilling equipment also includes: a double-tube drill bit, including an upper drill bit and a lower drill bit, the upper drill bit and the lower drill bit both having an inner tube and an outer tube, the outer tube of the upper drill bit being connected to the upper transmission structure, and the outer tube of the lower drill bit being connected to the lower transmission structure; an upper core tube, the upper end of which is passed through the upper transmission structure and communicated with the inner tube of the upper drill bit; a lower core tube, the lower end of which is passed through the lower transmission structure and communicated with the inner tube of the lower drill bit, the lower end of the upper core tube slidingly fitting with the upper end of the lower core tube along the axial direction of the wellbore.
  • a double-tube drill bit including an upper drill bit and a lower drill bit, the upper drill bit and the lower drill bit both having an inner tube and an outer tube, the outer tube of the upper drill bit being connected
  • the drilling isolation device of the present invention is provided with a skeleton in the rubber tube, and the two ends of the skeleton are connected to the two rubber tube seats.
  • the skeleton forms a first expansion state with small ends and a large middle part, so that when the two rubber tube seats are close to each other, that is, the rubber tube packer is axially squeezed, the skeleton can guide the rubber tube to expand outwards during the process of expanding outwards from the first expansion state to the second expansion state, thereby preventing the rubber tube from shrinking inwards or other uncontrollable deformations when the rubber tube packer is axially squeezed and failing to achieve the purpose of isolation.
  • the support of the skeleton can improve the strength of the rubber cartridge during sealing, thereby improving the stability of the rubber cartridge packer; and the torque and drilling pressure provided by the upper drill bit are transmitted to the lower drill bit through the upper transmission structure and the lower transmission structure, so that in the drilling state, the two rubber cartridge seats can be close to each other due to the squeezing between the upper transmission structure and the lower transmission structure, so that the rubber cartridge expands outward and seals the wellbore annulus, and in the drill lifting state, the upper transmission structure can drive the upper rubber cartridge seat away from the lower rubber cartridge seat, so that the rubber cartridge retracts inward and separates from the wellbore.
  • the reverse circulation drilling equipment of the present invention when the double-tube drill tool is drilling, the wellbore annulus is isolated by the rubber tube isolation device to achieve forced circulation, ensuring that the circulating fluid can smoothly carry out the cuttings, which is conducive to continuous drilling.
  • FIG. 1 is a schematic structural diagram of a rubber cartridge packer according to a first embodiment of the present invention.
  • FIG. 2 is a schematic structural diagram of a rubber cartridge packer according to a second embodiment of the present invention.
  • FIG. 3 is a schematic structural diagram of a rubber cartridge packer according to a third embodiment of the present invention.
  • FIG. 4 is a cross-sectional view of a rubber cartridge according to a third embodiment of the present invention.
  • FIG5 is a partial cross-sectional view of the isolation while drilling device of the present invention in the drill lifting state.
  • FIG6 is an enlarged upper view of the isolation-while-drilling device of the present invention in the drill lifting state.
  • FIG. 7 is an enlarged view of the lower part of the isolation while drilling device of the present invention in the drill lifting state.
  • FIG8 is a schematic diagram of the overall structure of the reverse circulation drilling equipment of the present invention in the drill lifting state.
  • FIG. 9 is a schematic diagram of the overall structure of the reverse circulation drilling equipment of the present invention in the drilling state.
  • FIG. 10 is a partial enlarged view of the reverse circulation drilling equipment of the present invention in the drilling state.
  • FIG. 11 is a schematic structural diagram of the fluid injection and discharge mechanism and the discharge assisting structure of the present invention.
  • FIG. 12 is a schematic diagram of the structure of the double-tube drilling tool of the present invention for reverse circulation drilling.
  • FIG. 13 is a schematic structural diagram of the double-tube drilling tool of the present invention for positive circulation drilling.
  • Packing device while drilling 1. Rubber cartridge packer; 11. Rubber cartridge seat; 11', rubber cartridge seat; 111, mounting ring; 112, limit sleeve; 113, retaining ring; 114, slot; 115, mounting hole; 116, mounting surface; 12.
  • Rubber cartridge 121, hollow cavity; 122, outer wall surface; 123, inner wall surface; 13, frame; 131, two connecting rods; 1311, connecting rod; 1312, pin shaft; 1313, convex curved surface; 132, support sheet; 1321, convex curved surface; 133, support wire; 1331, convex curved surface; 14, compressible stroke; 15, positioning pin of rubber cartridge seat; 15 ’, positioning pin of rubber cylinder seat; 16, connecting sleeve; 2, upper transmission structure; 21, spline sleeve; 22, upper limit step surface; 23, double female joint; 24, upper joint; 3, lower transmission structure; 31, spline shaft; 32, lower limit step surface; 33, adjustment pad; 34, snap ring; 34’, snap ring; 4, upper rotating structure; 41, upper bearing sleeve; 42, upper bearing sleeve locking ring; 43, upper bearing; 44, upper limit ring; 5, lower rotating structure; 51, lower bearing sleeve; 52, lower bearing sleeve snap
  • 200 double-tube drilling tool; 201, upper drilling tool; 202, lower drilling tool; 203, fluid injection channel; 204, fluid return channel; 205, rock breaking tool; 206, anti-stuck drill bit; 207, reverse circulation air hammer; 208, centralizer; 209, anti-stuck impactor; 210, floating impact drill bit; 211, fluid injection and discharge mechanism; 212, injection structure; 213, rotary injection and discharge adapter; 214, discharge pipeline; 215, reverse circulation shock absorber; 216, drainage aid structure ; 217, drainage-aiding jet hole; 218, gooseneck tube; 219, drainage-aiding pipeline; 220, distribution channel; 221, reflux channel; 222, inner tube joint; 223, conductive layer; 224, inner tube female joint; 225, inner tube male joint; 226, conductive contact structure; 226', conductive contact structure; 227, wire; 227', wire; 228, sealing ring; 229, outer tube joint; 230, outer tube female joint; 231, outer tube male joint
  • the present invention also provides a drilling isolation device 100, including at least one rubber cartridge packer 1, and the drilling isolation device 100 also includes: an upper transmission structure 2, connecting the upper drilling tool and the uppermost rubber cartridge seat 11; a lower transmission structure 3, connecting the lower drilling tool and the lowermost rubber cartridge seat 11', the lower transmission structure 3 is connected to the upper transmission structure 2 and can move relative to each other along the axial direction of the wellbore 300; wherein, in the drilling state, the upper transmission structure 2 moves downward along the axial direction of the wellbore 300 relative to the lower transmission structure 3, and drives the upper rubber cartridge seat 11 to approach the lower rubber cartridge seat 11'; in the drilling state, the upper transmission structure 2 moves upward along the axial direction of the wellbore 300 relative to the lower transmission structure 3, and the upper rubber cartridge seat 11 moves away from the lower rubber cartridge seat 11'.
  • the present invention describes the structure with reference to the use state of the drilling isolation device 100 in a vertical well, and does not serve as a specific limitation.
  • the above refers to the direction close to the wellhead 302, and the below refers to the direction close to the well bottom 303.
  • the drilling isolation device 100 of the present invention is also applicable to horizontal wells or other wells.
  • the drilling isolation device 100 of the present invention transmits the torque and drilling pressure provided by the upper drill bit 201 to the lower drill bit 202 through the upper transmission structure 2 cooperating with the lower transmission structure 3, so that in the drilling state, the rubber cartridge packer 1 can expand outwards under the squeeze between the upper transmission structure 2 and the lower transmission structure 3 to isolate the wellbore annulus 301, and in the drilling state, the upper drill bit 201 drives the upper transmission structure 2 away from the lower transmission structure 3, so that the squeeze on the rubber cartridge packer 1 is gradually reduced and retracts inwards, thereby separating from the wellbore 300.
  • the upper transmission structure 2 and the lower transmission structure 3 are matched to form a structure similar to a telescopic transmission shaft, which can be telescopic along its axial direction and transmit torque.
  • the upper transmission structure 2 and the lower transmission structure 3 achieve axial telescopic and torque transmission through a spline connection.
  • the lower transmission structure 3 includes a spline shaft 31, and the upper transmission structure 2 includes a spline sleeve 21.
  • the lower end of the spline shaft 31 is connected to the lower drilling tool 202, and the upper end of the spline shaft 31 passes through at least one rubber cylinder packer 1 and is inserted into the spline sleeve 21, and is spline-connected to the spline sleeve 21 along the axial direction of the wellbore 300.
  • Other suitable telescopic transmission shaft structures in the prior art can also be selected according to the requirements of torque transmission.
  • the lower drilling tool 202 in this embodiment includes a reverse circulation air hammer 207 and an anti-stuck drill bit 206 connected in sequence from top to bottom.
  • the present invention is particularly suitable for reverse circulation drilling, especially when there are leakage formations such as fractured formations 305 and/or easily eroded formations 306 around the wellbore 300, the wellbore annulus 301 is isolated by the isolation device 100 being attached to the stable formation 304 below the fractured formation 305 and/or easily eroded formation 306, so that the circulation flow field will not be affected by the fractured formation 305 and/or easily eroded formation 306.
  • the rubber packer 1 can isolate the wellbore annulus 301 between the wellbore 300 and the double-tube drilling tool 200 near the rock breaking tool 205, realize forced circulation, and make the drill cuttings generated by the drilling of the lower drilling tool 202 return to the surface from the fluid return channel 204 of the double-tube drilling tool 200 along with the circulating fluid. It should be understood that the isolation while drilling device 100 of the present invention is also suitable for It is used for other forms of drilling or exploration in the prior art to prevent high-pressure overflow or other purposes.
  • the rubber cartridge sealer 1 includes: two rubber cartridge seats 11, which are arranged opposite to each other and at intervals; a rubber cartridge 12, whose two ends are connected to the two rubber cartridge seats 11, and the rubber cartridge 12 can be deformed when squeezed; a skeleton 13, whose two ends are connected to the two rubber cartridge seats 11 and are located inside the rubber cartridge 12, and the radial dimensions of the two ends of the skeleton 13 are smaller than the radial dimensions of the middle thereof to form a first expansion form; wherein, when the two rubber cartridge seats 11 are relatively close to each other, the skeleton 13 can expand from the first expansion form to the second expansion form, and support the rubber cartridge 12 to guide the rubber cartridge 12 to expand and deform outward, and when the two rubber cartridge seats 11 are relatively far away from each other, the skeleton 13 can retract from the second expansion form to the first expansion form.
  • the rubber cartridge sealer 1 of the present invention adds a skeleton 13 in the rubber cartridge 12, and the two ends of the skeleton 13 are connected to the two rubber cartridge seats 11, and when the distance between the two rubber cartridge seats 11 remains unchanged, that is, when the rubber cartridge sealer 1 is in a free state, the skeleton 13 maintains a first expansion state with small ends and a large middle portion, so that when the two rubber cartridge seats 11 are relatively close to each other, that is, when the rubber cartridge sealer 1 is axially squeezed, the skeleton 13 can guide the rubber cartridge 12 to expand outward during the process of expanding outward from the first expansion state to form the second expansion state, thereby avoiding the problem that the rubber cartridge 12 shrinks inward or undergoes other uncontrollable deformations and fails to achieve sealing when the rubber cartridge sealer 1 is axially squeezed, and when the two rubber cartridge seats 11 are relatively close to each other, that is, when the axial squeezing of the rubber cartridge sealer 1 is reduced, the skeleton 13 shrinks inward
  • the two rubber cylinder seats 11 are rigid structures, and the distance between the two rubber cylinder seats 11 constitutes the compressible stroke 14 of the rubber cylinder packer 1. Therefore, the compressible stroke 14 of the rubber cylinder packer 1 can be adjusted by designing the distance between the two rubber cylinder seats 11 when the rubber cylinder packer 1 is in a free state, thereby controlling the outward expansion range of the rubber cylinder 12.
  • the rubber cylinder packer 1 is in a free state, the rubber cylinder 12 is generally cylindrical.
  • the radial dimension of the skeleton 13 in the first expansion form (that is, the radial dimension at the maximum position of the middle radial dimension) is smaller than the radial dimension of the rubber cylinder 12 in the free state.
  • the skeleton 13 can support the rubber cylinder 12 from the first expansion form, and can also support the rubber cylinder 12 after expanding outward to a certain extent.
  • the maximum radial dimension position of the skeleton 13 in the first expansion form is located in the middle position of the skeleton 13 in the axial direction.
  • the skeleton 13 is expanded and retracted by the rotation transformation of the connecting rod structure; or as shown in FIG2 and FIG3 , the skeleton 13 is expanded and retracted by elastic deformation.
  • the skeleton 13 can be installed in the hollow cavity 121 of the rubber cylinder 12, which is easy to install; as shown in FIG3 , the skeleton 13 can also be embedded in the wall of the rubber cylinder 12, which can support the rubber cylinder 12 more evenly.
  • the skeleton 13 is generally a cage-shaped structure.
  • the skeleton 13 is installed in the hollow cavity 121 of the rubber cylinder 12.
  • the skeleton 13 includes a plurality of two connecting rods 131, which are evenly spaced and arranged along the circumference of the rubber cylinder 12, and the two connecting rods 131 include two connecting rods 1311, the connecting rods 1311 have opposite first and second ends, the first ends of the two connecting rods 1311 are hinged by a pin 1312, and the second ends of the two connecting rods 1311 are connected to the two rubber cylinder seats 11; wherein, the connecting rods 1311 of the plurality of two connecting rods 131 can rotate around the pin 1312 to enable the skeleton 13 to expand and retract.
  • the two connecting rods 1311 rotate around the pin shaft 1312 toward the inner side of the rubber cylinder 12, and the pin shaft 1312 moves radially outwardly along the rubber cylinder 12, thereby realizing the expansion of the skeleton 13; the two connecting rods 1311 rotate around the pin shaft 1312 toward the outer side of the rubber cylinder 12, and the pin shaft 1312 moves radially inwardly along the rubber cylinder 12, thereby realizing the retraction of the skeleton 13.
  • the two connecting rods 1311 have the same length.
  • the second ends of the two connecting rods 1311 can be hinged to the two rubber cylinder seats 11, or can be abutted against the two rubber cylinder seats 11.
  • the rubber cylinder seat 11 is provided with a mounting surface 116 connected to the second end of the connecting rod 1311.
  • the multiple two connecting rods 131 are limited by the distance between the mounting surfaces 116 of the two rubber cylinder seats 11 in the free state and cannot rotate, so that the skeleton 13 maintains the first expansion state.
  • the first end of the connecting rod 1311 is bent toward the inside of the rubber tube 12, and the convex surface 1313 formed by the bending is arranged toward the inner wall surface 123 of the rubber tube 12.
  • the first end where the two connecting rods 1311 are hinged is the position where the radial dimension of the skeleton 13 is the largest, that is, the position where the rubber tube 12 is supported.
  • the convex surface 1313 formed by the bending is used to support the rubber tube 12. In the process of guiding the rubber tube 12 to expand outward, the supporting force provided by the skeleton 13 is prevented from being concentrated locally on the rubber tube 12 and causing damage to the rubber tube 12.
  • the rubber tube 12 can be subjected to a more uniform force and fit more closely with the wellbore 300.
  • the shape of the bending of the connecting rod 1311 is not specifically limited, and can be designed according to the shape of the rubber tube 12 after expansion, so that the expansion shape of the skeleton 13 is as close as possible to the expansion shape of the rubber tube 12.
  • the skeleton 13 is installed in the hollow cavity 121 of the rubber cylinder 12.
  • the skeleton 13 includes a plurality of support sheets 132, the support sheets 132 are bent as a whole, and the convex surface 1321 formed by the bending fits with the inner wall surface 123 of the rubber cylinder 12, and the plurality of support sheets 132 are evenly spaced and arranged along the circumference of the rubber cylinder 12, and the two ends of the support sheets 132 are connected to the two rubber cylinder seats 11; wherein, the plurality of support sheets 132 can produce elastic deformation to enable the skeleton 13 to expand and retract.
  • the support sheets 132 are pre-bent by steel sheets, and are generally in the shape of "(", so that the support sheets 132 have both a certain supporting force and a certain elastic deformation ability, and can enable the skeleton 13 to maintain the first expansion shape in a free state.
  • the inner wall surface 123 of the rubber cylinder 12 is generally a concave surface that fits with the support sheets 132.
  • the skeleton 13 is embedded in the wall of the rubber cylinder 12.
  • the skeleton 13 includes a plurality of support wires 133, the support wires 133 are bent as a whole, and the convex surface 1331 formed by the bending is arranged toward the outer wall surface 122 of the rubber cylinder 12.
  • the plurality of support wires 133 are evenly spaced and arranged along the circumference of the rubber cylinder 12, and the two ends of the support wires 133 pass through the two ends of the rubber cylinder 12 and are connected to the two rubber cylinder seats 11; wherein the plurality of support wires 133 can generate elastic deformation.
  • the support wires 133 are pre-bent steel wires, generally in a "(" shape, so that the skeleton 13 maintains the first expansion shape in a free state.
  • the support wires 133 are positioned and arranged in the molding die of the rubber sleeve 12 to be integrally formed with the rubber sleeve 12.
  • the skeleton 13 of the first embodiment is the easiest to install and provides the greatest support force.
  • the skeleton 13 of the second embodiment can better fit the inner wall surface 123 of the rubber tube 12 and provide a more uniform support force.
  • the skeleton 13 formed by the support wire 133 will not cause damage to the rubber tube 12 during the process of expanding from the first expansion form to the second expansion form, so it can be directly embedded in the wall of the rubber tube 12.
  • the rubber cartridge seat 11 can be an integrally formed structure. As shown in FIG. 2 and FIG. 3 , the rubber cartridge seat 11 can also be assembled from a split structure. Specifically, the rubber cartridge seat 11 includes a mounting ring 111, a retaining ring 113, and a limiting sleeve 112. The two ends of the rubber cartridge 12 are connected to the mounting rings 111 of the two rubber cartridge seats 11. The limiting sleeve 112 is installed in the mounting ring 111 through the retaining ring 113 and is located on the inner side of the skeleton 13. The spacing between the limiting sleeves 112 of the two rubber cartridge seats 11 constitutes the compressible stroke 14 of the rubber cartridge packer 1.
  • the two ends of the skeleton 13 can be connected to the outer wall surfaces of the two limiting sleeves 112, or to the mounting ring 111, or to other parts of the rubber cartridge seat 11.
  • the rubber cartridge seat 11 is provided with a mounting hole 115 and a slot 114, the slot 114 is used to insert other structures, and the mounting hole 115 is used to penetrate the rubber cartridge seat locating pin, and the rubber cartridge seat 11 is connected to other structures through the rubber cartridge seat locating pin.
  • the uppermost rubber cartridge seat 11 is rotationally connected to the upper transmission structure 2 via the upper rotation structure 4, and the lowermost rubber cartridge seat 11′ is rotationally connected to the lower transmission structure 3 via the lower rotation structure 5.
  • the rubber cartridge packer 1 will not rotate with the rotation of the lower transmission structure 3 and the upper transmission structure 2 when the upper drilling tool 201 and the lower drilling tool 202 are drilling, so that the rubber cartridge 12 can fit with the wellbore 300 in a relatively static state, avoiding the rubber cartridge 12 and the wellbore 300 from rotating relative to each other in their circumferential direction and causing the rubber cartridge 12 to wear.
  • a suitable upper rotation structure 4 is selected according to the installation space between the upper transmission structure 2 and the uppermost rubber cartridge seat 11, and a suitable lower rotation structure 5 is selected according to the installation space between the lower transmission structure 3 and the lowermost rubber cartridge seat 11′.
  • the upper rotating structure 4 includes an upper bearing sleeve 41, an upper bearing sleeve locking ring 42 and at least one upper bearing 43.
  • the upper bearing sleeve 41 is connected to the uppermost rubber cartridge seat 11, and is rotationally connected to the upper transmission structure 2 through the upper bearing sleeve locking ring 42 and the upper bearing 43.
  • the lower end of the upper bearing sleeve 41 is inserted into the upper end of the uppermost rubber cartridge seat 11, and is connected through the rubber cartridge seat locating pin 15 arranged along the radial direction of the wellbore 300.
  • the upper end of the upper bearing sleeve 41 is sleeved on the spline sleeve 21 and sealed by a sealing ring.
  • the upper bearing sleeve locking ring 42 is threadedly connected to the lower end of the spline sleeve 21, and the upper bearing sleeve 41 is rotationally matched with the upper bearing sleeve locking ring 42.
  • the inner wall surface of the upper bearing sleeve 41 is provided with an upper limit ring 44,
  • the upper limit ring 44 cooperates with the spline sleeve 21 to form an upper bearing groove, and the upper bearing 43 is installed in the upper bearing groove to reduce the sliding friction between the upper bearing sleeve 41 and the upper bearing sleeve locking ring 42.
  • the number of the upper bearing 43 is one.
  • the lower rotating structure 5 includes a lower bearing sleeve 51, a lower bearing sleeve snap ring 52 and at least one lower bearing 53.
  • the lower bearing sleeve 51 is connected to the bottommost rubber cartridge seat 11 ', and is rotatably connected to the lower transmission structure 3 through the lower bearing 53.
  • the lower bearing sleeve snap ring 52 is installed on the lower transmission structure 3.
  • the lower bearing sleeve snap ring 52 is used to axially limit the lower bearing sleeve 51 and the lower bearing 53.
  • the upper end of the lower bearing sleeve 51 is plugged into the lower end of the bottommost rubber cartridge seat 11 ', and is connected through the rubber cartridge seat positioning pin 15 arranged along the radial direction of the wellbore 300.
  • the lower end of the lower bearing sleeve 51 is sleeved on the spline shaft 31 and sealed by a sealing ring.
  • the inner wall surface of the lower bearing sleeve 51 is provided with a lower limiting ring 54, and the spline sleeve 21 is provided with a supporting step surface for supporting the lower bearing 53.
  • the supporting step surface cooperates with the lower limiting ring 54 to form a lower bearing groove, and the lower bearing 53 is installed in the lower bearing groove.
  • the lower bearing sleeve snap ring 52 is snapped with the spline sleeve 21, and the lower bearing sleeve snap ring 52 cooperates with the lower limiting ring 54 to form another lower bearing groove, in which the lower bearing 53' is installed to reduce the sliding friction between the lower bearing sleeve 51 and the lower bearing 53.
  • the lower bearing sleeve snap ring 52 is used for limiting, so as to prevent the lower bearing sleeve 51, the lower bearing 53 and the lower bearing 53' from moving in the axial direction. There is a gap between the lower bearing sleeve snap ring 52 and the bottom rubber cartridge seat 11', so as to prevent the lower bearing sleeve snap ring 52 from friction when rotating relative to the bottom rubber cartridge seat 11'.
  • the outer wall surface of the spline shaft 31 is provided with a lower limit step surface 32
  • the inner wall surface of the spline sleeve 21 is provided with an upper limit step surface 22
  • an adjustment pad 33 is installed on the lower limit step surface 32
  • the spacing between the upper limit step surface 22 and the adjustment pad 33 in the axial direction of the wellbore 300 constitutes the stroke that the spline shaft 31 and the spline sleeve 21 can move relative to each other in the axial direction of the wellbore 300.
  • the stroke that the spline shaft 31 and the spline sleeve 21 can move relative to each other in the axial direction of the wellbore 300 can be changed, thereby also adjusting the expansion range of the rubber cartridge packer 1.
  • At least one retaining ring 34 is provided at the upper end of the spline shaft 31, and at least one supporting surface is provided on the inner wall surface of the upper transmission structure 2.
  • the spline shaft 31 is suspended and supported on at least one supporting surface through at least one retaining ring 34.
  • the supporting surface is used to bear the weight of the spline shaft 31 and the lower drilling tool 202 connected thereto.
  • at least one limiting surface is also provided on the inner wall surface of the upper transmission structure 2, and the limiting surface is located above the supporting surface.
  • the range of axial movement of the upper transmission structure 2 relative to the lower transmission structure 3 in the wellbore 300 can be limited by the matching of the limiting surface and the supporting surface.
  • a retaining ring 34 and a retaining ring 34' are provided at the upper end of the spline shaft 31, and the number of supporting surfaces is one.
  • the retaining ring 34 and the retaining ring 34' are arranged at intervals along the axial direction of the spline shaft 31.
  • the spline shaft 31 is first suspended and supported on the support surface by the clamp ring 34 located below.
  • the upper transmission structure 2 further includes a double female joint 23 and an upper joint 24.
  • the upper end of the upper joint 24 is connected to the upper drilling tool 201.
  • the lower end of the upper joint 24 is connected to the upper end of the spline sleeve 21 through the double female joint 23.
  • the end surface of the upper end of the spline sleeve 21 constitutes a support surface.
  • the end surface of the lower end of the upper joint 24 constitutes a limit surface.
  • the spline sleeve, the double female joint and the upper joint can also be an integrally formed structure.
  • the number of rubber cartridge packers 1 may be one, or two, three or more.
  • a plurality of rubber cartridge packers 1 are arranged along the axial direction of the wellbore 300 and are connected by a connecting sleeve 16. Therefore, the uppermost rubber cartridge seat 11 connected to the upper transmission structure 2 and the lowermost rubber cartridge seat 11' connected to the lower transmission structure 3 may be two rubber cartridge seats of the same rubber cartridge packer 1, or two rubber cartridge seats of different rubber cartridge packers 1.
  • the two rubber cartridge seats of all rubber cartridge packers 1 are relatively close; in the drilling state, the two rubber cartridge seats of all rubber cartridge packers 1 are relatively far away.
  • the two ends of the connecting sleeve 16 are inserted into the rubber cartridge seats of two adjacent rubber cartridge packers 1, and are connected by the rubber cartridge seat locating pins 15'.
  • the present invention also provides a reverse circulation drilling equipment, including a packing-while-drilling device 100
  • the reverse circulation drilling equipment also includes: a double-tube drilling tool 200, including an upper drilling tool 201 and a lower drilling tool 202, the upper drilling tool 201 and the lower drilling tool 202 both having an inner tube and an outer tube, the outer tube of the upper drilling tool 201 being connected to the upper transmission structure 2, and the outer tube of the lower drilling tool 202 being connected to the lower transmission structure 3; an upper core tube 6, the upper end of which is inserted into the upper transmission structure 2 and connected to the inner tube of the upper drilling tool 201; a lower core tube 7, the lower end of which is inserted into the lower transmission structure 3 and connected to the inner tube of the lower drilling tool 202, the lower end of the upper core tube 6 and the upper end of the lower core tube 7 being in sealing and sliding cooperation along the axial direction of the wellbore 300.
  • the reverse circulation drilling equipment of the present invention when the double-tube drilling tool 200 is drilling, the wellbore annulus 301 is isolated by the isolation-while-drilling device 100 to achieve forced circulation, ensuring that the circulating fluid can smoothly carry out the cuttings, which is conducive to continuous drilling.
  • the inner tube of the upper drilling tool 201 and the inner tube of the lower drilling tool 202 are connected through the upper core tube 6 and the lower core tube 7, thereby forming a fluid return channel 204.
  • the outer tube of the upper drilling tool 201 and the outer tube of the lower drilling tool 202 are connected through the upper transmission structure 2 and the lower transmission structure 3, so that the annulus between the outer tube and the inner tube of the upper drilling tool 201 and the annulus between the outer tube and the inner tube of the lower drilling tool 202 are connected to form a fluid injection channel 203.
  • a rock breaking tool 205 is installed at one end of the lower drilling tool 202 close to the bottom of the well 303.
  • the rock breaking tool 205 has an injection channel and a suction channel. The injection channel is connected to the fluid injection channel.
  • the injection channel 203 is connected, and the suction channel is connected to the fluid return channel 204; the fluid in the fluid injection channel 203 flows from the injection channel into the bottom hole 303 to form rock breaking fluid, and the rock breaking fluid carries rock cuttings into the fluid return channel 204 under the suction action of the suction channel.
  • a platform 307 is set up above the wellhead 302, and the double-tube drilling tool 200 passes through the platform 307 for drilling.
  • the fluid injection device injects pressurized fluid into the fluid injection channel 203, so that the fluid in the fluid injection channel 203 is ejected from the injection channel of the rock breaking tool 205 to the bottom of the well 303 to form rock breaking fluid;
  • the rock breaking tool 205 includes but is not limited to a reverse circulation drill bit, a reverse circulation roller drill bit, and a reverse circulation PDC drill bit, which has a negative pressure suction capability, so that the rock breaking fluid at the bottom of the well 303 can be sucked from the suction channel to the fluid return channel 204;
  • the reverse circulation drilling equipment of the present invention can avoid the accumulation of rock breaking fluid in the wellbore annulus 301, and return from the fluid return channel 204, thereby ensuring the stable operation of the circulation flow field.
  • At least one centralizer 208 is installed on the double-tube drill 200.
  • the centralizer 208 is arranged near the wellhead 302 relative to the isolation device 100 while drilling.
  • the centralizer 208 can expand outward to centralize the double-tube drill 200; in the state of lifting the drill, the centralizer 208 can also retract inward to a radial size smaller than the wellbore 300.
  • the rock breaking tool 205 includes an anti-stuck drill bit 206.
  • the anti-stuck drill bit 206 can expand outward to drill; in the state of lifting the drill, the anti-stuck drill bit 206 can also retract inward to a radial size smaller than the wellbore 300.
  • the risk of drill sticking is further reduced by the cooperation of the isolation device 100 while drilling, the centralizer 208, and the anti-stuck drill bit 206.
  • the double-tube drilling tool 200 is equipped with an anti-stuck impactor 209 and a floating impact drill bit 210, and the anti-stuck impactor 209 and the floating impact drill bit 210 are sequentially installed from bottom to top on the top of the packing while drilling device 100; when the double-tube drilling tool 200 encounters resistance when lifting the drill, the impact piston in the anti-stuck impactor 209 can hit the floating impact drill bit 210 upward to make the floating impact drill bit 210 impact upward to drill.
  • the connection between the packing while drilling device 100 and the upper drilling tool 201 is most likely to cause drill jamming.
  • the anti-stuck impactor 209 and the floating impact drill bit 210 By installing the anti-stuck impactor 209 and the floating impact drill bit 210 on the top of the packing while drilling device 100, even if drill jamming occurs, the upper obstacles can be drilled out by reverse drilling of the floating impact drill bit 210 to contact the drill jam.
  • a fluid injection and discharge mechanism 211 is installed at one end of the double-tube drilling tool 200 located above the ground, and the fluid injection and discharge mechanism 211 includes an injection structure 212, a rotary injection and discharge adapter 213 and a discharge pipe 214.
  • the injection structure 212 is connected to the outer pipe of the upper drilling tool 201 through the flow distribution channel 220 of the rotary injection and discharge adapter 213, and the discharge pipe 214 is connected to the inner pipe of the upper drilling tool 201 through the return flow channel 221 of the rotary injection and discharge adapter 213.
  • the injection structure 212 includes a top drive device or a faucet, and the gooseneck 218 of the top drive device or the faucet is connected to the fluid injection device through the injection pipe.
  • a plurality of drainage-assisting structures 216 are installed on the drainage pipe 214 to assist
  • the drainage structure 216 can inject the drainage-aiding fluid into the discharge pipe 214 and form a drainage-aiding jet, which can push the fluid in the discharge pipe 214 to be discharged.
  • the drainage-aiding structure 216 includes a drainage-aiding pipe 219 and a plurality of drainage-aiding jet holes 217.
  • the drainage-aiding pipe 219 is installed on the discharge pipe 214.
  • the plurality of drainage-aiding jet holes 217 are evenly arranged along the circumference of the discharge pipe 214, and the flow direction of the fluid in the drainage-aiding jet holes 217 is inclined toward the flow direction of the fluid in the discharge pipe 214.
  • the drainage-aiding pipe 219 is connected to the discharge pipe 214 through the plurality of drainage-aiding jet holes 217.
  • the plurality of drainage-aiding structures 216 are arranged at different positions according to the conveying distance of the discharge pipe 214.
  • the rotary injection-discharge adapter 213 is installed at one end of the upper drilling tool 201 located above the ground through a reverse circulation damper 215 .
  • the inner tube of the upper drilling tool 201 and the inner tube of the lower drilling tool 202 are both provided with a conductive structure 232, and the double-tube drilling tool 200 transmits power and signals through the conductive structure 232.
  • the double-tube drilling tool 200 can not only transmit signals but also transmit electrical energy. Therefore, the present invention can be applied not only to vertical well construction but also to horizontal well construction.
  • the present invention can effectively remove the cuttings bed and can accurately control the pressure loss of the circulating flow field, which is beneficial to further extend the length of the horizontal section when drilling unconventional oil and gas resources, and is also beneficial to safe and efficient drilling in a narrow density window.
  • the present invention can be used not only for reverse circulation drilling but also for positive circulation drilling, that is, fluid is injected from the fluid return channel 204 and the fluid injection channel 203 is closed.
  • the inner tube of the upper drilling tool 201 and the inner tube of the lower drilling tool 202 both include a plurality of inner tube sections 222
  • the conductive structure 232 includes a conductive layer 223, the conductive layer 223 is coated on the outer wall surface of the inner tube section 222, two adjacent inner tube sections 222 are plugged together through an inner tube male joint 225 and an inner tube female joint 224, at least one conductive wire 227 is embedded in the inner tube male joint 225, at least one conductive wire 227' is embedded in the inner tube female joint 224, and at least one conductive wire 226 and at least one conductive wire 226' are provided on the contact surfaces of the inner tube male joint 225 and the inner tube female joint 224, and the conductive contact structures 226 and 226' are
  • the outer tube of the upper drilling tool 201 and the outer tube of the lower drilling tool 202 each include a plurality of outer tube sections 229, and two adjacent outer tube sections 229 are plugged together through an outer tube male connector 231 and an outer tube female connector 230.
  • the conductive structure may also include a coil wound around the inner tube of the upper drilling tool and the inner tube of the lower drilling tool.
  • the conductive contact structure 226' and the conductive contact structure 226 can be a plurality of conductive contact points, which are arranged at intervals along the circumference of the inner tube section 222; or they can be conductive contact surfaces, which are generally annular surfaces.
  • Each group of conductive contact structures has a sealing ring 228 at both ends, thereby isolating the conductive contact structures 226' and conductive contact structures 226 from the external fluid, and can also Avoid mutual interference between multiple sets of conductive contact structures.

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  • Life Sciences & Earth Sciences (AREA)
  • Engineering & Computer Science (AREA)
  • Geology (AREA)
  • Mining & Mineral Resources (AREA)
  • Physics & Mathematics (AREA)
  • Environmental & Geological Engineering (AREA)
  • Fluid Mechanics (AREA)
  • General Life Sciences & Earth Sciences (AREA)
  • Geochemistry & Mineralogy (AREA)
  • Earth Drilling (AREA)

Abstract

L'invention concerne un appareil formant garniture d'étanchéité pendant le forage et un dispositif de forage à circulation inverse. L'appareil formant garniture d'étanchéité (100) pendant le forage comprend : au moins une garniture d'étanchéité à cylindre en caoutchouc (1) qui comprend un cylindre en caoutchouc (12), un cadre (13) et deux sièges de cylindre en caoutchouc (11) ; et une structure de transmission supérieure (2) et une structure de transmission inférieure (3) qui peuvent se déplacer l'une par rapport à l'autre le long de la direction axiale d'un arbre (300). Dans un état de forage, la structure de transmission supérieure (2) se déplace vers le bas par rapport à la structure de transmission inférieure (3) le long de la direction axiale de l'arbre (300) et entraîne le siège de cylindre en caoutchouc supérieur (11) pour s'approcher du siège de cylindre tubulaire inférieur (11), et le cadre (13) peut s'étendre d'une première forme d'expansion à une seconde forme d'expansion et supporte le cylindre en caoutchouc (12) pour guider le cylindre en caoutchouc (12) pour se dilater vers l'extérieur et se déformer. Dans un état de déclenchement, la structure de transmission supérieure (2) se déplace vers le haut par rapport à la structure de transmission inférieure (3) le long de la direction axiale de l'arbre (300), le siège de cylindre en caoutchouc supérieur (11) s'éloigne du siège de cylindre en caoutchouc inférieur (11), et le cadre (13) peut se rétracter de la seconde forme d'expansion à la première forme d'expansion. L'appareil peut éviter le problème selon lequel l'étanchéité ne peut pas être obtenue en raison d'une contraction vers l'intérieur ou d'une autre déformation incontrôlable d'un cylindre en caoutchouc, de sorte que le risque de collage de tige de forage n'est pas susceptible de se produire, et la stabilité d'une garniture d'étanchéité à cylindre en caoutchouc est améliorée.
PCT/CN2023/121302 2022-09-30 2023-09-26 Appareil formant garniture d'étanchéité pendant le forage et dispositif de forage à circulation inverse WO2024067533A1 (fr)

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CN202211216475.5 2022-09-30
CN202211216475.5A CN117803348A (zh) 2022-09-30 2022-09-30 随钻封隔装置及反循环钻井设备

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Citations (8)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US4403660A (en) * 1980-08-08 1983-09-13 Mgc Oil Tools, Inc. Well packer and method of use thereof
CN207583344U (zh) * 2017-11-27 2018-07-06 中国石油大学(华东) 一种金属骨架胶筒
CN212317924U (zh) * 2020-05-18 2021-01-08 大庆市龙兴石油机械有限公司 一种内管串工具胀封套管外封隔器
CN212317928U (zh) * 2020-05-18 2021-01-08 大庆市龙兴石油机械有限公司 组合式油层保护封隔器
CN113863879A (zh) * 2020-06-30 2021-12-31 中国石油化工股份有限公司 一种气体反循环钻井用分流装置
CN114482910A (zh) * 2022-04-16 2022-05-13 山东恒驰石油装备有限责任公司 一种封隔器胶筒及封隔器
CN114658386A (zh) * 2022-05-24 2022-06-24 纬达石油装备有限公司 一种扩张式封隔器及其使用方法
CN115434657A (zh) * 2022-09-30 2022-12-06 中国石油天然气集团有限公司 骨架式伸缩密封装置、封隔器及应用

Patent Citations (8)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US4403660A (en) * 1980-08-08 1983-09-13 Mgc Oil Tools, Inc. Well packer and method of use thereof
CN207583344U (zh) * 2017-11-27 2018-07-06 中国石油大学(华东) 一种金属骨架胶筒
CN212317924U (zh) * 2020-05-18 2021-01-08 大庆市龙兴石油机械有限公司 一种内管串工具胀封套管外封隔器
CN212317928U (zh) * 2020-05-18 2021-01-08 大庆市龙兴石油机械有限公司 组合式油层保护封隔器
CN113863879A (zh) * 2020-06-30 2021-12-31 中国石油化工股份有限公司 一种气体反循环钻井用分流装置
CN114482910A (zh) * 2022-04-16 2022-05-13 山东恒驰石油装备有限责任公司 一种封隔器胶筒及封隔器
CN114658386A (zh) * 2022-05-24 2022-06-24 纬达石油装备有限公司 一种扩张式封隔器及其使用方法
CN115434657A (zh) * 2022-09-30 2022-12-06 中国石油天然气集团有限公司 骨架式伸缩密封装置、封隔器及应用

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