WO2024067533A1 - Packer apparatus while drilling and reverse circulation drilling device - Google Patents

Abstract

A packer apparatus while drilling and a reverse circulation drilling device. The packer apparatus (100) while drilling comprises: at least one rubber cylinder packer (1) which comprises a rubber cylinder (12), a framework (13) and two rubber cylinder seats (11); and an upper transmission structure (2) and a lower transmission structure (3) which can move relative to each other along the axial direction of a shaft (300). In a drilling state, the upper transmission structure (2) moves downwards relative to the lower transmission structure (3) along the axial direction of the shaft (300) and drives the upper rubber cylinder seat (11) to approach the lower tubber cylinder seat (11), and the framework (13) can expand from a first expansion form to a second expansion form and supports the rubber cylinder (12) to guide the rubber cylinder (12) to expand outwards and deform. In a trip out state, the upper transmission structure (2) moves upwards relative to the lower transmission structure (3) along the axial direction of the shaft (300), the upper rubber cylinder seat (11) moves away from the lower rubber cylinder seat (11), and the framework (13) can retract from the second expansion form to the first expansion form. The apparatus can avoid the problem that sealing cannot be achieved due to inward contraction or other uncontrollable deformation of a rubber cylinder, so that the risk of drill pipe sticking is not prone to occur, and the stability of a rubber cylinder packer is improved.

Description

Drilling isolation device and reverse circulation drilling equipment

Related Applications

This application claims the priority of the Chinese invention patent with patent application number 202211216475.5, application date September 30, 2022, and invention name “A drilling isolation device and reverse circulation drilling equipment”.

Technical Field

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.

Background technique

This section is intended to provide a background or context to the embodiments of the invention recited in the claims. No description herein is admitted to be prior art by inclusion in this section.

With the further emphasis on energy security, the number of unconventional oil and gas resource exploration and deep and ultra-deep wells is increasing. On the one hand, the surface wellbore size is getting larger and deeper; on the other hand, the loss of formation fluids will cause varying degrees of pollution to the environment, and will also increase the drilling cycle due to other complex problems caused by well leakage. This not only brings higher comprehensive costs to surface drilling, but also brings environmental problems that cannot be ignored in some blocks. Therefore, reverse circulation drilling has always been the focus of the industry's efforts to tackle and promote it. In addition, the exploration and development of unconventional oil and gas continues to increase, and the requirements for efficient development continue to increase. 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. In double-wall reverse circulation drilling, 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. On the one hand, 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.

However, there are technical problems in implementing forced circulation using annular isolation: (1) deformation is uncontrollable; (2) drill jamming accidents are prone to occur; (3) the isolation rubber tube structure is not strong enough; (4) it cannot expand and contract as needed; and (5) it is impossible to achieve isolation while drilling during drilling.

Summary of the invention

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 above-mentioned purpose of the present invention can be achieved by adopting the following technical solutions:

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, and drives the upper rubber cylinder seat close to the lower rubber cylinder seat, and the skeleton can expand from the first expansion state to the second expansion state, and support the rubber cylinder to guide the rubber cylinder to expand and deform outward; in the drilling state, the upper transmission structure moves upward along the axial direction of the wellbore relative to the lower transmission structure, the upper rubber cylinder seat moves away from the lower rubber cylinder seat, and the skeleton can retract from the second expansion state to the first expansion state.

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.

The characteristics and advantages of the present invention are:

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. When the distance between the two rubber tube seats remains unchanged, that is, the rubber tube packer is in a free state, 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. In addition, when the two rubber tube seats are close to each other, that is, When the axial extrusion on the rubber cartridge packer is reduced, the skeleton retracts inward from the second expansion state to form the first expansion state, so the risk of drill sticking is not likely to occur. In addition, 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.

BRIEF DESCRIPTION OF THE DRAWINGS

In order to more clearly illustrate the technical solutions in the embodiments of the present invention, the drawings required for use in the description of the embodiments will be briefly introduced below. Obviously, the drawings described below are only some embodiments of the present invention. For ordinary technicians in this field, other drawings can be obtained based on these drawings without creative work.

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.

In the figure:

100. 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 ring; 53, lower bearing; 53’, lower bearing; 54, lower limit ring; 6, upper core tube; 7, lower core tube;

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; 232, conductive structure;

300, wellbore; 301, wellbore annulus; 302, wellhead; 303, well bottom; 304, stable formation; 305, fractured formation; 306, easily eroded formation; 307, platform.

Detailed ways

The following will be combined with the drawings in the embodiments of the present invention to clearly and completely describe the technical solutions in the embodiments of the present invention. Obviously, the described embodiments are only part of the embodiments of the present invention, not all of the embodiments. Based on the embodiments of the present invention, all other embodiments obtained by ordinary technicians in this field without creative work are within the scope of protection of the present invention.

Implementation Method 1

As shown in Figures 5, 6 and 7, 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'.

As shown in Figures 8 and 9, for the convenience of description, 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.

As shown in Figures 5, 8 and 9, 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.

Specifically, 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. In this embodiment, 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.

As shown in Fig. 8, Fig. 9 and Fig. 10, 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. Specifically, when the upper drilling tool 201 drives the lower drilling tool 202 to drill through the upper transmission structure 2 and the lower transmission structure 3, 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.

In an embodiment of the present invention, as shown in Figures 1, 2 and 3, 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 from the second expansion state to form the first expansion state, so that the risk of drill jamming is not easy to occur. In addition, the support of the skeleton 13 can improve the strength of the rubber cartridge 12 during sealing, thereby improving the stability of the rubber cartridge sealer 1.

Specifically, 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. When 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. Preferably, 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.

In the embodiment of the present invention, as shown in FIG1 , 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. As shown in FIG1 and FIG2 , 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. Specifically, the skeleton 13 is generally a cage-shaped structure.

As shown in FIG1 , in the first embodiment, 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. Specifically, 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. Specifically, 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.

As shown in FIG1 , 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. By bending this position toward the inside of the rubber tube 12, 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. At the same time, 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.

As shown in FIG. 2 , in the second embodiment, 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. Specifically, 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.

As shown in FIG. 3 and FIG. 4 , in the third embodiment, 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. Specifically, 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.

As shown in Fig. 1, Fig. 2 and Fig. 3, compared with the second embodiment and the third embodiment, the skeleton 13 of the first embodiment is the easiest to install and provides the greatest support force. Compared with the first embodiment and the third embodiment, 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. Compared with the first embodiment and the second embodiment, in the third embodiment, 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.

As shown in FIG. 1 , 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.

As shown in FIG5 , in the embodiment of the present invention, 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. By providing the upper rotation structure 4 and 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′.

As shown in Figure 6, 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. Specifically, 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. In this embodiment, the number of the upper bearing 43 is one.

As shown in FIG7 , 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. Specifically, 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'.

As shown in FIG6 , in the embodiment of the present invention, 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, and 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. By replacing the adjustment pads 33 of different thicknesses or changing the number of the adjustment pads 33, 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.

As shown in FIG6 , in an embodiment of the present invention, 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. In the state of lifting the drill, 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. Specifically, 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. In this embodiment, 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. When the clamp ring 34 fails, the spline shaft 31 moves downward and is then suspended and supported on the support surface by the clamp ring 34' above, thereby preventing the spline shaft 31 and the lower drilling tool connected thereto from falling to the ground. In the wellbore 300.

As shown in FIG6 , 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. By providing the double female joint 23 and the upper joint 24, there is no need to process the support surface and the limit surface separately, and the processing is simple. Optionally, 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. In the present embodiment, 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. In the drilling state, 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. Specifically, 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'.

Implementation Method 2

As shown in Fig. 5, Fig. 8, Fig. 9 and Fig. 10, 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 packing-while-drilling device 100 in this embodiment has the same specific structure, working principle and benefit effect as the packing-while-drilling device 100 in the second embodiment, which will not be described in detail here.

In 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.

Specifically, 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.

As shown in Figures 8 and 9, 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.

As shown in FIG8 and FIG9, in the embodiment of the present invention, 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. In the drilling state, 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. In the drilling state, 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.

As shown in FIG8 and FIG9, in the embodiment of the present invention, 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. 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.

As shown in Fig. 8, Fig. 9 and Fig. 11, in the embodiment of the present invention, 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. Specifically, 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.

As shown in FIG. 11 , in the embodiment of the present invention, 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. Specifically, 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.

As shown in FIG. 8 and FIG. 9 , in the embodiment of the present invention, 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 .

As shown in FIG. 12 and FIG. 13, in an embodiment of the present invention, 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. By providing the conductive structure 232 on the inner tube of the upper drilling tool 201 and the inner tube of the lower drilling tool 202, 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. When used in horizontal wells, 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.

As shown in FIG. 12 and FIG. 13 , 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. In an embodiment of the present invention, 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 conductively connected to the corresponding conductive layer 223 through the conductive wires 227 and 227'. 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. Optionally, 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.

Specifically, 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. There are multiple conductive contact structures 226' and conductive contact structures 226, and multiple sealing rings 228 are provided on the contact surfaces of the inner tube male connector 225 and the inner tube female connector 224. 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.

The above are only several embodiments of the present invention. Those skilled in the art may make various changes or modifications to the embodiments of the present invention based on the contents disclosed in the application documents without departing from the spirit and scope of the present invention.

Claims (25)

1. A packing-while-drilling device, comprising:

   At least one rubber cartridge packer, comprising a rubber cartridge, a frame and two rubber cartridge seats, the two rubber cartridge seats being arranged opposite to each other and spaced apart; the two ends of the rubber cartridge are connected to the two rubber cartridge seats, and the rubber cartridge can be deformed under compression; the two ends of the frame are connected to the two rubber cartridge seats and are located inside the rubber cartridge, 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 state;

   An upper transmission structure, connecting the upper drilling tool and the uppermost rubber cylinder seat;

   A lower transmission structure, connecting the lower drilling tool and the rubber cylinder seat at the bottom, the lower transmission structure is connected to the upper transmission structure and can move relative to each other along the axial direction of the wellbore;

   Among them, in the drilling state, the upper transmission structure moves downward along the axial direction of the wellbore relative to the lower transmission structure, and drives the upper rubber cylinder seat to approach the lower rubber cylinder seat, and the skeleton can expand from the first expansion form to the second expansion form, and support the rubber cylinder to guide the rubber cylinder to expand and deform outward; in the drilling state, the upper transmission structure moves upward along the axial direction of the wellbore relative to the lower transmission structure, and the upper rubber cylinder seat moves away from the lower rubber cylinder seat, and the skeleton can retract from the second expansion form to the first expansion form.
2. The isolation while drilling device according to claim 1, wherein:

   The skeleton achieves expansion and retraction through the rotation transformation of the connecting rod structure; or

   The skeleton achieves expansion and contraction through elastic deformation.
3. The isolation while drilling device according to claim 1, wherein:

   The rubber cylinder has a hollow cavity, and the frame is installed in the hollow cavity.
4. The isolation while drilling device according to claim 3, wherein:

   The skeleton includes a plurality of two-link rods, which are evenly spaced and arranged along the circumference of the rubber cylinder. The two-link rods include two links, which have a first end and a second end relative to each other. The first ends of the two links are hinged to each other through a pin, and the second ends of the two links are connected to the two rubber cylinder seats. The links of the plurality of two-link rods can rotate around the pin to enable the skeleton to expand and retract.
5. The isolation while drilling device according to claim 4, wherein:

   The first end of the connecting rod is bent toward the inner side of the rubber cylinder, and the convex surface formed by the bending is arranged toward the inner wall surface of the rubber cylinder.
6. The isolation while drilling device according to claim 3, wherein:

   The skeleton includes a plurality of support sheets, which are bent as a whole, and the convex surface formed by the bending fits with the inner wall surface of the rubber cylinder. The plurality of support sheets are evenly spaced and arranged along the circumference of the rubber cylinder, and the two ends of the support sheets are connected to the two rubber cylinder seats; wherein the plurality of support sheets can produce elastic deformation to enable the skeleton to expand and retract.
7. The isolation while drilling device according to claim 2, wherein:

   The frame is embedded in the wall of the rubber cylinder.
8. The isolation while drilling device according to claim 7, wherein:

   The skeleton includes a plurality of support wires, the support wires are bent as a whole, and the convex surface formed by the bending is arranged toward the outer wall surface of the rubber tube, and the plurality of support wires are evenly spaced and arranged along the circumference of the rubber tube, and the two ends of the support wires pass through the two ends of the rubber tube and are connected to the two rubber tube seats;

   Wherein, the plurality of support wires can produce elastic deformation to enable the skeleton to expand and retract.
9. The isolation while drilling device according to claim 1, wherein:

   The uppermost rubber cylinder seat is rotatably connected to the upper transmission structure via an upper rotating structure, and the lowermost rubber cylinder seat is rotatably connected to the lower transmission structure via a lower rotating structure.
10. The isolation while drilling device according to claim 9, wherein:

    The upper rotating structure includes an upper bearing sleeve, an upper bearing sleeve locking ring and at least one upper bearing. The upper bearing sleeve is connected to the uppermost rubber cylinder seat and is rotationally connected to the upper transmission structure through the upper bearing sleeve locking ring and the upper bearing.
11. The isolation while drilling device according to claim 9, wherein:

    The lower rotating structure includes a lower bearing sleeve, a lower bearing sleeve retaining ring and at least one lower bearing. The lower bearing sleeve is connected to the lowermost rubber cylinder seat and is rotationally connected to the lower transmission structure through the lower bearing. The lower bearing sleeve retaining ring is installed on the lower transmission structure, and the lower bearing sleeve retaining ring is used to axially limit the lower bearing sleeve and the lower bearing.
12. The isolation while drilling device according to claim 1, wherein:

    The lower transmission structure includes a spline shaft, and the upper transmission structure includes a spline sleeve. The lower end of the spline shaft is connected to the lower drilling tool, and the upper end of the spline shaft passes through at least one rubber cartridge packer and is inserted into the spline sleeve, and is spline-connected to the spline sleeve along the axial direction of the wellbore.
13. The isolation while drilling device according to claim 12, wherein:

    The outer wall surface of the spline shaft is provided with a lower limit step surface, the inner wall surface of the spline sleeve is provided with an upper limit step surface, an adjustment pad is installed on the lower limit step surface, and the distance between the upper limit step surface and the adjustment pad in the axial direction of the wellbore constitutes the relative movement between the spline shaft and the spline sleeve in the axial direction of the wellbore. Maximum stroke.
14. The isolation while drilling device according to claim 12, wherein:

    The upper end of the spline shaft is provided with at least one retaining ring, and the inner wall surface of the upper transmission structure is provided with at least one supporting surface. In the drill lifting state, the spline shaft is suspended and supported on at least one supporting surface through at least one retaining ring.
15. The isolation while drilling device according to claim 14, wherein:

    The upper transmission structure also includes a double female joint and an upper joint, the upper end of the upper joint is connected to the upper drilling tool, the lower end of the upper joint is connected to the upper end of the spline sleeve through the double female joint, and the end surface of the upper end of the spline sleeve constitutes a supporting surface.
16. The isolation while drilling device according to claim 1, wherein:

    There are multiple rubber cartridge packers, which are arranged along the axial direction of the wellbore and connected through a connecting sleeve.
17. A reverse circulation drilling equipment, comprising the isolation while drilling device according to any one of claims 1 to 16, and the reverse circulation drilling equipment further comprises:

    A double-tube drilling tool, comprising an upper drilling tool and a lower drilling tool, wherein the upper drilling tool and the lower drilling tool both have an inner tube and an outer tube, the outer tube of the upper drilling tool is connected to the upper transmission structure, and the outer tube of the lower drilling tool is connected to the lower transmission structure;

    An upper core pipe, the upper end of which is inserted into the upper transmission structure and communicated with the inner pipe of the upper drilling tool;

    The lower end of the lower core pipe is inserted into the lower transmission structure and communicated with the inner pipe of the lower drilling tool. The lower end of the upper core pipe and the upper end of the lower core pipe are in sealing and sliding cooperation along the axial direction of the wellbore.
18. The reverse circulation drilling apparatus according to claim 17, wherein:

    At least one centralizer is also installed on the double-tube drill bit. The centralizer is arranged close to the wellhead relative to the isolation-while-drilling device. In the drilling state, the centralizer can expand outward to centralize the double-tube drill bit; in the drill lifting state, the centralizer can also retract inward to a radial size smaller than the wellbore.
19. The reverse circulation drilling apparatus according to claim 17, wherein:

    An anti-stuck drill bit is installed at one end of the lower drilling tool close to the bottom of the well. In the drilling state, the anti-stuck drill bit can expand outward to drill; in the drill lifting state, the anti-stuck drill bit can also retract inward to a radial size smaller than the wellbore.
20. The reverse circulation drilling apparatus according to claim 17, wherein:

    The double-tube drilling tool is equipped with an anti-sticking impactor and a floating impact drill bit, and the anti-sticking impactor and the floating impact drill bit are sequentially installed above the drilling isolation device from bottom to top;

    When the double-tube drilling tool encounters resistance when lifting the drill, the impact piston in the anti-stuck impactor can hit the floating The floating impact drill bit is moved to impact and drill upward.
21. The reverse circulation drilling apparatus according to claim 17, wherein:

    A fluid injection and discharge mechanism is installed at one end of the double-tube drilling tool located above the ground, and the fluid injection and discharge mechanism includes an injection structure, a rotating injection and discharge adapter, and a discharge pipe. The injection structure is connected to the outer tube of the upper drilling tool through the distribution channel of the rotating injection and discharge adapter, and the discharge pipe is connected to the inner tube of the upper drilling tool through the reflux channel of the rotating injection and discharge adapter.
22. The reverse circulation drilling apparatus according to claim 21, wherein:

    A plurality of drainage-aiding structures are installed on the discharge pipe, and the drainage-aiding structures can inject drainage-aiding fluid into the discharge pipe to form drainage-aiding jets, and the drainage-aiding jets can push the fluid in the discharge pipe to be discharged.
23. The reverse circulation drilling apparatus according to claim 21, wherein:

    The rotary injection-discharge adapter is mounted on one end of the upper drilling tool located above the ground through a reverse circulation shock absorber.
24. The reverse circulation drilling apparatus according to claim 17, wherein:

    The inner tube of the upper drilling tool and the inner tube of the lower drilling tool are both provided with a conductive structure, and the double-tube drilling tool performs power transmission and signal transmission through the conductive structure.
25. The reverse circulation drilling apparatus according to claim 24, wherein:

    The inner tube of the upper drilling tool and the inner tube of the lower drilling tool both include multiple inner tube sections, the conductive structure includes a conductive layer, the conductive layer is coated on the outer wall surface of the inner tube section, two adjacent inner tube sections are plugged together through an inner tube male joint and an inner tube female joint, at least one conductive wire is embedded in the inner tube male joint and the inner tube female joint, and at least one group of conductive contact structures that match each other are provided on the contact surfaces of the inner tube male joint and the inner tube female joint, and the conductive contact structure is connected to the corresponding conductive layer through the corresponding conductive wire.