Tubular column assembly and fracturing system

Abstract

The utility model relates to the technical field of uranium mining, and discloses a tubular column assembly and a fracturing system. The tubular column assembly comprises a first sleeve and a second sleeve. The first sleeve is made of a first material. One end of the second sleeve is connected with one end of the first sleeve, so that the second sleeve is axially communicated with the first sleeve. And the second sleeve is made of a second material. Wherein the first material is different from the second material. According to the pipe column assembly, the second sleeve is axially communicated with the first sleeve, and the whole pipe column assembly is formed. The first material and the second material are different, so that the compressive strength is improved, the fracturing construction condition is met, the reservoir fracturing transformation effect is improved, the cost is reduced, and the economical efficiency is improved.

Description

Technical Field

[0001] This application belongs to the field of uranium mining technology, specifically relating to a tubing assembly and a fracturing system. Background Technology

[0002] In the field of uranium resource exploration, the mining of low-permeability sandstone uranium resources faces challenges such as low porosity and permeability, difficulty in injecting leaching agents, and small swept volume, which prevent the leaching agents from fully contacting and reacting with the uranium ore.

[0003] In related technologies, in-situ leaching uranium production is used for reservoir fracturing to improve reservoir permeability. However, the casing material used in in-situ leaching uranium production is rigid polyvinyl chloride (UPVC), which results in low compressive strength of the casing, making it difficult to meet the fracturing construction conditions and affecting the reservoir fracturing effect. Utility Model Content

[0004] This application aims to address at least one of the technical problems existing in the related art.

[0005] Therefore, a first aspect of this application provides a tubular assembly.

[0006] A second aspect of this application provides a fracturing system.

[0007] According to a first aspect of the embodiments of this application, a tubular assembly is provided, comprising: a first sleeve, the first sleeve being made of a first material; a second sleeve, one end of the second sleeve being connected to one end of the first sleeve to enable axial communication between the second sleeve and the first sleeve, the second sleeve being made of a second material; wherein the first material and the second material are different.

[0008] In one possible implementation of the first aspect, the first material comprises rigid polyvinyl chloride; the second material comprises fiberglass.

[0009] In one possible implementation of the first aspect, the tubular assembly further includes: a positioning block disposed on the inner wall of the first sleeve or the inner wall of the second sleeve; wherein the positioning block is located near the end of the second sleeve facing the first sleeve.

[0010] In one possible implementation of the first aspect, when the positioning block is disposed on the first sleeve, the tubular assembly further includes: a mounting groove disposed on the inner wall of the first sleeve, the positioning block being disposed within the mounting groove; and a spring member, one end of which is connected to the first sleeve, and the other end extending into the mounting groove and abutting against the positioning block.

[0011] In one possible implementation of the first aspect, when the positioning block is disposed on the second sleeve, the positioning block is bonded to the inner wall of the second sleeve.

[0012] In one possible implementation of the first aspect, the material of the positioning block includes a soluble material.

[0013] In one possible implementation of the first aspect, the second casing is provided with perforations for allowing liquid within the second casing to enter the ore layer.

[0014] According to a second aspect of the embodiments of this application, a fracturing system is proposed, comprising: a tubing assembly as described in any of the preceding embodiments.

[0015] In one possible implementation of the second aspect, the fracturing system further includes a packer disposed within the tubing assembly and located at the end of the second casing facing the first casing.

[0016] In one possible implementation of the second aspect, the fracturing system further includes: fracturing equipment; and an injection pipe, one end of which is connected to the packer and extends into the second sleeve, and the other end of which is connected to the fracturing equipment.

[0017] The tubing assembly and fracturing system provided in this application can achieve at least the following technical effects:

[0018] In this application, one end of the second casing is connected to one end of the first casing, thereby axially connecting the second casing and the first casing to form an integral tubing assembly. The first material and the second material are different. The first casing is made of the first material (e.g., UPVC) to reduce costs and improve economic efficiency; the second casing is made of the second material (e.g., fiberglass) to increase compressive strength, meet fracturing construction conditions, and improve reservoir fracturing stimulation effects.

[0019] The above general description and the description below are exemplary and illustrative only and are not intended to limit this application. Attached Figure Description

[0020] One or more embodiments are illustrated by way of example with reference to the accompanying drawings. These illustrations and drawings do not constitute a limitation on the embodiments. Elements having the same reference numerals in the drawings are shown as similar elements. The drawings are not to be scaled. And wherein:

[0021] Figure 1 This is a schematic diagram of the structure of the tubular assembly provided in the embodiments of this disclosure;

[0022] Figure 2 This is a schematic diagram of the structure of the first sleeve provided in an embodiment of this disclosure;

[0023] Figure 3 This is a schematic diagram of the fracturing system provided in an embodiment of the present disclosure;

[0024] Figure 4 This is a schematic diagram of the application structure of the fracturing system provided in the embodiments of this disclosure.

[0025] The reference numerals in the attached figures are as follows:

[0026] 100: Pipeline assembly; 101: First sleeve; 102: Second sleeve; 103: Positioning block; 104:

[0027] Mounting slot; 105: Spring element; 106: Perforation hole;

[0028] 200: Fracturing system; 201: Packer; 202: Fracturing equipment; 203: Injection tubing;

[0029] 300: Drilling well; 400: Uranium ore layer; 500: Seepage channel. Detailed Implementation

[0030] To provide a more detailed understanding of the features and technical content of the embodiments of this disclosure, the implementation of the embodiments of this disclosure will be described in detail below with reference to the accompanying drawings. The accompanying drawings are for illustrative purposes only and are not intended to limit the embodiments of this disclosure. In the following technical description, for ease of explanation, several details are used to provide a full understanding of the disclosed embodiments. However, one or more embodiments may still be implemented without these details. In other cases, well-known structures and devices may be simplified in their depiction to simplify the drawings.

[0031] The terms "first," "second," etc., used in the specification, claims, and accompanying drawings of this disclosure are used to distinguish similar objects and are not necessarily used to describe a specific order or sequence. It should be understood that such data can be interchanged where appropriate for the embodiments of this disclosure described herein. Furthermore, the terms "comprising" and "having," and any variations thereof, are intended to cover non-exclusive inclusion.

[0032] In this disclosure, the terms "upper," "lower," "inner," "middle," "outer," "front," and "rear," etc., indicate the orientation or positional relationship based on the orientation or positional relationship shown in the accompanying drawings. These terms are primarily for better description of the embodiments of this disclosure and their implementations, and are not intended to limit the indicated devices, elements, or components to having a specific orientation, or to require them to be constructed and operated in a specific orientation. Furthermore, some of the aforementioned terms may be used to indicate other meanings besides orientation or positional relationship; for example, the term "upper" may in some cases indicate a dependency or connection relationship. Those skilled in the art can understand the specific meaning of these terms in the embodiments of this disclosure according to the specific circumstances.

[0033] Furthermore, the terms "set up," "connect," and "fix" should be interpreted broadly. For example, "connection" can be a fixed connection, a detachable connection, or an integral structure; it can be a mechanical connection or an electrical connection; it can be a direct connection or an indirect connection through an intermediate medium, or it can be an internal connection between two devices, components, or parts. Those skilled in the art can understand the specific meaning of the above terms in the embodiments of this disclosure according to the specific circumstances.

[0034] Unless otherwise stated, the term "multiple" means two or more.

[0035] In this embodiment of the disclosure, the character " / " indicates that the objects before and after it are in an "or" relationship. For example, A / B means: A or B.

[0036] The term "and / or" describes an association between objects, indicating that three relationships can exist. For example, A and / or B means: A or B, or A and B.

[0037] It should be noted that, unless otherwise specified, the embodiments and features described in the present disclosure can be combined with each other.

[0038] According to a first aspect of the embodiments of this application, a tubular assembly 100 is provided. In conjunction with... Figures 1 to 4 As shown, the tubing assembly 100 includes a first sleeve 101 and a second sleeve 102. The first sleeve 101 is made of a first material. One end of the second sleeve 102 is connected to one end of the first sleeve 101, so that the second sleeve 102 is axially connected to the first sleeve 101. The second sleeve 102 is made of a second material. The first material and the second material are different.

[0039] In this embodiment, one end of the second sleeve 102 is connected to one end of the first sleeve 101, so that the second sleeve 102 and the first sleeve 101 are axially connected to form the whole of the tubing assembly 100, which facilitates the transportation of liquids (such as leachate, fracturing fluid, etc.).

[0040] In this embodiment, by using different materials for the first and second casings, the compressive strength is improved, meeting the fracturing conditions and enhancing the reservoir fracturing effect. This also reduces costs, improves economic efficiency, and provides both compressive strength and corrosion resistance with a long service life, allowing for maximum cost savings while meeting construction requirements. Specifically, using the first material (e.g., UPVC) for the first casing 101 reduces costs and improves economic efficiency. Using the second material (e.g., fiberglass) for the second casing 102 improves compressive strength, meets fracturing conditions, enhances reservoir fracturing effect, and also improves corrosion resistance and extends service life.

[0041] When the tubing assembly 100 is used in in-situ leaching uranium production, it is installed within the wellbore 300. The second casing 102 (e.g., fiberglass casing) is located in the section of the wellbore 300 corresponding to the uranium ore layer 400. In other words, the second casing 102 is located in the fracturing section and withstands high pressure during fracturing to inject fluid (e.g., fracturing fluid) into the uranium ore layer 400. The first casing 101 (UPVC casing) is located in the remaining sections of the wellbore 300. This means that the first casing 101 does not need to withstand high pressure during fracturing, thus reducing costs and improving economic efficiency. By cooperating with the first casing 101 and the second casing 102, and combining reservoir fracturing technology to improve reservoir permeability, increased injection and production are achieved, thereby enabling economical mining of uranium deposits. In this embodiment, the high pressure refers to the pressure that the second casing 102 needs to withstand when fracturing the uranium ore layer 400 in the in-situ leaching uranium production process; the specific value is not limited.

[0042] It should be noted that the shape of the first sleeve 101 and the second sleeve 102 is not limited; for example, they can be straight pipes or bent pipes.

[0043] In one possible implementation, one end of the second sleeve 102 is threaded to one end of the first sleeve 101.

[0044] In this embodiment, the threaded connection not only enables the first sleeve 101 and the second sleeve 102 to be axially connected to form the entire pipe column assembly 100, but also achieves sealing at the connection between the first sleeve 101 and the second sleeve 102, thereby improving the overall performance of the pipe column assembly 100.

[0045] For example, the first sleeve 101 is made of rigid polyvinyl chloride (UPVC), and the second sleeve 102 is made of fiberglass. A sealed connection is achieved through threaded connection between the UPVC sleeve and the fiberglass sleeve. That is, the UPVC sleeve and the fiberglass sleeve are connected to form a single unit, and the material combination of UPVC and fiberglass ensures a seal at the connection point.

[0046] In some embodiments, the first material comprises rigid polyvinyl chloride (PVC). The second material comprises fiberglass.

[0047] In this embodiment, the first material includes rigid polyvinyl chloride (PVC), meaning the first casing 101 is made of rigid PVC, which reduces costs and improves economic efficiency. The second material includes fiberglass, meaning the second casing 102 is made of fiberglass, which improves compressive strength, meets fracturing conditions, enhances reservoir fracturing effects, improves corrosion resistance, and extends service life.

[0048] It should be noted that the first material is not limited to rigid polyvinyl chloride (PVC). It can be used in fracturing sections within 300 meters of drilling depth, and any material that can reduce costs is also acceptable. The second material is not limited to fiberglass. It can be used in fracturing sections within 300 meters of drilling depth, and any material that can improve compressive strength is also acceptable.

[0049] Combining as 1 to Figure 4 As shown, in some embodiments, the tubing assembly 100 further includes a positioning block 103, which is disposed on the inner wall of the first sleeve 101 or the inner wall of the second sleeve 102. The positioning block 103 is located near the end of the second sleeve 102 facing the first sleeve 101.

[0050] In this embodiment, a positioning block 103 is disposed on the inner wall of the first sleeve 101, near the end of the second sleeve 102 facing the first sleeve 101, for precise positioning of the end of the second sleeve 102 facing the first sleeve 101. By disposing of the positioning block 103 on the inner wall of the second sleeve 102, near the end of the second sleeve 102 facing the first sleeve 101, the position of the end of the second sleeve 102 facing the first sleeve 101 is precisely positioned. In practical applications, the precise positioning of the end of the second sleeve 102 facing the first sleeve 101 by the positioning block 103 achieves precise positioning of the insertion position of the packer 201, thus meeting construction requirements while minimizing costs.

[0051] In one application example, when the tubing assembly 100 is installed in the drilling rig 300, the position of the end of the second casing 102 facing the first casing 101 can be initially determined based on the lengths of the first casing 101 and the second casing 102. However, due to the curvature of the drilling rig 300, it is difficult to accurately locate the position of the end of the second casing 102 facing the first casing 101 based solely on the lengths of the first casing 101 and the second casing 102. Therefore, the positioning block 103 is used to accurately locate the position of the end of the second casing 102 facing the first casing 101.

[0052] In this example, during the process of inserting the packer 201 into the tubing assembly 100, when the packer 201 comes into contact with the positioning block 103, the packer 201 will experience resistance. That is, the positioning block 103 is used to accurately position the end of the packer 201 inserted into the second casing 102 facing the first casing 101, so as to accurately separate the first casing 101 and the second casing 102, thereby enabling fracturing construction without damaging the first casing 101, saving costs to the greatest extent, with high economic efficiency, simple operation, convenient construction, and meeting the field application conditions.

[0053] In one possible implementation, combining Figures 1 to 4 As shown, multiple positioning blocks 103 are provided. The positioning blocks 103 are arranged circumferentially on the inner wall of the first sleeve 101 or the second sleeve 102.

[0054] In some embodiments, combined with Figure 2 As shown, with the positioning block 103 disposed on the first sleeve 101, the tube column assembly 100 further includes a mounting groove 104 and a spring member 105. The mounting groove 104 is disposed on the inner wall of the first sleeve 101. The positioning block 103 is disposed within the mounting groove 104. One end of the spring member 105 is connected to the first sleeve 101, and the other end of the spring member 105 extends into the mounting groove 104 and abuts against the positioning block 103.

[0055] Specifically, the mounting groove 104 is disposed on the inner wall of the first sleeve 101, and the mounting groove 104 is close to the end of the second sleeve 102 facing the first sleeve 101. The positioning block 103 is disposed in the mounting groove 104, so that the position of the positioning block 103 is close to the end of the second sleeve 102 facing the first sleeve 101.

[0056] In this embodiment, one end of the spring member 105 is connected to the first sleeve 101, fixing the spring member 105 to the first sleeve 101. The other end of the spring member 105 extends into the mounting groove 104 and abuts against the positioning block 103, fixing the positioning block 103 within the mounting groove 104. This improves the stability of the positioning block 103 during the movement or installation of the first sleeve 101. By fixing the positioning block 103 with the spring member 105, when the packer 201 is lowered to contact the positioning block 103, the positioning block 103, under the action of the packer 201, can detach from the mounting groove 104 and fall along the first sleeve 101 and the second sleeve 102 to the bottom of the well 300.

[0057] For example, when the positioning block 103 is disposed on the first sleeve 101, the distance between the positioning block 103 and the end of the second sleeve 102 facing the first sleeve 101 is a preset distance. When the packer 201 is lowered to contact the positioning block 103, the packer 201 encounters resistance. At this time, the packer 201 continues to be lowered a preset distance to reach the end of the second sleeve 102 facing the first sleeve 101, thus accurately lowering the packer 201 into the end of the second sleeve 102 facing the first sleeve 101. Furthermore, during the continued lowering of the packer 201, the packer 201 pushes the positioning block 103 to fall off, making the operation simple.

[0058] In one possible implementation, the spring element 105 includes a spring.

[0059] It should be noted that the number of springs 105 is not limited, as long as they can stably fix the positioning block 103 in the mounting groove 104 and allow the positioning block 103 to be easily detached from the mounting groove 104 when subjected to the action of the packer 201.

[0060] In some embodiments, combined with Figure 1 , Figure 3 and Figure 4 As shown, when the positioning block 103 is disposed on the second sleeve 102, the positioning block 103 is bonded to the inner wall of the second sleeve 102.

[0061] In this embodiment, the positioning block 103 is bonded to the inner wall of the second sleeve 102, thereby fixing the positioning block 103 to the inner wall of the second sleeve 102.

[0062] For example, when the packer 201 is lowered into the first sleeve 101 and the second sleeve 102 until it contacts the positioning block 103, the packer 201 is subjected to resistance. At this time, the packer 201 is located at the end of the second sleeve 102 facing the first sleeve 101, so as to achieve precise positioning of the packer 201, which is convenient to operate and meets the construction conditions while saving costs to the greatest extent.

[0063] It should be noted that the adhesive used to bond the positioning block 103 to the second sleeve 102 is not limited; for example, it can be epoxy resin adhesive.

[0064] In some embodiments, the material of the positioning block 103 includes a soluble material.

[0065] In this embodiment, the positioning block 103 is made of a soluble material, which gives the positioning block 103 self-dissolving properties. This allows the positioning block 103 to accurately position the packer 201 without affecting on-site construction operations, making it simple and convenient.

[0066] In a specific application example, when the positioning block 103 is set in the mounting groove 104 of the first casing 101, the positioning block 103 is dislodged to the bottom of the drilling 300 by the action of the packer 201. Due to the self-dissolving properties of the positioning block 103, the liquid (e.g., fracturing fluid) that self-dissolves in the drilling 300 avoids or reduces the space occupied by the positioning block 103 at the bottom of the well.

[0067] In another specific application example, when the positioning block 103 is bonded to the inner wall of the second casing 102 with epoxy resin adhesive, the positioning block 103 has self-dissolving properties, as the epoxy resin adhesive is insoluble in water. After the packer 201 is set, liquid (e.g., fracturing fluid) is injected into the second casing 102, and the positioning block 103 self-dissolves in the liquid within the drilling rig 300, avoiding or reducing its occupation of bottom hole space. The epoxy resin adhesive is insoluble in water, and after curing, it forms a high-strength, chemically resistant hard adhesive layer, further improving the compressive strength of the second casing 102 while avoiding or reducing its occupation of bottom hole space.

[0068] It should be noted that the specific type of soluble material is not limited; for example, it can be polyvinyl alcohol.

[0069] In some embodiments, combined with Figure 1 , Figure 3 and Figure 4 As shown, the second casing 102 is provided with a perforation 106, which is used to allow the liquid inside the second casing 102 to enter the ore layer.

[0070] In this embodiment, the liquid in the second casing 102 is allowed to enter the ore layer through the perforation 106, thereby achieving fracturing of the ore layer.

[0071] In practical applications, a perforation projectile can be used to penetrate the wall of the second casing 102, forming a perforation 106. When the perforation 106 penetrates the wall of the second casing 102, a seepage channel 500 corresponding to the location of the perforation 106 will be formed in the near-wellbore zone outside the second casing 102. During fracturing, the liquid inside the second casing 102 is ejected at high pressure through the perforation 106 and enters the seepage channel 500, thus fracturing the ore layer. After fracturing is completed, the leaching agent can be ejected at high pressure through the perforation 106 and enters the ore layer through the seepage channel 500, ensuring sufficient contact between the leaching agent and the ore layer.

[0072] According to a second aspect of the embodiments of this application, a fracturing system 200 is provided. In conjunction with... Figures 1 to 4 As shown, the fracturing system 200 includes a tubing assembly 100 as in any of the preceding embodiments.

[0073] In this embodiment, the fracturing system 200 includes the tubing assembly 100 as in any of the previous embodiments, and therefore has the technical effects of the tubing assembly 100 in the aforementioned embodiments, which will not be repeated here.

[0074] In some embodiments, combined with Figure 3 and Figure 4 As shown, the fracturing system 200 also includes a packer 201, which is disposed within the tubing assembly 100 and located at the end of the second casing 102 facing the first casing 101.

[0075] In this embodiment, the packer 201 is located at the end of the second casing 102 facing the first casing 101, that is, the packer 201 is located inside the second casing 102 and adjacent to the connection between the first casing 101 and the second casing 102. By positioning the packer 201 at the end of the second casing 102 facing the first casing 101, the first casing 101 and the second casing 102 are precisely separated. This satisfies construction requirements while minimizing costs, improving reservoir fracturing effectiveness, and extending service life. During fracturing, the packer 201 precisely separates the first casing 101 and the second casing 102, allowing the first casing 101 to withstand less high pressure while the second casing 102 withstands higher pressure. This improves the integrity and service life of the tubing assembly 100 during fracturing, and also enhances the integrity and safety of the drilling rig 300.

[0076] In some embodiments, combined with Figure 3 and Figure 4 As shown, the fracturing system 200 also includes a fracturing device 202 and an injection pipe 203. One end of the injection pipe 203 is connected to the packer 201 and extends into the second casing 102, while the other end of the injection pipe 203 is connected to the fracturing device 202.

[0077] Specifically, one end of the injection pipe 203 can pass through the packer 201 and extend into the second casing 102 to inject liquid into the second casing 102 for fracturing operations. The other end of the injection pipe 203 is connected to the fracturing equipment 202, so that the fracturing equipment 202 can deliver fracturing fluid to the injection pipe 203.

[0078] A specific application example:

[0079] Combination Figure 4As shown, firstly, the ore layer segment to be fracturing is determined, for example, uranium ore layer 400. Then, packer 201 is lowered into the ore layer. When packer 201 contacts positioning block 103, it encounters resistance. At this point, packer 201 is lowered to the end of second casing 102 facing first casing 101, that is, to a position below the connection between first casing 101 and second casing 102, i.e., to the setting position. Next, packer 201 is set. After packer 201 is set, fracturing equipment 202 injects liquid (fracturing fluid) into second casing 102 through injection pipe 203. The fracturing fluid enters uranium ore layer 400 through perforation 106 of second casing 102 for fracturing. Because of the separation effect of the packer 201 on the first casing 101 and the second casing 102, the first casing 101 will not be damaged by the high pressure of the fracturing process, thereby improving the integrity and service life of the tubing assembly 100, and thus improving the integrity and safety of the drilling 300.

[0080] In some embodiments, the fracturing system 200 further includes a pressure sensor, a controller, and an alarm. The pressure sensor is disposed on the packer 201 and connected to the controller. The pressure sensor collects resistance data of the packer 201 against the positioning block 103 and sends it to the controller. The controller is connected to the alarm. When the packer 201 encounters resistance from the positioning block 103, the controller controls the alarm to sound an alarm, reminding personnel that the packer 201 has been lowered into position.

[0081] For example, during the lowering of packer 201 into the tubing assembly 100, when packer 201 contacts positioning block 103, pressure sensor can collect resistance data from positioning block 103 on packer 201. Pressure sensor sends resistance data to controller, controller controls alarm to sound, reminding personnel that packer 201 has been lowered into place.

[0082] In this example, if the positioning block 103 is located on the inner wall of the first sleeve 101, after the pressure sensor collects resistance data of the packer 201, the packer 201 continues to descend a preset distance until it reaches the end of the second sleeve 102 facing the first sleeve 101. If the positioning block 103 is located on the inner wall of the second sleeve 102, when the pressure sensor collects resistance data of the packer 201, the packer 201 stops descending. At this time, the packer 201 is located at the end of the second sleeve 102 facing the first sleeve 101.

[0083] It should be noted that the installation location of the pressure sensor is not limited. As long as the resistance data experienced by the packer 201 can be collected when the packer 201 is lowered into contact with the positioning block 103.

[0084] In this embodiment, the controller includes a chip with logic operation capabilities and corresponding circuitry. The control center includes one or more signal input terminals and one or more signal output terminals. For example, the control center is a microcontroller system, which includes a microcontroller chip of a certain model and corresponding power supply circuits, crystal oscillator circuits, etc. The microcontroller system includes input / output terminals directly connected to the pins of the microcontroller chip, and input / output terminals indirectly connected to the pins of the microcontroller through signal adapters (e.g., relays); or the control center is a programmable logic controller (PLC) system, which includes a central processing unit (CPU) module, analog input modules, analog output modules, digital input modules, and digital output modules, etc.

[0085] The above are merely preferred embodiments of this application and are not intended to limit this application. Any modifications, equivalent substitutions, and improvements made within the spirit and principles of this application should be included within the protection scope of this application. The above are merely preferred embodiments of this application. It should be noted that for those skilled in the art, several improvements and modifications can be made without departing from the technical principles of this application, and these improvements and modifications should also be considered within the protection scope of this application.

Claims

1. A tubular assembly, characterized in that, include: The first sleeve, wherein the material of the first sleeve is the first material; The second sleeve has one end connected to one end of the first sleeve so that the second sleeve is axially connected to the first sleeve, and the material of the second sleeve is a second material; The first material and the second material are different.

2. The tubular assembly according to claim 1, characterized in that, The first material includes rigid polyvinyl chloride; The second material includes fiberglass.

3. The tubular assembly according to claim 1, characterized in that, Also includes: A positioning block is disposed on the inner wall of the first sleeve or the inner wall of the second sleeve; The positioning block is located near the end of the second sleeve facing the first sleeve.

4. The tubular assembly according to claim 3, characterized in that, When the positioning block is disposed on the first sleeve, the tubing assembly further includes: An installation groove is provided on the inner wall of the first sleeve, and the positioning block is provided in the installation groove; The spring component has one end connected to the first sleeve and the other end extending into the mounting groove and abutting against the positioning block.

5. The tubular assembly according to claim 3, characterized in that, When the positioning block is disposed on the second sleeve, the positioning block is bonded to the inner wall of the second sleeve.

6. The tubular assembly according to claim 3, characterized in that, The positioning block is made of a soluble material.

7. The tubular assembly according to any one of claims 1 to 6, characterized in that, The second casing is provided with perforations to allow the liquid inside the second casing to enter the ore layer.

8. A fracturing system, characterized in that, include: The tubular assembly as described in any one of claims 1 to 7.

9. The fracturing system according to claim 8, characterized in that, Also includes: A packer is disposed within the tubular assembly and located at the end of the second sleeve facing the first sleeve.

10. The fracturing system according to claim 9, characterized in that, Also includes: Fracturing equipment; The injection tube has one end connected to the packer and extends into the second sleeve, while the other end is connected to the fracturing equipment.

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