Fracturing flow diversion control system

Abstract

The application discloses a fracturing shunt control system, which comprises a sand liquid device, a pump truck device, a pipeline device, a shunt valve device and a control device. The pipeline device comprises an upstream pipeline for guiding fracturing sand liquid provided by the sand liquid device to multiple pump truck units of the pump truck device and a downstream pipeline for guiding fracturing sand liquid pumped by the multiple pump truck units to different fracturing wells. The shunt valve device is arranged on the upstream pipeline or the downstream pipeline and can distribute flow to the different fracturing wells. A fracturing detection assembly of the control device is used for detecting fracturing conditions of the different fracturing wells. The controller is configured to control the shunt valve device to distribute flow according to the fracturing conditions detected by the fracturing detection assembly, so that the fracturing system does not need to be arranged for each well when synchronous fracturing is performed on the different fracturing wells, and flow can be distributed to the different fracturing wells according to the fracturing conditions, thereby achieving the purposes of reducing fracturing cost and reducing the adjustment difficulty of fracturing displacement.

Description

Technical Field

[0001] This invention belongs to the field of oil and gas field development technology, and in particular relates to a fracturing diversion control system. Background Technology

[0002] In recent years, thanks to the large-scale development of unconventional oil and gas, horizontal well 3D well networks and horizontal well hydraulic fracturing technologies have made significant progress. During horizontal well fracturing, multiple surface fracturing truck sets and manifold systems are required to carry out fracturing operations. High-pressure pump truck sets inject high-pressure fracturing fluid and proppant into the formation, breaking open the target layer and creating fractures, ultimately forming a complex 3D fracture network, increasing the formation contact area, and achieving volumetric modification.

[0003] Currently, large-scale fracturing typically utilizes three-dimensional horizontal well network technology, requiring simultaneous fracturing of multiple wells and zipper-style fracturing. When deploying manifolds on the surface, each well needs its own fracturing system, with multiple fracturing trucks connected to a single well via manifolds. Furthermore, during fracturing, the fracturing flow rate sometimes needs adjustment based on formation and engineering conditions. However, in actual field operations, adjusting the flow rate is difficult, involves numerous and dangerous procedures, and is not economically efficient. Summary of the Invention

[0004] In view of the above-mentioned defects or deficiencies of the existing technology, the present invention provides a fracturing diversion control system, which aims to solve the technical problems of existing multi-well synchronous fracturing requiring each well to be equipped with a separate fracturing system and the difficulty in adjusting the fracturing flow rate.

[0005] To achieve the above objectives, the present invention provides a fracturing diversion control system, wherein the fracturing diversion control system includes: a fracturing fluid supply unit, a pump truck unit, a pipeline unit, a diversion valve unit, and a control device; the fracturing fluid supply unit is used to provide fracturing fluid; the pump truck unit includes multiple pump truck units arranged in parallel; the pipeline unit includes an upstream pipeline for guiding the fracturing fluid supplied by the fracturing fluid supply unit to the multiple pump truck units, and a downstream pipeline for guiding the fracturing fluid pumped out by the multiple pump truck units to different fracturing wells; the diversion valve unit is located on the upstream or downstream pipeline and configured to distribute the flow to different fracturing wells; the control device includes a controller and a fracturing detection component, the fracturing detection component is used to detect the fracturing status of different fracturing wells, the controller is communicatively connected to the diversion valve unit and the fracturing detection component respectively, and is configured to control the diversion valve unit to distribute the flow according to the fracturing status detected by the fracturing detection component.

[0006] In this embodiment of the invention, the diversion valve device includes a diversion housing and a valve core drive mechanism. The diversion housing forms an inlet valve channel, a valve core drive cavity, a first outlet valve channel, and a second outlet valve channel. The inlet valve channel is located at the upstream end of the valve core drive cavity, and the first outlet valve channel and the second outlet valve channel are bifurcated at the downstream end of the valve core drive cavity. The first outlet valve channel and the second outlet valve channel are used to be correspondingly located on paths guiding different fracturing wells. The valve core drive mechanism is movably located in the valve core drive cavity and is used to adjust the diversion ratio of the first outlet valve channel and the second outlet valve channel.

[0007] The control device also includes a flow detection component for detecting the flow rate of the first and second outlet valve channels respectively. The controller is communicatively connected to the flow detection component and is further configured to: determine the synchronous fracturing flow rate of different fracturing wells based on the fracturing situation detected by the fracturing detection component; determine the synchronous fracturing flow split ratio based on the synchronous fracturing flow rate; control the valve core drive mechanism to adjust the flow split ratio of the first and second outlet valve channels to the synchronous fracturing flow split ratio; receive the flow rate data detected by the flow detection component; and, if it is determined from the flow rate data that the synchronous fracturing flow rate has not been reached, control the valve core drive mechanism to correct the synchronous fracturing flow split ratio.

[0008] In this embodiment of the invention, the controller is further configured to: receive a synchronous fracturing mode command; control the start-up of the fracturing fluid device, the pump truck device, and the diversion valve device, wherein the fracturing fluid device is configured to provide fracturing fluid at a first viscosity, and the diversion valve device is configured to distribute the flow rate according to an initial diversion ratio; receive fracturing status detected by the fracturing detection component; control the diversion valve device to distribute the flow rate according to the fracturing status so that different fracturing wells are in the same fracture development morphology; and control the fracturing fluid device to provide fracturing fluid at a second viscosity when the fracturing fluid forms a high-viscosity pre-slug in the fracturing well. The fracturing fluid is supplied at a second viscosity, wherein the second viscosity is less than the first viscosity. When the fracturing fluid forms a low-viscosity slickwater pre-slug in the fracturing well, the fracturing sand device is controlled to supply fracturing sand at a third viscosity, wherein the third viscosity is between the second viscosity and the first viscosity. When a complex fracture network begins to form in the far well zone, the fracturing sand device is controlled to increase the viscosity of the fracturing sand and the proportion of fracturing sand in a stepwise manner, and when the preset maximum viscosity and preset maximum sand quantity are reached, the fracturing sand device is controlled to supply fracturing sand at a constant viscosity and a constant proportion of fracturing sand until the fracturing operation is completed.

[0009] In this embodiment of the invention, the sand-liquid mixing mechanism and the diversion valve device in the sand-liquid device are both at least two. One sand-liquid mixing mechanism is connected to several first pump truck units in the pump truck device, and the other sand-liquid mixing mechanism is connected to several second pump truck units in the pump truck device. At least two diversion valve devices are arranged in parallel on the downstream pipeline. The inlet of one diversion valve device is connected to several first pump truck units, and the two outlets formed are used to guide the first fracturing well and the second fracturing well respectively. The inlet of the other diversion valve device is connected to several second pump truck units, and the two outlets formed are used to guide the first fracturing well and the second fracturing well respectively.

[0010] When fracturing fluid forms a low-viscosity slickwater pre-slug in the fracturing well, controlling the fracturing fluid device to provide fracturing fluid at a third viscosity includes: when fracturing fluid forms a low-viscosity slickwater pre-slug in the fracturing well, controlling one fracturing fluid mixing mechanism to provide fracturing fluid of a fourth viscosity, controlling another fracturing fluid mixing mechanism to provide fracturing fluid of a fifth viscosity, and adjusting the split ratio of the split valve device corresponding to the fracturing fluid to form a pulsed alternating injection of fracturing fluid in the first fracturing well and the second fracturing well, wherein the fourth viscosity is between the second viscosity and the first viscosity, and the fifth viscosity is less than the fourth viscosity.

[0011] In this embodiment of the invention, the controller is further configured to: receive an asynchronous fracturing mode command; control the start-up of the sand-fluid device, the pump truck device, and the diversion valve device, wherein the diversion valve device is configured to perform fracturing operation on the first formation of the first fracturing well at full flow; after the fracturing operation on the first formation of the first fracturing well is completed, control the diversion valve device to perform fracturing operation on the first formation of the second fracturing well at full flow; after the fracturing operation on the first formation of the second fracturing well is completed, control the diversion valve device to perform fracturing operation on the second formation of the first fracturing well at full flow; repeat the above operations until the fracturing operations of the first fracturing well and the second fracturing well in different formations are completed.

[0012] In this embodiment of the invention, the flow divider housing includes an inlet valve pipe section, a valve cavity section, and an outlet valve pipe section connected in sequence. The inlet valve pipe section forms an inlet valve channel, and the outlet valve pipe section forms a first outlet valve channel and a second outlet valve channel at intervals. The valve cavity section forms a valve core driving cavity, and the first end of the valve core driving cavity is connected to the inlet valve channel, and the second end is connected to the first outlet valve channel and the second outlet valve channel respectively.

[0013] The valve core drive mechanism includes a valve core assembly and a drive component. The valve core assembly is rotatably disposed in the valve core drive cavity and forms a first valve core channel and a second valve core channel spaced apart. Both the first valve core channel and the second valve core channel extend along the length direction of the valve core drive cavity. The first valve core channel is used to connect the inlet valve channel and the first outlet valve channel to form a first flow divider. The second valve core channel is used to connect the inlet valve channel and the second outlet valve channel to form a second flow divider. The drive component is used to drive the valve core assembly to rotate so as to adjust the flow rate of the first flow divider and the second flow divider.

[0014] In this embodiment of the invention, the valve core assembly includes a valve core body, a first stop body, and a second stop body. The first stop body and the second stop body are respectively disposed on the inner wall of the valve core drive cavity, with a valve inlet channel between them, and both extend along the length direction of the valve core drive cavity. The valve core body includes a rotating core part that is driven and connected to a drive member and a spacer plate part disposed on the periphery of the rotating core part. The rotating core part is rotatably disposed in the inner circle formed by the first stop body and the second stop body, and the periphery of the rotating core part is respectively attached to and abuts against the first stop body and the second stop body to form a valve core flow space. The spacer plate part extends between the first stop body and the second stop body and is attached to and abuts against the inner wall of the valve core drive cavity to divide the valve core flow space to form a first valve core channel and a second valve core channel.

[0015] In this embodiment of the invention, both the first stop body and the second stop body include a fixing part disposed on the inner wall of the valve core driving cavity and an abutting part detachably disposed on the side of the fixing part facing the partition plate part.

[0016] In this embodiment of the invention, the cross-sections of the valve core flow space and the spacer plate are both arranged in a fan-shaped annular pattern along the direction from the inlet valve section to the outlet valve section, and the cross-sectional areas are both arranged in an increasing manner.

[0017] In this embodiment of the invention, the valve inlet pipe section includes a valve inlet end cap detachably connected to the valve cavity section, and a valve inlet pipe body disposed on the side of the valve inlet end cap away from the valve cavity section. The valve inlet channel extends from the valve inlet pipe body through the valve inlet end cap and is arranged in a gradually expanding manner. The shape of the opening of the valve inlet channel transitions from a circle to a fan-shaped ring in the direction from the valve inlet pipe body toward the valve inlet end cap. The first stop body and the second stop body are disposed on opposite sides of the valve inlet channel in a circumferential direction, and their ends are fitted with the inner side of the valve inlet end cap. The first stop body and the second stop body also have the solid part of the valve inlet end cap between them and the inner wall of the valve inlet channel.

[0018] And / or, the valve cavity section and the outlet valve pipe section are integrally formed. The first outlet valve channel and the second outlet valve channel both extend from the outlet valve pipe section through the end of the valve cavity section and are respectively connected to the valve core drive cavity. The first outlet valve channel and the second outlet valve channel are both gradually narrowed in the direction from the valve cavity section toward the outlet valve pipe section, and the shape of the channel openings transitions from a fan-shaped annulus to a circle. The inner cavity of the valve cavity section has a first step portion and a second step portion formed between the two outlet valve channels and the valve core drive cavity for correspondingly fitting the ends of the first stop body and the second stop body. The first stop body and the second stop body also have solid portions of the step portion between them and the peripheral walls of the corresponding outlet valve channels.

[0019] Through the above technical solution, the fracturing diversion control system provided by the embodiments of the present invention has the following beneficial effects:

[0020] The above technical solution includes a fracturing fluid device, a pump truck device, a pipeline device, a diversion valve device, and a control device. By adding a diversion valve device to the upstream or downstream pipeline of the pump truck device, and the diversion valve device being able to distribute the flow of fracturing fluid directed to different fracturing wells, it is not necessary to arrange a separate fracturing system for each well when simultaneously fracturing different fracturing wells. The fracturing diversion control system provided by this invention can achieve simultaneous fracturing of different fracturing wells. Furthermore, the controller of the control device can obtain the fracturing status of different fracturing wells through the fracturing detection component, thereby enabling the diversion valve device to distribute the flow of fluid to different fracturing wells according to the fracturing status, achieving the purpose of reducing fracturing costs and reducing the difficulty of adjusting the fracturing discharge.

[0021] Other features and advantages of the embodiments of the present invention will be described in detail in the following detailed description section. Attached Figure Description

[0022] The accompanying drawings are provided to further illustrate embodiments of the present invention and form part of the specification. They are used together with the following detailed description to explain the embodiments of the present invention, but do not constitute a limitation thereof. In the drawings:

[0023] Figure 1 This is a schematic diagram of the structure of the first embodiment of the fracturing diversion control system according to the present invention;

[0024] Figure 2 This is a schematic diagram of the structure of the second embodiment of the fracturing diversion control system according to the present invention;

[0025] Figure 3 This is a schematic diagram of the third embodiment of the fracturing diversion control system according to the present invention;

[0026] Figure 4This is a schematic diagram of the fourth embodiment of the fracturing diversion control system according to the present invention;

[0027] Figure 5 This is a schematic diagram of the fifth embodiment of the fracturing diversion control system according to the present invention;

[0028] Figure 6 This is a schematic diagram of the sixth embodiment of the fracturing diversion control system according to the present invention;

[0029] Figure 7 This is a schematic diagram of the structure of a flow divider valve device according to an embodiment of the present invention;

[0030] Figure 8 This is a disassembly diagram of a diversion valve device according to an embodiment of the present invention;

[0031] Figure 9 This is a schematic diagram of the structure of the valve inlet pipe section from one perspective according to an embodiment of the present invention;

[0032] Figure 10 This is a schematic diagram of the valve inlet pipe section from another perspective according to an embodiment of the present invention;

[0033] Figure 11 This is a schematic diagram of the valve core assembly according to an embodiment of the present invention;

[0034] Figure 12 This is a schematic diagram of the structure of the inlet valve pipe section and valve core assembly according to an embodiment of the present invention;

[0035] Figure 13 This is a schematic diagram of the valve cavity section and the valve outlet pipe section from one perspective according to an embodiment of the present invention;

[0036] Figure 14 This is a schematic diagram of the valve cavity section and the valve outlet pipe section from another perspective according to an embodiment of the present invention;

[0037] Figure 15 This is a structural schematic diagram of the valve cavity section and the outlet valve pipe section from another perspective according to an embodiment of the present invention;

[0038] Figure 16 This is a schematic diagram of the valve cavity section according to an embodiment of the present invention;

[0039] Figure 17 This is a schematic diagram of the valve inlet channel according to an embodiment of the present invention;

[0040] Figure 18 This is a schematic diagram of various embodiments of the replaceable structure of the valve core according to the present invention.

[0041] Explanation of reference numerals in the attached figures

[0042] 100. Diverter housing; 110. Inlet valve section; 111. Inlet valve passage; 112. Inlet valve end cap; 113. Inlet valve pipe body; 120. Valve cavity section; 121. Valve core drive cavity; 122. T-shaped tenon; 123. First step; 124. Second step; 130. Outlet valve section; 131. First outlet valve passage; 132. Second outlet valve passage; 200. Valve core drive mechanism; 201. Valve core assembly; 202. First valve core passage; 203. Second valve core passage; 204. Valve core body; 205. First stop body; 206. Second stop body; 207. 208. Rotating core; 209. Spacer plate; 210. Shaft mounting hole; 211. T-shaped tenon; 212. Fixing part; 213. Abutment part; 214. Sealing element; 300. Fracturing fluid device; 301. Fracturing fluid tank; 302. Fracturing sand box; 303. Fracturing fluid mixing mechanism; 400. Pump truck device; 410. Pump truck unit; 411. First pump truck unit; 412. Second pump truck unit; 500. Pipeline device; 501. Upstream pipeline; 502. Downstream pipeline; 600. Diversion valve device; 700. Fracturing well; 701. First fracturing well; 702. Second fracturing well; Detailed Implementation

[0043] The specific embodiments of the present invention will be described in detail below with reference to the accompanying drawings. It should be understood that the specific embodiments described herein are for illustration and explanation only and are not intended to limit the present invention.

[0044] The fracturing diversion control system of the present invention is described below with reference to the accompanying drawings.

[0045] like Figures 1 to 7 As shown, the present invention provides a fracturing diversion control system, wherein the fracturing diversion control system includes:

[0046] The fracturing fluid supply unit 300 is used to supply fracturing fluid;

[0047] The pump truck unit 400 includes multiple pump truck units 410 arranged in parallel.

[0048] The pipeline assembly 500 includes an upstream pipeline 501 for directing fracturing sand provided by the sand-fracturing unit 300 to a plurality of pump truck units 410, and a downstream pipeline 502 for directing fracturing sand pumped out by the plurality of pump truck units 410 to different fracturing wells 700.

[0049] A diversion valve device 600 is installed on the upstream pipeline 501 or the downstream pipeline 502 and is configured to distribute the flow to different fracturing wells 700.

[0050] The control device includes a controller and a fracturing detection component. The fracturing detection component is used to detect the fracturing conditions of different fracturing wells 700. The controller is communicatively connected to the diversion valve device 600 and the fracturing detection component, and is configured to control the diversion valve device 600 to distribute the flow according to the fracturing conditions detected by the fracturing detection component.

[0051] In the above technical solution, since it includes a sand-fluid device 300, a pump truck device 400, a pipeline device 500, a diversion valve device 600, and a control device, by adding a diversion valve device 600 to the upstream pipeline 501 or downstream pipeline 502 of the pump truck device 400, and the diversion valve device 600 can distribute the flow of fracturing sand fluid directed to different fracturing wells 700, it is not necessary to arrange a separate fracturing system for each well when simultaneously fracturing different fracturing wells 700. The fracturing diversion control system provided by this invention can realize the simultaneous fracturing of different fracturing wells 700. Furthermore, the controller of the control device can obtain the fracturing status of different fracturing wells 700 through the fracturing detection component, thereby enabling the diversion valve device 600 to distribute the flow of different fracturing wells 700 according to the fracturing status, achieving the purpose of reducing fracturing costs and reducing the difficulty of adjusting the fracturing discharge.

[0052] Specifically, such as Figure 8 As shown, the diversion valve device 600 has an inlet valve channel 111 and at least two outlet valve channels. The flow rate of the fracturing sand fluid flowing into the inlet valve channel 111 can be adjusted to change the flow rate of the fracturing sand fluid flowing out of the at least two outlet valve channels. More specifically, in Figure 1 In the first embodiment of the fracturing diversion control system shown, a diversion valve device 600 distributes the flow rate of all pump units 410 in the pump unit 400 to the two fracturing wells 700; Figure 2 In the second embodiment of the fracturing diversion control system shown, two diversion valve devices 600 distribute the flow rate of all pump units 410 in the pump unit 400 to the two fracturing wells 700; Figure 3 In the third embodiment of the fracturing diversion control system shown, multiple diversion valve devices 600 distribute the flow rate of all pump units 410 in the pump unit 400 to the two fracturing wells 700; Figure 4 In the fourth embodiment of the fracturing diversion control system shown, multiple diversion valve devices 600 distribute the flow of all pump truck units 410 in the pump truck device 400 to the three fracturing wells 700.

[0053] More specifically, such as Figures 1 to 4As shown, in the first to fourth embodiments of the fracturing diversion control system, the diversion valve device 600 can be installed on the downstream pipeline 502, and when the number of fracturing wells 700 and the number of valve outlet channels of one diversion valve device 600 are both two, the number of diversion valve devices 600 in one fracturing diversion control system can be one, two or more, but generally less than or equal to half the number of pump truck units 410. That is, the inlet valve channel 111 of one diversion valve device 600 should connect to at least two pump truck units 410 to reduce the number of diversion valve devices 600 used. In addition, the two valve outlet channels of each diversion valve device 600 are directly connected to two fracturing wells 700 respectively, so the sand flow rate of each fracturing well 700 is equal to the sand flow rate of all valve outlet channels connected to it. It should be noted that, due to the influence of the fracturing scale, when the fracturing scale and fracturing discharge are huge, and the peak discharge exceeds the allowable flow of the diversion valve device 600, two or more diversion valve devices 600 are used. The control device jointly controls each diversion valve device 600 to achieve flow control of different fracturing wells 700. This reduces the number of pump truck units 410 connected to the inlet of each diversion valve device 600, reduces the discharge, and increases the safety factor.

[0054] Furthermore, such as Figure 5 As shown, in the fifth embodiment of the fracturing diversion control system, the diversion valve device 600 can be installed on the upstream pipeline 501, and when the number of fracturing wells 700 and the number of valve outlet channels of one diversion valve device 600 are both two, the number of diversion valve devices 600 in a fracturing diversion control system can be half the number of pump truck units 410. Then, the number of valve outlet channels in a fracturing diversion control system is equal to the number of pump truck units 410, so that the valve outlet channels and pump truck units 410 are connected in a one-to-one correspondence. At the same time, a portion of the pump truck units 410 connected in parallel are connected to one of the two fracturing wells 700 through the downstream pipeline 502, and the remaining portion of the pump truck units 410 connected in parallel are connected to the other of the two fracturing wells 700 through the downstream pipeline 502. It should be noted that, due to the scale of fracturing, when the fluid pressure boosted by the pump truck unit 400 is enormous and exceeds the allowable pressure of the diversion valve unit 600, the diversion valve unit 600 is installed upstream (low-pressure inlet end) of the pump truck unit 410 in the pump truck unit 400. The flow rate at the low-pressure end of the pump truck unit 410 is controlled by each diversion valve unit 600 to achieve flow control at the high-pressure end. Ultimately, real-time control of the flow rate / discharge of the two fracturing wells 700 during the synchronous fracturing process is achieved, so that each diversion valve unit 600 does not have to bear the high pressure and high-speed flow at the high-pressure end, which can improve the safety factor.

[0055] In an embodiment of the present invention, see Figure 7 and Figure 8The diversion valve device 600 includes a diversion housing 100 and a valve core drive mechanism 200. The diversion housing 100 forms an inlet valve channel 111, a valve core drive chamber 121, a first outlet valve channel 131, and a second outlet valve channel 132. The inlet valve channel 111 is located upstream of the valve core drive chamber 121. The first outlet valve channel 131 and the second outlet valve channel 132 are bifurcated and located downstream of the valve core drive chamber 121. The first outlet valve channel 131 and the second outlet valve channel 132 are correspondingly positioned on paths guiding different fracturing wells 700. The valve core drive mechanism 200 is movably disposed within the valve core drive chamber 121 and is used to adjust the diversion ratio of the first outlet valve channel 131 and the second outlet valve channel 132, i.e., by... The control valve core drive mechanism 200 moves within the valve core drive chamber 121, which can adjust the flow rate of sand fluid flowing out from the first outlet valve channel 131 and the second outlet valve channel 132. Specifically, the flow split ratio of the first outlet valve channel 131 and the second outlet valve channel 132 can be defined as the ratio of the sand fluid flow rates of the first outlet valve channel 131 and the second outlet valve channel 132. Since the first outlet valve channel 131 and the second outlet valve channel 132 are located on the paths leading to different fracturing wells 700, regardless of whether the flow split valve device 600 is installed on the upstream pipeline 501 or the downstream pipeline 502, the fracturing flow rate of different fracturing wells 700 can be adjusted by adjusting the flow split ratio of the two.

[0056] In addition, the control device also includes a flow detection component for detecting the flow rate of the first outlet valve channel 131 and the second outlet valve channel 132 respectively. The controller is communicatively connected to the flow detection component and is further configured to:

[0057] Step 100: Determine the synchronous fracturing flow rate for different fracturing wells 700 based on the fracturing conditions detected by the fracturing detection component.

[0058] Furthermore, since the formation conditions of different fractured wells 700 are different, the heterogeneity of the formation leads to different fracturing initiation times. Therefore, under the same fracturing flow rate, different fractured wells 700 cannot achieve synchronous fracturing stages. To achieve synchronous fracturing, a fracturing detection component can be installed in each fractured well 700 to detect the fracturing situation. This allows for the determination of whether the fracturing stages of different fractured wells 700 are synchronized based on the real-time detection of the fracturing situation. If the fracturing stages are not synchronized, it can be determined that the current fracturing flow rate of different fractured wells 700 is inappropriate and needs to be adjusted. Meanwhile, based on the fracturing conditions of different fracturing wells 700, the subsequent synchronous fracturing flow rate of different fracturing wells 700 can be determined. Specifically, when the fracturing condition of one fracturing well 700 (in_1) is slower than that of another fracturing well 700 (in_2), the fracturing flow rate of in_1 can be increased accordingly, and the fracturing flow rate of in_2 can be decreased. In the process of determining the synchronous fracturing flow rate, the corresponding synchronous fracturing flow rate can be obtained by looking up the table of the pre-stored fracturing condition-synchronous fracturing flow rate relationship table based on the real-time detected fracturing condition. In addition, the synchronous fracturing flow rate can also be calculated by substituting the fracturing parameters corresponding to the fracturing condition detected by the fracturing detection component into the calculation formula, which is pre-stored.

[0059] Furthermore, the fracturing detection component may include downhole pressure gauges installed in each fracturing well 700. Based on the pressure detection data from the downhole pressure gauges, fracturing curves can be generated. The change in bottom hole pressure over time can, to some extent, reflect the extension and development of fractures.

[0060] Step 110: Determine the simultaneous fracturing flow split ratio based on the simultaneous fracturing flow rate.

[0061] Specifically, since each fracturing well 700 may have more than two outlet valve channels corresponding to it, the synchronous fracturing flow rate of each fracturing well 700 should be the sum of the outflow flow rate of each outlet valve channel connected to it. The outflow flow rate of each outlet valve channel is equal to the product of the inflow flow rate of the corresponding inlet valve channel 111 and the flow diversion ratio coefficient. It should be noted that the flow diversion ratio coefficient refers to the ratio of the outflow flow rate of the corresponding outlet valve channel to the inflow flow rate of the inlet valve channel 111.

[0062] For example, when there are two fracturing wells 700, and the two outlet valve channels of each diversion valve device 600 are directed one-to-one to the two fracturing wells 700, the calculation formula can be:

[0063]

[0064] Among them, Q in_1 Q in_2 Q represents the simultaneous fracturing flow rates of fracturing wells in_1 and in_2, respectively. iη represents the inflow flow rate of the inlet valve channel 111 of the i-th diverter valve device 600. i The first diversion ratio coefficient representing the first outlet valve channel 131 of the i-th diversion valve device 600, (1-η) i Let ) represent the second diversion ratio coefficient of the second outlet valve channel 132 of the i-th diversion valve device 600. From this, the first diversion ratio coefficient and the second diversion ratio coefficient of the i-th diversion valve device 600 can be determined. The ratio of the first diversion ratio coefficient to the second diversion ratio coefficient is the synchronous diversion ratio of the diversion valve device 600.

[0065] Step 120: Control valve core drive mechanism 200 adjusts the flow ratio of the first outlet valve channel 131 and the second outlet valve channel 132 to the synchronous fracturing flow ratio.

[0066] It should be noted that the synchronous fracturing diversion ratio of different diversion valve devices 600 can be the same or different, as long as the synchronous fracturing flow rate entering different fracturing wells 700 after diversion is ensured.

[0067] Step 130: Receive the flow rate data detected by the flow detection component.

[0068] Furthermore, the flow detection component includes multiple flow sensors. Each flow sensor is provided on the first outlet valve channel 131 and the second outlet valve channel 132 of each diversion valve device 600, and each flow sensor is communicatively connected to the controller so as to send the flow data detected in each outlet valve channel to the controller.

[0069] Step 140: If the synchronous fracturing flow rate is not reached based on the flow rate data, the control valve core drive mechanism 200 corrects the synchronous fracturing flow ratio.

[0070] Furthermore, the controller can add the flow rate data detected by the flow sensor on the outlet valve channel of the same fracturing well 700 to obtain the real-time fracturing flow rate of each fracturing well 700, and compare the real-time fracturing flow rate of each fracturing well 700 with the synchronous fracturing flow rate. If the synchronous fracturing flow rate is not reached, the controller valve core drive mechanism 200 corrects the synchronous fracturing flow ratio of the diversion valve device 600 until the real-time fracturing flow rate reaches the synchronous fracturing flow rate or is within the allowable error range, thereby ensuring the stable operation of synchronous fracturing.

[0071] In this embodiment of the invention, the controller is further configured as follows:

[0072] Step 200: Receive synchronous fracturing mode command.

[0073] Specifically, the control device also includes a remote control or a display, which is communicatively connected to the controller and has a synchronous fracturing mode selection button to send synchronous fracturing mode commands to the controller.

[0074] Step 210: Start the control sand-fracturing device 300, pump truck device 400 and flow divider device 600, wherein the sand-fracturing device 300 is configured to provide fracturing sand at a first viscosity, and the flow divider device 600 is configured to distribute the flow according to the initial flow divider ratio.

[0075] Furthermore, after receiving the synchronous fracturing mode command, the controller controls the fracturing sand device 300 to provide fracturing sand at the first viscosity, the pump truck device 400 to start at the maximum displacement, and the diversion valve device 600 to distribute the flow at the initial diversion ratio.

[0076] Step 220: Receive the fracturing status detected by the fracturing detection component.

[0077] After a period of time, the fracturing status of each fracturing well can be obtained through the fracturing detection component.

[0078] Step 230: Control the flow distribution device 600 to distribute the flow according to the fracturing situation so that different fracturing wells 700 achieve the same fracture development morphology.

[0079] More specifically, step 230 may include at least steps 100 to 120, namely, firstly, the required synchronous fracturing flow rate for different fracturing wells 700 can be determined based on the fracturing situation detected by the fracturing detection component, so that different fracturing wells 700 can achieve the same fracture development morphology when fracturing operations are performed under synchronous fracturing flow rate; then, the synchronous fracturing flow ratio of each diversion valve device 600 is determined based on the synchronous fracturing flow rate of different fracturing wells 700; finally, the valve core drive mechanism 200 of each diversion valve device 600 is controlled to adjust the initial flow ratio to the synchronous fracturing flow ratio, so as to ensure that different fracturing wells 700 can achieve the same fracture development morphology after the flow is redistributed.

[0080] It should be noted that the detection of fracturing conditions and the adjustment of the flow ratio can be carried out throughout the entire fracturing operation of the 700-meter fracturing well to further ensure the synchronous fracturing operation.

[0081] Step 240: When the fracturing sand fluid forms a high-viscosity pre-plug in the fracturing well 700, the sand fluid device 300 is controlled to supply fracturing fluid at a second viscosity, wherein the second viscosity is less than the first viscosity.

[0082] Because the fracturing fluid is initially supplied with high-flow-rate, high-viscosity fracturing sand, a high-viscosity pre-slug can form in the formation. This high-viscosity pre-slug is less likely to leak into the formation, which is conducive to the development of simple main fractures. After the high-viscosity pre-slug is formed, the viscosity of the fracturing fluid can be reduced and the injection of fracturing sand can be stopped. This allows a low-viscosity slickwater pre-slug to form after the high-viscosity pre-slug. The low-viscosity slickwater pre-slug is more likely to leak into the formation, which is conducive to the formation of complex fractures.

[0083] Furthermore, such as Figures 1 to 6 As shown, the fracturing fluid device 300 includes a fracturing fluid tank 301, a fracturing sand tank 302, a glue tank (not shown), and a fracturing fluid mixing mechanism 303. The fracturing fluid tank 301 stores fracturing fluid and supplies the fracturing fluid required for mixing to the fracturing fluid mixing mechanism 303. The fracturing sand tank 302 stores fracturing sand and supplies the fracturing sand required for mixing to the fracturing fluid mixing mechanism 303. The glue tank stores glue and supplies the glue required to the fracturing fluid mixing mechanism 303. Each of the pipelines leading from the fracturing fluid tank 301, the fracturing sand tank 302, and the glue tank to the fracturing fluid mixing mechanism 303 is equipped with an on / off valve that is communicatively connected to a controller. The fracturing fluid tank 301, the fracturing sand tank 302, and the glue tank are mounted on a weighing device to facilitate control of the mixing ratio of the corresponding substances. Furthermore, the controller can calculate the flow rate of the corresponding substances based on the opening degree and opening duration of the on / off valves, thereby controlling the mixing ratio of the corresponding substances. The fracturing fluid mixing mechanism 303 is used to mix the injected fracturing fluid, fracturing sand and adhesive, and to supply the upstream pipeline 501 with viscous fracturing sand. Of course, the present invention is not limited to this. By controlling the opening and closing of the valve, the fracturing fluid, fracturing sand and adhesive can be selected, and not all three must be selected.

[0084] Step 250: When the fracturing fluid forms a low-viscosity slickwater pre-plug in the fracturing well 700, the fracturing fluid control device 300 supplies fracturing fluid at a third viscosity, wherein the third viscosity is between the second viscosity and the first viscosity.

[0085] After the low-viscosity slickwater pre-plug is formed in place, fracturing fluid and fracturing sand continue to be supplied to the fracturing fluid mixing mechanism 303, and the proportion of adhesive is increased to improve the viscosity of the mixed fracturing sand, which is beneficial to the continued development of complex fracture networks.

[0086] Step 260: When a complex fracture network begins to form in the far well zone, the fracturing fluid device 300 is controlled to increase the viscosity of the fracturing fluid and the proportion of fracturing sand in a stepwise manner. When the preset maximum viscosity and preset maximum sand quantity are reached, the fracturing fluid device 300 is controlled to provide fracturing sand at a constant viscosity and constant sand ratio until the fracturing operation is completed.

[0087] It is important to note that the "far-well zone" refers to a location more than 20 meters away from the wellhead of the fractured well 700. A complex fracture network refers to fractures with an observed acoustic emission event rate of 5 times per cubic meter. Furthermore, the formation of a complex fracture network in the far-well zone can be observed and determined using inter-well microseismic data. If observation indicates the formation of a complex fracture network in the far-well zone, the ratio of the fracturing fluid to the fracturing sand is increased in a stepwise manner to promote the extension of the complex fractures. When the mixing ratio of the fracturing fluid and fracturing sand reaches its maximum, a high-viscosity, high-sand-ratio fracturing fluid is injected in a follow-up manner to create support in the main fractures of the near-well zone. Additionally, when one fractured well 700 completes fracturing operations in the target layer, while the other fractured well 700 has not, the flow rate is entirely injected into the incomplete fracturing well 700 via the diversion valve device 600. At this point, the injection flow rate into the completed fracturing well 700 is 0, entering the stage of fracturing completion and flowback. The other fractured well 700 continues fracturing until it is complete.

[0088] See Figure 6 In the sixth embodiment of the present invention, the sand-liquid mixing mechanism 303 and the diversion valve device 600 in the sand-liquid device 300 are both at least two. One sand-liquid mixing mechanism 303 is connected to several first pump truck units 411 in the pump truck device 400, and the other sand-liquid mixing mechanism 303 is connected to several second pump truck units 412 in the pump truck device 400. At least two diversion valve devices 600 are arranged in parallel on the downstream pipeline 502. The inlet of one diversion valve device 600 is connected to several first pump truck units 411, and the two outlets formed are used to respectively connect one to the other. The fracturing fluid is directed to the first fracturing well 701 and the second fracturing well 702. The inlet of another diversion valve device 600 is connected to several second pump truck units 412, and the two outlets formed are used to guide the fracturing fluid to the first fracturing well 701 and the second fracturing well 702 respectively. This ensures that the material flowing from the two outlets of the diversion valve device 600 connected to the several first pump truck units 411 originates from a sand-fluid mixing mechanism 303, and the material flowing from the two outlets of the diversion valve device 600 connected to the several second pump truck units 412 originates from another sand-fluid mixing mechanism 303. Based on the above-mentioned fracturing diversion control system, in step 250, when the fracturing fluid forms a low-viscosity slickwater pre-slug in the fracturing well 700, controlling the sand-fluid device 300 to provide fracturing sand fluid at a third viscosity includes:

[0089] When the fracturing fluid forms a low-viscosity slickwater pre-slug in the fracturing well 700, one of the sand-fluid mixing mechanisms 303 is controlled to provide fracturing fluid of a fourth viscosity, and another sand-fluid mixing mechanism 303 is controlled to provide fracturing sand fluid of a fifth viscosity. The flow ratio of the diversion valve device 600 corresponding to the fracturing sand fluid is adjusted to form a pulsed alternating injection of fracturing sand fluid in the first fracturing well 701 and the second fracturing well 702. The fourth viscosity is between the second viscosity and the first viscosity, and the fifth viscosity is less than the fourth viscosity.

[0090] One of the fracturing fluid mixing mechanisms 303 is used to provide fracturing fluid of the fourth viscosity, and can inject medium-viscosity fracturing fluid into the first fracturing well 701 and the second fracturing well 702 through the corresponding diversion valve device 600. The diversion ratio of this diversion valve device 600 can be a fixed value. The other fracturing fluid mixing mechanism 303 is used to provide fracturing fluid of the fifth viscosity, and the diversion ratio of the corresponding diversion valve device 600 can be adjusted so that low-viscosity fracturing fluid with sand bands can be injected into the first fracturing well 701 and the second fracturing well 702 in a pulsed alternating manner. This allows each fracturing well 700 to inject a larger flow rate of fracturing fluid within a certain pulse cycle, so as to promote the continued development of complex fractures.

[0091] Specifically, the flow ratio of the diversion valve device 600 corresponding to the fracturing sand fluid can be determined according to η. 2_1 and η 2_2 Periodic adjustments are made alternately in sequence, η 2_1 η represents the split ratio during the time period t1-t2. 2_2 This represents the split ratio during the time period t2-t3, and in terms of η 2_1 During flow distribution, the flow rate of fracturing sand injected into the first fracturing well 701 is much greater than the flow rate of fracturing sand injected into the second fracturing well 702, with η 2_2 When allocating flow rates, the flow rate of fracturing fluid injected into the second fracturing well 702 is much greater than the flow rate of fracturing fluid injected into the first fracturing well 701, for example: η 2_1 It can be 9:1, η 2_2 It can be 1:9.

[0092] In this embodiment of the invention, the controller is further configured to:

[0093] Step 300: Receive asynchronous fracturing mode command.

[0094] Specifically, the control device also includes a remote control or a display. The remote control or display is communicatively connected to the controller and has an asynchronous fracturing mode selection button to send asynchronous fracturing mode commands to the controller. It should be noted that before issuing the asynchronous fracturing mode command, the perforation operation of the first formation of the first fracturing well 701 must be completed first to facilitate subsequent fracturing operations.

[0095] Step 310: Start the sand-fluid control device 300, pump truck device 400 and diversion valve device 600, wherein the diversion valve device 600 is configured to perform fracturing operation on the first formation of the first fracturing well 701 at full flow.

[0096] Furthermore, the fracturing fluid control unit 300 provides viscous fracturing fluid, the pump truck unit 400 is started at maximum displacement, and the flow diversion valve unit 600 distributes all flow to the first fracturing well 701, with no flow injected into the second fracturing well 702, to quickly complete the fracturing operation on the first formation of the first fracturing well 701. It should be noted that while the system is fracturing the first formation of the first fracturing well 701, perforation operations can be simultaneously performed on the first formation of the second fracturing well 702.

[0097] Step 320: After the fracturing operation of the first formation in the first fracturing well 701 is completed, the diversion valve device 600 is controlled to perform fracturing operation on the first formation of the second fracturing well 702 at full flow.

[0098] Furthermore, after the fracturing operation of the first formation in the first fracturing well 701 is completed, the sand-fluid device 300 continues to supply viscous fracturing sand fluid, and the pump truck device 400 is started at maximum displacement. Simultaneously, the flow ratio of the diversion valve device 600 is adjusted so that all flow is allocated to the second fracturing well 702, with no flow injected into the first fracturing well 701, thereby quickly completing the fracturing operation of the first formation in the second fracturing well 702. It should be noted that while the system is fracturing the first formation in the second fracturing well 702, it can simultaneously perform perforation operations on the second formation in the first fracturing well 701, and change the target fracturing layer of the first fracturing well 701 to the second formation.

[0099] Step 330: After the fracturing operation of the first formation in the second fracturing well 702 is completed, the diversion valve device 600 is controlled to perform fracturing operation on the second formation of the first fracturing well 701 at full flow.

[0100] More specifically, after the fracturing operation of the first formation in the second fracturing well 702 is completed, the sand-fluid device 300 continues to supply viscous fracturing sand fluid, and the pump truck device 400 is started at maximum displacement. Simultaneously, the flow ratio of the diversion valve device 600 is adjusted so that all flow is allocated to the first fracturing well 701, with no flow injected into the second fracturing well 702, thereby quickly completing the fracturing operation of the second formation in the first fracturing well 701. It should be noted that while the system is fracturing the second formation in the first fracturing well 701, it can simultaneously perform perforation operations on the second formation in the second fracturing well 702, and change the target fracturing layer of the second fracturing well 702 to the second formation.

[0101] Step 340: Repeat the above operation until the fracturing operation of the first fracturing well 701 and the second fracturing well 702 in different formations is completed.

[0102] Therefore, while the flow rate is switched to the target layer of the first fracturing well 701 for fracturing, the target layer of the second fracturing well 702 is perforated and awaits fracturing. After the target layer of the first fracturing well 701 is fracturing, the flow rate is switched back to the second fracturing well 702 to fracturing the target layer of the second fracturing well 702. At the same time, the first fracturing well 701 changes its target layer perforation and awaits fracturing. This cycle is repeated, thus enabling seamless flow rate switching in the zipper-type asynchronous fracturing process. It eliminates the long waiting time of the traditional setting-perforation-pump start-fracturing-pump stop-change of target layer-resetting-perforation-pump start-fracturing process, avoiding the defects of pump stoppage during perforation and inability to perforate during fracturing. This significantly reduces fracturing time and saves fracturing costs.

[0103] In embodiments of the present invention, such as Figure 4 As shown, in the fracturing diversion control system for fracturing operations on three fracturing wells 700, one of the fracturing wells 700 can be used as a wellhead venting device. In the event of a fracturing accident, the safety of the fracturing equipment can be ensured. For example, if the formation cannot be fractured, causing the wellhead and bottomhole equipment to suddenly bear high pressure that is about to exceed the allowable pressure limit, or if any form of fluid is ejected from the high-pressure pipeline due to the accident, and the pump unit 410 cannot be shut down to reduce pressure suddenly, the fracturing sand fluid can be switched to the wellhead venting device by controlling the diversion valve device to vent, preventing the wellhead and bottomhole equipment from bursting, or the ejected high-pressure fracturing fluid from hitting on-site personnel and equipment, thus ensuring fracturing safety.

[0104] Please see again Figure 7 and Figure 8In this embodiment of the invention, the diversion housing 100 includes an inlet valve pipe section 110, a valve cavity section 120, and an outlet valve pipe section 130 connected in sequence. The inlet valve pipe section 110 forms an inlet valve channel 111, and the outlet valve pipe section 130 forms a first outlet valve channel 131 and a second outlet valve channel 132 that are spaced apart. The valve cavity section 120 forms a valve core drive cavity 121, and the first end of the valve core drive cavity 121 is connected to the inlet valve channel 111, and the second end is connected to the first outlet valve channel 131 and the second outlet valve channel 132 respectively.

[0105] The valve core drive mechanism 200 includes a valve core assembly 201 and a drive member. The valve core assembly 201 is rotatably disposed in the valve core drive cavity 121 and forms a first valve core channel 202 and a second valve core channel 203 spaced apart. The first valve core channel 202 and the second valve core channel 203 both extend along the length direction of the valve core drive cavity 121. The first valve core channel 202 is used to connect the inlet valve channel 111 and the first outlet valve channel 131 to form a first diversion channel. The second valve core channel 203 is used to connect the inlet valve channel 111 and the second outlet valve channel 132 to form a second diversion channel. The drive member is used to drive the valve core assembly 201 to rotate so as to adjust the flow rate of the first diversion channel and the second diversion channel.

[0106] In the above technical solution, since it includes a flow divider housing 100 and a valve core drive mechanism 200, the inlet valve pipe section 110 of the flow divider housing 100 forms an inlet valve channel 111, and the outlet valve pipe section 130 forms a first outlet valve channel 131 and a second outlet valve channel 132 spaced apart. The valve cavity section 120 located between the inlet valve pipe section 110 and the outlet valve pipe section 130 forms a valve core drive cavity 121, and the valve core drive cavity 121 connects the inlet valve channel 111 and the two outlet valve channels. The valve core assembly 201 of the valve core drive mechanism 200 is rotatably disposed in the valve core drive cavity 121 and forms a first valve core channel 202 and a second valve core channel 203 spaced apart. The first valve core channel 202 is used to connect the inlet valve channel 111 and the first outlet valve channel 131 to form a first flow divider channel. The second valve core channel 203 is used to connect the inlet valve channel 111 and the second outlet valve channel 132 to form a second diversion channel. The driving component can drive the valve core assembly 201 to rotate. The rotation of the valve core assembly 201 can change the position of the first valve core channel 202 and the second valve core channel 203, thereby adjusting the flow rate of the first diversion channel and the second diversion channel. Thus, a fracturing system can distribute the fracturing flow rate to different fracturing wells through the diversion valve device, so that when fracturing different fracturing wells simultaneously, it is not necessary to arrange the fracturing system separately for each well. In addition, the valve core drive mechanism 200 is also convenient for adjusting the fracturing flow rate of different fracturing wells, thereby achieving the purpose of reducing fracturing costs and reducing the difficulty of adjusting the fracturing flow rate.

[0107] Specifically, the two ends of the valve core assembly 201 are rotatably disposed at the two ends of the valve cavity section 120, and at least one end of the valve core assembly 201 extends out of the valve cavity section 120 and is drivenly connected to a driving member, which may be a rotary motor. Furthermore, a sealing structure is provided between the end of the valve core assembly 201 extending out of the valve cavity section 120 and the valve cavity section 120. Of course, the invention is not limited to this; the driving member may also be disposed within the valve core driving cavity 121.

[0108] See Figure 7 , Figure 8 and Figure 11 In this embodiment of the invention, the valve core assembly 201 includes a valve core body 204, a first stop body 205, and a second stop body 206. The first stop body 205 and the second stop body 206 are respectively disposed on the inner wall of the valve core drive cavity 121, spaced apart by the valve inlet channel 111, and both extend along the length direction of the valve core drive cavity 121. The valve core body 204 includes a rotating core portion 207 drivenly connected to the drive member and a spacer plate portion 208 disposed on the periphery of the rotating core portion 207. 07 is rotatably disposed in the inner ring formed by the first stop body 205 and the second stop body 206, and the periphery of the rotating core 207 is respectively attached to and abuts against the first stop body 205 and the second stop body 206 to form a valve core flow space. The partition plate 208 extends between the first stop body 205 and the second stop body 206 and is attached to and abuts against the inner wall of the valve core drive cavity 121 to divide the valve core flow space to form the first valve core channel 202 and the second valve core channel 203. The first valve core channel 202 is formed by the enclosure of the first stop body 205, the valve core body 204, the spacer plate portion 208, and the inner wall of the valve core drive cavity 121. The second valve core channel 203 is formed by the enclosure of the second stop body 206, the valve core body 204, the spacer plate portion 208, and the inner wall of the valve core drive cavity 121. The driving member can drive the spacer plate portion 208 to rotate between the first stop body 205 and the second stop body 206, so as to adjust the flow area of ​​the first valve core channel 202 and the second valve core channel 203, thereby adjusting the flow rate of the first diversion channel and the second diversion channel. Meanwhile, the first stop 205 and the second stop 206 can act as stops when the partition plate 208 rotates to two extreme positions. When the partition plate 208 rotates to the first position where it abuts against the first stop 205, the first valve core channel 202 is closed and the second valve core channel 203 is fully open. Correspondingly, the first diversion channel is closed and the flow rate is 0, while the second diversion channel is fully open and the flow rate reaches its maximum. When the partition plate 208 rotates to the second position where it abuts against the second stop 206, the second valve core channel 203 is closed and the first valve core channel 202 is fully open. Correspondingly, the second diversion channel is closed and the flow rate is 0, while the first diversion channel is fully open and the flow rate reaches its maximum.

[0109] Specifically, the rotating core 207 can be cylindrical, and the sides of the first stop 205 and the second stop 206 facing the rotating core 207 are located on the same circumference. The circumference of the cylindrical rotating core 207 is circumferentially fitted to the first stop 205 and the second stop 206, respectively. Meanwhile, a shaft mounting hole 209 is provided through the axis of the rotating core 207. The driving shaft passes through the shaft mounting hole 209, with both ends extending out of the rotating core 207 and rotatably positioned at both ends of the valve cavity section 120. At least one end of the driving shaft extends out of the valve cavity section 120 and is drivenly connected to the driving component.

[0110] Of course, the present invention is not limited to this. The valve core body 204 does not need to be provided with a partition plate portion 208. The first valve core channel 202 and the second valve core channel 203 on the valve core assembly 201 can also be directly opened on the valve core body 204. That is, the flow area of ​​the first valve core channel 202 and the second valve core channel 203 themselves is not variable. The driving member drives the valve core body 204 to rotate. It can rotate to a third position where the first valve core channel 202 is blocked and closed by the solid part of the valve inlet pipe section 110, and the second valve core channel 203 is fully open and connected to the valve inlet channel 111. It can also rotate to a fourth position where the second valve core channel 203 is blocked and closed by the solid part of the valve inlet pipe section 110, and the first valve core channel 202 is fully open and connected to the valve inlet channel 111. Thus, the flow rate of the first diversion channel and the second diversion channel can also be adjusted.

[0111] like Figure 11 and Figure 13As shown, in this embodiment of the invention, at least one of the first stop body 205 and the second stop body 206 is slidably connected to the inner wall of the valve core drive cavity 121 via a T-shaped tenon and mortise joint, so that the corresponding stop body can be axially pushed into or pulled out of the valve core drive cavity 121. By slidably connecting the first stop body 205 or the second stop body 206 to the inner wall of the valve core drive cavity 121 via a T-shaped tenon and mortise joint, it is convenient to assemble or disassemble the first stop body 205 or the second stop body 206 on the inner wall of the valve core drive cavity. Specifically, the T-shaped tenon and mortise connection structure is located on the side of the first stop 205 or the second stop 206 away from the partition plate 208. The T-shaped tenon and mortise connection structure includes a T-shaped mortise 122 and a T-shaped tenon 210. The T-shaped mortise 122 is located on the inner wall of the valve cavity drive chamber, and the T-shaped tenon 210 is located on the side of the first stop 205 or the second stop 206 away from the partition plate 208. When connecting the first stop 205 or the second stop 206 to the inner wall of the valve cavity drive chamber, the T-shaped tenon 210 is aligned with the T-shaped mortise 122 and pushed. Meanwhile, both the first stop body 205 and the second stop body 206 have T-shaped tenons 210 on the side opposite to the partition plate portion 208. Correspondingly, two T-shaped tenons 122 are formed on the inner wall of the valve chamber drive cavity for the T-shaped tenons 210 of the first stop body 205 and the second stop body 206 to be installed one-to-one. Of course, the present invention is not limited to this, and the first stop body 205 and the second stop body 206 can also be fixedly connected to the inner wall of the valve chamber drive cavity by threaded parts.

[0112] Please see again Figure 11 In this embodiment of the invention, both the first stop body 205 and the second stop body 206 include a fixing part 211 disposed on the inner wall of the valve core driving cavity 121 and an abutment part 212 detachably disposed on the side of the fixing part 211 facing the partition plate part 208. That is, the abutment part 212 serves to stop the partition plate part 208. During the abutment and stopping process, the abutment part 212 is prone to wear. By detachably disposing it on the fixing part 211, it is easy to replace the abutment part 212.

[0113] See Figure 11 and Figure 12In this embodiment of the invention, the cross-sections of the valve core flow space and the spacer plate portion 208 along the direction from the inlet valve section 110 to the outlet valve section 130 are both fan-shaped and annular, with the cross-sectional areas increasing progressively. Setting the cross-section of the valve core flow space as fan-shaped means that the outer wall of the rotating core portion 207 enclosing the valve core flow space and the inner wall of the valve core drive cavity 121 can both be circumferential surfaces. This facilitates standardized production of the rotating core portion 207 of the valve core body 204 and the inner wall of the valve core drive cavity 121. Simultaneously, the progressively increasing cross-sectional area of ​​the valve core flow space, where the first and second stop plates form the inner wall of the valve core flow space on one side, ensures the smooth flow of fracturing sand fluid within the first valve core channel 202 and the second valve core channel 203. This also better accommodates the design where the inlet valve section 110 has only one inlet valve channel 111, while the outlet valve pipe has two outlet valve channels, providing sufficient dimensions for the flow area design of the two outlet valve channels. Furthermore, by setting the cross-section of the partition plate portion 208 to a fan-shaped annular shape, the cross-sectional shape of the first valve core channel 202 and the second valve core channel 203 can also be fan-shaped annular, which facilitates the control of the flow area ratio of the first valve core channel 202 and the second valve core channel 203. In addition, by setting the cross-sectional area of ​​the partition plate portion 208 to increase incrementally, the channel opening size at the rear end of the first valve core channel 202 and the second valve core channel 203 can be avoided from being too large.

[0114] like Figures 8 to 12As shown, in this embodiment of the invention, the inlet valve pipe section 110 includes an inlet valve end cap 112 detachably connected to the valve cavity section 120, and an inlet valve pipe body 113 disposed on the side of the inlet valve end cap 112 away from the valve cavity section 120. The inlet valve channel 111 extends from the inlet valve pipe body 113 through the inlet valve end cap 112 and is arranged in a gradually expanding manner. The shape of the channel opening of the inlet valve channel 111 transitions from a circle to a fan-shaped annulus in the direction along the inlet valve pipe body 113 toward the inlet valve end cap 112, that is, the inlet valve pipe body 113 is away from the inlet valve. The opening shape of the channel at one end of the end cap 112 can be circular, which facilitates the docking of the valve inlet pipe body 113 with the upstream pipeline device. The opening shape of the valve inlet channel 111 on the valve inlet end cap 112 can be fan-shaped, which allows for better communication with the downstream first valve core channel 202 and second valve core channel 203. Furthermore, the valve inlet channel 111 is arranged in a gradually expanding manner along the flow direction of the fracturing sand fluid, which can ensure the smooth flow of the fracturing sand fluid in the valve inlet channel 111. At the same time, the first stop body 205 and the second stop body 206 are respectively arranged on opposite sides of the valve inlet channel 111 in the circumferential direction, and their ends are fitted to the inner side of the valve inlet end cap 112. The first stop body 205 and the second stop body 206 also have the solid part of the valve inlet end cap 112 between them and the inner wall of the valve inlet channel 111. When it is necessary to close the first diversion channel and fully open the second diversion channel, the partition plate 208 can be driven to rotate between the first stop 205 and the inner wall of the inlet valve channel 111. Since the solid part of the inlet valve end cap 112 is still left at this position, the partition plate 208 can abut against the first stop 205 on the first plate side and against the inlet valve end cap 112 at the end, so as to ensure the stability of the closure of the first diversion channel. When it is necessary to close the second diversion channel and fully open the first diversion channel, the partition plate 208 can be driven to rotate between the second stop 206 and the inner wall of the inlet valve channel 111. Since the solid part of the inlet valve end cap 112 is also left at this position, the partition plate 208 can abut against the second stop 206 on the second plate side and against the inlet valve end cap 112 at the end, so as to ensure the stability of the closure of the second diversion channel.

[0115] Specifically, the valve inlet channel 111 can smoothly transition from a circular channel opening to a fan-shaped annular channel opening. That is, the inner wall of the valve inlet channel 111 has a streamlined curved surface design. During the design, the blending function in Creo software can be used to streamline the transition between two openings with different cross-sections, so that the flow channel cross-section smoothly transitions from a circle to a fan-shaped annular shape. This reduces the frictional resistance on the flow channel wall when the flow is split, preventing the wall from being eroded and failing.

[0116] like Figures 13 to 15As shown, in this embodiment of the invention, the valve cavity section 120 and the valve outlet pipe section 130 are integrally formed. The first valve outlet channel 131 and the second valve outlet channel 132 both extend from the valve outlet pipe section 130 through the end of the valve cavity section 120 and are respectively connected to the valve core drive cavity 121. That is, the first valve outlet channel 131 and the second valve outlet channel 132 each include a first section on the valve outlet pipe section 130 and a second section at the end of the valve cavity section 120. The first valve outlet channel 131 and the second valve outlet channel 132 are both gradually tapering in the direction from the valve cavity section 120 toward the valve outlet pipe section 130, and the shape of the channel openings transitions from a fan-shaped annulus to a circle. The two channel openings at the end furthest from the valve cavity section 120 can both be circular, which facilitates the connection of the first valve outlet channel 131 and the second valve outlet channel 132 of the valve outlet pipe section 130 with the downstream manifold. The channel openings of the first valve outlet channel 131 and the second valve outlet channel 132 on the valve cavity section 120 can be fan-shaped, which allows for better communication with the upstream first valve core channel 202 and the second valve core channel 203. Furthermore, the first valve outlet channel 131 and the second valve outlet channel 132 are arranged in a gradually narrowing manner along the flow direction of the fracturing sand fluid, which can ensure the smooth flow of the fracturing sand fluid in the two valve outlet channels. Meanwhile, the inner cavity of the valve chamber section 120 has a first step portion 123 and a second step portion 124 formed between the two valve outlet channels and the valve core drive cavity 121, which are respectively fitted to the ends of the first stop body 205 and the second stop body 206. The first stop body 205 and the second stop body 206, as part of the valve core assembly 201, are placed in the valve core drive cavity 121. Furthermore, in order for the two valve core channels to be connected to the two valve outlet channels in a one-to-one correspondence, the first stop body 205 and the second stop body 206 must be… The first and second outer sides of the two valve outlet channels are respectively located on the first and second outer sides. It should be noted that the first and second outer sides of the two valve outlet channels are relative to the position between the two valve outlet channels being located on the inner side of the two valve outlet channels. Therefore, in order to achieve a one-to-one abutment between the ends of the first stop body 205 and the second stop body 206 and the first step portion 123 and the second step portion 124 respectively, the first step portion 123 and the second step portion 124 should also be correspondingly located on the first and second outer sides of the two valve outlet channels. Simultaneously, the first stop body 205 and the second stop body 206 each have a solid portion of the step portion between them and the peripheral wall of the corresponding valve outlet channel.When the first diversion channel needs to be closed and the second diversion channel needs to be fully opened, the partition plate 208 rotates to the first plate side to abut against the first stop body 205, and the front end abuts against the inlet valve end cover 112, and the rear end can also abut against the first step 123; when the second diversion channel needs to be closed and the first diversion channel needs to be fully opened, the partition plate 208 rotates to the second plate side to abut against the second stop body 206, and the front end abuts against the inlet valve end cover 112, and the rear end can also abut against the second step 124, thereby ensuring the stability of the partition plate 208 closure.

[0117] In this embodiment of the invention, the spacer plate portion 208 has a first side surface facing the first stop body 205 that abuts against the first stop body 205, and the spacer plate portion 208 has a second side surface facing the second stop body 206 that abuts against the second stop body 206. When the first side surface and the second side surface abut against the corresponding stop body, the front part near the inlet valve pipe section 110 contacts the rear part near the outlet valve pipe section 130 first, thereby preventing the proppant (fracturing sand) from clogging and accumulating, which would prevent the valve from being closed.

[0118] like Figure 12 As shown, the valve core assembly 201 has sealing grooves on the valve core body 204, the first stop body 205, and the second stop body 206. A sealing element 213 is provided in the sealing groove. The sealing groove on the valve core body 204 includes a first section that surrounds the rotating shaft mounting hole 209 on the end face of the rotating core part 207 and a second section that extends from the end face of the spacer part 208 to the periphery. The sealing grooves on the first stop body 205 and the second stop body 206 extend from their respective end faces to the periphery.

[0119] like Figure 16 As shown, in this embodiment of the invention, the outer side of the valve cavity section 120 is provided with a placement seat 125, and the placement seat 125 can be placed horizontally on the ground or on a horizontal support surface.

[0120] In embodiments of the present invention, such as Figure 17 (b) and Figure 17 As shown in (c), a replaceable guide vane is installed within the valve inlet passage 111. The replaceable guide vane can reduce turbulence and erosion of the tip of the spacer plate portion 208. Specifically, there can be multiple replaceable guide vanes, which are sequentially spaced along the extending direction of the valve inlet passage 111. Of course, the invention is not limited to this, such as... Figure 17 As shown in (a), it is also possible not to install a replaceable guide vane in the inlet valve channel 111 in order to reduce hydraulic friction.

[0121] In this embodiment of the invention, the tip (the side facing the valve inlet channel 111) and the side of the spacer plate portion 208 of the valve core body 204 are both replaceable structures, that is, the valve core body 204 is provided in separate parts, and the corresponding parts can be replaced after being eroded and worn, such as... Figure 18 As shown, there are multiple ways to implement a replaceable structure.

[0122] The fracturing diversion control system provided by this invention mainly relies on a cascaded system design of multiple pump pipelines, with the selection made according to site conditions. When a single diversion system strategy is selected, the flow of multiple wells can be diverted by controlling only a single diversion valve device. This approach is simple in structure, easy to maintain, and highly reliable. However, in this state, the single diversion valve device needs to withstand the flow of all pumps, placing high demands on the erosion and structural strength of the diversion valve device. When a cascaded structure of multiple diversion valve devices is selected, the flow and pressure of a single diversion valve device can be reduced by arranging multiple diversion valve devices, thereby reducing the erosion of the diversion valve device. The allowable structural strength requirements of the pumps can be appropriately reduced, increasing the pump's applicability and safety. Real-time diversion of flow from multiple wells can also be achieved through joint control of the diversion states of multiple pumps. Furthermore, by changing the arrangement of the diversion valve devices—from placing them downstream of the pump truck at the high-pressure end to upstream at the low-pressure end—the pressure that the pumps need to withstand can be further reduced, thereby improving safety and operational reliability.

[0123] Due to the heterogeneity of the formation, fracture propagation rates are uneven. When one well encounters pressure buildup and fractures cannot propagate, while another well's fractures extend normally, or when the fracture rupture / prolongation pressure in one well is greater than in another, without intervention, the fractures in the easily ruptured well will continue to extend, while those in the difficult-to-propagate wells will stop propagating, ultimately resulting in asynchronous fracturing. Therefore, during synchronous fracturing, if a well is detected to be unable to propagate due to increased fracture rupture / prolongation pressure, a multi-valve control system in a multi-flow system can allocate a larger flow rate to that well. The pressure buildup generated by the high flow rate can instantly increase the pressure within the fracture, causing the difficult-to-rupture fractures to continue propagating. Finally, by controlling the flow rate of the flow distribution system through wellhead pressure feedback, rapid and real-time switching of flow rates between wells can be achieved, enabling synchronous fracturing of multiple wells.

[0124] In the synchronous fracturing process: the fracture propagation morphology can be controlled by changing the composition of the fracturing fluid. High-viscosity, high-volume fracturing fluid is used near the wellbore to form a high-volume, high-viscosity pre-slug, allowing the fracture to expand rapidly near the wellbore, reducing contact time with the formation, and minimizing near-wellbore leakage through high viscosity. The extent of fracture extension in each well is dynamically controlled through a diversion system. Once the fracture reaches the far-wellbore area, the fracturing fluid viscosity is reduced to form a low-viscosity slickwater pre-slug, increasing leakage, forming hydration microfractures, and promoting the generation and initiation of network fractures. Simultaneously, pulsed proppant injection prevents near-wellbore sand blockage. During pulsed proppant injection, a high-concentration proppant diversion valve is used to pulse-adjust the proppant injection rate in each well. Simultaneously, a pure fluid diversion valve is used to pulse-adjust the fluid volume in the opposite direction, ensuring that the total fluid inflow into each well remains constant while the proppant volume is pulsed, thus achieving pulsed proppant injection. Later, the fracture network in the distal well zone is controlled to extend further, i.e., the fracturing fluid viscosity and proppant concentration are increased in a stepwise manner. When fracture propagation is uneven, the flow rate diversion ratio of each well is adjusted in real time. Fluid injection is given to wells with difficult fracture propagation to create pressure and generate fractures, while the fluid volume is appropriately reduced for wells with easily propagating fractures. Ultimately, the fracture control rates of the two wells are controlled to be comparable, achieving synchronous fracturing (fracture network propagation rate can be observed and judged through inter-well microseismic data).

[0125] Furthermore, as can be seen from the structure of the diversion valve device of the present invention, the internal cavity of the diversion valve structure has a streamlined feature, which is fully adapted to the diversion of fracturing fluid under special conditions such as high pressure, high speed, and proppant carrying during synchronous fracturing. The main principle is that, under high pressure, high speed, and proppant carrying conditions, depending on the design fluid Reynolds number, one, two, or more streamlined guide vanes are placed in the inlet, which can achieve two effects: first, to keep the fluid in a laminar state as much as possible, reducing the turbulence or flow disturbance formed by the boundary layer at the bottom of the inlet, thereby reducing the cavitation and erosion of the diversion valve device by the fluid; second, to add one or more stages of guide vanes in front of the high-speed erosion zone at the valve tip to withstand the erosion, so that the guide vanes replace the valve tip in bearing the erosion. High-speed fluid erosion reduces the frequency of valve tip replacement, and the replacement cost of the guide vane after erosion is much lower than that of the valve tip, thus reducing equipment maintenance costs. When the flow rate is low, the guide vane can be omitted, reducing friction. The inlet flow channel gradually transitions from a circular tube to a fan shape, connecting with the lower valve cavity flow channel to avoid the formation of eddies due to uneven flow at the connection, reducing erosion of the equipment. In the diversion channel, the traditional method of changing the flow channel of butterfly valves or needle valves is replaced with a large contact surface that matches the sloping curved sidewall of the valve cavity. This structure makes the flow channel smooth, adapts to the diversion of high-speed and high-pressure fluids, significantly reduces the lateral bearing torque, and reduces the erosion of the valve by high-speed fluid. Furthermore, the design incorporates a structure where the valve tip engages with the sidewall before the bottom, preventing sand blockage and ensuring proper closure. The principle is as follows: if the bottom of the valve engages with the sidewall before the tip, the fracturing fluid carrying sand that hasn't yet flowed out will gradually accumulate in the space between the valve sidewall and the valve cavity sidewall due to inertia. High-pressure, high-speed sand will become stuck at the bottom of the valve, preventing closure. However, if the valve tip engages with the sidewall before the bottom, the fluid supply to that side channel can be quickly cut off, closing the channel. Simultaneously, any sand that hasn't yet flowed out can be expelled by inertia. Even if some sand remains in the channel, the sand at the top of the channel will be eliminated. The supply of sand has been cut off, and the diversion valve is no longer continuously supplied, yet its closure remains effective. Furthermore, the specially designed structure with different contact sequences prevents the entire valve's sidewall and the valve cavity's sloping curved surface from completely fitting together, creating a huge negative pressure that makes the valve difficult to rotate again, resulting in negative pressure self-locking. Therefore, this structure has the advantage of avoiding negative pressure self-locking. Additionally, the structure of this invention ensures that the reliability of the diversion is maintained even when the valve's sidewall is partially eroded and worn. This is because the sidewall of this structure is a curved surface; when any part of the curved surface can close, the diversion valve effectively closes the fluid in that path. Therefore, even if part of the structure is worn due to erosion, it does not affect the overall sealing performance.

[0126] In the description of this invention, it should be understood that the terms "first" and "second" are used for descriptive purposes only and should not be construed as indicating or implying relative importance or implicitly specifying the number of indicated technical features. Therefore, a feature defined as "first" or "second" may explicitly or implicitly include at least one of that feature. In the description of this invention, "a plurality of" means at least two, such as two, three, etc., unless otherwise explicitly specified.

[0127] In this invention, unless otherwise explicitly specified and limited, the terms "installation," "connection," "linking," and "fixing," etc., should be interpreted broadly. For example, they can refer to a fixed connection, a detachable connection, or an integral part; they can refer to a mechanical connection, an electrical connection, or a connection that allows communication between them; they can refer to a direct connection or an indirect connection through an intermediate medium; they can refer to the internal communication of two components or the interaction between two components, unless otherwise explicitly limited. Those skilled in the art can understand the specific meaning of the above terms in this invention according to the specific circumstances.

[0128] In the description of this specification, the references to terms such as "one embodiment," "some embodiments," "example," "specific example," or "some examples," etc., indicate that a specific feature, structure, material, or characteristic described in connection with that embodiment or example is included in at least one embodiment or example of the present invention. In this specification, the illustrative expressions of the above terms do not necessarily refer to the same embodiment or example. Furthermore, the specific features, structures, materials, or characteristics described may be combined in any suitable manner in one or more embodiments or examples. Moreover, without contradiction, those skilled in the art can combine and integrate the different embodiments or examples described in this specification, as well as the features of different embodiments or examples.

[0129] Although embodiments of the present invention have been shown and described above, it is understood that the above embodiments are exemplary and should not be construed as limiting the present invention. Those skilled in the art can make changes, modifications, substitutions and variations to the above embodiments within the scope of the present invention.

Claims

1. A fracturing diversion control system, characterized in that, The fracturing diversion control system includes: A fracturing fluid supply unit (300) is used to supply fracturing fluid; The pump truck unit (400) includes multiple pump truck units (410) arranged in parallel. The pipeline assembly (500) includes an upstream pipeline (501) for directing fracturing sand provided by the sand-fracturing unit (300) to a plurality of the pump truck units (410), and a downstream pipeline (502) for directing fracturing sand pumped out by the plurality of the pump truck units (410) to different fracturing wells (700). A diversion valve device (600) is provided on the upstream pipeline (501) or the downstream pipeline (502) and configured to distribute flow to different fracturing wells (700); The control device includes a controller and a fracturing detection component. The fracturing detection component is used to detect the fracturing status of different fracturing wells (700). The controller is communicatively connected to the diversion valve device (600) and the fracturing detection component, and is configured to control the diversion valve device (600) to distribute flow according to the fracturing status detected by the fracturing detection component. The diversion valve device (600) includes a diversion housing (100) and a valve core drive mechanism (200). The diversion housing (100) forms an inlet valve channel (111), a valve core drive cavity (121), a first outlet valve channel (131), and a second outlet valve channel (132). The inlet valve channel (111) is located at the upstream end of the valve core drive cavity (121). The first outlet valve channel (131) and the second outlet valve channel (132) are bifurcated at the downstream end of the valve core drive cavity (121). The first outlet valve channel (131) and the second outlet valve channel (132) are respectively located on the paths leading to different fracturing wells (700). The valve core drive mechanism (200) is movably located in the valve core drive cavity (121) and is used to adjust the diversion ratio of the first outlet valve channel (131) and the second outlet valve channel (132). The valve core drive mechanism (200) includes a valve core assembly (201) and a drive member. The valve core assembly (201) is rotatably disposed in the valve core drive cavity (121) and forms a first valve core channel (202) and a second valve core channel (203) spaced apart. The first valve core channel (202) and the second valve core channel (203) both extend along the length direction of the valve core drive cavity (121). The first valve core channel (202) is used to connect the inlet valve channel (111) and the first outlet valve channel (131) to form a first flow channel. The second valve core channel (203) is used to connect the inlet valve channel (111) and the second outlet valve channel (132) to form a second flow channel. The drive member is used to drive the valve core assembly (201) to rotate so as to adjust the flow rate of the first flow channel and the second flow channel. The valve core assembly (201) includes a valve core body (204), a first stop body (205), and a second stop body (206). The first stop body (205) and the second stop body (206) are respectively disposed on the inner wall of the valve core drive cavity (121) with respect to the valve inlet channel (111), and both extend along the length direction of the valve core drive cavity (121). The valve core body (204) includes a rotating core part (207) that is driven and connected to the drive member, and a spacer plate part (208) disposed on the periphery of the rotating core part (207). The rotating core part (207) is rotatable. The rotating core (207) is dynamically disposed in the inner ring formed by the first stop (205) and the second stop (206), and the periphery of the rotating core (207) is respectively attached to and abuts against the first stop (205) and the second stop (206) to form a valve core flow space. The spacer plate (208) extends between the first stop (205) and the second stop (206) and is attached to and abuts against the inner wall of the valve core drive cavity (121) to divide the valve core flow space to form the first valve core channel (202) and the second valve core channel (203).

2. The fracturing diversion control system according to claim 1, characterized in that, The control device further includes a flow detection component for detecting the flow rates of the first outlet valve channel (131) and the second outlet valve channel (132) respectively. The controller is communicatively connected to the flow detection component and is further configured to: The synchronous fracturing flow rate of different fracturing wells (700) is determined based on the fracturing conditions detected by the fracturing detection component. The simultaneous fracturing flow rate is determined based on the simultaneous fracturing flow rate. The valve core drive mechanism (200) is controlled to adjust the flow ratio of the first outlet valve channel (131) and the second outlet valve channel (132) to the synchronous fracturing flow ratio; Receive the flow rate data detected by the flow detection component; If the synchronous fracturing flow rate is not reached based on the flow rate data, the valve core drive mechanism (200) is controlled to correct the synchronous fracturing flow ratio.

3. The fracturing diversion control system according to claim 1, characterized in that, The controller is further configured to: Receive synchronous fracturing mode commands; The control sand-fracturing device (300), pump truck device (400) and diversion valve device (600) are started, wherein the sand-fracturing device (300) is configured to provide fracturing sand-fracturing fluid at a first viscosity, and the diversion valve device (600) is configured to distribute the flow rate according to an initial diversion ratio; Receive the fracturing status detected by the fracturing detection component; The flow distribution device (600) is controlled according to the fracturing situation to distribute the flow so that different fracturing wells (700) are in the same fracture development morphology; In the case where the fracturing sand fluid forms a high-viscosity pre-plug in the fracturing well (700), the sand fluid control device (300) provides the fracturing fluid at a second viscosity, wherein the second viscosity is less than the first viscosity; When the fracturing fluid forms a low-viscosity slickwater pre-plug in the fracturing well (700), the fracturing fluid control device (300) provides fracturing fluid at a third viscosity, wherein the third viscosity is between the second viscosity and the first viscosity; When a complex fracture network begins to form in the far well zone, the fracturing fluid control device (300) increases the viscosity of the fracturing fluid and the proportion of fracturing sand in a stepwise manner, and when the preset maximum viscosity and preset maximum sand quantity are reached, the fracturing fluid control device (300) provides fracturing fluid with constant viscosity and constant proportion of fracturing fluid until the fracturing operation is completed.

4. The fracturing diversion control system according to claim 3, characterized in that, The sand-liquid mixing mechanism (303) and the diversion valve device (600) in the sand-liquid device (300) are both at least two in number. One of the sand-liquid mixing mechanisms (303) is connected to several first pump truck units (411) in the pump truck device (400), and the other sand-liquid mixing mechanism (303) is connected to several second pump truck units (412) in the pump truck device (400). At least two diversion valve devices (600) are arranged in parallel on the downstream pipeline (502). On the pump truck, the inlet of one of the diversion valve devices (600) is connected to several of the first pump truck units (411), and the two outlets formed are used to guide the first fracturing well (701) and the second fracturing well (702) respectively. The inlet of the other diversion valve device (600) is connected to several of the second pump truck units (412), and the two outlets formed are used to guide the first fracturing well (701) and the second fracturing well (702) respectively. In the case where the fracturing fluid forms a low-viscosity slickwater pre-slug in the fracturing well (700), the fracturing fluid control device (300) supplies fracturing fluid at a third viscosity, including: When the fracturing fluid forms a low-viscosity slickwater pre-slug in the fracturing well (700), one of the sand-fluid mixing mechanisms (303) is controlled to provide fracturing fluid of a fourth viscosity, and the other sand-fluid mixing mechanism (303) is controlled to provide fracturing sand fluid of a fifth viscosity. The diversion ratio of the diversion valve device (600) corresponding to the fracturing sand fluid is adjusted to form a pulsed alternating injection of fracturing sand fluid in the first fracturing well (701) and the second fracturing well (702), wherein the fourth viscosity is between the second viscosity and the first viscosity, and the fifth viscosity is less than the fourth viscosity.

5. The fracturing diversion control system according to claim 1, characterized in that, The controller is further configured to: Receive asynchronous fracturing mode commands; The control sand-fluid device (300), pump truck device (400) and diversion valve device (600) are started, wherein the diversion valve device (600) is configured to perform fracturing operation on the first formation of the first fracturing well (701) at full flow. After the fracturing operation of the first formation in the first fracturing well (701) is completed, the diversion valve device (600) is controlled to perform fracturing operation on the first formation of the second fracturing well (702) at full flow. After the fracturing operation of the first formation in the second fracturing well (702) is completed, the diversion valve device (600) is controlled to perform fracturing operation on the second formation of the first fracturing well (701) at full flow. Repeat the above operation until the fracturing operation of the first fracturing well (701) and the second fracturing well (702) in different formations is completed.

6. The fracturing diversion control system according to any one of claims 2 to 5, characterized in that, The flow divider housing (100) includes an inlet valve pipe section (110), a valve cavity section (120), and an outlet valve pipe section (130) connected in sequence. The inlet valve pipe section (110) forms an inlet valve channel (111), the outlet valve pipe section (130) forms a first outlet valve channel (131) and a second outlet valve channel (132) spaced apart, and the valve cavity section (120) forms a valve core drive cavity (121).

7. The fracturing diversion control system according to claim 6, characterized in that, Both the first stop body (205) and the second stop body (206) include a fixing part (211) provided on the inner wall of the valve core drive cavity (121) and an abutment part (212) detachably provided on the side of the fixing part (211) facing the spacer part (208).

8. The fracturing diversion control system according to claim 6, characterized in that, The valve core flow space and the spacer plate (208) are both arranged in a fan-shaped annular configuration in the direction from the inlet valve section (110) toward the outlet valve section (130), and the cross-sectional areas are both arranged in an increasing manner.

9. The fracturing diversion control system according to claim 8, characterized in that, The valve inlet pipe section (110) includes a valve inlet end cap (112) detachably connected to the valve cavity section (120), and a valve inlet pipe body (113) disposed on the side of the valve inlet end cap (112) facing away from the valve cavity section (120). The valve inlet channel (111) extends from the valve inlet pipe body (113) through the valve inlet end cap (112) and is gradually widened. The opening shape of the valve inlet channel (111) is along the valve inlet pipe body (113). The direction towards the valve end cover (112) transitions from a circle to a fan-shaped ring. The first stop body (205) and the second stop body (206) are respectively disposed on opposite sides of the valve inlet channel (111) along the circumferential direction, and their ends are fitted to the inner side of the valve end cover (112). The first stop body (205) and the second stop body (206) also have the solid part of the valve end cover (112) between them and the inner wall of the valve inlet channel (111). And / or, the valve cavity section (120) and the valve outlet pipe section (130) are integrally formed. The first valve outlet channel (131) and the second valve outlet channel (132) both extend from the valve outlet pipe section (130) through the end of the valve cavity section (120) and are respectively connected to the valve core drive cavity (121). The first valve outlet channel (131) and the second valve outlet channel (132) are both tapered in the direction from the valve cavity section (120) toward the valve outlet pipe section (130). Furthermore, the shape of the channel openings transitions from a fan-shaped ring to a circle. The inner cavity of the valve chamber section (120) has a first step portion (123) and a second step portion (124) formed between the two valve outlet channels and the valve core drive cavity (121) for correspondingly fitting with the ends of the first stop body (205) and the second stop body (206). The first stop body (205) and the second stop body (206) also have solid portions of the step portion between them and the peripheral walls of the corresponding valve outlet channels.

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