Fan-shaped well pattern fracturing simulation experiment device and method

Abstract

The application discloses a kind of fan-shaped well pattern fracturing simulation experimental device and method, the device includes: the formation simulation piece with chamber, chamber is used to cast material in, to simulate formation environment;Wellbore simulation piece group, wellbore simulation piece group at least includes first wellbore simulation piece and second wellbore simulation piece, the first end of first wellbore simulation piece and the first end of second wellbore simulation piece are located outside chamber respectively and are equipped with control valve, the second end of first wellbore simulation piece is stretched into chamber and is equipped with first perforation simulation piece, the second end of second wellbore simulation piece is stretched into chamber and passes through corresponding first perforation simulation piece, second perforation simulation piece is equipped at the second end of second wellbore simulation piece, to be used for the simulation of fan-shaped well pattern multi-stage fracturing scene.The application can simulate fan-shaped well pattern fracturing well layout truly, help the improvement and improvement of fan-shaped well pattern fracturing well layout, can provide more experimental basis and theoretical guidance for actual oilfield fracturing and research fan-shaped well pattern fracturing design.

Description

Technical Field

[0001] This invention relates to the field of rock mechanics in petroleum engineering, and in particular to a fan-shaped well network fracturing simulation experimental device and method. Background Technology

[0002] When hydraulically fracturing tight, low-permeability reservoirs such as shale, multi-stage fracturing and other production enhancement techniques are often employed. The main understanding of fracture initiation and propagation is that the principal stress direction controls the fracture direction. Therefore, in practical engineering, horizontal well networks are designed and constructed based on this understanding. These horizontal wells are parallel to each other, and then each horizontal well undergoes staged fracturing to form a complex fracture network, thereby reducing construction costs and maximizing the utilization of reservoir reserves.

[0003] Multistage fracturing in horizontal wells is one of the key technologies for the efficient development of unconventional oil and gas reservoirs. However, some well sites are limited by factors such as reservoir distribution area and environmental protection, making conventional well placement impossible. Therefore, to maximize the utilization of reserves in such reservoirs, a fan-shaped well pattern can be used to form a fracture network. However, currently, there is a lack of corresponding experimental equipment for fan-shaped well pattern placement, making it impossible to conduct experiments on fracturing using this pattern and lacking theoretical guidance for actual fracturing operations.

[0004] Therefore, based on years of experience and practice in related industries, the inventor proposes a fan-shaped well network fracturing simulation experimental device and method to overcome the shortcomings of existing technologies. Summary of the Invention

[0005] The purpose of this invention is to provide a fan-shaped well network fracturing simulation experimental device and method, which can improve and perfect the existing fan-shaped well network fracturing well layout, and can provide more experimental basis and theoretical guidance for actual oilfield fracturing and research on fan-shaped well network fracturing design.

[0006] The objective of this invention can be achieved through the following methods: This invention provides a fan-shaped well pattern fracturing simulation experimental device, the fan-shaped well pattern fracturing simulation experimental device comprising: A formation simulation component having a chamber for pouring materials to simulate a formation environment; A wellbore simulation assembly, comprising at least a first wellbore simulation component and a second wellbore simulation component, wherein the first end of the first wellbore simulation component and the first end of the second wellbore simulation component are respectively located outside the chamber and are provided with control valves, the second end of the first wellbore simulation component extends into the chamber and is provided with a first perforation simulation component, the second end of the second wellbore simulation component extends into the chamber and passes through the corresponding first perforation simulation component, and a second perforation simulation component is provided at the second end of the second wellbore simulation component, for use in simulating multi-stage fracturing scenarios of a fan-shaped well network.

[0007] In a preferred embodiment of the present invention, the number of wellbore simulation component groups is multiple, and the different wellbore simulation component groups are independent of each other.

[0008] In a preferred embodiment of the present invention, the angle between the first wellbore simulation component and the second wellbore simulation component and the direction of the maximum horizontal principal stress is preset to simulate different fan-shaped well network multi-stage fracturing scenarios.

[0009] In a preferred embodiment of the present invention, the control valve is a three-way valve having a first port, a second port, and a third port, the first port, the second port, and the third port being used to connect to the pressurization pump, the wellbore simulation assembly, and the pressure gauge, respectively.

[0010] In a preferred embodiment of the present invention, the first perforation simulation component and the second perforation simulation component are respectively formed by bonding two polytetrafluoroethylene sheets together, and the first perforation simulation component and the second perforation simulation component are respectively nested in the second end of the first wellbore simulation component and the second wellbore simulation component.

[0011] In a preferred embodiment of the present invention, the orientation of the first perforation simulator relative to the first wellbore simulator, and / or the orientation of the second perforation simulator relative to the second wellbore simulator, is adjusted to change the angle of the perforations formed by the two polytetrafluoroethylene sheets.

[0012] This invention provides a method for simulating fracturing in a sector-shaped well network, which uses the aforementioned simulation apparatus for fracturing in a sector-shaped well network. The method includes the following steps: Step S1: Apply triaxial stress confining pressure to the material poured into the formation simulation component to simulate formation pressure; Step S2: High-pressure fluid is injected sequentially into the first and second wellbore simulation components in the wellbore simulation component group to perform fracturing, so as to simulate the multi-stage fracturing scenario of a fan-shaped well network in the formation.

[0013] In a preferred embodiment of the present invention, in step S1, the wellbore simulation assembly is connected to a pressurizing pump and a pressure gauge via a control valve. The simulated formation pressure is adjusted by the cooperation of the pressurizing pump and the wellbore simulation assembly so that the simulated formation pressure is the same as the actual formation pressure.

[0014] In a preferred embodiment of the present invention, in step S2, a simultaneous fracturing method is used to simulate a multi-stage fracturing scenario of a fan-shaped well network in the formation, wherein the number of wellbore simulation components is at least two sets, and the simultaneous fracturing method includes the following steps: Step S201: Inject high-pressure fluid into the first wellbore simulation component in each of the two sets of wellbore simulation components to perform fracturing; Step S202: Collect fracturing data from the two first wellbore simulators respectively, and stop injecting high-pressure fluid into the two first wellbore simulators; Step S203: Inject high-pressure fluid into the second wellbore simulation component in each of the two sets of wellbore simulation component groups to perform fracturing; Step S204: Collect fracturing data from the two second wellbore simulators respectively, and stop injecting high-pressure fluid into the two second wellbore simulators; Step S205: Complete the multi-stage fracturing experiment simulating a fan-shaped well network in the formation using synchronous fracturing.

[0015] In a preferred embodiment of the present invention, in step S2, a zipper-type fracturing method is used to simulate a multi-stage fracturing scenario of a fan-shaped well network in the formation. The number of wellbore simulation components is at least two sets. The zipper-type fracturing method includes the following steps: Step S201': Inject high-pressure fluid into the first wellbore simulator in the first group of wellbore simulators to perform fracturing, collect fracturing data of the first wellbore simulator, and then stop injecting high-pressure fluid; Step S202': Inject high-pressure fluid into the first wellbore simulator in the second group of wellbore simulators to perform fracturing, collect fracturing data of the first wellbore simulator, and then stop injecting high-pressure fluid; Step S203': Inject high-pressure fluid into the second wellbore simulator in the first group of wellbore simulators to perform fracturing, collect fracturing data of the second wellbore simulator, and then stop injecting high-pressure fluid; Step S204': Inject high-pressure fluid into the second wellbore simulator in the second wellbore simulator group to perform fracturing, collect fracturing data of the second wellbore simulator, and then stop injecting high-pressure fluid; Step S205': Complete the multi-stage fracturing experiment simulating a fan-shaped well network in the formation using a zipper-type fracturing method.

[0016] As described above, the features and advantages of the fan-shaped well network fracturing simulation experimental device and method of the present invention are as follows: Material is poured into the cavity of the formation simulation component to simulate the formation environment. The wellbore simulation component group includes at least a first wellbore simulation component and a second wellbore simulation component. The first end of the first wellbore simulation component and the first end of the second wellbore simulation component are respectively located outside the cavity and equipped with control valves to control the injection of high-pressure fluid. The second end of the first wellbore simulation component extends into the cavity and is equipped with a first perforation simulation component. The second end of the second wellbore simulation component extends into the cavity and passes through the corresponding first perforation simulation component. A second perforation simulation component is provided at the second end of the second wellbore simulation component, thereby forming a fan-shaped well network layout to achieve a realistic simulation of a multi-stage fracturing scenario with a fan-shaped well network. This experimental device can improve and perfect the existing fan-shaped well network fracturing layout method, providing more experimental basis and theoretical guidance for actual oilfield fracturing and research on fan-shaped well network fracturing design. Attached Figure Description

[0017] The following figures are intended only to illustrate and explain the present invention and do not limit the scope of the invention. Wherein: Figure 1 This is a schematic diagram of the structure of the fan-shaped well network fracturing simulation experimental device of the present invention.

[0018] Figure 2 This is a schematic diagram of the structure of a fan-shaped well network fracturing simulation experimental device in a specific embodiment of the present invention.

[0019] Figure 3 This is one of the process flow diagrams for the fan-shaped well network fracturing simulation experiment method of the present invention.

[0020] Figure 4 This is the second process flow diagram of the fracturing simulation experiment method for the sector-shaped well network of the present invention.

[0021] Figure 5 This is the third process flow diagram of the fracturing simulation experiment method for the sector-shaped well network of the present invention.

[0022] The reference numerals in the accompanying drawings of this invention are: 1. Formation simulation component; 101. Chamber; 2. Wellbore simulation component assembly; 201. First wellbore simulation component; 202. Second wellbore simulation component; 3. Control valve; 401. First perforation simulation component; 402. Second perforation simulation component. Detailed Implementation

[0023] To provide a clearer understanding of the technical features, objectives, and effects of the present invention, specific embodiments of the present invention will now be described with reference to the accompanying drawings.

[0024] Implementation Method 1

[0025] like Figure 1 As shown, the present invention provides a fan-shaped well network fracturing simulation experimental device, which includes a formation simulation component 1 and a wellbore simulation component group 2. The formation simulation component 1 has a chamber 101, which is used to pour materials to simulate the formation environment. The wellbore simulation component group includes at least a first wellbore simulation component 201 and a second wellbore simulation component 202. The first end of the first wellbore simulation component 201 (i.e., the two ends of the first wellbore simulation component 201 are the first end and the second end, respectively) and the second wellbore simulation component 202 are... The first end of 2 (the two ends of the second wellbore simulation component 202 are the first end and the second end, respectively) is located outside the chamber 101 and is equipped with a control valve 3. The second end of the first wellbore simulation component 201 extends into the chamber 101 and is equipped with a first perforation simulation component 401. The second end of the second wellbore simulation component 202 extends into the chamber 101 and passes through the corresponding first perforation simulation component 401. A second perforation simulation component 402 is provided at the second end of the second wellbore simulation component 202 for simulating the multi-stage fracturing scenario of the fan-shaped well network.

[0026] This invention involves casting materials into the chamber 101 of a formation simulation component 1 to simulate the formation environment. The wellbore simulation component group 2 includes at least a first wellbore simulation component 201 and a second wellbore simulation component 202. The first end of the first wellbore simulation component 201 and the first end of the second wellbore simulation component 202 are located outside the chamber 101 and are equipped with control valves 3 to control the injection of high-pressure fluid. The second end of the first wellbore simulation component 201 extends into the chamber 101 and is equipped with a first perforation simulation component 401. The second end of the second wellbore simulation component 202 extends into the chamber 101 and passes through the corresponding first perforation simulation component 401. A second perforation simulation component 402 is provided at the second end of the second wellbore simulation component 202, thereby forming a fan-shaped well network layout to realistically simulate a multi-stage fracturing scenario. This experimental device can improve and perfect existing fan-shaped well network fracturing layout methods, providing more experimental basis and theoretical guidance for actual oilfield fracturing and research on fan-shaped well network fracturing design.

[0027] In an optional embodiment of the present invention, the number of wellbore simulation component groups 2 can be multiple, and different wellbore simulation component groups 2 are independent of each other. For example... Figure 1As shown, the number of wellbore simulation component groups 2 can be two. Each group of wellbore simulation component groups 2 is used to simulate a horizontal well. Each group of wellbore simulation component groups 2 includes a first wellbore simulation component 201 and a second wellbore simulation component 202. One first wellbore simulation component 201 and one second wellbore simulation component 202 in each group of wellbore simulation component groups 2 are used to simulate one horizontal well. Therefore, the first wellbore simulation component 201 and the second wellbore simulation component 2 in the two groups of wellbore simulation component groups 2 can be used to simulate two horizontal wells. Each group of wellbore simulation component groups 2 does not interfere with each other, thus enabling multi-stage fracturing according to preset experimental conditions. The number of wellbore simulation component groups 2 can be flexibly set as needed, and the specific number is not limited in this invention.

[0028] Furthermore, the first wellbore simulation component 201 and the second wellbore simulation component 202 may be made of, but are not limited to, high-pressure resistant metal capillaries.

[0029] In an optional embodiment of the present invention, the formation simulation component 1 is a prefabricated mold with a chamber 101. The material poured into the chamber 101 can be, but is not limited to, a mixture of cement, gypsum, quartz sand, and water. The mixture of cement, gypsum, quartz sand, and water is stirred and then poured into the chamber 101. The size of the formation simulation component 1 can be flexibly set according to the experimental requirements of the simulated formation. For example, it can be a square container with a length, width, and height of 300 mm. Before pouring the material into the chamber 101, the portion of the well shaft simulation component 2 that needs to be placed in the material can be placed in the chamber 101. After pouring, there is no need to perform drilling, cutting, or well-adhesion operations to place the well shaft simulation component 2, which is convenient and quick.

[0030] In an optional embodiment of the invention, such as Figure 1 As shown, the angles between the first wellbore simulator 201 and the second wellbore simulator 202 and the direction of the maximum horizontal principal stress (in this invention, the maximum horizontal principal stress refers to the maximum horizontal stress in the formation, which is the maximum stable stress in the formation) are preset to simulate different fan-shaped well network multi-stage fracturing scenarios. When arranging the first wellbore simulator 201 and the second wellbore simulator 202, it is necessary to ensure that the first wellbore simulator 201 and the second wellbore simulator 202 are not arranged perpendicular to the direction of the maximum horizontal principal stress, so that the angle between the direction of the maximum horizontal principal stress of the first wellbore simulator 201 and the second wellbore simulator 202 is not equal to 90°. During the experiment, the angles between the first wellbore simulator 201 and / or the second wellbore simulator 202 and the direction of the maximum horizontal principal stress can be changed according to the preset simulation conditions to realize the fan-shaped well network simulation.

[0031] In an optional embodiment of the present invention, the control valve 3 may be a three-way valve having a first port, a second port, and a third port. The first port, the second port, and the third port are respectively used to connect to the booster pump, the wellbore simulation assembly 2, and the pressure gauge, thereby enabling real-time control of the injection of high-pressure fluid through the booster pump and the three-way valve, and real-time monitoring of the pump injection pressure through the pressure gauge. In the present invention, the control valve 3 can be individually connected to each first wellbore simulation assembly 201 and each second wellbore simulation assembly 202, thereby enabling individual control of the pump injection for each first wellbore simulation assembly 201 and each second wellbore simulation assembly 202. The number of three-way valves can be flexibly set as needed, for example... Figure 1 There are four three-way valves. In addition, by setting the control valve 3, it can be shut off individually after the single-stage fracturing of the fan-shaped well network is completed, so as to control the first wellbore simulation component 201 or the second wellbore simulation component 202 opposite to it to stop the injection of high-pressure fluid, so as to maintain the stability of the pressure in the fracture.

[0032] In an optional embodiment of the present invention, the first perforation simulator 401 and the second perforation simulator 402 can each be formed by bonding two polytetrafluoroethylene sheets together. The first perforation simulator 401 is nested at the second end of the first wellbore simulator 201, and the second perforation simulator 402 is nested at the second end of the second wellbore simulator 202. This structure prevents materials within the formation simulator 1 from clogging the first wellbore simulator 201 and the second wellbore simulator 202, ensuring the smooth progress of the experiment.

[0033] Furthermore, by adjusting the orientation of the first perforation simulator 401 relative to the first wellbore simulator 201, and / or by adjusting the orientation of the second perforation simulator 402 relative to the second wellbore simulator 202, the angle of the perforations formed by the two polytetrafluoroethylene (PTFE) sheets can be changed, thereby controlling the injection angle of the high-pressure fluid according to actual experimental conditions. The PTFE sheets can be small-diameter circular sheets, thus reducing the perforation size and improving the utilization efficiency of the formation simulator 1. The size of the PTFE sheets can be flexibly set according to actual experimental conditions; for example, the diameter of the PTFE sheet can be 30 mm and the thickness can be 0.5 mm. Additionally, the spacing between adjacent perforation simulators 401 and 402 can be flexibly set according to actual experimental conditions, allowing for simulation experiments with different spacings; for example, the spacing between adjacent perforation simulators can be 80 mm.

[0034] The features and advantages of the sector-shaped well network fracturing simulation experimental device of the present invention are as follows: I. The fan-shaped well network fracturing simulation experimental device uses a casting method to prepare a formation simulation component 1, which can place multiple sets of wellbore simulation components 2 inside, so as to achieve the purpose of individually controlling the fracturing of each set of wellbore simulation components 2, and realistically simulating the fan-shaped well network fracturing scenario.

[0035] II. The fan-shaped well network fracturing simulation experimental device can change the angle between the pre-set multiple sets of well barrel simulation components 2 and the direction of the maximum horizontal principal stress. The first well barrel simulation component 201 or the second well barrel simulation component 202 is not deployed perpendicular to the direction of the maximum horizontal principal stress, so as to achieve the purpose of simulating the fan-shaped well network fracturing scenario.

[0036] Third, the fan-shaped well network fracturing simulation experimental device can be set up with multiple sets of wellbore simulation components 2 to simulate multiple horizontal wells, realize the simulation of multiple wells and multiple fractures in the fan-shaped well network, and the included angle between the simulated multiple horizontal wells can be changed to meet the simulation of different sectors of the fan-shaped well network.

[0037] Fourth, this fan-shaped well network fracturing simulation experimental device can realistically simulate the fan-shaped well network fracturing scenario, improve and perfect the existing fan-shaped well network fracturing well layout method, and provide more experimental basis and theoretical guidance for actual oilfield fracturing and research on fan-shaped well network fracturing design.

[0038] Implementation Method 2

[0039] like Figure 3 As shown, the present invention provides a method for simulating fracturing in a sector-shaped well network, which uses the aforementioned simulation apparatus for fracturing in a sector-shaped well network. The method includes the following steps: Step S1: Apply triaxial stress confining pressure to the material poured into the formation simulation component 1 to simulate formation pressure; Step S2: High-pressure fluid is injected into the first wellbore simulation component 201 and the second wellbore simulation component 202 in the wellbore simulation component group 2 in sequence. The high-pressure fluid fracturing the material poured in the chamber 101 through the corresponding first perforation simulation component 401 and the second perforation simulation component 402 to simulate the multi-stage fracturing scenario of the fan-shaped well network in the formation.

[0040] In an optional embodiment of the present invention, in step S1, the wellbore simulation assembly 2 is connected to a pressurizing pump and a pressure gauge via a control valve 3. The simulated formation pressure is adjusted by the cooperation of the pressurizing pump and the wellbore simulation assembly 2 so that the simulated formation pressure is the same as the actual formation pressure.

[0041] In an optional embodiment of the present invention, such as Figure 4 As shown, in step S2, a simultaneous fracturing method can be used to simulate a multi-stage fracturing scenario of a fan-shaped well network in the formation. The number of wellbore simulation components 2 is at least two sets. The simultaneous fracturing method includes the following steps: Step S201: High-pressure fluid is injected into the first wellbore simulation component 201 in the two sets of wellbore simulation component groups 2 respectively. The high-pressure fluid fracturing the material poured in the chamber 101 through the corresponding first perforation simulation component 401. Step S202: Collect fracturing data from the two first wellbore simulation components 201 respectively, and stop injecting high-pressure fluid into the two first wellbore simulation components 201; Step S203: High-pressure fluid is injected into the second wellbore simulation component 202 in the two sets of wellbore simulation component groups 2 respectively. The high-pressure fluid fracturing the material poured in the chamber 101 through the corresponding second perforation simulation component 402. Step S204: Collect fracturing data from the two second wellbore simulation components 202 respectively, and stop injecting high-pressure fluid into the two second wellbore simulation components 202; Step S205: Complete the multi-stage fracturing experiment simulating a fan-shaped well network in the formation using synchronous fracturing.

[0042] In another alternative embodiment of the invention, such as Figure 5 As shown, in step S2, a zipper-type fracturing method can also be used to simulate a multi-stage fracturing scenario of a fan-shaped well network in the formation. The number of wellbore simulation components 2 is at least two sets. The zipper-type fracturing method includes the following steps: Step S201': Inject high-pressure fluid into the first wellbore simulator 201 in the first wellbore simulator group 2. The high-pressure fluid fracturing the material poured in the chamber 101 through the corresponding first perforation simulator 401, collecting the fracturing data of the first wellbore simulator 201, and then stopping the injection of high-pressure fluid. Step S202': Inject high-pressure fluid into the first wellbore simulator 201 in the second wellbore simulator group 2. The high-pressure fluid fracturing the material poured in the chamber 101 through the corresponding first perforation simulator 401, collecting the fracturing data of the first wellbore simulator 201, and then stopping the injection of high-pressure fluid. Step S203': Inject high-pressure fluid into the second wellbore simulator 202 in the first wellbore simulator group 2. The high-pressure fluid fracturing the material poured in the chamber 101 through the corresponding second perforation simulator 402, collecting the fracturing data of the second wellbore simulator 202, and then stopping the injection of high-pressure fluid. Step S204': Inject high-pressure fluid into the second wellbore simulator 202 in the second wellbore simulator group 2. The high-pressure fluid fracturing the material poured in the chamber 101 through the corresponding second perforation simulator 402, collecting the fracturing data of the second wellbore simulator 202, and then stopping the injection of high-pressure fluid. Step S205': Complete the multi-stage fracturing experiment simulating a fan-shaped well network in the formation using a zipper-type fracturing method.

[0043] In the above steps, the fracturing data collected can be, but is not limited to, conventional data from formation fracturing experiments, such as fracture rupture pressure, porosity, type of fracturing fluid, rheology, power of fracturing equipment, and pumping fluid discharge rate. This application is intended to limit the method of simulation experiments and does not limit the types of fracturing data collected.

[0044] In one specific embodiment of the present invention, such as Figure 2 As shown, the experimental setup was prepared as follows: Two polytetrafluoroethylene sheets are bonded together to form a perforation, and nested and connected to one end of the simulated well barrel. The other end of the simulated well barrel is connected to control valve 3. The corresponding serial numbers are as follows: Control valve 32 is connected to one end of the second shaft 22 of the first horizontal well, and the other end of the second shaft 22 of the first horizontal well is nested with the second perforation 42 of the first horizontal well; Control valve 31 is connected to one end of the first shaft 21 of the first horizontal well, and the first shaft 21 of the first horizontal well passes through the second perforation 42 of the first horizontal well, and the other end of the first shaft 21 of the first horizontal well is nested with the first perforation 41 of the first horizontal well; Control valve 33 is connected to one end of the second shaft 23 of the second horizontal well, and the other end of the second shaft 23 of the second horizontal well is nested with the second section perforation 43 of the second horizontal well; Control valve 34 is connected to one end of the first shaft 24 of the second horizontal well, and the first shaft 24 of the second horizontal well passes through the second section perforation 43 of the second horizontal well, and the other end of the first shaft 24 of the second horizontal well is nested with the first section perforation 44 of the second horizontal well.

[0045] The four wellbores are connected to form a plane (all four wellbores are in the same plane), and placed in the center of the formation simulation component 1. During placement, the spacing between adjacent perforations can be controlled to be equal. Cement, gypsum, and quartz sand are mixed with water and poured into the formation simulation component 1 to obtain the simulated formation. The materials need to be cured within the formation simulation component 1 for a period of time, which can be, but is not limited to, 14 days.

[0046] For simulation of experimental methods: After the formation simulation component 1 is prepared and cured according to the above method, a triaxial stress confining pressure is applied to the formation simulation component 1 to simulate the formation pressure; the other two ports of the control valve 3 are connected to the pressurization pump and the pressure gauge respectively, and high-pressure fluid is injected into the corresponding wellbore under the confining pressure condition, while the pump injection pressure is monitored.

[0047] Simultaneous fracturing was employed: high-pressure fluid was simultaneously injected into the first wellbore 21 of the first horizontal well and the first wellbore 24 of the second horizontal well for fracturing, and fracturing data was collected. After fracturing was completed, the injection of high-pressure fluid was stopped, and control valves 1 and 4 were closed to maintain stable pressure within the fracture. Subsequently, high-pressure fluid was simultaneously injected into the second wellbore 22 of the first horizontal well and the second wellbore 23 of the second horizontal well for fracturing, and fracturing data was collected. After fracturing was completed, the injection of high-pressure fluid was stopped, and control valves 2 and 3 were closed. This simultaneous fracturing method simulated a multi-stage fracturing experiment of a fan-shaped well network in the formation.

[0048] A zipper-style fracturing method was adopted: high-pressure fluid was injected into the first wellbore 21 of the first horizontal well for fracturing. After fracturing, fracturing data was collected, high-pressure fluid injection was stopped, and the corresponding control valve 31 was closed. High-pressure fluid was injected into the first wellbore 24 of the second horizontal well for fracturing. After fracturing, fracturing data was collected, high-pressure fluid injection was stopped, and the corresponding control valve 34 was closed. High-pressure fluid was injected into the second wellbore 22 of the first horizontal well for fracturing. After fracturing, fracturing data was collected, high-pressure fluid injection was stopped, and the corresponding control valve 32 was closed. High-pressure fluid was injected into the second wellbore 23 of the second horizontal well for fracturing. After fracturing, fracturing data was collected, high-pressure fluid injection was stopped, and the corresponding control valve 33 was closed. This completed the multi-stage fracturing experiment simulating a fan-shaped well network in the formation using the zipper-style fracturing method.

[0049] In each step of the above experimental method, only the on / off state of the described control valve 3 is operated, while the control valve 3 not described is considered to be in the off state.

[0050] The fan-shaped well network fracturing simulation experiment method of the present invention can simulate the synchronous fracturing mode and the zipper-type fracturing mode of the fan-shaped well network by changing the fracturing process of the first wellbore simulation component 201 and the second wellbore simulation component 202 in each group of wellbore simulation components 2, thereby meeting different simulation requirements.

[0051] In addition, the fan-shaped well network fracturing simulation experimental method of the present invention also has the characteristics and advantages that the fan-shaped well network fracturing simulation experimental device of the present invention can achieve, which will not be repeated here.

[0052] The above description is merely an illustrative embodiment of the present invention and is not intended to limit the scope of the invention. Any equivalent changes and modifications made by those skilled in the art without departing from the concept and principles of the present invention should fall within the scope of protection of the present invention.

Claims

1. A fan-shaped well network fracturing simulation experimental device, characterized in that, The sector-shaped well network fracturing simulation experimental device includes: A formation simulation component having a chamber for pouring materials to simulate a formation environment; Multiple sets of wellbore simulation components are provided, and the different sets of wellbore simulation components are independent of each other. Each set of wellbore simulation components includes at least a first wellbore simulation component and a second wellbore simulation component. The first end of the first wellbore simulation component and the first end of the second wellbore simulation component are located outside the chamber and are provided with control valves. The second end of the first wellbore simulation component extends into the chamber and is provided with a first perforation simulation component. The second end of the second wellbore simulation component extends into the chamber and passes through the corresponding first perforation simulation component. A second perforation simulation component is provided at the second end of the second wellbore simulation component for simulating multi-stage fracturing scenarios of fan-shaped well networks. The first perforation simulator and the second perforation simulator are respectively formed by bonding two polytetrafluoroethylene sheets together, and the first perforation simulator and the second perforation simulator are respectively nested in the second end of the first wellbore simulator and the second wellbore simulator.

2. The fan-shaped well network fracturing simulation experimental device as described in claim 1, characterized in that, The angle between the first and second wellbore simulation components and the direction of the maximum horizontal principal stress is preset to simulate different multi-stage fracturing scenarios of fan-shaped well networks.

3. The fan-shaped well network fracturing simulation experimental device as described in claim 1, characterized in that, The control valve is a three-way valve, which has a first port, a second port, and a third port. The first port, the second port, and the third port are respectively used to connect to the pressurization pump, the wellbore simulation assembly, and the pressure gauge.

4. The fan-shaped well network fracturing simulation experimental device as described in claim 1, characterized in that, Adjust the orientation of the first perforation simulator relative to the first wellbore simulator, and / or adjust the orientation of the second perforation simulator relative to the second wellbore simulator to change the angle of the perforations formed by the two polytetrafluoroethylene sheets.

5. A method for simulating fracturing in a sector-shaped well network, characterized in that, The method employs the sector-shaped well network fracturing simulation experimental device described in any one of claims 1 to 4, and includes the following steps: Step S1: Apply triaxial stress confining pressure to the material poured into the formation simulation component to simulate formation pressure; Step S2: High-pressure fluid is injected sequentially into the first and second wellbore simulation components in the wellbore simulation component group to perform fracturing, so as to simulate the multi-stage fracturing scenario of a fan-shaped well network in the formation.

6. The fan-shaped well network fracturing simulation experimental method as described in claim 5, characterized in that, In step S1, the wellbore simulation assembly is connected to a pressurizing pump and a pressure gauge via a control valve. The pressurizing pump and the wellbore simulation assembly work together to adjust the simulated formation pressure so that the simulated formation pressure is the same as the actual formation pressure.

7. The fan-shaped well network fracturing simulation experimental method as described in claim 5, characterized in that, In step S2, a simultaneous fracturing method is used to simulate a multi-stage fracturing scenario of a fan-shaped well network in the formation. The number of wellbore simulation components is at least two sets. The simultaneous fracturing method includes the following steps: Step S201: Inject high-pressure fluid into the first wellbore simulation component in each of the two sets of wellbore simulation components to perform fracturing; Step S202: Collect fracturing data from the two first wellbore simulators respectively, and stop injecting high-pressure fluid into the two first wellbore simulators; Step S203: Inject high-pressure fluid into the second wellbore simulation component in each of the two sets of wellbore simulation component groups to perform fracturing; Step S204: Collect fracturing data from the two second wellbore simulators respectively, and stop injecting high-pressure fluid into the two second wellbore simulators; Step S205: Complete the multi-stage fracturing experiment simulating a fan-shaped well network in the formation using synchronous fracturing.

8. The fan-shaped well network fracturing simulation experimental method as described in claim 5, characterized in that, In step S2, a zipper-type fracturing method is used to simulate a multi-stage fracturing scenario of a fan-shaped well network in the formation. The number of wellbore simulation components is at least two sets. The zipper-type fracturing method includes the following steps: Step S201': Inject high-pressure fluid into the first wellbore simulator in the first group of wellbore simulators to perform fracturing, collect fracturing data of the first wellbore simulator, and then stop injecting high-pressure fluid; Step S202': Inject high-pressure fluid into the first wellbore simulator in the second group of wellbore simulators to perform fracturing, collect fracturing data of the first wellbore simulator, and then stop injecting high-pressure fluid; Step S203': Inject high-pressure fluid into the second wellbore simulator in the first group of wellbore simulators to perform fracturing, collect fracturing data of the second wellbore simulator, and then stop injecting high-pressure fluid; Step S204': Inject high-pressure fluid into the second wellbore simulator in the second wellbore simulator group to perform fracturing, collect fracturing data of the second wellbore simulator, and then stop injecting high-pressure fluid; Step S205': Complete the multi-stage fracturing experiment simulating a fan-shaped well network in the formation using a zipper-type fracturing method.

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