Rock core matrix experimental device for simulating shale oil reservoir fracturing-elastic development

Abstract

The invention discloses a rock core matrix experimental device for simulating shale oil reservoir fracturing-elastic development, which comprises a constant-pressure constant-speed pump, an intermediate container for storing fracturing fluid, a device for storing the fracturing fluid after reverse drainage, a first three-way valve, a first six-way valve, a first rock core holder group, a second rock core holder group, a third rock core holder group and a confining pressure pump system, the device is suitable for the technical field of rock core displacement experiments, the intermediate container for storing fracturing fluid is connected with the device for storing the reversely discharged fracturing fluid through the first three-way valve, each rock core holder group is connected with the output of the first three-way valve in combination with the first six-way valve, and the first valve and the second valve are used in cooperation with opening and closing of the first valve and the second valve; integration of shale oil fracturing-elastic development simulation by the experimental device can be realized; three core holders are arranged on each parallel branch and connected through valves to form a combined core, and shale oil crack-matrix coupling flow rules can be explored by reasonably configuring core types in the core holders in combination with pressure gauge data and nuclear magnetic resonance means.

Description

Technical Field

[0001] The present invention belongs to the technical field of core displacement experiments, and specifically relates to a core matrix experimental device for simulating hydraulic fracturing - elastic development of shale oil reservoirs. Background Art

[0002] A core displacement device is a physical property testing instrument used in the field of energy science and technology. Its main functions include liquid permeability measurement, formation sensitivity (formation damage) evaluation, enhanced oil recovery chemical evaluation, seepage characteristics research, and enhanced oil recovery research.

[0003] For example, a Chinese invention patent with the patent application number "202121405991.3" and the name "An oil reservoir displacement simulation device" includes a displacement device, a plurality of sand - filled models connected in parallel, and a production device; the sand - filled model includes a cemented lower plate and an upper plate, the upper plate is transparent, sandstone particles are filled between the lower plate and the upper plate, and at least one liquid injection port is provided at one end of the upper plate close to the displacement device, and at least one liquid outlet is provided at one end close to the production device. This invention has a plurality of sand - filled models connected in parallel, simulating simultaneous displacement of multiple - layer oil reservoirs and being able to reflect more real actual situations; through the setting of the positions and quantities of the liquid injection ports and liquid outlets, it can well simulate the real well pattern distribution.

[0004] Another example is a Chinese invention patent with the patent application number "201610534108.8" and the name "A core displacement device", which includes an injection module, a model module, a measurement module, and a control module. The model module includes a sand - filling tool and a sand - filling container. The sand - filling container is a cube, and the accommodation space of the sand - filling container is divided into a first sand - filling space, a second sand - filling space, and a third sand - filling space by the sand - filling tool, and the particle sizes of the first sandstone, the second sandstone, and the third sandstone are different.

[0005] Shale reservoirs have small porosity, complex pore structures, and very high pore flow resistance, belonging to low-permeability reservoirs. In most cases, they have no natural production capacity or the production is below the lower limit of industrial oil production. Special technological measures are required to obtain industrial oil production in shale. The current horizontal well staged fracturing technology is the key to realizing the efficient development of shale oil, and elastic development is the main production method for shale oil. Revealing the coupled flow law between artificial fractures and the matrix in shale reservoirs and clarifying the production dynamics and influencing factors of shale oil under the fracturing-elastic development mode are crucial for the design of shale reservoir development plans and development effects. However, most current indoor displacement experiments on shale reservoirs use single cores, without considering the interference of complex reservoir fractures and the influence of other factors, and cannot simulate the change in flow capacity during the entire process from fracturing to elastic production in shale reservoirs, thus unable to objectively reflect the actual situation. Therefore, we urgently need to establish a combined core matrix displacement experimental device for complex fractures in shale reservoirs to scientifically characterize the flow capacity and production dynamics of shale oil during the fracturing-elastic development process. Summary of the Invention

[0006] The purpose of the present invention is to overcome the defects of the prior art and provide a core matrix experimental device for simulating the fracturing-elastic development of shale reservoirs.

[0007] To achieve the above purpose, the present invention adopts the following technical solutions:

[0008] A core matrix experimental device for simulating the fracturing-elastic development of shale reservoirs, comprising a constant pressure and constant speed pump, an intermediate container for storing fracturing fluid, a storage device for the backflow of fracturing fluid, a first three-way valve, a first six-way valve, a first core holder group, a second core holder group, a third core holder group, and an overburden pressure pump system; the first core holder group, the second core holder group, and the third core holder group are connected in parallel, and each core holder group contains three separate core holders; the first three-way valve connects the intermediate container for storing fracturing fluid with the elastic development produced fluid storage device and the input of the first six-way valve; the first six-way valve connects the output of the first three-way valve with the three core holder groups; the overburden pressure pump system is connected to the first core holder group, the second core holder group, and the third core holder group respectively by the overburden pressure pump branches.

[0009] Preferably, the first core holder group is formed by connecting core holder one, core holder two, and core holder three in series.

[0010] Preferably, pressure gauges are arranged at the inlet and outlet ends of each core holder in the first core holder group, which are pressure gauge two, pressure gauge three, pressure gauge four, and pressure gauge five in sequence.

[0011] Preferably, the second core holder group is formed by connecting core holder six, core holder five, and core holder four in series.

[0012] Preferably, pressure gauges are provided at both the liquid inlet end and the liquid outlet end of each core holder in the second core holder group, which are pressure gauge nine, pressure gauge eight, pressure gauge seven, and pressure gauge six in sequence.

[0013] Preferably, the third core holder group is formed by connecting core holder nine, core holder eight, and core holder seven in series.

[0014] Preferably, pressure gauges are provided at both the liquid inlet end and the liquid outlet end of each core holder in the third core holder group, which are pressure gauge thirteen, pressure gauge twelve, pressure gauge eleven, and pressure gauge ten in sequence.

[0015] Preferably, a valve two and a back pressure pump are provided between the elastic development liquid-producing reservoir device and the first three-way valve.

[0016] Preferably, a valve one is provided between the intermediate container for storing fracturing fluid and the first three-way valve.

[0017] Preferably, a pressure gauge one is provided between the first three-way valve and the first six-way valve.

[0018] Preferably, the confining pressure pump system includes a confining pressure pump.

[0019] Preferably, the confining pressure pump is connected to the first core holder group through a second six-way valve.

[0020] Preferably, the confining pressure pump is connected to the second core holder group through a third six-way valve.

[0021] Preferably, the confining pressure pump is connected to the third core holder group through a fourth six-way valve.

[0022] In summary, due to the adoption of the above technical solutions, the beneficial effects of the present invention are as follows:

[0023] In the present invention, the intermediate container for storing fracturing fluid and the fracturing fluid backflow storage device are connected through the first three-way valve, and each core holder group is connected to the output of the first three-way valve through the first six-way valve. By cooperating with the opening and closing of valve one and valve two, the experimental device can simulate the integration of shale oil fracturing and elastic development.

[0024] In the present invention, three core holders are cleverly arranged on each parallel branch and connected with valves to form a combined core. By reasonably configuring the core types in the core holders, combining the pressure gauge data and nuclear magnetic resonance means, the coupled flow law of shale oil fractures and matrix can be explored. Secondly, the effects of different sand filling concentrations and different effective stresses on the coupled flow law of different fractures and matrix can also be investigated. Description of the Drawings

[0025] Figure 1It is a schematic diagram of the overall structure of the present invention;

[0026] Figure 2 It is a one-dimensional frequency encoding map before and after the elastic development of the first core of the present invention;

[0027] Figure 3 It is a one-dimensional frequency encoding map before and after the elastic development of the second core of the present invention;

[0028] Figure 4 It is a one-dimensional frequency encoding map before and after the elastic development of the third core of the present invention;

[0029] Figure 5 It is a one-dimensional frequency encoding map before and after the elastic development of the fourth core of the present invention;

[0030] Figure 6 It is a one-dimensional frequency encoding map before and after the elastic development of the fifth core of the present invention;

[0031] Figure 7 It is a one-dimensional frequency encoding map before and after the elastic development of the sixth core of the present invention;

[0032] Figure 8 It is a one-dimensional frequency encoding map before and after the elastic development of the seventh core of the present invention;

[0033] Figure 9 It is a one-dimensional frequency encoding map before and after the elastic development of the eighth core of the present invention;

[0034] Figure 10 It is a one-dimensional frequency encoding map before and after the elastic development of the ninth core of the present invention;

[0035] Figure 11 It is a diagram of the change in elastic mining pressure of the present invention;

[0036] Reference numerals: 1. Constant pressure and constant speed pump; 2. Intermediate container for storing fracturing fluid; 3. Storage device for the fracturing fluid after backflow; 4. Back pressure pump; 5. Valve 1; 6. Valve 2; 7. First three-way valve; 8. Pressure gauge 1; 9. First six-way valve; 10. Pressure gauge 2; 11. Core holder 1; 12. Pressure gauge 3; 13. Core holder 2; 14. Pressure gauge 4; 15. Core holder 3; 16. Pressure gauge 5; 17. Second three-way valve; 18. Pressure gauge 6; 19. Core holder 4; 20. Pressure gauge 7; 21. Core holder 5; 22. Pressure gauge 8; 23. Core holder 6; 24. Pressure gauge 9; 25. Pressure gauge 10; 26. Core holder 7; 27. Pressure gauge 11; 28. Core holder 8; 29. Pressure gauge 12; 30. Core holder 9; 31. Pressure gauge 13; 32. Confining pressure pump; 33. Second six-way valve; 34. Third six-way valve; 35. Fourth six-way valve. Detailed implementation manners

[0037] The following, in conjunction with the attached Figures 1-11 , further describes the specific implementation manners of a core matrix experimental device for simulating the fracturing-elastic development of a shale oil reservoir according to the present invention. The core matrix experimental device for simulating the fracturing-elastic development of a shale oil reservoir according to the present invention is not limited to the descriptions of the following embodiments.

[0038] Embodiment 1:

[0039] A core matrix experimental device for simulating the fracturing-elastic development of a shale oil reservoir, as Figure 1 shown, includes a constant-pressure and constant-speed pump 1, an intermediate container 2 for storing fracturing fluid, a storage device 3 for storing the backflowed fracturing fluid, a first three-way valve 7, a first six-way valve 9, a first core holder group, a second core holder group, a third core holder group, and a confining pressure pump system; the first core holder group, the second core holder group, and the third core holder group are connected in parallel, and each core holder group contains three separate core holders; the first three-way valve 7 connects the intermediate container 2 for storing fracturing fluid with the elastic development produced fluid storage device 3 and the input of the first six-way valve 9; the first six-way valve 9 connects the output of the first three-way valve 7 with the three core holder groups; the confining pressure pump system is connected to the first core holder group, the second core holder group, and the third core holder group in one-to-one correspondence by the confining pressure pump branches.

[0040] Embodiment 2:

[0041] A core matrix experimental device for simulating the fracturing-elastic development of a shale oil reservoir, as Figure 1 shown, has other structures similar to those in Embodiment 1, and the first core holder group is formed by connecting core holder one 11, core holder two 13, and core holder three 15 in series.

[0042] Furthermore, pressure gauges are provided at both the liquid inlet end and the liquid outlet end of each core holder in the first core holder group, which are pressure gauge two 10, pressure gauge three 12, pressure gauge four 14, and pressure gauge five 16 in sequence.

[0043] Embodiment 3:

[0044] A core matrix experimental device for simulating the fracturing-elastic development of a shale oil reservoir, as Figure 1 shown, has other structures similar to those in Embodiment 1, and the second core holder group is formed by connecting core holder six 23, core holder five 21, and core holder four 19 in series.

[0045] Furthermore, pressure gauges are provided at both the liquid inlet end and the liquid outlet end of each core holder in the second core holder group, which are pressure gauge nine 24, pressure gauge eight 22, pressure gauge seven 20, and pressure gauge six 18 in sequence.

[0046] Embodiment 4:

[0047] A core matrix experimental device for simulating the fracturing-elastic development of shale reservoirs, as Figure 1 shown. The other structures are similar to those in Embodiment 1. The third core holder group is formed by connecting core holder nine 30, core holder eight 28, and core holder seven 26 in series.

[0048] Furthermore, pressure gauges are provided at both the liquid inlet end and the liquid outlet end of each core holder in the third core holder group, which are pressure gauge thirteen 31, pressure gauge twelve 29, pressure gauge eleven 27, and pressure gauge ten 25 in sequence.

[0049] Embodiment 5:

[0050] A core matrix experimental device for simulating the fracturing-elastic development of shale reservoirs, as Figure 1 shown. The other structures are similar to those in Embodiment 1. A valve two 6 and a back pressure pump 4 are provided between the elastic development liquid production reservoir device 3 and the first three-way valve 7.

[0051] Embodiment 6:

[0052] A core matrix experimental device for simulating the fracturing-elastic development of shale reservoirs, as Figure 1 shown. The other structures are similar to those in Embodiment 1. A valve one 5 is provided between the intermediate container 2 for storing fracturing fluid and the first three-way valve.

[0053] Embodiment 7:

[0054] A core matrix experimental device for simulating the fracturing-elastic development of shale reservoirs, as Figure 1 shown. The other structures are similar to those in Embodiment 1. A pressure gauge one 8 is provided between the first three-way valve and the first six-way valve.

[0055] Embodiment 8:

[0056] A core matrix experimental device for simulating the fracturing-elastic development of shale reservoirs, as Figure 1 shown. The other structures are similar to those in Embodiment 1. The confining pressure pump system includes a confining pressure pump 32.

[0057] Furthermore, there is a second six-way valve 33 connecting the confining pressure pump 32 and the first core holder group.

[0058] Furthermore, there is a third six-way valve 34 connecting the confining pressure pump 32 and the second core holder group.

[0059] Furthermore, there is a fourth six-way valve 35 connecting the confining pressure pump 32 and the third core holder group.

[0060] Embodiment 9:

[0061] A core matrix experimental device for simulating the fracturing-elastic development of shale reservoirs, as Figure 1As shown in the figure, it includes a constant-pressure and constant-speed pump 1, an intermediate container 2 for storing fracturing fluid, a first valve 5, a first three-way valve 7, a first pressure gauge 8, a first six-way valve 9, a first core holder group, a second three-way valve 35, a second core holder group, and a third core holder group arranged in sequence along the pipeline direction; another path includes a confining pressure pump 32, a second six-way valve 33, a third six-way valve 34, and a fourth six-way valve 35; among them, the confining pressure pump 32 is connected to the holder of any first core holder group through the second six-way valve 33, connected to the holder of any second core holder group through the third six-way valve 34, and connected to the holder of any third core holder group through the fourth six-way valve 35.

[0062] In this embodiment, the first core holder group, the second core holder group, and the third core holder group are all set to three groups in series, and the relationship between the three groups is parallel. In addition to the three series-connected core holders in each core holder group branch, a pressure gauge is placed at the inlet end and the outlet end of each core holder, that is, four pressure gauges are placed in one core holder group branch.

[0063] In this embodiment, the first three-way valve 7 connects the first valve 5 with the intermediate container 2 for storing fracturing fluid, the second valve 6, the back pressure pump 4, and the storage device 3 after the fracturing fluid is backflowed.

[0064] The working principle of Embodiment 9 is briefly described below:

[0065] In Embodiment 9, the intermediate container 2 for storing fracturing fluid and the storage device 3 after the fracturing fluid is backflowed are connected through the first three-way valve. Combining the first six-way valve 9 to connect each core holder group with the output of the first three-way valve 7 and cooperating with the opening and closing of the first valve 5 and the second valve 6, the experimental device can simulate the integration of shale oil fracturing and elastic development.

[0066] Based on the actual situation of the shale reservoir, Embodiment 9 sets a combined scheme of three core holder groups. The fractured cores after being saturated with oil are respectively placed into the three core holders of the first core holder group, and then the laminated cores after being saturated with oil are respectively placed into the six core holders of the second core holder group and the third core holder group. By adjusting the types of the three cores in the first core holder group, the coupling flow laws of different fractures and matrices in the shale reservoir can be explored. The core types can include main fracture cores, branch fracture cores, micro-fracture cores, laminated cores and other types.

[0067] In Embodiment 9, by changing the sand placement concentration in the fractured cores, as well as the confining pressure and injection pressure borne by each core, the influence of different sand placement concentrations and different effective stresses on the coupling flow of fractures and matrices in the shale reservoir is investigated.

[0068] Furthermore, the specific working steps of Embodiment 9:

[0069] Saturated oil: Before the test, nine cores after being saturated with oil were respectively scanned by nuclear magnetic resonance to obtain the oil mass and oil saturation of each core. The pressure during core saturation with kerosene was 25 MPa, and the saturation time was 30 days.

[0070] Core assembly: Then, the main fracture cores, micro-fracture cores, and laminated cores were grouped and placed into three sets of parallel core holders.

[0071] Air tightness detection: High-pressure nitrogen was filled into the core matrix experimental device to detect the air tightness of the device and ensure the rigor of the experiment.

[0072] Fracturing: Simulating the shale oil fracturing stage, valve two 6 was closed, valve one 5 was opened, and a constant-pressure and constant-speed pump 1 was used to pressurize the intermediate container 2 storing the fracturing fluid, so that the stored fracturing fluid flowed through the first three-way valve 7 and the first six-way valve 9 and flowed towards the three sets of core holders.

[0073] Fracturing fluid flowback: Simulating the fracturing fluid flowback stage, since the cores in the first set of core holders contain fractures and the fluid flow resistance is small, while the other two sets of cores are shale laminated cores with large fluid flow resistance, most of the fracturing fluid flows into the first set of core holders and then diffuses to both sides after passing through the second three-way valve. Part of the fracturing fluid flows into the second set of core holders along the core holder four 19 and flows towards the core holder six 23, and another part of the fracturing fluid flows into the third set of core holders along the core holder seven 26 and flows towards the core holder nine 30. During this period, a confining pressure pump 32 was used to control the confining pressure of the nine core holders in the three sets of core holders through the second six-way valve 33, the third six-way valve 34, and the fourth six-way valve 35, and the data of the thirteen pressure gauges of the monitoring device were monitored. When the pressure rose to a certain stable value, the fracturing stage ended and valve one 5 was closed.

[0074] Elastic production: Simulating the shale oil elastic production stage, the back pressure was controlled by a back pressure pump 4, valve two 6 was opened, and the fluid in the core holder set began to flow back along the first six-way valve 9, the first three-way valve 7, and along valve two 6 until the data of each pressure gauge was stable and the fluid volume in the storage device 3 hardly increased after the fracturing fluid flowback. Then the elastic production stage ended, valve two 6 was closed, the confining pressure was removed, and the test ended.

[0075] Detection of shale oil recovery degree: After the elastic production ended, the cores in the nine core holders were removed and scanned by nuclear magnetic resonance again to test the oil mass and oil saturation of each core. Combining the relevant data of each core before the test, the elastic recovery degree of the combined core shale oil after fracturing - elastic production can be obtained.

[0076] Post - processing of experimental data: By organizing the pressure change data of each pressure gauge during the fracturing - elastic production process, the fracturing curves of each core can be obtained, the pressure propagation speed and magnitude at different positions can be analyzed, and the pressure propagation characteristics of cores with different conductivity can be obtained.

[0077] Clean the experimental device.

[0078] Furthermore, the basic parameters of the experimental device selected in this embodiment are as follows:

[0079] It includes a constant - pressure and constant - speed pump, an intermediate container for confining pressure pump, a back - pressure valve, a pressure acquisition system, a six - way valve, a high - pressure core holder dedicated for NMR, and an NMR spectrometer.

[0080] Furthermore, the experimental materials selected in this embodiment are as follows:

[0081] Kerosene is selected as the experimental formation fluid. The experimental shale cores are numbered as #1, #2, #3, #4, #5, #6, #7, #8, #9, and the specific parameters of the cores are shown in Table 1.

[0082] Table 1 Basic physical properties of experimental cores

[0083]

[0084] Furthermore, the designed experimental results in this example are as follows:

[0085] Nuclear magnetic resonance technology is based on the Larmor frequency, and a T2 spectrum is obtained using a spin - echo pulse sequence. The abscissa of the T2 spectrum is the relaxation time, and the ordinate is the signal intensity. The relaxation time is related to the pore size of the core. Fluids in large pores have a long relaxation time, while fluids in small pores have a short relaxation time. The pore size and distribution range of the core can be characterized by the relaxation time. The ordinate signal intensity is related to the fluid content in the corresponding pores.

[0086] The result measured by the CPMG sequence is a T2 map, and the result measured by the GR - HSE sequence is a one - dimensional frequency - encoding map, which shows the distribution of hydrogen saturation in the axial direction of the core through the nuclear magnetic resonance signal quantity. In this example, it is the distribution of crude oil in the axial direction of the core. The key NMR parameters are shown in Table 2:

[0087] Table 2 Key parameters for NMR testing

[0088]

[0089] In order to analyze the utilization of crude oil in different pores before and after elastic production, the core is scanned by nuclear magnetic resonance technology before and after production.

[0090] Such as Figures 2-10As shown, the one-dimensional frequency encoding maps of the nine cores with matrix distribution before and after elastic development in Example 9 reflect the oil-bearing distribution of the crude oil in the cores before and after the experiment. The nine cores all show the rule that the remaining oil saturation gradually increases from the inlet to the outlet, which indicates that in the process of elastic production, the farther away from the inlet end, the worse the production effect, and almost no oil is produced at the end of the core. However, for Cores #1, #2, and #3, as Figures 2-4 shown, the crude oil at the outlet end is also mobilized, which indicates that the main fractures developed in the core greatly reduce the flow resistance of the crude oil in the matrix, thereby effectively improving the production degree of the crude oil in the near-fracture area and achieving the purpose of improving the recovery rate. As Figures 5-7 shown, for the cores with micro-fractures developed in #4, #5, and #6, from the inlet end to the outlet section, the oil saturation shows an increasing trend. The tiny fractures distributed in the matrix can effectively improve the seepage ability of the crude oil in the formation. On the contrary, the production degree of the laminated core is relatively low compared with other cores.

[0091] As Figure 11 shown, in the process of elastic production, the formation pressure decreases rapidly in the initial stage and tends to be gentle in the later stage, which is consistent with the actual development law of shale oil reservoir fracturing. It can be analyzed that the fracturing elastic development is divided into two stages. The first stage is that the moving boundary gradually expands outwards until all the crude oil around the well or fracture is produced. The second stage is the stage of gentle pressure reduction, and the pressure gradually drops to a reasonable bottom-hole flowing pressure.

[0092] At the same time, by comparing different fracture development situations, it can be known that the larger the permeability variation coefficient, the stronger the pressure-sensitive effect, the more obvious the initial pressure change, but the pressure decreases slowly in the later stage. The reason is that when developing shale oil reservoirs, due to the pressure-sensitive effect, the pressure near the production well drops quickly, and the permeability also loses quickly, resulting in a rapid increase in the seepage resistance and a rapid decline in production capacity.

[0093] In Example 9, by comparing the oil saturation before and after fracturing-elastic production, the elastic utilization degree of shale oil with different fracture types was obtained; the pressure change curves were sorted out and analyzed to clarify the pressure propagation characteristics of shale under different conductivity capabilities.

[0094] The above content is a further detailed description of the present invention in combination with specific preferred embodiments. It cannot be determined that the specific implementation of the present invention is only limited to these descriptions. For those of ordinary skill in the technical field to which the present invention belongs, without departing from the concept of the present invention, several simple deductions or substitutions can be made, and all should be regarded as belonging to the protection scope of the present invention.

Claims

1. A core matrix experimental device for simulating the fracturing-elastic development process of shale oil reservoirs, characterized in that: The invention comprises a constant pressure and constant speed pump (1), an intermediate container (2) for storing fracturing fluid, a storage device (3) for fracturing fluid backflow, a first three-way valve (7), a first six-way valve (9), a first core clamp group, a second core clamp group, a third core clamp group, and a confining pressure pump system; the first core clamp group, the second core clamp group and the third core clamp group are connected in parallel, and each core clamp group includes three separate core clamps; the first three-way valve (7) connects the intermediate container (2) for storing fracturing fluid with the elastic development production storage device (3) and the input of the first six-way valve (9); the first six-way valve (9) connects the output of the first three-way valve (7) and the three core clamp groups; the confining pressure pump system comprises a confining pressure pump section connected to the first core clamp group, the second core clamp group and the third core clamp group in a one-to-one correspondence.

2. A core matrix experimental device for simulating fracturing-elastic development process according to claim 1, characterized in that: The first core clamp group is composed of a core clamp one (11), a core clamp two (13), and a core clamp three (15) connected in series.

3. A core matrix experimental device for simulating fracturing-elastic development process according to claim 2, characterized in that: Each core holder of the first core holder group is provided with a pressure gauge at the liquid inlet and liquid outlet, which are pressure gauge 2 (10), pressure gauge 3 (12), pressure gauge 4 (14), and pressure gauge 5 (16) in sequence.

4. A core matrix experimental device for simulating fracturing-elastic development process according to claim 1, characterized in that: The second core clamp group is composed of core clamp six (23), core clamp five (21), and core clamp four (19) connected in series.

5. A core matrix experimental device for simulating fracturing-elastic development process according to claim 4, characterized in that: Each core holder of the second core holder group is provided with a pressure gauge at the liquid inlet and liquid outlet, which are pressure gauge nine (24), pressure gauge eight (22), pressure gauge seven (20), and pressure gauge six (18) in sequence.

6. A core matrix experimental device for simulating fracturing-elastic development process according to claim 1, characterized in that: The third core clamp group is composed of a core clamp nine (30), a core clamp eight (28), and a core clamp seven (26) connected in series.

7. A core matrix experimental device for simulating a fracturing-elastic development process according to claim 6, characterized in that: Each core holder of the third core holder group is provided with a pressure gauge at the liquid inlet and liquid outlet, which are pressure gauge thirteen (31), pressure gauge twelve (29), pressure gauge eleven (27), and pressure gauge ten (25) in sequence.

8. A core matrix experimental device for simulating fracturing-elastic development process according to claim 1, characterized in that: A second valve (6) and a back-pressure pump (4) are provided between the elastic development and liquid production reservoir device (3) and the first three-way valve (7).

9. A core matrix experimental device for simulating fracturing-elastic development process according to claim 1, characterized in that: A valve 1 (5) is arranged between the intermediate container (2) storing the fracturing fluid and the first three-way valve.

10. A core matrix experimental device for simulating fracturing-elastic development process according to claim 1, characterized in that: A pressure gauge 1 (8) is arranged between the first three-way valve and the first six-way valve.

11. A core matrix experimental device for simulating fracturing-elastic development process according to claim 1, characterized in that: The confining pressure pump system comprises a confining pressure pump (32).

12. A core matrix experimental device for simulating fracturing-elastic development process according to claim 11, characterized in that: A second six-way valve (33) is connected between the confining pressure pump (32) and the first core clamp assembly.

13. A core matrix experimental device for simulating fracturing-elastic development process according to claim 11, characterized in that: A third six-way valve (34) is connected between the confining pressure pump (32) and the second core clamp assembly.

14. A core matrix experimental device for simulating fracturing-elastic development process according to claim 11, characterized in that: A fourth six-way valve (35) is connected between the confining pressure pump (32) and the third core clamp assembly.

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