Reservoir dynamic reservoir formation simulation and heterogeneity quantitative evaluation method and related device

Abstract

The invention discloses a reservoir dynamic reservoir formation simulation and heterogeneity quantitative evaluation method and a related device. The method comprises the following steps: determining configuration conditions according to lithology data, and configuring and preparing a simulated rock core sample under the configuration conditions; according to the cause characteristics, each reservoir forming time period of the reservoir forming process and reaction conditions corresponding to each reservoir forming time period are determined, the reaction conditions comprise temperature, pressure and fluid, and each reservoir forming simulation time period is determined based on each reservoir forming time period; acting the reaction conditions corresponding to the storage simulation time periods on the simulation rock core sample; obtaining characterization characteristics of the rock core sample in each reservoir formation simulation time period, wherein the characterization characteristics comprise physical property characteristics, rock mechanics characteristics and diagenetic fluid characteristics; the heterogeneity of the reservoir is determined based on the reaction conditions and the characterization characteristics. The method overcomes the defect that the reservoir formation result of the simulated reservoir does not meet the requirement due to the fact that the heterogeneity of the reservoir is not considered in the reservoir formation simulation process. And the defect that the reservoir heterogeneity cannot be quantitatively evaluated in the reservoir formation process is further overcome.

Description

Technical Field

[0001] The present invention relates to the technical field of oil and gas field development, and particularly relates to a method for simulating dynamic reservoir formation and quantitatively evaluating heterogeneity, and related devices. Background Art

[0002] The exploitation plan of an oil and gas field often depends on the reservoir formation process of the oil and gas reservoir. The exploitation plan of the oil and gas field is formulated by simulating the reservoir formation process of the oil reservoir. At present, the diagenetic evolution simulation experiment method is used to simulate the reservoir formation process of the oil and gas reservoir. In the diagenetic evolution simulation experiment method, the experimental samples of the reservoir are placed in a reaction kettle, and the experimental samples are heated and pressurized in the reaction kettle, and the oil and gas content before and after heating and pressurizing the samples is studied to simulate the reservoir formation process of the oil and gas reservoir. Summary of the Invention

[0003] In the diagenetic evolution simulation experiment method, the oil and gas content of the experimental samples before and after heating and pressurizing is studied, and the influence of temperature and pressure parameters on the reservoir formation of the oil and gas reservoir is studied during the simulation process. This method does not consider the influence of heterogeneity on the reservoir formation of the oil and gas reservoir during the simulation process. However, the oil and gas reservoir often has significant heterogeneity. Since this method does not consider heterogeneity during the simulation of the reservoir formation process of the oil and gas reservoir, when the oil and gas reservoir has strong heterogeneity, the obtained simulation results do not meet the requirements, and further the exploitation plan obtained based on this method does not meet the requirements.

[0004] In view of the above problems, the present invention is proposed to provide a method for simulating dynamic reservoir formation and quantitatively evaluating heterogeneity, and related devices that overcome the above problems or at least partially solve the above problems.

[0005] An embodiment of the present invention provides a system for simulating dynamic reservoir formation, including: a control device, a rock sample preparation unit, a reaction unit, an injection unit, a physical property analysis unit, a mechanical property analysis unit, and a diagenetic fluid analysis unit;

[0006] The control device is configured to determine the configuration conditions of the simulated core samples according to the lithology data of the oil and gas reservoir; determine each reservoir formation time period and the corresponding reaction conditions of each reservoir formation time period during the reservoir formation process according to the genetic characteristics of the oil and gas reservoir, where the reaction conditions include at least one of pressure, temperature, and fluid; determine each reservoir formation simulation time period based on each reservoir formation time period; obtain the characterization features of the core samples within each reservoir formation simulation time period, where the characterization features include at least one of physical property features, rock mechanical features, and diagenetic fluid features; determine the heterogeneity of the reservoir according to the reaction conditions and the characterization features;

[0007] The rock sample preparation unit is configured to prepare simulated core samples under the configuration conditions of the simulated core samples;

[0008] The reaction unit is used to place a simulated core sample and generate corresponding pressures and temperatures during each reservoir-forming simulation time period to act on the simulated core sample;

[0009] The injection unit is used to inject corresponding fluids into the simulated core sample during each reservoir-forming simulation time period;

[0010] The physical property analysis unit is used to determine the physical property characteristics of the simulated core sample by using multi-energy spectrum CT scanning technology during each reservoir-forming simulation time period;

[0011] The mechanical property analysis unit is used to determine the rock mechanical characteristics of the simulated core sample by using ultrasonic monitoring technology during each reservoir-forming simulation time period;

[0012] The diagenetic fluid analysis unit is used to determine the diagenetic fluid characteristics of the simulated core sample during each reservoir-forming simulation time period.

[0013] In a further optional implementation manner, the physical property characteristics include at least one of mineral component characteristics and pore characteristics; the diagenetic fluid characteristics include at least one of fluid characteristics and pH characteristics.

[0014] In a further optional implementation manner, it further includes a data acquisition unit connected to the control device;

[0015] The data acquisition unit is used to obtain the reaction conditions, physical property characteristics, rock mechanical characteristics, and diagenetic fluid characteristics during each reservoir-forming simulation time period, and perform format conversion on the reaction conditions, physical property characteristics, rock mechanical characteristics, and diagenetic fluid characteristics and send them to the control device.

[0016] In a further optional implementation manner, the control device is used to determine the configuration conditions of the simulated core sample according to the lithology data of the oil and gas reservoir, including:

[0017] The control device is used to determine the particle screening range of the core sample according to the lithology data of the oil and gas reservoir, and the particle screening range includes at least one of a mineral component range, a content range of each component, a particle size range, and a roundness range;

[0018] The rock sample preparation unit is used to prepare a simulated core sample under the configuration conditions of the simulated core sample, including:

[0019] The rock sample preparation unit is used to crush the sampled core to obtain particles, screen the particles within the particle screening range, and wash, dry, and press the screened particles to obtain a simulated core sample.

[0020] In a further optional implementation manner, the control device is used to determine each reservoir-forming simulation time period based on each reservoir-forming time period, including:

[0021] The control device is used to compress each storage time period into each storage simulation time period according to a specified ratio.

[0022] A further optional implementation manner, the physical property analysis unit is used to determine the physical property characteristics of the simulated core sample by using the multi-energy spectrum CT scanning technology within each storage simulation time period, including:

[0023] The physical property analysis unit is used to equally divide the simulated core sample into several segments to obtain several simulated sub-core samples within each diagenetic simulation time period, and use the multi-energy spectrum CT scanning technology to obtain the pore characteristics and mineral component characteristics of the several simulated sub-core samples; based on the pore characteristics and mineral component characteristics of the several simulated sub-core samples, obtain the pore characteristics and mineral component characteristics of the simulated core sample;

[0024] The mechanical property analysis unit is used to determine the rock mechanical characteristics of the simulated core sample by using the ultrasonic monitoring technology within each storage simulation time period, including:

[0025] The mechanical property analysis unit is used to equally divide the simulated core sample into several segments to obtain several simulated sub-core samples within each diagenetic simulation time period, use the acoustic velocity measurement technology to obtain the rock mechanical characteristics of the several simulated sub-core samples, and based on the rock mechanical characteristics of the several simulated sub-core samples, obtain the rock mechanical characteristics of the simulated core sample;

[0026] The diagenetic fluid analysis unit is used to determine at least one of the diagenetic fluid characteristics and the pH value characteristics of the simulated core sample within each storage simulation time period, including:

[0027] The diagenetic fluid analysis unit is used to determine the diagenetic fluid components and the pH value of the simulated core sample within each diagenetic simulation time period, and respectively determine the fluid characteristics and the pH value characteristics based on the change values of the diagenetic fluid components and the change values of the pH value at a specified time point.

[0028] A further optional implementation manner, the rock sample preparation unit includes a mineral crusher, a mineral powder sieve, a mineral powder tablet press, and a detection component connected in sequence; the detection component includes an X-ray gun and an X-ray tube connected in sequence;

[0029] The mineral crusher is used to crush the sampled core to obtain particles; the mineral powder sieve is used to screen the particles based on a preset particle screening range; the mineral powder tablet press is used to press the screened particles to obtain a simulated core sample;

[0030] The X-ray gun is used to emit X-rays to the simulated core sample; the X-ray tube is used to determine the components of the simulated core sample according to the X-rays reflected by the simulated core sample.

[0031] In a further optional embodiment, the rock sample preparation unit further includes a mineral powder conveyor belt, as well as a mass sensor, a mineral washer, and a mineral dryer that are sequentially connected to the mineral powder sieve, and the mineral dryer is also connected to the mineral powder tablet press;

[0032] The mineral powder conveyor belt is used to transport the screened particles; the mass sensor is used to determine the mass of the screened particles; the mineral washer is used to wash the selected particles; the mineral dryer is used to dry the selected particles.

[0033] In a further optional embodiment, the reaction unit includes a heating coil and a pressurizing assembly;

[0034] The heating coil is used to heat the simulated core sample at a corresponding temperature during each storage simulation time period;

[0035] The pressurizing assembly includes an upper hydraulic unit above the heating coil, a lower hydraulic unit below the heating coil, and a layered pressurizing unit on the side of the heating coil; the upper hydraulic unit is used to generate a corresponding longitudinal upward pressure during each storage simulation time period;

[0036] The lower hydraulic unit is used to generate a corresponding longitudinal downward pressure during each storage simulation time period;

[0037] The layered pressurizing unit is used to generate a corresponding layered pressure during each storage simulation time period.

[0038] In a further optional embodiment,

[0039] The upper hydraulic unit includes an upper hydraulic device above the heating coil and an upper hydraulic pipe provided on the upper hydraulic device;

[0040] The lower hydraulic unit includes a lower hydraulic device below the heating coil and a lower hydraulic pipe provided on the lower hydraulic device;

[0041] The layered pressurizing unit includes a first layered pressurizer, a second layered pressurizer, a third layered pressurizer, a fourth layered pressurizer on the side of the heating coil, and a first layered pressurizing liquid pipe provided on the first layered pressurizer, a second layered pressurizing liquid pipe provided on the second layered pressurizer, a third layered pressurizing liquid pipe provided on the third layered pressurizer, and a fourth layered pressurizing liquid pipe provided on the fourth layered pressurizer.

[0042] In a further optional embodiment, the injection unit includes a vertical injection unit and a lateral injection unit,

[0043] The vertical injection unit is used to inject corresponding fluids in the vertical direction of the simulated core sample during each reservoir formation simulation period; the lateral injection unit is used to inject corresponding fluids in the lateral direction of the simulated core sample during each reservoir formation simulation period.

[0044] In a further optional implementation manner, the vertical injection unit includes a vertical diagenetic fluid injector located above the heating coil, a vertical diagenetic fluid injection pipe arranged on the vertical diagenetic fluid injector, a vertical diagenetic fluid outflow pipe located below the heating coil, and a vertical diagenetic fluid outflow pipe arranged on the vertical diagenetic fluid outflow device;

[0045] The lateral injection unit includes a lateral diagenetic fluid injector located on the side of the heating coil, a lateral diagenetic fluid injection pipe arranged on the lateral diagenetic fluid injector, a lateral diagenetic fluid outflow device located on the other side of the heating coil, and a lateral diagenetic fluid outflow pipe arranged on the lateral diagenetic fluid outflow device.

[0046] In a further optional implementation manner, the injection unit further includes a first diagenetic fluid transfer pump, a second diagenetic fluid transfer pump, and a third diagenetic fluid transfer pump connected to the lateral diagenetic fluid injection pipe and the vertical diagenetic fluid injection pipe; a first diagenetic fluid storage tank, a second diagenetic fluid storage tank, and a third diagenetic fluid storage tank respectively connected to the first diagenetic fluid transfer pump, the second diagenetic fluid transfer pump, and the third diagenetic fluid transfer pump;

[0047] The first diagenetic fluid storage tank is used to store fluids; the second diagenetic fluid storage tank is used to store fluids; the third diagenetic fluid storage tank is used to store fluids;

[0048] The first diagenetic fluid transfer pump is used to inject the fluids stored in the first diagenetic fluid storage tank into the diagenetic fluid injection pipe and the vertical diagenetic fluid injection pipe; the second diagenetic fluid transfer pump is used to inject the fluids stored in the second diagenetic fluid storage tank into the diagenetic fluid injection pipe and the vertical diagenetic fluid injection pipe; the third diagenetic fluid transfer pump is used to inject the fluids stored in the third diagenetic fluid storage tank into the diagenetic fluid injection pipe and the vertical diagenetic fluid injection pipe.

[0049] In a further optional implementation manner, the physical property analysis unit includes an electron beam and CT data collector connected to the reaction unit, and a deflection coil, a focusing coil, a vacuum pump, and an electron gun sequentially connected to the electron beam;

[0050] The electron gun is used to generate electrons with different energies; the vacuum pump is used to transport electrons with different energies; the focusing coil is used to focus electrons with different energies; the deflection coil is used to deflect the focused electrons; the electron beam is used to act on the simulated core sample with the deflected electrons; the CT data collector is used to collect the electrons passing through the simulated core sample.

[0051] Further optional embodiments

[0052] The diagenetic fluid analysis unit includes a sample tank connected to the reaction unit, an interference filter, a pH meter, and a spectrometer connected to the sample tank, a UV spectrophotometer diaphragm connected to the interference filter, and a UV light source connected to the UV spectrophotometer diaphragm;

[0053] The sample tank is used to place the simulated core sample; the UV light source is used to generate UV light; the UV spectrophotometer diaphragm is used to determine the intensity of the UV light; the interference filter is used to filter out non-UV light; the pH meter is used to determine the acidity and alkalinity of the environment where the simulated core sample is located; the spectrometer is used to receive the UV light reflected by the simulated core sample.

[0054] Further optional embodiments, the mechanical property analysis unit includes an ultrasonic receiver and an ultrasonic transmitter connected to the reaction unit;

[0055] The ultrasonic transmitter is used to generate ultrasonic waves to act on the simulated core sample; the ultrasonic receiver is used to receive the ultrasonic waves reflected by the simulated core sample.

[0056] Further optional embodiments

[0057] The data acquisition unit includes a first data converter connected to the reaction unit and the control device, a second data converter connected to the third diagenetic fluid delivery pump and the control device, a third data converter connected to the first diagenetic fluid delivery pump and the control device, a fourth data converter connected to the second diagenetic fluid delivery pump and the control device, a fifth data converter connected to the physical property analysis unit and the control device, and a sixth data converter connected to the diagenetic fluid analysis unit and the control device;

[0058] The first data converter is used to perform format conversion on the temperature and pressure in each diagenetic storage simulation time period; the second data converter is used to perform format conversion on the data of the fluid delivered by the first diagenetic fluid delivery pump; the third data converter is used to perform format conversion on the data of the fluid delivered by the second diagenetic fluid delivery pump; the fourth data converter is used to perform format conversion on the data of the fluid delivered by the third diagenetic fluid delivery pump; the fifth data converter is used to perform format conversion on the physical property characteristics in each diagenetic storage simulation time period; the sixth data converter is used to perform format conversion on the rock mechanical characteristics and diagenetic fluid characteristics in each diagenetic storage simulation time period.

[0059] Further optional embodiments, a sample clamping unit is further provided between the rock sample preparation unit and the reaction unit;

[0060] The sample clamping unit is used to clamp the simulated core sample to the reaction unit;

[0061] The sample clamping unit includes a sample transfer clamp telescopic rod and a sample transfer clamp connected to the sample transfer clamp telescopic rod.

[0062] An embodiment of the present invention provides a method for quantitatively evaluating reservoir heterogeneity based on dynamic reservoir formation simulation, including:

[0063] Determine the configuration conditions of the simulated core sample according to the lithology data of the oil and gas reservoir, and configure the simulated core sample under the configuration conditions of the simulated core sample;

[0064] According to the genetic characteristics of the oil and gas reservoir, determine each reservoir formation time period and the corresponding reaction conditions of each reservoir formation time period during the reservoir formation process. The reaction conditions include at least one of pressure, temperature, and fluid; determine each reservoir formation simulation time period based on each reservoir formation time period;

[0065] Apply the reaction conditions corresponding to each reservoir formation simulation time period to the simulated core sample;

[0066] Obtain the physical property characteristics of the simulated core sample determined by the physical property analysis unit using multi-energy spectrum CT scanning technology, the rock mechanical characteristics of the simulated core sample determined by the mechanical property analysis unit using ultrasonic monitoring technology, and the diagenetic fluid characteristics of the simulated core sample determined by the diagenetic fluid analysis unit during each reservoir formation simulation time period, and obtain the characterization characteristics of the core sample during each reservoir formation simulation time period. The characterization characteristics include at least one of physical property characteristics, rock mechanical characteristics, and diagenetic fluid characteristics;

[0067] Determine the heterogeneity of the reservoir according to the reaction conditions and the characterization characteristics.

[0068] In a further optional implementation manner, the physical property characteristics include at least one of mineral component characteristics and pore characteristics, and the diagenetic fluid characteristics include fluid characteristics and pH characteristics.

[0069] In a further optional implementation manner, determining the heterogeneity of the reservoir according to the reaction conditions and the characterization characteristics includes:

[0070] Use the optimal mathematical algorithm to process the reaction conditions and the characterization characteristics collected during each diagenesis simulation time period to obtain the correlation relationship between heterogeneity and the reaction conditions and the characterization characteristics, where the heterogeneity is characterized by pore characteristics.

[0071] In a further optional implementation manner, the correlation relationship between heterogeneity and reaction conditions and characterization characteristics is as follows:

[0072] H t = β0 + β1H x+β2H v +β3T + β4t + β5ΔX i +β6PH + β7P + δ;

[0073] Wherein, Ht is the heterogeneity of the oil and gas reservoir, characterized by pore characteristics; Hx is the mineral component characteristic, HV is the rock mechanical characteristic, T is the temperature characteristic, t is the diagenetic time characteristic, △Xi is the fluid characteristic, PH is the acidity and alkalinity characteristic, P is the pressure characteristic, β0 is the first regression coefficient, β1 is the second regression coefficient, β2 is the third regression coefficient, β3 is the fourth regression coefficient, β4 is the fifth regression coefficient, β5 is the sixth regression coefficient, β6 is the seventh regression coefficient, β7 is the eighth regression coefficient, and δ is the ninth regression coefficient.

[0074] An embodiment of the present invention provides a control device, including:

[0075] A configuration module, configured to determine the configuration conditions of the simulated core sample according to the lithology data of the oil and gas reservoir, and send the configuration conditions to the core sample configuration unit;

[0076] A reservoir formation module, configured to determine each reservoir formation time period and the corresponding reaction conditions of the reservoir formation process according to the genetic characteristics of the oil and gas reservoir, where the reaction conditions include at least one of pressure, temperature, and fluid; determine each reservoir formation simulation time period based on each reservoir formation time period;

[0077] An action module, configured to send the pressure and temperature corresponding to each reservoir formation simulation time period to the reaction unit, and send the fluid corresponding to each reservoir formation simulation time period to the injection unit;

[0078] An association module, configured to obtain the physical property characteristics of the simulated core sample determined by the physical property analysis unit using the multi-energy spectrum CT scanning technology, the rock mechanical characteristics of the simulated core sample determined by the mechanical property analysis unit using the ultrasonic monitoring technology, and the diagenetic fluid characteristics of the simulated core sample determined by the diagenetic fluid analysis unit during each reservoir formation simulation time period, to obtain the characterization characteristics of the core sample during each reservoir formation simulation time period, where the characterization characteristics include at least one of physical property characteristics, rock mechanical characteristics, and diagenetic fluid characteristics;

[0079] A characterization module, configured to determine the heterogeneity of the reservoir according to the reaction conditions and the characterization characteristics.

[0080] An embodiment of the present invention provides a computer storage medium, in which computer executable instructions are stored, and when the computer executable instructions are executed by a processor, the above-mentioned quantitative evaluation method for reservoir heterogeneity based on dynamic reservoir formation simulation is implemented.

[0081] An embodiment of the present invention provides a control device, including: a memory, a processor, and a computer program stored on the memory and executable on the processor. When the processor executes the program, the above-mentioned quantitative evaluation method for reservoir heterogeneity based on dynamic storage simulation is implemented.

[0082] The beneficial effects of the above technical solution provided by the embodiment of the present invention at least include:

[0083] For each diagenetic stage, the present invention takes into account reaction conditions and characterization features. The reaction conditions include temperature, pressure, and fluid, and the characterization features include physical property features, rock mechanical features, and diagenetic fluid features. The optimal mathematical algorithm is used to perform mathematical calculations on the reaction conditions and characterization features to obtain the correlation relationship between heterogeneity and reaction conditions as well as characterization features. The reaction conditions and characterization features of the reservoir are evaluated using the correlation relationship between heterogeneity and reaction conditions as well as characterization features to obtain the heterogeneity of the reservoir. The present invention overcomes the problem that the heterogeneity of the reservoir is not considered in the simulation of the reservoir storage process, resulting in the simulation results of the reservoir storage not meeting the requirements. Further, it overcomes the problem that the heterogeneity of the reservoir cannot be quantitatively evaluated during the reservoir storage process.

[0084] Other features and advantages of the present invention will be described in the subsequent description, and part of them will become obvious from the description or be understood by implementing the present invention. The objectives and other advantages of the present invention can be achieved and obtained through the structures specifically pointed out in the written description, claims, and drawings.

[0085] The technical solution of the present invention will be further described in detail below through the drawings and embodiments. Description of the Drawings

[0086] The drawings are used to provide a further understanding of the present invention, and constitute a part of the description. They are used together with the embodiments of the present invention to explain the present invention, and do not constitute a limitation to the present invention. In the drawings:

[0087] Figure 1 It is a schematic structural diagram of a reservoir dynamic storage simulation system in Embodiment 1 of the present invention;

[0088] Figure 2 It is a specific structural diagram of a reservoir dynamic storage simulation system in Embodiment 1 of the present invention;

[0089] Figure 3 It is a schematic enlarged structural diagram of a high-temperature module and an injection unit in Embodiment 1 of the present invention;

[0090] Figure 4 It is a schematic enlarged structural diagram of a high-pressure module in Embodiment 1 of the present invention;

[0091] Figure 5Schematic flowchart of the method for quantitatively evaluating reservoir heterogeneity based on dynamic reservoir simulation in the second embodiment of the present invention;

[0092] Figure 6 Schematic structural diagram of the control device in the embodiment of the present invention.

[0093] Explanation of reference numerals:

[0094] 111, First data converter; 112, Second data converter; 113, Third data converter; 114, Fourth data converter; 115, Fifth data converter; 116, Sixth data converter;

[0095] 211, Electron gun; 212, Vacuum pump; 213, Focusing coil; 214, Deflection coil; 215, Electron beam; 216, CT data collector;

[0096] 311, Ultrasonic receiver; 312, Ultrasonic transmitter;

[0097] 430, Pressure gauge; 411, Upper hydraulic device; 412, Upper hydraulic pipe; 413, Lower hydraulic device; 421, First layered pressure intensifier; 422, First layered pressure intensifying liquid pipe; 423, Second layered pressure intensifier; 426, Second layered pressure intensifying liquid pipe; 424, Third layered pressure intensifier; 427, Third layered pressure intensifying liquid pipe; 425, Fourth layered pressure intensifier; 428, Fourth layered pressure intensifying liquid pipe; 414, Lower hydraulic pipe; 431, Vertical diagenetic fluid injection pipe; 432, Vertical diagenetic fluid injector; 433, Lateral diagenetic fluid injector; 434, Lateral diagenetic fluid injection pipe; 435, Lateral diagenetic fluid outflow pipe; 436, Lateral diagenetic fluid outflow device; 437, Vertical diagenetic fluid outflow device; 438, Vertical diagenetic fluid outflow pipe; 821, Diagenetic fluid outflow pipe; 441, Heating coil;

[0098] 511, X-ray gun; 512, Simulated core sample; 513, X-ray tube;

[0099] 611, Sample transfer clamp; 612, Sample transfer clamp telescopic rod;

[0100] 711, Mineral dryer; 712, Mass sensor; 713, Mineral washer; 721, Mineral crusher; 722, Mineral powder sieve; 723, Mineral powder conveyor belt; 731, Mineral powder tablet press;

[0101] 811. First diagenetic fluid transfer pump; 812. Second diagenetic fluid transfer pump; 813. First diagenetic fluid storage tank; 814. Second diagenetic fluid storage tank; 815. Third diagenetic fluid storage tank; 816. Third diagenetic fluid transfer pump; 821. Diagenetic fluid outflow pipe; 822. Ultraviolet light source; 823. Ultraviolet spectrophotometer diaphragm; 824. pH meter; 825. Sample cell; 826. Spectrometer; 828. Interference filter; 827. Diagenetic fluid waste tank. Detailed implementation mode

[0102] The exemplary embodiments of the present disclosure will be described in more detail below with reference to the accompanying drawings. Although the exemplary embodiments of the present disclosure are shown in the drawings, it should be understood that the present disclosure can be implemented in various forms and should not be limited by the embodiments set forth herein. On the contrary, these embodiments are provided so that the present disclosure can be more thoroughly understood and the scope of the present disclosure can be fully conveyed to those skilled in the art.

[0103] Embodiment 1

[0104] Embodiment 1 of the present invention provides a reservoir dynamic reservoir formation simulation system, the structure of which is as Figure 1 shown, including a control device, a core preparation unit, a reaction unit, an injection unit, a physical property analysis unit, a mechanical property analysis unit, and a diagenetic fluid analysis unit connected to the control device. Among them, the reaction unit is also connected to the core preparation unit, the injection unit, the physical property analysis unit, the mechanical property analysis unit, and the diagenetic fluid analysis unit.

[0105] In the control device in this embodiment, the configuration conditions of the simulated core sample are determined according to the lithology data of the oil and gas reservoir; according to the genetic characteristics of the oil and gas reservoir, each reservoir formation time period and the corresponding reaction conditions during the reservoir formation process are determined, and the reaction conditions include pressure, temperature, and fluid. Each reservoir formation simulation time period is determined based on each reservoir formation time period; the characterization features of the core sample within each reservoir formation simulation time period are obtained, and the heterogeneity of the reservoir is determined according to the reaction conditions and the characterization features. Among them, the characterization features include at least one of physical property features, rock mechanical features, and diagenetic fluid features.

[0106] In this embodiment, the control device determines the configuration conditions of the simulated core sample according to the lithology data of the oil and gas reservoir; specifically, the control device determines the particle screening range of the core sample according to the lithology data of the oil and gas reservoir, and the particle screening range includes at least one of the mineral component range, the content range of each component, the particle size range, and the roundness range.

[0107] In this embodiment, the control device determines each reservoir formation simulation time period based on each reservoir formation time period; specifically, the control device compresses each reservoir formation time period into each reservoir formation simulation time period according to a specified ratio.

[0108] In this embodiment, the rock sample preparation unit prepares a simulated core sample under the configuration conditions of the simulated core sample; specifically, the rock sample preparation unit crushes the sampled core to obtain particles, screens the particles within the particle screening range, and washes, dries, and compresses the screened particles to obtain a simulated core sample.

[0109] In this embodiment, the rock sample preparation unit prepares a simulated core sample under the configuration conditions of the simulated core sample; specifically, the rock sample preparation unit crushes the sampled core to obtain particles, screens the particles within the particle screening range, and washes, dries, and compresses the screened particles to obtain a simulated core sample.

[0110] In this embodiment, the reaction unit places the simulated core sample and generates corresponding pressure and temperature acting on the simulated core sample during each storage simulation time period.

[0111] In this embodiment, the physical property analysis unit determines the physical property characteristics of the simulated core sample using multi-energy spectrum CT scanning technology during each storage simulation time period. Specifically, the physical property analysis unit is used to equally divide the simulated core sample into several segments to obtain several simulated sub-core samples during each diagenetic simulation time period, and uses multi-energy spectrum CT scanning technology to obtain the pore characteristics and mineral composition characteristics of the several simulated sub-core samples; based on the pore characteristics and mineral composition characteristics of the several simulated sub-core samples, the pore characteristics and mineral composition characteristics of the simulated core sample are obtained.

[0112] In this embodiment, the mechanical property analysis unit determines the rock mechanical characteristics of the simulated core sample using ultrasonic monitoring technology during each storage simulation time period. Specifically, the mechanical property analysis unit equally divides the simulated core sample into several segments to obtain several simulated sub-core samples during each diagenetic simulation time period, uses acoustic velocity measurement technology to obtain the rock mechanical characteristics of the several simulated sub-core samples, and based on the rock mechanical characteristics of the several simulated sub-core samples, the rock mechanical characteristics of the simulated core sample are obtained.

[0113] In this embodiment, the diagenetic fluid analysis unit determines the diagenetic fluid characteristics of the simulated core sample during each storage simulation time period, and the diagenetic fluid characteristics include at least one of fluid characteristics and pH characteristics. Specifically, the diagenetic fluid analysis unit determines the diagenetic fluid components and pH values of the simulated core sample during each diagenetic simulation time period, and determines the fluid characteristics and acid-base characteristics respectively based on the change values of the diagenetic fluid components and the change values of the pH values at the specified time points.

[0114] In this embodiment, it further includes a data acquisition unit connected to the control device; the data acquisition unit is also connected to the reaction unit, the injection unit, the physical property analysis unit, the mechanical property analysis unit, and the diagenetic fluid analysis unit; the data acquisition unit acquires the reaction conditions, physical property characteristics, rock mechanical characteristics, and diagenetic fluid characteristics during each reservoir formation simulation time period, and converts the formats of the reaction conditions, physical property characteristics, rock mechanical characteristics, and diagenetic fluid characteristics and sends them to the control device. Specifically, the data acquisition unit converts the reaction conditions, physical property characteristics, rock mechanical characteristics, and diagenetic fluid characteristics of different types of equipment in the simulation system during each reservoir formation simulation time period and sends them to the control device, so as to ensure that the data formats of different equipment are consistent and facilitate subsequent analysis and calculation. The data acquisition unit ensures the unity of the data format and improves the efficiency.

[0115] In this embodiment, it further includes a sample clamping unit arranged between the rock sample preparation unit and the reaction unit; the sample clamping unit clamps the simulated core sample into the reaction unit.

[0116] In this implementation, the specific structure of the reservoir dynamic reservoir formation simulation system is shown in Figure 2. The rock sample preparation unit includes a mineral crusher 721, a mineral powder sieve 722, a mineral powder tablet press 731, and a detection component that are connected in sequence; the detection component includes an X-ray gun 511 and an X-ray tube 513 that are connected in sequence; the mineral crusher 721 crushes the sampled core to obtain particles; the mineral powder sieve 722 screens the particles based on a preset particle screening range; the mineral powder tablet press 731 presses the screened particles to obtain a simulated core sample.

[0117] In this embodiment, the rock sample preparation unit further includes Figure 2 a mineral powder conveyor belt 723 as shown, and a mass sensor 712, a mineral washer 713, and a mineral dryer 711 that are connected to the mineral powder sieve 722 in sequence. The mineral dryer 711 is also connected to the mineral powder tablet press 731; the mineral powder conveyor belt 723 transports the screened particles; the mass sensor 712 determines the mass of the screened particles; the mineral washer 713 washes the selected particles; the mineral dryer 711 dries the selected particles.

[0118] Among them, the working process of the rock sample preparation unit: Under the configuration conditions of the simulated core sample, the mineral crusher 721 crushes the sampled core to obtain particles. The mineral powder sieve 722 screens the particles within a preset particle screening range to obtain screened particles. The mass sensor 712 determines the mass of the screened particles to select screened particles with appropriate mass. The mineral washer 713 washes the screened particles to remove impurities contained in the screened particles. The mineral dryer 711 dries the screened particles to remove moisture contained in the screened particles. The mineral powder tablet press 731 presses the screened particles to obtain a number of simulated core samples. The mineral powder conveyor belt 723 drives the screened particles placed in the mass sensor 712 through the mineral washer 713, the mineral dryer 711, and the mineral powder tablet press 731 to realize the automatic transportation of the screened particles; The X-ray gun 511 emits X-rays to the simulated core sample, and the X-ray tube 513 receives the X-rays passing through the simulated core sample, and determines the components of the simulated core sample based on the X-rays passing through the simulated core sample to select the simulated core samples with conforming components.

[0119] In this embodiment, the sample clamping unit specifically includes Figure 2 the sample transfer clamp 611 and the sample transfer clamp telescopic rod 612 as shown; The working process of the sample clamping unit: The sample transfer clamp 611 on the sample transfer clamp telescopic rod 612 clamps the simulated core sample with conforming components into the reaction unit.

[0120] In this implementation, the reaction unit includes Figure 3 the heating coil 441 as shown and Figure 4 the pressurizing component as shown; The heating coil 441 is used to heat the simulated core sample at the corresponding temperature within each storage simulation time period; The pressurizing component includes an upper hydraulic unit located above the heating coil 441, a lower hydraulic unit located below the heating coil 441, and a layered pressurizing unit located on the side of the heating coil 441; The upper hydraulic unit generates the corresponding longitudinal upward pressure within each storage simulation time period; The lower hydraulic unit generates the corresponding longitudinal downward pressure within each storage simulation time period; The layered pressurizing unit generates the corresponding layered pressure within each storage simulation time period, so as to better simulate the pressures corresponding to different layered periods during the reservoir formation process.

[0121] Among them, the upper hydraulic unit includes Figure 4 the upper hydraulic actuator 411 located above the heating coil 441 and the upper hydraulic pipe 412 arranged on the upper hydraulic actuator; The lower hydraulic unit includes Figure 4The lower hydraulic actuator 413 located below the heating coil 441 as shown and the lower hydraulic pipe 414 provided on the lower hydraulic actuator; a layered pressurization unit, including a first layered pressurizer 421, a second layered pressurizer 423, a third layered pressurizer 424, a fourth layered pressurizer 425 located on the side of the heating coil 441, and a first layered pressurization liquid pipe 422 provided on the first layered pressurizer 421, a second layered pressurization liquid pipe 426 provided on the second layered pressurizer 423, a third layered pressurization liquid pipe 427 provided on the third layered pressurizer 424, a fourth layered pressurization liquid pipe 428 provided on the fourth layered pressurizer 425. The reaction unit further includes a pressure gauge 430 so that technicians can observe the internal pressure of the reaction unit at any time.

[0122] Among them, the working process of the reaction unit: The heating coil 441 generates corresponding temperatures during each storage simulation time period and acts on the simulated core sample. The type of the heating coil 441 is a thermistor type. The pressure liquid enters the upper hydraulic actuator 411 through the upper hydraulic pipe 412, and the pressure liquid enters the lower hydraulic actuator 413 through the lower hydraulic pipe 414. The upper hydraulic actuator 411 and the lower hydraulic actuator 413 generate corresponding longitudinal pressures during each storage simulation time period, simulating the longitudinal pressures at different depths acting on the simulated core sample; the pressure liquid enters the first layered pressurizer 421, the second layered pressurizer 423, the third layered pressurizer 424, and the fourth layered pressurizer 425 through the first layered pressurization liquid pipe 422, the second layered pressurization liquid pipe 426, the third layered pressurization liquid pipe 427, and the fourth layered pressurization liquid pipe 428 respectively; the first layered pressurizer 421, the second layered pressurizer 423, the third layered pressurizer 424, and the fourth layered pressurizer 425 act together to generate corresponding layered pressures during each storage simulation time period, simulating the pressures corresponding to different layered periods during the reservoir formation process acting on the simulated core sample.

[0123] In this example, the injection unit specifically includes Figure 3 the vertical injection unit and the lateral injection unit as shown. The vertical injection unit injects corresponding fluids in the vertical direction of the simulated core sample during each storage simulation time period; the lateral injection unit injects corresponding fluids in the lateral direction of the simulated core sample during each storage simulation time period. The specific structure of the injection unit is as Figure 3The vertical injection unit shown includes a vertical diagenetic fluid injector 432 located above the heating coil 441, a vertical diagenetic fluid injection pipe 431 provided on the vertical diagenetic fluid injector 432, a vertical diagenetic fluid outflow pipe 438 located below the heating coil 441, and a vertical diagenetic fluid outflow pipe 438 provided on the vertical diagenetic fluid outflow device 437; the lateral injection unit includes a lateral diagenetic fluid injector 433 located on the side of the heating coil 441, a lateral diagenetic fluid injection pipe 434 provided on the lateral diagenetic fluid injector 433, a lateral diagenetic fluid outflow device 436 located on the other side of the heating coil 441, and a lateral diagenetic fluid outflow pipe 435 provided on the lateral diagenetic fluid outflow device 436.

[0124] In this embodiment, the injection unit further includes a Figure 3 diagenetic fluid outflow pipe 821 as shown. The diagenetic fluid outflow pipe 821 is connected to the lateral diagenetic fluid outflow pipe 435 and the vertical diagenetic fluid outflow pipe 438 to introduce the outflowing fluid into the diagenetic fluid waste tank 827.

[0125] In this embodiment, the injection unit further includes a Figure 2 first diagenetic fluid transfer pump 811, a second diagenetic fluid transfer pump 812, and a third diagenetic fluid transfer pump 816 connected to the lateral diagenetic fluid injection pipe 434 and the vertical diagenetic fluid injection pipe 431; a first diagenetic fluid storage tank 813, a second diagenetic fluid storage tank 814, and a third diagenetic fluid storage tank 815 respectively connected to the first diagenetic fluid transfer pump 811, the second diagenetic fluid transfer pump 812, and the third diagenetic fluid transfer pump 816; the first diagenetic fluid storage tank 813 stores fluid; the second diagenetic fluid storage tank 814 stores fluid; the third diagenetic fluid storage tank 815 stores fluid; the first diagenetic fluid transfer pump 811 injects the fluid stored in the first diagenetic fluid storage tank 813 into the vertical diagenetic fluid injection pipe 431 and the lateral diagenetic fluid injection pipe 434; the second diagenetic fluid transfer pump 812 injects the fluid stored in the second diagenetic fluid storage tank 814 into the vertical diagenetic fluid injection pipe 431 and the lateral diagenetic fluid injection pipe 434; the third diagenetic fluid transfer pump 816 injects the fluid stored in the third diagenetic fluid storage tank 815 into the vertical diagenetic fluid injection pipe 431 and the lateral diagenetic fluid injection pipe 434.

[0126] Among them, the working process of the injection unit: within each storage simulation time period, the first diagenetic fluid transfer pump 811, the second diagenetic fluid transfer pump 812, and the third diagenetic fluid transfer pump 816 respectively introduce the fluids stored in the first diagenetic fluid storage tank 813, the second diagenetic fluid storage tank 814, and the third diagenetic fluid storage tank 815 into the vertical diagenetic fluid injection pipe 431 and the lateral diagenetic fluid injection pipe 434. The vertical diagenetic fluid injector 432 and the lateral diagenetic fluid injector 433 inject the fluid into the simulated core sample. The fluid passing through the simulated core sample is exported through the vertical diagenetic fluid outflow device and the lateral diagenetic fluid outflow device via the vertical diagenetic fluid outflow pipe 438 and the lateral diagenetic fluid outflow pipe 435. The exported fluid flows into the diagenetic fluid waste tank 827 through the diagenetic fluid outflow pipe 821.

[0127] Among them, the specific structure of the physical property analysis unit includes Figure 2 the electron gun 211, the vacuum pump 212, the focusing coil 213, the deflection coil 214, the electron beam 215, and the CT data collector 216 as shown; among them, the electron gun 211 generates electrons with different energies; the vacuum pump 212 transports electrons with different energies; the focusing coil 213 focuses the electrons with different energies; the deflection coil 214 deflects the focused electrons; the electron beam 215 acts on the simulated core sample with the deflected electrons; the CT data collector 216 collects the electrons passing through the simulated core sample.

[0128] Among them, the working process of the physical property analysis unit: the electron gun 211 generates electrons with different energies, the vacuum pump 212 makes the electrons with different energies move in a vacuum environment, the focusing coil 213 focuses the electrons with different energies into an electron beam, the electron beam 215 acts on the simulated core sample with the electron beam, the CT data collector 216 collects the electron beam passing through the simulated core sample, and the CT data collector 216 determines the pore characteristics and mineral component characteristics of the simulated core sample based on the electron beam passing through the simulated core sample.

[0129] Among them, the specific structure of the mechanical property analysis unit includes the ultrasonic receiver 311 and the ultrasonic transmitter 312 connected to the reaction unit;. The ultrasonic transmitter 312 generates ultrasonic waves that act on the simulated core sample; the ultrasonic receiver 311 receives the ultrasonic waves reflected by the simulated core sample.

[0130] Among them, the working process of the mechanical property analysis unit: within each storage simulation time period, the ultrasonic transmitter 312 emits ultrasonic waves that act on the simulated core sample, the ultrasonic receiver 311 receives the ultrasonic waves reflected by the simulated core sample, and the ultrasonic receiver 311 determines the rock mechanical characteristics of the simulated sample based on the ultrasonic waves reflected by the simulated core sample.

[0131] Among them, the specific structure of the diagenetic fluid analysis unit includes a sample tank 825 connected to the reaction unit, an interference filter 828, a pH meter 824, and a spectrometer 826 connected to the sample tank 825, a UV spectrophotometer diaphragm 823 connected to the interference filter 828, and a UV light source 822 connected to the UV spectrophotometer diaphragm 823. The sample tank 825 is used to place the simulated core sample; the UV light source 822 generates UV light; the UV spectrophotometer diaphragm 823 determines the intensity of the UV light; the interference filter 828 filters out non-UV light; the pH meter 824 determines the acidity and alkalinity of the environment where the simulated core sample is located; the spectrometer 826 receives the UV light reflected by the simulated core sample.

[0132] Among them, the working process of the diagenetic fluid analysis unit: within each diagenetic storage simulation time period, the UV light source 822 generates UV light of a specified frequency. The UV light of the specified frequency passes through the UV spectrophotometer diaphragm 823, and the UV spectrophotometer diaphragm 823 determines the intensity of the UV light of the specified frequency to select and generate UV light with appropriate intensity. The UV light of the specified frequency passes through the interference filter 828 to filter out non-UV light in the UV light of the specified frequency and acts on the simulated core sample in the sample tank 825. The spectrometer 826 analyzes the UV light reflected by the simulated core sample to obtain the diagenetic fluid components, and the pH meter 824 obtains the acidity and alkalinity values around the simulated core sample; based on the change values of the diagenetic fluid components and the change values of the acidity and alkalinity values at a specified time point, the fluid characteristics and the acidity and alkalinity characteristics are determined respectively.

[0133] Among them, the data acquisition unit includes Figure 2 as shown, a first data converter 111 connected to the reaction unit and the control device, a second data converter 112 connected to the third diagenetic fluid delivery pump 816 and the control device, a third data converter 113 connected to the first diagenetic fluid delivery pump 811 and the control device, a fourth data converter 114 connected to the second diagenetic fluid delivery pump 812 and the control device, a fifth data converter 115 connected to the physical property analysis unit and the control device, and a sixth data converter 116 connected to the diagenetic fluid analysis unit and the control device; the first data converter 111 performs format conversion on the temperature and pressure in each diagenetic storage simulation time period; the second data converter 112 performs format conversion on the data of the fluid delivered by the first diagenetic fluid delivery pump 811; the third data converter 113 performs format conversion on the data of the fluid delivered by the second diagenetic fluid delivery pump 812; the fourth data converter 114 performs format conversion on the data of the fluid delivered by the third diagenetic fluid delivery pump 816; the fifth data converter 115 performs format conversion on the physical property characteristics in each diagenetic storage simulation time period; the sixth data converter 116 performs format conversion on the rock mechanics characteristics and diagenetic fluid characteristics in each diagenetic storage simulation time period.

[0134] Among them, the working process of the data acquisition unit: The first data converter 111 acquires the temperature and pressure within each storage simulation time period, converts the temperature and pressure according to the specified data format, and sends them to the control device; The second data converter 112 acquires the data of the fluid transported by the first diagenetic fluid delivery pump 811 and performs format conversion and sends it to the control device; The third data converter 113 acquires the data of the fluid transported by the second diagenetic fluid delivery pump 812 and performs format conversion and sends it to the control device; The fourth data converter 114 acquires the data of the fluid transported by the third diagenetic fluid delivery pump 816 and performs format conversion and sends it to the control device; The fifth data converter 115 acquires the physical property characteristics of the simulated core sample within each storage simulation time period, converts the physical property characteristics, and sends them to the control device; The sixth data converter 116 acquires the diagenetic fluid characteristics of the mold within each storage simulation time period, converts the diagenetic fluid characteristics, and sends them to the control device.

[0135] In this embodiment, for each diagenetic stage, reaction conditions and characterization features are considered. The reaction conditions include temperature, pressure, and fluid, and the characterization features include physical property characteristics, rock mechanical characteristics, and diagenetic fluid characteristics; Using the optimal mathematical algorithm to perform mathematical calculations on the reaction conditions and characterization features, the correlation relationship between heterogeneity and reaction conditions and characterization features is obtained, and the reaction conditions and characterization features of the reservoir are evaluated using the correlation relationship between heterogeneity and reaction conditions and characterization features to obtain the heterogeneity of the reservoir. The present invention overcomes the problem that the heterogeneity of the reservoir is not considered during the simulation of the reservoir storage process, resulting in the simulated reservoir storage results not meeting the requirements. It further overcomes the problem that the heterogeneity of the reservoir cannot be quantitatively evaluated during the reservoir storage process.

[0136] Embodiment Two

[0137] Embodiment Two of the present invention provides a method for quantitatively evaluating the heterogeneity of a reservoir based on dynamic storage simulation, and its process is as Figure 5 , including the following steps:

[0138] Step S501: Determine the configuration conditions of the simulated core sample according to the lithology data of the oil and gas reservoir, and configure the simulated core sample under the configuration conditions of the simulated core sample.

[0139] In this embodiment, the control device determines the configuration conditions of the simulated core sample according to the lithology data of the oil and gas reservoir, and the control device controls the core sample preparation unit to configure the simulated core sample according to the configuration conditions of the simulated core sample.

[0140] Step S502: According to the genetic characteristics of the oil and gas reservoir, determine each storage time period of the storage process and the corresponding reaction conditions for each storage time period, and determine each storage simulation time period based on each storage time period. Among them, the reaction conditions include at least one of pressure, temperature, and fluid.

[0141] In this embodiment, the control device determines each reservoir-forming time period of the reservoir-forming process and the corresponding pressure, temperature, and fluid for each reservoir-forming time period according to the genetic characteristics of the oil and gas reservoir. The control device determines each reservoir-forming simulation time period based on each reservoir-forming time period. For example, if the entire reservoir-forming process of the reservoir is 100 years, the entire reservoir-forming process is decomposed into an initial stage, a middle stage, and a late stage, where the initial stage is 20 years, the middle stage is 70 years, and the late stage is 10 years. The entire simulation process is 100 days. The initial simulation time is determined to be 20 days, the middle simulation time is determined to be 70 days, and the late simulation time is determined to be 10 days. And the pressure, temperature, and fluid corresponding to each time period in the initial, middle, and late stages are determined.

[0142] Step S503: Apply the reaction conditions corresponding to each reservoir-forming simulation time period to the simulated core sample.

[0143] In this embodiment, the simulated core sample is placed in a reaction unit. The reaction unit simulates various physical and chemical reactions during the reservoir-forming process, has good sealing performance, can withstand high pressure and high temperature conditions, and is resistant to the erosion of corrosive fluids. The control device controls the high-temperature module to generate a corresponding temperature in each simulated diagenesis time period and act on the simulated core sample in the reaction unit. The high-temperature module provides a stable temperature field through an electric heating element to simulate the formation temperature conditions. The control device controls the high-pressure module to generate a corresponding pressure in the reservoir-forming simulation time period and act on the simulated core sample in the reaction unit. The hydraulic pump in the high-pressure module dynamically provides the pressure acting on the simulated core sample.

[0144] The control device controls the injection unit to inject the corresponding fluid into the simulated core sample in the reaction unit in each simulated diagenesis time period. The injection unit simulates the fluid environment in the real geological conditions and simulates the migration mode of the diagenetic fluid during the reservoir-forming process in each simulated diagenesis time period, where the migration mode includes lateral migration and vertical migration. Fluids are injected into the simulated core sample in the reaction unit. For example, water, brine, oil, acid, etc. are injected into the simulated core sample.

[0145] Step S504: Obtain the physical property characteristics of the simulated core sample determined by the physical property analysis unit using the multi-energy spectrum CT scanning technology, the rock mechanical characteristics of the simulated core sample determined by the mechanical property analysis unit using the ultrasonic monitoring technology, and the diagenetic fluid characteristics of the simulated core sample determined by the diagenetic fluid analysis unit in each reservoir-forming simulation time period, so as to obtain the characterization characteristics of the core sample in each reservoir-forming simulation time period. The characterization characteristics include at least one of physical property characteristics, rock mechanical characteristics, and diagenetic fluid characteristics.

[0146] In this embodiment, the physical property characteristics of the simulated core samples determined by the physical property analysis unit using the multi - energy - spectrum CT scanning technology are obtained during each reservoir - forming simulation time period. Specifically, the analysis unit uses multi - energy - spectrum CT scanning. By utilizing the absorption differences of X - rays with different energies for different substances, different components and pore structures of the simulated core samples are distinguished to obtain a three - dimensional image of the simulated core samples. Based on the three - dimensional image of the simulated core samples, the pore characteristics and component characteristics of the simulated core samples can be obtained, and the influence of fluids on the simulated core samples can be avoided. For example, the simulated core sample is equally divided into S segments in the three - dimensional space (X, Y, Z) directions, and a total of S 3 simulated sub - core samples are obtained. The computerized tomography (CT) technology is used to analyze the simulated sub - core samples in detail to obtain the pore characteristics and component characteristics of the simulated sub - core samples. Among them, the pore characteristics of the simulated sub - core samples are denoted as φ i , where i represents the number of blocks of the simulated sub - core samples; the heterogeneity is characterized by the pore characteristics, and the heterogeneity is calculated using the formula, where φ is the mean value of φ i , and N is the number of simulated sub - core samples. The relative standard deviation H of the pore characteristics of the simulated sub - core samples changes with the number of segmentation segments S. The number of segmentation segments is determined according to the standard deviation H of the actual situation. For example, when the number of segmentation segments is 10 according to the actual situation, the relative standard deviation H begins to stabilize. Therefore, in this embodiment, the number of segmentation segments is set to 10 segments.

[0147] The rock mechanical characteristics of the simulated core samples determined by the mechanical property analysis unit using the ultrasonic monitoring technology are obtained during each reservoir - forming simulation time period. Specifically, the rock mechanical characteristics of the simulated core samples are determined based on the acoustic velocity measurement method, and the rock mechanical characteristics are calculated using the formula, where H v is the rock mechanical characteristic of the simulated core sample, V i is the rock mechanical characteristic of the i - th simulated sub - core sample, is the average value of v i , and n is the number of simulated sub - core samples.

[0148] The diagenetic fluid characteristics of the simulated core samples determined by the diagenetic fluid analysis unit are obtained during each reservoir - forming simulation time period. Specifically, at the specified time points during each reservoir - forming simulation time period, the change values of the diagenetic fluid components and the change values of the acid - base values are determined, and the diagenetic fluid characteristics and the acid - base characteristics are determined based on the change values of the diagenetic fluid components and the acid - base values. The diagenetic fluid characteristics are calculated using the formula ΔX = M 注入前 - M 注入后 , where ΔX represents the diagenetic fluid characteristics, M 注入前 represents the chemical components of the diagenetic fluid before injection at the specified time, and M 注入后It represents the chemical components of the diagenetic fluid after injection at a specified time, where the chemical components of the diagenetic fluid include at least one of Al3+, Mg2+, Ca2+, K+, Na+, S2-, Cl-, SO42-, CO22-, and HCO2-. The pH characteristic is the pH difference obtained by subtracting the pH value after the specified time from the pH value before the specified time.

[0149] Step S505: Determine the heterogeneity of the reservoir according to the reaction conditions and characterization features.

[0150] In this embodiment, an optimal mathematical algorithm is used to process the reaction conditions and characterization features collected in each diagenetic simulation time period to obtain the correlation between heterogeneity, reaction conditions, and characterization features. The heterogeneity is characterized by pore features; the optimal mathematical algorithm used can be the least squares method.

[0151] The correlation between heterogeneity, reaction conditions, and characterization features is as follows:

[0152] H t = β0 + β1H x + β2H v + β3T + β4t + β5ΔX i + β6PH + β7P + δ;

[0153] Where Ht is the heterogeneity of the oil and gas reservoir, characterized by its pore features; Hx is the mineral component feature, H V is the rock mechanics feature, T is the temperature feature, t is the diagenetic time feature, △Xi is the fluid feature (i is the component Al3+, Mg2+, Ca2+, K+, Na+, S2-, Cl-, SO42-, CO22-, HCO2-), PH is the pH characteristic, P is the pressure feature, β0 is the first regression coefficient, β1 is the second regression coefficient, β2 is the third regression coefficient, β3 is the fourth regression coefficient, β4 is the fifth regression coefficient, β5 is the sixth regression coefficient, β6 is the seventh regression coefficient, β7 is the eighth regression coefficient, and δ is the ninth regression coefficient. The values of the regression coefficients reflect the influence intensity of diagenetic features and mineral component features on the heterogeneity of the reservoir.

[0154] Furthermore, in order to reflect the change characteristics of heterogeneity during the entire simulation process, a heterogeneity evolution coefficient is proposed. The heterogeneity evolution coefficient is represented by a formula, where t is the evolution time, H t is the heterogeneity of the reservoir at time t, H0 is the heterogeneity of the reservoir at the initial time, and k is the heterogeneity evolution coefficient. The evolution coefficient can reflect the change degree of reservoir heterogeneity and can further guide the design of the exploitation plan.

[0155] In the process of simulating the reservoir formation of the present invention, each reservoir formation time period is considered, and the influence of physical properties and diagenetic characteristics is considered during each reservoir formation time period. The pore characteristics are used to characterize the heterogeneity of the reservoir, and the heterogeneity factor is introduced in the process of simulating the reservoir formation; considering the heterogeneity of the reservoir makes the simulation results closer to the actual geological situation, and thus the simulation results obtained by the present invention are more accurate, providing more accurate and reliable scientific data for the development evaluation of oil and gas reservoirs.

[0156] The present invention controls temperature, pressure, and fluid in an automated manner to ensure the accuracy and repeatability of experimental results, reduce human operation errors, and improve the efficiency of experimental operations.

[0157] Based on the same inventive concept, an embodiment of the present invention also provides a control device, and the structure of the device is as Figure 6 shown, including: a configuration module 601, a reservoir formation module 602, an action module 603, an association module 604, and a characterization module 605.

[0158] The configuration module 601 is used to determine the configuration conditions of the simulated core sample according to the lithology data of the oil and gas reservoir, and send the configuration conditions to the core sample configuration unit.

[0159] The reservoir formation module 602 is used to determine each reservoir formation time period of the reservoir formation process and the corresponding pressure, temperature, and fluid during each reservoir formation time period. The fluid includes fluid components and the proportion of each component; based on each reservoir formation time period, each reservoir formation simulation time period is determined.

[0160] The action module 603 is used to send the pressure and temperature corresponding to each reservoir formation simulation time period to the reaction unit, and send the fluid corresponding to each reservoir formation simulation time period to the injection unit.

[0161] The association module 604 is used to obtain the physical property characteristics of the simulated core sample determined by the physical property analysis unit using the multi-energy spectrum CT scanning technology, the rock mechanical characteristics of the simulated core sample determined by the mechanical property analysis unit using the ultrasonic monitoring technology, and the diagenetic fluid characteristics of the simulated core sample determined by the diagenetic fluid analysis unit during each reservoir formation simulation time period, and obtain the characterization characteristics of the core sample during each reservoir formation simulation time period. The characterization characteristics include at least one of physical property characteristics, rock mechanical characteristics, and diagenetic fluid characteristics.

[0162] The characterization module 605 is used to determine the heterogeneity of the reservoir according to the reaction conditions and the characterization characteristics.

[0163] Based on the same inventive concept, the present invention also provides a computer storage medium. The computer storage medium stores computer-executable instructions, and when the computer-executable instructions are executed by a processor, the above-mentioned method for quantitatively evaluating the heterogeneity of a reservoir based on dynamic reservoir formation simulation is implemented.

[0164] Based on the same inventive concept, an embodiment of the present invention further provides a control device, including: a memory, a processor, and a computer program stored on the memory and executable on the processor. When the processor executes the program, the above-mentioned quantitative evaluation method for reservoir heterogeneity based on dynamic storage simulation is implemented.

[0165] Regarding the device in the above embodiment, the specific manners in which each module performs operations have been described in detail in the embodiments related to the method, and will not be elaborated herein.

[0166] Unless otherwise specifically stated, terms such as processing, computing, calculating, determining, displaying, etc. may refer to the actions and / or processes of one or more processing or computing systems, or similar devices, which operate on and transform data represented as physical (such as electronic) quantities in the registers or memories of the processing system into other data similarly represented as physical quantities in the memories, registers, or other such information storage, transmission, or display devices of the processing system. Information and signals can be represented using any of a variety of different technologies and methods. For example, the data, instructions, commands, information, signals, bits, symbols, and chips mentioned throughout the above description can be represented by voltages, currents, electromagnetic waves, magnetic fields or particles, optical fields or particles, or any combination thereof.

[0167] It should be understood that the specific order or hierarchy of steps in the disclosed processes is an example of an exemplary method. Based on design preferences, it should be understood that the specific order or hierarchy of steps in the process can be rearranged without departing from the scope of the present disclosure. The appended method claims present the elements of the various steps in an exemplary order and are not intended to be limited to the specific order or hierarchy.

[0168] In the above detailed description, various features are combined in a single embodiment to simplify the present disclosure. This method of disclosure should not be interpreted as reflecting an intention that the embodiments of the claimed subject matter require more features than are clearly stated in each claim. On the contrary, as reflected in the appended claims, the present invention lies in a state with fewer features than all the features of the disclosed single embodiment. Therefore, the appended claims are hereby clearly incorporated into the detailed description, where each claim stands alone as a separate preferred embodiment of the present invention.

[0169] Those skilled in the art should also understand that all the illustrative logical blocks, modules, circuits, and algorithmic steps described in conjunction with the embodiments herein can be implemented as electronic hardware, computer software, or a combination thereof. To clearly illustrate the interchangeability between hardware and software, the above various illustrative components, blocks, modules, circuits, and steps have been generally described in terms of their functions. Whether such a function is implemented as hardware or software depends on the specific application and the design constraints imposed on the overall system. Skilled technicians can implement the described functions in a flexible manner for each specific application. However, such implementation decisions should not be construed as departing from the scope of protection of the present disclosure.

[0170] The steps of the methods or algorithms described in conjunction with the embodiments herein can be directly embodied as hardware, software modules executed by a processor, or a combination thereof. The software modules can be located in a RAM memory, a flash memory, a ROM memory, an EPROM memory, an EEPROM memory, a register, a hard disk, a removable disk, a CD-ROM, or any other form of storage medium well-known in the art. An exemplary storage medium is connected to the processor so that the processor can read information from and write information to the storage medium. Of course, the storage medium can also be a component of the processor. The processor and the storage medium can be located in an ASIC. The ASIC can be located in a user terminal. Of course, the processor and the storage medium can also exist as discrete components in the user terminal.

[0171] For software implementation, the techniques described in this application can be implemented using modules (e.g., procedures, functions, etc.) that perform the functions described in this application. These software codes can be stored in a memory unit and executed by a processor. The memory unit can be implemented inside the processor or outside the processor. In the latter case, it is communicatively coupled to the processor by various means, which are well-known in the art.

[0172] The above description includes examples of one or more embodiments. Of course, it is impossible to describe all possible combinations of components or methods for the purpose of describing the above embodiments. However, those of ordinary skill in the art should recognize that the various embodiments can be further combined and arranged. Therefore, the embodiments described herein are intended to cover all such changes, modifications, and variations that fall within the scope of protection of the appended claims. In addition, with respect to the term "comprising" used in the specification or claims, the manner in which this term is covered is similar to the term "including," as is explained when "including" is used as a transitional word in the claims. In addition, any term "or" used in the claims or the specification is intended to mean "non-exclusive or."

Claims

1. A reservoir dynamic formation simulation system, characterized in that: include: Control device, rock sample preparation unit, reaction unit, injection unit, physical property analysis unit, mechanical property analysis unit, diagenetic fluid analysis unit; The control device is used to determine the configuration conditions of the simulated core samples according to the lithological data of the oil and gas reservoir; determine each storage time period of the storage process and the reaction conditions corresponding to each storage time period according to the genetic characteristics of the oil and gas reservoir, and the reaction conditions include at least one of pressure, temperature, and fluid; determine each storage simulation time period based on each storage time period; obtain the characterization characteristics of the core samples in each storage simulation time period, and the characterization characteristics include at least one of physical property characteristics, rock mechanical characteristics, and diagenetic fluid characteristics; determine the heterogeneity of the reservoir according to the reaction conditions and the characterization characteristics; The rock sample preparation unit is used to configure and prepare the simulated core sample under the configuration conditions of the simulated core sample; The reaction unit is used to place the simulated core sample and generate corresponding pressure and temperature to act on the simulated core sample in each reservoir simulation time period; The injection unit is used to inject the corresponding fluid into the simulated core sample in each reservoir simulation time period; The physical property analysis unit is used to determine the physical property characteristics of the simulated core sample by using the multi-energy spectrum CT scanning technology in each reservoir simulation time period; The mechanical property analysis unit is used to determine the rock mechanical characteristics of the simulated core sample by using ultrasonic monitoring technology during each reservoir simulation time period; The diagenetic fluid analysis unit is used to determine the diagenetic fluid characteristics of the simulated core sample within each reservoir simulation time period.

2. The system according to claim 1, characterized in that The physical property characteristics include at least one of mineral component characteristics and pore characteristics; the diagenetic fluid characteristics include at least one of fluid characteristics and pH characteristics.

3. The system according to claim 2, characterized in that Also includes a data acquisition unit connected to the control device; The data acquisition unit is used to obtain the reaction conditions, physical properties, rock mechanical characteristics, and diagenetic fluid characteristics in each reservoir simulation time period, and convert the reaction conditions, physical properties, rock mechanical characteristics, and diagenetic fluid characteristics into a format and send them to the control device.

4. The system according to claim 1, characterized in that The control device is used to determine the configuration conditions of the simulated core sample according to the lithological data of the oil and gas reservoir, including: The control device is used to determine the particle screening range of the core sample according to the lithological data of the oil and gas reservoir, and the particle screening range includes at least one of the mineral component range, the content range of each component, the particle size range, and the roundness range; The rock sample preparation unit is used to configure and prepare the simulated core sample under the configuration conditions of the simulated core sample, including: The rock sample preparation unit is used to crush the sampled rock core to obtain particles, screen the particles within a particle screening range, and wash, dry and press the screened particles to obtain a simulated rock core sample.

5. The system according to claim 4, characterized in that The control device is used to determine each reservoir formation simulation time period based on each reservoir formation time period, including: The control device is used to compress each storage formation time period into each storage formation simulation time period according to a specified ratio.

6. The system according to claim 5, characterized in that The physical property analysis unit is used to determine the physical property characteristics of the simulated core sample by using the multi-energy spectrum CT scanning technology in each reservoir simulation time period, including: The physical property analysis unit is used to divide the simulated core sample into several sections to obtain several simulated sub-core samples in each diagenetic simulation time period, and obtain the pore characteristics and mineral component characteristics of the several simulated sub-core samples by using multi-energy spectrum CT scanning technology; and obtain the pore characteristics and mineral component characteristics of the simulated core sample based on the pore characteristics and mineral component characteristics of the several simulated sub-core samples; The mechanical property analysis unit is used to determine the rock mechanical characteristics of the simulated core sample by using ultrasonic monitoring technology in each reservoir simulation time period, including: The mechanical property analysis unit is used to divide the simulated core sample into several sections to obtain several simulated sub-core samples in each diagenetic simulation time period, obtain the rock mechanical characteristics of the several simulated sub-core samples by using the acoustic wave velocity measurement technology, and obtain the rock mechanical characteristics of the simulated core sample based on the rock mechanical characteristics of the several simulated sub-core samples; The diagenetic fluid analysis unit is used to determine at least one of the diagenetic fluid characteristics and the pH characteristics of the simulated core sample in each reservoir simulation time period, including: The diagenetic fluid analysis unit is used to determine the diagenetic fluid components and pH values ​​of the simulated core samples within each diagenetic simulation time period, and to determine the fluid characteristics and pH characteristics based on the change values ​​of the diagenetic fluid components and the change values ​​of the pH values ​​at the specified time points.

7. The system according to claim 1, characterized in that The rock sample preparation unit includes a mineral crusher, a mineral powder sifter and a mineral powder tablet press connected in sequence, and a detection component; the detection component includes an X-ray gun and an X-ray tube connected in sequence; The mineral crusher is used to crush the sampled core to obtain particles; the mineral powder sifter is used to screen the particles based on a preset particle screening range; the mineral powder tablet press is used to press the screened particles to obtain a simulated core sample; The X-ray gun is used to emit X-rays to the simulated core sample; the X-ray tube is used to determine the components of the simulated core sample according to the X-rays reflected by the simulated core sample.

8. The system according to claim 7, characterized in that The rock sample preparation unit also includes a mineral powder conveyor belt, and a mass sensor, a mineral washer, and a mineral dryer which are sequentially connected to the mineral powder sifter, and the mineral dryer is also connected to the mineral powder tablet press; The mineral powder conveyor belt is used to transport the screened particles; the quality sensor is used to determine the quality of the screened particles; the mineral washer is used to wash the selected particles; and the mineral dryer is used to dry the selected particles.

9. The system according to claim 8, characterized in that The reaction unit includes a heating coil and a pressurizing component; The heating coil is used to heat the simulated core sample at the corresponding temperature in each reservoir simulation time period; The pressurizing assembly includes an upper hydraulic unit located above the heating coil, a lower hydraulic unit located below the heating coil, and a layered pressurizing unit located on the side of the heating coil; the upper hydraulic unit is used to generate corresponding longitudinal upper pressure in each storage simulation time period; The lower hydraulic unit is used to generate corresponding longitudinal downforce in each storage simulation time period; The stratified pressure unit is used to generate corresponding stratified pressure in each reservoir simulation time period.

10. The system according to claim 9, characterized in that The upper hydraulic unit comprises an upper hydraulic machine located above the heating coil and an upper hydraulic pipe arranged on the upper hydraulic machine; The lower hydraulic unit comprises a lower hydraulic machine located below the heating coil and a lower hydraulic pipe arranged on the lower hydraulic machine; The layered pressurizing unit includes a first layered pressurizer, a second layered pressurizer, a third layered pressurizer, a fourth layered pressurizer, and a first layered pressurizing liquid pipe arranged on the first layered pressurizer, a second layered pressurizing liquid pipe arranged on the second layered pressurizer, a third layered pressurizing liquid pipe arranged on the third layered pressurizer, and a fourth layered pressurizing liquid pipe arranged on the fourth layered pressurizer.

11. The system according to claim 10, characterized in that The injection unit includes a vertical injection unit and a lateral injection unit. The vertical injection unit is used to inject the corresponding fluid in the vertical direction of the simulated core sample within each reservoir simulation time period; the lateral injection unit is used to inject the corresponding fluid in the lateral direction of the simulated core sample within each reservoir simulation time period.

12. The system according to claim 11, characterized in that The vertical injection unit comprises a vertical diagenetic fluid injector located above the heating coil, a vertical diagenetic fluid injection pipe arranged on the vertical diagenetic fluid injector, a vertical diagenetic fluid outflow pipe located below the heating coil, and a vertical diagenetic fluid outflow pipe arranged on the vertical diagenetic fluid outflow pipe; The lateral injection unit includes a lateral diagenetic fluid injector located on the side of the heating coil, a lateral diagenetic fluid injection pipe arranged on the lateral diagenetic fluid injector, a lateral diagenetic fluid outflow device located on the other side of the heating coil, and a lateral diagenetic fluid outflow pipe arranged on the lateral diagenetic fluid outflow device.

13. The system of claim 12, wherein: The injection unit further comprises a first diagenetic fluid delivery pump, a second diagenetic fluid delivery pump, and a third diagenetic fluid delivery pump connected to the lateral diagenetic fluid injection pipe and the vertical diagenetic fluid injection pipe; a first diagenetic fluid storage tank, a second diagenetic fluid storage tank, and a third diagenetic fluid storage tank respectively connected to the first diagenetic fluid delivery pump, the second diagenetic fluid delivery pump, and the third diagenetic fluid delivery pump; A first diagenetic fluid storage tank is used to store fluid; a second diagenetic fluid storage tank is used to store fluid; and a third diagenetic fluid storage tank is used to store fluid; The first diagenetic fluid delivery pump is used to inject the fluid stored in the first diagenetic fluid storage tank into the diagenetic fluid injection pipe and the vertical diagenetic fluid injection pipe; the second diagenetic fluid delivery pump is used to inject the fluid stored in the second diagenetic fluid storage tank into the diagenetic fluid injection pipe and the vertical diagenetic fluid injection pipe; the third diagenetic fluid delivery pump is used to inject the fluid stored in the third diagenetic fluid storage tank into the diagenetic fluid injection pipe and the vertical diagenetic fluid injection pipe.

14. The system of claim 13, wherein: The physical property analysis unit includes an electron beam and a CT data collector connected to the reaction unit, and a deflection coil, a focusing coil, a vacuum pump, and an electron gun connected to the electron beam in sequence; Electron guns, used to generate electrons of different energies; vacuum pumps, used to transport electrons of different energies; Focusing coils, used to focus electrons of different energies; A deflection coil, used to deflect the focused electrons; an electron beam for applying deflected electrons to a simulated core sample; A CT data collector is used to collect electrons passing through the simulated core sample.

15. The system of claim 14, wherein: The diagenetic fluid analysis unit comprises a sample slot connected to the reaction unit, an interference filter, a pH meter, and a spectrometer connected to the sample slot, an ultraviolet spectrophotometer diaphragm connected to the interference filter, and an ultraviolet light source connected to the ultraviolet spectrophotometer diaphragm; A sample slot, used for placing a simulated core sample; an ultraviolet light source, used for generating ultraviolet light; The UV spectrophotometer diaphragm is used to determine the intensity of the UV light; the interference filter is used to eliminate non-UV light; the pH meter is used to determine the pH value of the environment where the simulated core sample is located; and the spectrometer is used to receive the UV light reflected by the simulated core sample.

16. The system of claim 15, wherein: The mechanical property analysis unit includes an ultrasonic receiver and an ultrasonic transmitter connected to the reaction unit; The ultrasonic transmitter is used for generating ultrasonic waves to act on the simulated core sample; and the ultrasonic receiver is used for receiving the ultrasonic waves reflected by the simulated core sample.

17. The system of claim 16, wherein: The data acquisition unit includes a first data converter connected to the reaction unit and the control device, a second data converter connected to the third diagenetic fluid delivery pump and the control device, a third data converter connected to the first diagenetic fluid delivery pump and the control device, a fourth data converter connected to the second diagenetic fluid delivery pump and the control device, a fifth data converter connected to the physical property analysis unit and the control device, and a sixth data converter connected to the diagenetic fluid analysis unit and the control device; The first data converter is used for format conversion of temperature and pressure in each storage simulation time period; A second data converter, used for converting the format of the data of the fluid delivered by the first diagenetic fluid delivery pump; A third data converter, used for converting the format of the data of the fluid delivered by the second diagenetic fluid delivery pump; a fourth data converter, used for converting the format of the data of the fluid delivered by the third diagenetic fluid delivery pump; The fifth data converter is used for format conversion of physical property characteristics within each reservoir simulation time period; the sixth data converter is used for format conversion of rock mechanical characteristics and diagenetic fluid characteristics within each reservoir simulation time period.

18. The system of claim 17, wherein: A sample clamping unit is also provided between the rock sample preparation unit and the reaction unit; The sample clamping unit is used to clamp the simulated core sample to the reaction unit; The sample clamping unit comprises a sample transfer clamp telescopic rod and a sample transfer clamp connected to the sample transfer clamp telescopic rod.

19. A quantitative evaluation method for reservoir heterogeneity based on dynamic reservoir simulation, characterized in that: include: Determining configuration conditions of simulated core samples according to lithological data of oil and gas reservoirs, and configuring and preparing simulated core samples under the configuration conditions of simulated core samples; Determine each storage time period of the storage process and the reaction conditions corresponding to each storage time period according to the genetic characteristics of the oil and gas reservoir, wherein the reaction conditions include at least one of pressure, temperature, and fluid; determine each storage simulation time period based on each storage time period; Apply the reaction conditions corresponding to each reservoir simulation time period to the simulated core sample; Obtaining the physical property characteristics of the simulated core samples determined by the physical property analysis unit using the multi-energy spectrum CT scanning technology, the rock mechanical characteristics of the simulated core samples determined by the mechanical property analysis unit using the ultrasonic monitoring technology, and the diagenetic fluid characteristics of the simulated core samples determined by the diagenetic fluid analysis unit in each reservoir simulation time period, and obtaining the characterization characteristics of the core samples in each reservoir simulation time period, wherein the characterization characteristics include at least one of the physical property characteristics, the rock mechanical characteristics, and the diagenetic fluid characteristics; The heterogeneity of the reservoir is determined based on the reaction conditions and the characterization features.

20. The method of claim 19, wherein: The physical property characteristics include at least one of mineral component characteristics and pore characteristics, and the diagenetic fluid characteristics include fluid characteristics and pH characteristics.

21. The method of claim 20, wherein: Determining the heterogeneity of the reservoir according to the reaction conditions and the characterization features includes: The reaction conditions and the characterization features collected in each diagenetic simulation time period are processed using an optimal mathematical algorithm to obtain a correlation between heterogeneity and the reaction conditions and the characterization features, wherein the heterogeneity is characterized by pore characteristics.

22. The method according to claim 21, characterized in that The relationship between heterogeneity and reaction conditions and characterization characteristics is shown below: H t =β0+β1H x +β2H v +β3T+β4t+β5ΔX i +β6PH+β7P+δ; Among them, Ht is the heterogeneity of the oil and gas reservoir, which is characterized by pore characteristics; Hx is the mineral component characteristics, H V is the rock mechanics characteristic, T is the temperature characteristic, t is the diagenesis time characteristic, △Xi is the fluid characteristic, PH is the acidity characteristic, P is the pressure characteristic, β0 is the first regression coefficient, β1 is the second regression coefficient, β2 is the third regression coefficient, β3 is the fourth regression coefficient, β4 is the fifth regression coefficient, β5 is the sixth regression coefficient, β6 is the seventh regression coefficient, β7 is the eighth regression coefficient, and δ is the ninth regression coefficient.

23. A control device, characterized in that: include: A configuration module, used to determine configuration conditions of simulated core samples according to lithological data of oil and gas reservoirs, and send the configuration conditions to a rock sample configuration unit; A reservoir formation module, used to determine each reservoir formation time period of the reservoir formation process and the reaction conditions corresponding to each reservoir formation time period according to the genetic characteristics of the oil and gas reservoir, wherein the reaction conditions include at least one of pressure, temperature and fluid; and to determine each reservoir formation simulation time period based on each reservoir formation time period; An action module, used for sending the pressure and temperature corresponding to each reservoir simulation time period to the reaction unit, and sending the fluid corresponding to each reservoir simulation time period to the injection unit; The correlation module is used to obtain the physical property characteristics of the simulated core sample determined by the physical property analysis unit using the multi-energy spectrum CT scanning technology in each reservoir simulation time period, the rock mechanical characteristics of the simulated core sample determined by the mechanical property analysis unit using the ultrasonic monitoring technology, and the diagenetic fluid characteristics of the simulated core sample determined by the diagenetic fluid analysis unit, and obtain the characterization characteristics of the core sample in each reservoir simulation time period, wherein the characterization characteristics include at least one of the physical property characteristics, the rock mechanical characteristics, and the diagenetic fluid characteristics; A characterization module is used to determine the heterogeneity of the reservoir according to the reaction conditions and the characterization features.

24. A computer storage medium, characterized in that The computer storage medium stores computer executable instructions, which, when executed by a processor, implement the quantitative evaluation method for reservoir heterogeneity based on dynamic reservoir formation simulation as described in any one of claims 19 to 22.

25. A control device, characterized in that: include: A memory, a processor, and a computer program stored in the memory and executable on the processor, wherein when the processor executes the program, the method for quantitatively evaluating reservoir heterogeneity based on dynamic reservoir formation simulation as described in any one of claims 19 to 22 is implemented.

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