An unconventional oil and gas hydraulic fracturing and drainage integration simulation method, device and electronic equipment

Abstract

The present specification provides an unconventional oil and gas hydraulic fracturing and drainage integrated simulation method, device and electronic equipment, wherein the method comprises: inputting a three-dimensional geological model, a three-dimensional geomechanical model and a fracturing pump injection program into a fracture dynamic expansion simulation model, inputting output data of the fracture dynamic expansion simulation model and a rock compression and expansion table into a numerical simulator, and simulating, by the numerical simulator, changes in formation parameters during injection of fracturing fluid into the formation during a hydraulic fracturing process. The present scheme performs fine fracture dynamic expansion simulation on the basis of three-dimensional fine geological modeling; a rock compaction / expansion table is derived and the fracturing fluid injection process is simulated according to the actual pump injection program, and history matching is completed according to actual production data, on the basis of which development effect evaluation and development mode optimization and the like can be completed. The integrated process can effectively and accurately simulate the whole process from fracturing fluid entering the formation to reverse drainage production, and the accuracy of predicting oil production based on the simulation results is higher.

Description

Technical Field

[0001] This application relates to the field of oil and gas field development technology, and in particular to an integrated simulation method, apparatus and electronic equipment for unconventional oil and gas hydraulic fracturing and drainage. Background Technology

[0002] Currently, tight oil and shale oil production commonly employs a flexible development approach combining horizontal well fracturing and large-scale slickwater fracturing. While initial production is high, it declines rapidly, with early decline rates reaching 40%–50%. Flexible development results in low recovery rates, and subsequent energy replenishment and recovery are challenging. Large-scale slickwater hydraulic fracturing typically features high flow rates, high fluid volumes, high sand volumes, and low sand-to-fluid ratios. Studies show that during fracturing operations, slickwater fracturing fluid may be present in the wellbore, supported main fractures, matrix, and unsupported fractures, but the proportion used for fracture creation is very small. A significant amount of fracturing fluid is lost into the formation, primarily through unsupported microfractures, accounting for over 90% of the total fracturing fluid loss.

[0003] Downhole coring and imaging logging results from the reservoir indicate that no network of fractures was found in the shale oil reservoir after large-scale hydraulic fracturing. Instead, numerous micro-scale fractures parallel to the main fracture were observed, with very close spacing. Simultaneously, proppant-supported fractures were scarce, suggesting the generation of numerous micro-scale fractures parallel to the main fracture during fracturing. Downhole pressure gauge tests show that pressure near proppant fractures decays rapidly, while pressure on micro-scale fractures does not decline, indicating that their flow capacity is similar to the matrix and not connected to the main fracture. Actual production data from the field shows that the water cut generally drops rapidly from 100% to a plateau value within about 6 months, and remains stable during subsequent production. For the same fracturing scale, oil production primarily depends on the water production rate; a higher stable water cut results in lower cumulative production in the first year. A lower flowback rate corresponds to a faster decrease in water cut; a low flowback rate corresponds to a low water cut, and the retained fracturing fluid mainly serves to replenish energy.

[0004] Accurately simulating fracturing fluid loss and backflow during production is crucial for improving the accuracy of numerical simulations of shale oil and tight oil. With the development of large-scale commercial software and the deepening of the "geology-engineering integration" concept, integrated methods involving single-platform multi-functional coupled calculations or multi-platform collaborative docking have become the optimal solution for shale oil and tight oil field applications. Currently, relatively mature single-platform fracturing numerical simulation platforms include Schlumberger's "Petrel-Kinetix-INTERSECT": based on Petrel's 3D fine geological modeling and 3D fine geomechanical modeling, it uses the Kinetix module to simulate the dynamic propagation of fractures, and the simulation results are then used to simulate the INTERSECT high-performance numerical simulator, achieving a seamless link between engineering fracturing and reservoir simulation, seismology, geology, geomechanics and other disciplines; Baker Hughes' JewelSuite platform: integrating 3D geological modeling, geomechanical modeling, MFrac fracturing simulation and other modules, it can call Eclipse / CMG numerical simulator and Abaqus dynamic mechanics simulator, realizing integrated geological and engineering research; and RFD's tNavigator platform, which supports seismic interpretation, geological modeling, hydraulic fracturing simulation and numerical simulation, with an integrated and cyclical workflow and real-time updates to the geological model. Multiple platforms, such as geological modeling software Petrel; fracture dynamic propagation simulation software GOHFER, Kinetix, Meyer, FracMan, and ResFrac; and reservoir numerical simulation software CMG and ECLIPSE, mostly have interfaces that connect with each other by reading standard keywords. Collaborative integration across multiple platforms can fully leverage the advantages of each stage in the integrated workflow.

[0005] However, the various integrated simulation methods mentioned above have the following problems: (1) The fracturing software makes a trade-off between simulation speed and simulation accuracy, which cannot meet the high-efficiency and accurate simulation requirements of the mine; (2) When performing numerical simulation, it usually only focuses on the influence of the main support fractures and ignores the influence of a large number of unsupported micro fractures; (3) At present, the true meaning of fracturing-drainage coupling has not been realized, and the large amount of fracturing fluid that is filtered into the unsupported micro fractures is not considered in the actual numerical simulation. Summary of the Invention

[0006] This specification provides an integrated simulation method, apparatus, and electronic equipment for unconventional oil and gas hydraulic fracturing and drainage, in order to solve the problem of low simulation accuracy of existing methods for unconventional oil and gas hydraulic fracturing and drainage.

[0007] To address the aforementioned technical problems, this specification provides a first aspect of an integrated simulation method for unconventional oil and gas hydraulic fracturing and drainage, comprising: acquiring a three-dimensional geological model and a three-dimensional geomechanical model of the target block; acquiring a dynamic fracture propagation simulation model, wherein the inputs to the dynamic fracture propagation simulation model are the three-dimensional geological model, the three-dimensional mechanical model, and the fracturing pumping program; acquiring a rock compression and expansion table of the target block; inputting the three-dimensional geological model, the three-dimensional geomechanical model, and the fracturing pumping program into the dynamic fracture propagation simulation model; inputting the output data of the dynamic fracture propagation simulation model and the rock compression and expansion table into a numerical simulator, wherein the numerical simulator simulates the changes in formation parameters during the injection of fracturing fluid into the formation during hydraulic fracturing.

[0008] In some embodiments, the method further includes: predicting the oil production of the target block based on simulation results after fracturing fluid injection into the formation.

[0009] In some embodiments, the rock compression expansion table is calculated according to the following formula: Where, k p k is the permeability at the initial pressure. i Permeability under a given pressure; C PDL PDL filtration coefficient; ΔP is the pressure difference, ΔP i Let ΔP be the initial pressure difference. p The pressure difference at a specific pressure; C fp C is the compressibility coefficient under initial pressure. fi Φ is the compressibility coefficient under a given pressure. p Porosity at initial pressure, Φ i Porosity under a given pressure.

[0010] In some embodiments, the rock compression expansion table is determined based on the filtration loss coefficient and the relative permeability curve; correspondingly, the method further includes: obtaining the actual historical yield data of the target plot; adjusting the rock compression expansion table by adjusting the filtration loss coefficient and the relative permeability curve to obtain multiple compression expansion tables; based on each compression expansion table, using the crack dynamic propagation simulation model and the numerical simulator, determining the predicted historical yield data corresponding to each rock compression expansion table; wherein, the relative permeability curve is used to determine the permeability; calculating the fitting effect value between the predicted historical yield data and the actual historical yield data corresponding to each rock compression expansion table; and taking the rock compression expansion table with the optimal fitting effect value as the final rock compression expansion table.

[0011] In some embodiments, the rock compression-expansion table includes an elastic deformation stage, an expansion stage, and an unloading stage. The elastic deformation stage corresponds to the state in which the rock deforms but has not yet cracked when the fracturing fluid is first injected into the formation. The expansion stage corresponds to the state in which the rock begins to crack and the cracks gradually increase in size and number. The unloading stage corresponds to the flowback process after the fracturing is completed.

[0012] In some embodiments, a three-dimensional geological model is determined by the following method: a structural model, a sedimentary facies model, and a strata model of the target block are established sequentially by simulation methods, and the structural model, sedimentary facies model, and strata model are used as constraints of the three-dimensional geological model. A three-dimensional geological model of the target block is established by using variogram analysis and sequential Gaussian stochastic simulation algorithms.

[0013] In some embodiments, the three-dimensional geomechanical model is determined by the following method: calculating the Poisson's ratio, Yang Shi modulus, shear modulus, bulk modulus, brittleness index, minimum horizontal principal stress, and maximum horizontal principal stress corresponding to each pixel in the three-dimensional geological model based on the P-wave transit time, S-wave transit time, and density curve obtained from well logging; and organizing the calculation results of each pixel to form a three-dimensional geomechanical model.

[0014] In some embodiments, before inputting the three-dimensional geological model and the three-dimensional geomechanical model into the fracture dynamic propagation simulation model, the model is coarsened using general keywords; accordingly, the coarsened three-dimensional geological model and the three-dimensional geomechanical model are input into the fracture dynamic propagation simulation model; and / or, in some embodiments, before inputting the output data of the fracture dynamic propagation simulation model into the numerical simulator, the local mesh at the fracture is refined using normative keywords; accordingly, the result of the local mesh refinement is input into the numerical simulator.

[0015] The second aspect of this specification provides an integrated simulation device for unconventional oil and gas hydraulic fracturing and drainage, comprising: a first acquisition unit for acquiring a three-dimensional geological model and a three-dimensional geomechanical model of the target site; a second acquisition unit for acquiring a dynamic fracture propagation simulation model, wherein the inputs to the dynamic fracture propagation simulation model are the three-dimensional geological model, the three-dimensional mechanical model, and the fracturing pumping program; a third acquisition unit for acquiring a rock compression and expansion table of the target site; and a simulation unit for inputting the three-dimensional geological model, the three-dimensional geomechanical model, and the fracturing pumping program into the dynamic fracture propagation simulation model, and inputting the output data of the dynamic fracture propagation simulation model and the rock compression and expansion table into a numerical simulator, wherein the numerical simulator simulates the changes in formation parameters during the injection of fracturing fluid into the formation during hydraulic fracturing.

[0016] In some embodiments, the apparatus further includes a prediction unit for predicting the oil production of a target block based on simulation results after fracturing fluid injection into the formation.

[0017] In some embodiments, the rock compression expansion table is calculated according to the following formula: Where, k p k is the permeability at the initial pressure. i Permeability under a given pressure; C PDL PDL filtration coefficient; ΔP is the pressure difference, ΔP i Let ΔP be the initial pressure difference. p The pressure difference at a specific pressure; C fp C is the compressibility coefficient under initial pressure. fi Φ is the compressibility coefficient under a given pressure. p Porosity at initial pressure, Φ i Porosity under a given pressure.

[0018] In some embodiments, the rock compression expansion table is determined based on the filtration loss coefficient and the relative permeability curve; correspondingly, the device further includes: a fourth acquisition unit, used to acquire the actual value of historical yield data of the target plot; a processing unit, used to adjust the rock compression expansion table by adjusting the filtration loss coefficient and the relative permeability curve to obtain multiple compression expansion tables; based on each compression expansion table, using the crack dynamic propagation simulation model and the numerical simulator, to determine the predicted value of historical yield data corresponding to each rock compression expansion table; wherein, the relative permeability curve is used to determine the permeability; a calculation unit, used to calculate the fitting effect value between the predicted value of historical yield data and the actual value of historical yield data corresponding to each rock compression expansion table; and a determination unit, used to take the rock compression expansion table corresponding to the optimal fitting effect value as the final rock compression expansion table.

[0019] In some embodiments, the rock compression-expansion table includes an elastic deformation stage, an expansion stage, and an unloading stage. The elastic deformation stage corresponds to the state in which the rock deforms but has not yet cracked when the fracturing fluid is first injected into the formation. The expansion stage corresponds to the state in which the rock begins to crack and the cracks gradually increase in size and number. The unloading stage corresponds to the flowback process after the fracturing is completed.

[0020] In some embodiments, a three-dimensional geological model is determined by the following method: a structural model, a sedimentary facies model, and a strata model of the target block are established sequentially by simulation methods, and the structural model, sedimentary facies model, and strata model are used as constraints of the three-dimensional geological model. A three-dimensional geological model of the target block is established by using variogram analysis and sequential Gaussian stochastic simulation algorithms.

[0021] In some embodiments, the three-dimensional geomechanical model is determined by the following method: calculating the Poisson's ratio, Yang Shi modulus, shear modulus, bulk modulus, brittleness index, minimum horizontal principal stress, and maximum horizontal principal stress corresponding to each pixel in the three-dimensional geological model based on the P-wave transit time, S-wave transit time, and density curve obtained from well logging; and organizing the calculation results of each pixel to form a three-dimensional geomechanical model.

[0022] In some embodiments, before inputting the three-dimensional geological model and the three-dimensional geomechanical model into the fracture dynamic propagation simulation model, the model is coarsened using general keywords; accordingly, the coarsened three-dimensional geological model and the three-dimensional geomechanical model are input into the fracture dynamic propagation simulation model; and / or, before inputting the output data of the fracture dynamic propagation simulation model into the numerical simulator, the local mesh at the fracture is refined using normative keywords; accordingly, the result of the local mesh refinement is input into the numerical simulator.

[0023] A third aspect of this specification provides an electronic device, comprising: a memory and a processor, wherein the processor and the memory are communicatively connected to each other, the memory stores computer instructions, and the processor executes the computer instructions to realize the unconventional oil and gas hydraulic fracturing and drainage integrated simulation method as described in any one of the first aspects.

[0024] This manual provides an integrated simulation method, apparatus, and electronic equipment for unconventional oil and gas hydraulic fracturing and production. Based on detailed 3D geological modeling, it utilizes a full / true 3D hydraulic fracturing simulator for refined dynamic fracture propagation simulation. The geological model and fracture propagation simulation results are then integrated with a high-performance reservoir numerical simulator for solution processing. A rock compaction / expansion table is derived, and the fracturing fluid injection process is simulated based on actual field pumping procedures. Historical data is fitted using actual production data, enabling evaluation of development effectiveness and optimization of development methods. This integrated process effectively and accurately simulates the entire process from fracturing fluid entering the formation to reverse flow production, resulting in higher accuracy in predicting oil production based on simulation results. Attached Figure Description

[0025] To more clearly illustrate the technical solutions in the embodiments of this application or the prior art, the drawings used in the description of the embodiments or the prior art will be briefly introduced below. Obviously, the drawings described below are only some embodiments recorded in this application. For those skilled in the art, other drawings can be obtained from these drawings without creative effort.

[0026] Figure 1 This diagram illustrates an unconventional oil and gas hydraulic fracturing and integrated drainage simulation method provided in this specification.

[0027] Figure 2 This is a schematic diagram of a three-dimensional geological model represented in the form of a three-dimensional planar model;

[0028] Figure 3 This is a data example for simulating fracture propagation based on the actual fracturing fluid type and fracturing pumping procedure in the mine.

[0029] Figure 4 This is a schematic diagram of the fitting process for the fracturing pump injection procedure;

[0030] Figure 5 A schematic diagram showing the distribution of water saturation before and after fracturing fluid injection;

[0031] Figure 6 A schematic diagram of the pressure distribution after fracturing fluid injection;

[0032] Figure 7 This is a schematic diagram of the pressure wave after a period of production following hydraulic fracturing.

[0033] Figure 8 A schematic diagram illustrating the conductivity of fractures in a single well;

[0034] Figure 9 This is a schematic diagram of a rock compression-swell curve drawn based on the above rock compression-swell table;

[0035] Figure 10 A schematic diagram of a method for determining the compressibility and expansion of rocks;

[0036] Figure 11 A diagram showing the predicted values ​​of historical production data and the actual values ​​of historical production data;

[0037] Figure 12 The fitted curve between the predicted value of historical oil production data and the actual value of historical oil production data;

[0038] Figure 13 This is a fitted curve between the predicted historical moisture content and the actual historical moisture content.

[0039] Figure 14 A schematic diagram illustrating the local mesh refinement of the output data from a crack dynamic propagation simulation model;

[0040] Figure 15 To predict the cumulative oil production curve of the target plot over the next 10 years;

[0041] Figure 16 This is a schematic diagram of another unconventional integrated oil and gas hydraulic fracturing and drainage simulation device provided in this manual.

[0042] Figure 17 A schematic diagram of the electronic device provided in this specification is shown. Detailed Implementation

[0043] To enable those skilled in the art to better understand the technical solutions in this application, the technical solutions in the embodiments of this application will be clearly and completely described below with reference to the accompanying drawings. Obviously, the described embodiments are only a part of the embodiments of this application, and not all of the embodiments. Based on the embodiments in this application, all other embodiments obtained by those skilled in the art without creative effort should fall within the scope of protection of this application.

[0044] This invention proposes an integrated fracturing-drainage simulation method that considers fracturing fluid loss. Based on a detailed three-dimensional geological model and accurate fracture propagation simulation results, it connects with an efficient reservoir numerical simulator, derives a rock compaction / expansion table, and fits the actual field pumping procedure and oil-water production data. The aim is to realistically simulate the oil-water seepage dynamics of large-scale hydraulically fracturing reservoirs at the field scale and guide subsequent production and development.

[0045] like Figure 1 As shown in the figure, this specification provides an integrated simulation method for unconventional oil and gas hydraulic fracturing and drainage, which includes the following steps:

[0046] S10: Obtain the three-dimensional geological model and three-dimensional geomechanical model of the target site.

[0047] A three-dimensional geological model of the target site is a three-dimensional spatial distribution and variation model of the stratigraphic parameters characterizing the physical properties of the target site. These stratigraphic parameters include porosity, permeability, oil saturation, and net-to-gross ratio, among others.

[0048] A three-dimensional geological model of a reservoir is the core of a reservoir geological model. It is a specific representation of the distribution and changes of reservoir characteristics and heterogeneity in three-dimensional space.

[0049] By utilizing the secondary digital processing results of well logging data from the target site, and using well point formation parameters, sedimentary microfacies and stratigraphic framework models as control conditions, along with geostatistics and advanced conditional simulation techniques, the variations in reservoir parameters between wells can be predicted, thereby obtaining a three-dimensional data volume of formation parameter distribution. This three-dimensional data volume constitutes the three-dimensional geological model of the target site.

[0050] In other words, a three-dimensional geological model of the target site can be established using a conditional simulation method under geological constraints. Specifically, a structural model, sedimentary facies model, and interlayer model of the target site are established sequentially through simulation methods. These models are then used as constraints for the three-dimensional geological model. A three-dimensional geological model of the target site is established using variogram analysis and sequential Gaussian stochastic simulation algorithms.

[0051] By fully utilizing rock mechanics parameters such as P-wave and S-wave transit time and density curves, the horizontal stress across the entire region can be calculated, and a three-dimensional geomechanical model of the target area can be established, including Poisson's ratio, Young's modulus, and maximum / minimum horizontal principal stresses. This three-dimensional geomechanical model is used for subsequent reservoir numerical simulations to guide the dynamic propagation of fractures.

[0052] The well logging data for the aforementioned target sites may include well point formation parameters as well as well logging data obtained through various non-invasive techniques. Non-invasive techniques refer to techniques that obtain subsurface geological information without drilling additional wells, such as seismic logging and electromagnetic logging.

[0053] The method described above for determining the three-dimensional geological model of the target site is existing in the prior art and will not be described in detail in this specification.

[0054] In some embodiments, a three-dimensional geomechanical model can be determined by the following method: calculating the Poisson's ratio, Young's modulus, shear modulus, bulk modulus, brittleness index, minimum horizontal principal stress, and maximum horizontal principal stress corresponding to each pixel in the three-dimensional geological model based on the P-wave transit time, S-wave transit time, and density curve obtained from well logging; and organizing the calculation results of each pixel to form a three-dimensional geomechanical model.

[0055] The calculation methods for Poisson's ratio, Yang's modulus, shear modulus, bulk modulus, brittleness index, minimum horizontal principal stress, and maximum horizontal principal stress are existing in the prior art and will not be described in detail in this specification.

[0056] S20: Obtain the dynamic fracture propagation simulation model, the input of which is a three-dimensional geological model, a three-dimensional mechanical model, and a fracturing pump injection program.

[0057] The fracturing pumping procedure, also known as the fracturing pumping operation parameters in the actual hydraulic fracturing process, includes pumping pressure, pumping rate, fracturing fluid type, proppant type and quantity, perforation design, etc.

[0058] Specifically, the dynamic fracture propagation simulation model can be based on a three-dimensional planar (PL3D) model to form a method for dynamic fracture propagation in tight oil vertical / horizontal wells. It uses a three-dimensional mesh structure algorithm to dynamically calculate and simulate the propagation of three-dimensional fractures.

[0059] A three-dimensional planar model is a geological model that represents underground oil and gas reservoirs as a series of interconnected planes, each plane representing a specific depth or stratum of the reservoir. For example, Figure 2 This is a schematic diagram of a three-dimensional geological model represented in the form of a three-dimensional planar model. The second column in the table is a schematic diagram of the distribution of stratigraphic parameters at a specific depth or stratum.

[0060] Specifically, the dynamic fracture propagation simulation model can represent a 3D geological model as multiple interconnected planes, each plane representing a specific depth or stratum within the target block. Similarly, a 3D geomechanical model can be represented as multiple interconnected planes, with the depth or stratum of each plane corresponding to that in the 3D geological model. Then, for each pixel in the 3D geological and geomechanical models, based on the corresponding geological and mechanical parameters of that pixel, and combined with the operational parameters in the fracturing pump injection program, the changes in the geological and mechanical parameters at the corresponding location of each pixel are simulated and calculated. The changes in mechanical parameters represent the dynamic propagation of the fracture, and the model used to simulate the dynamic propagation of the fracture is the simulation model of the fracture structure parameters.

[0061] The dynamic crack propagation simulation model can be implemented by a computer program, and the implementation code of the computer program will not be described in detail in this manual.

[0062] Figure 3 This is a data example for simulating fracture propagation based on the actual fracturing fluid type and fracturing pumping procedure in the mining area. Here, Stage# represents the fracturing stage number, Elapsed Time represents the cumulative fracturing time, Stage Time represents the time of a single injection stage, Fluid represents the fracturing fluid type, Clean Stage Vol.M3 represents the volume of fracturing fluid in a single stage, Cum Clean Vol.M3 represents the cumulative volume, Proppant represents the proppant type, Slurry Conc.Kg / M3 represents the proppant concentration, CumProppant.Kg represents the cumulative proppant mass, and Slurry Rate.M3 / M represents the pumping rate.

[0063] The input to the fracture dynamic propagation simulation model is the fracturing pump operation parameters during the actual hydraulic fracturing process. To verify the accuracy of the simulation, the pressure at a preset point in the well can be calculated based on the simulation results of the fracture dynamic propagation simulation model, and the pressure at the preset point detected on-site during the actual hydraulic fracturing process can be obtained. The simulated pressure is then fitted with the on-site measured pressure. Figure 4 This is a schematic diagram of the fracturing pump injection procedure. The horizontal axis represents cumulative time, the vertical axis represents pressure, the dashed line represents the measured pressure value in the field, the purple solid line represents the pressure value obtained from simulation calculation, and the gray solid line represents the fracture length. From Figure 4 It can be seen that the pressure fit is good, which means that the simulation model for crack dynamic propagation has a good fit.

[0064] The aforementioned dynamic fracture propagation simulation model calculates fracture propagation in a 3D geological model using each pixel as a unit, reflecting formation anisotropy and multiphase, multidimensional flow characteristics. Simulating the application of fracturing pumping procedures based on the 3D geological model demonstrates the influence of proppant delivery, fracturing fluid rheology, and dynamic filtration loss on fracture propagation. Therefore, this dynamic fracture propagation method can calculate and simulate the dynamic propagation of multi-segment, multi-cluster asymmetric fractures in horizontal wells, providing more accurate simulation of fracture morphology. Consequently, the oil production prediction based on a more accurate 3D geological model will be more accurate.

[0065] Figure 5 This is a schematic diagram showing the distribution of water saturation before and after fracturing fluid injection. Figure 6 This is a schematic diagram of the pressure distribution after fracturing fluid injection. Figure 7 This is a schematic diagram of the pressure wave after a period of production following hydraulic fracturing. Table 1 below shows an example of the physical properties around the well and the simulation results of fracture propagation.

[0066] Table 1. Physical parameters around the well and simulation results of fracture propagation.

[0067] Effective oil thickness / m 4.7 Average porosity 0.073 Average permeability / mD 0.106 Average Young's modulus / GPa 26.65 Mean Poisson's ratio 0.234 Average seam length / m 130.4 Average effective support seam length / m 81.66 Average seam height / m 3.72 Average flow capacity / md*m 102.96

[0068] Existing oil production prediction methods typically rely solely on 3D geological models, 3D geomechanical models, and historical production data to predict the oil production of a target formation. During the long-term production phase following hydraulic fracturing, predictions are usually based solely on formation parameters and historical production data, without considering the impact of fractures created during the fracturing process. However, fractures possess conductivity, can connect oil and gas reservoirs, and enhance recovery and production capacity. Therefore, ignoring the impact of fractures on oil production capacity leads to an underestimation of oil production. Figure 8 This is a schematic diagram illustrating the conductivity of fractures in a single well.

[0069] The unconventional oil and gas hydraulic fracturing and drainage integrated simulation method provided in this manual introduces a fracturing pumping program to fit the pumping process and simulate the fracture propagation process. This allows for a more accurate fracture morphology, which in turn more accurately reflects the connectivity of the oil and gas reservoir, improves the model's accuracy in simulating the formation structure, and thus enhances the accuracy of oil production prediction.

[0070] S30: Obtain the rock compression and expansion table for the target plot.

[0071] The rock compression and expansion table is used to represent the change in permeability of target rock with pressure during fracturing and flowback.

[0072] The rock expansion table includes the elastic deformation stage, the expansion stage, and the unloading stage. Tables 2 through 8 below are examples of rock compression expansion tables.

[0073] Table 2 Elastic Deformation Stage

[0074] Pressure / Kpa Porosity factor Penetration multiple in direction I Permeability multiple in the J direction Permeability multiple in the K direction 110 1.00 1.00 1.00 1.00 2000 1.00 1.00 1.00 1.00 4000 1.00 1.00 1.00 1.00 8000 1.00 1.00 1.00 1.00 18000 1.00 1.00 1.00 1.00 18500 1.02 1.01 1.01 1.01 19000 1.03 1.01 1.01 1.01 19500 1.04 1.02 1.02 1.02 20000 1.05 1.49 1.49 1.49

[0075] Table 3. Expansion Stage

[0076] Pressure / Kpa Porosity factor Penetration multiple in direction I Permeability multiple in the J direction Permeability multiple in the K direction 20000 1.05 1.49 1.49 1.49 25000 1.10 4.06 4.06 4.06 30000 1.20 11.02 11.02 11.02 35000 2.40 29.96 29.96 29.96 40000 3.60 81.45 81.45 81.45 45000 4.80 221.41 221.41 221.41 50000 5.00 601.85 601.85 601.85 60000 5.50 4447.07 4447.07 4447.07

[0077] Table 4 Unloading Phase Unloading Curve 1

[0078]

[0079]

[0080] Table 5 Unloading Phase Unloading Curve 2

[0081] Pressure / Kpa Porosity factor Penetration multiple in direction I Permeability multiple in the J direction Permeability multiple in the K direction 35000 2.40 29.96 29.96 29.96 30000 1.20 16.57 16.57 16.57 25000 1.10 9.17 9.17 9.17 20000 1.05 5.07 5.07 5.07 18000 1.02 4.00 4.00 4.00 8000 1.02 4.00 4.00 4.00 3000 1.02 4.00 4.00 4.00 100 1.02 4.00 4.00 4.00 10 1.02 4.00 4.00 4.00

[0082] Table 6 Unloading Phase Unloading Curve 3

[0083] Pressure / Kpa Porosity factor Penetration multiple in direction I Permeability multiple in the J direction Permeability multiple in the K direction 40000 3.60 81.45 81.45 81.45 35000 2.40 45.03 45.03 45.03 30000 1.20 24.89 24.89 24.89 25000 1.10 13.76 13.76 13.76 20000 1.05 7.61 7.61 7.61 18000 1.02 6.00 6.00 6.00 8000 1.02 6.00 6.00 6.00 3000 1.02 6.00 6.00 6.00 100 1.02 6.00 6.00 6.00 10 1.02 6.00 6.00 6.00

[0084] Table 7 Unloading Phase Unloading Curve 4

[0085] Pressure / Kpa Porosity factor Penetration multiple in direction I Permeability multiple in the J direction Permeability multiple in the K direction 45000 4.80 221.41 221.41 221.41 40000 3.60 124.76 124.76 124.76 35000 2.40 70.30 70.30 70.30 30000 1.20 39.62 39.62 39.62 25000 1.10 22.32 22.32 22.32 20000 1.05 12.58 12.58 12.58 18000 1.02 10.00 10.00 10.00 8000 1.02 10.00 10.00 10.00 3000 1.02 10.00 10.00 10.00 100 1.02 10.00 10.00 10.00 10 1.02 10.00 10.00 10.00

[0086] Table 8 Unloading Phase Unloading Curve 5

[0087] Pressure / Kpa Porosity factor Penetration multiple in direction I Permeability multiple in the J direction Permeability multiple in the K direction 50000.00 5.00 601.85 601.85 601.85 45000.00 4.80 353.57 353.57 353.57 40000.00 3.60 207.71 207.71 207.71 35000.00 2.40 122.03 122.03 122.03 30000.00 1.20 71.69 71.69 71.69 25000.00 1.10 42.12 42.12 42.12 20000.00 1.05 24.74 24.74 24.74 18000.00 1.02 20.00 20.00 20.00 8000.00 1.02 20.00 20.00 20.00 3000.00 1.02 20.00 20.00 20.00 100.00 1.02 20.00 20.00 20.00 10.00 1.02 20.00 20.00 20.00

[0088] Figure 9 This is a schematic diagram of a rock compression-expansion curve plotted based on the aforementioned rock compression-expansion table. On the horizontal axis, line segment AB represents the elastic deformation stage, corresponding to the initial injection of fracturing fluid into the formation. As pressure gradually increases, the rock undergoes minor deformation but has not yet cracked; during this process, the rock's permeability remains almost constant. Line segment BC represents the expansion stage, corresponding to the initial cracking stage. As pressure gradually increases, the number and size of cracks in the rock gradually increase, resulting in a gradual increase in rock permeability. Line segment CDE represents the unloading stage, corresponding to the flowback process after hydraulic fracturing. During this process, no further artificial pressure is applied to the well; oil and gas automatically flow to the surface relying on the existing pressure in the formation and the pipeline network structure. Because the fracturing process creates many new fractures in the formation, the permeability in the formation at the end of the unloading stage is higher than that in the elastic deformation stage.

[0089] As can be seen from the specific description of the rock compression and expansion table, it effectively simulates the entire process of rock fracturing and flowback, reflecting the impact of fracturing on formation permeability. Since permeability is a crucial parameter for predicting oil production, using the rock compression and expansion table can further improve the accuracy of oil production predictions.

[0090] Existing oil production prediction methods typically determine formation parameters such as permeability of the target area through well logging before hydraulic fracturing, and then use the permeability determined before hydraulic fracturing to predict oil production after fracturing. However, because hydraulic fracturing introduces many new fractures, the permeability of the target area changes before and after fracturing. Therefore, using the pre-fracturing permeability to predict oil production after hydraulic fracturing is prone to significant errors.

[0091] The unconventional oil and gas hydraulic fracturing and integrated production simulation method provided in this manual, by introducing a rock compression and expansion table, can more accurately determine the permeability of the target block after hydraulic fracturing, improve the accuracy of the permeability value used to predict oil production, and thus improve the accuracy of oil production prediction.

[0092] This manual provides a derivation process for a calculation method used in rock compression and expansion tables. The specific derivation process is as follows:

[0093] The filtration coefficient, controlled by the compressibility of the formation rocks and fluids, is C. P for:

[0094]

[0095] Among them, C P ΔP is the filtration loss coefficient at a certain pressure. p The pressure difference at a specific pressure, in kPa; k p C represents the permeability at the initial pressure. fp Let be the compressibility coefficient under the initial pressure (kPa). -1 ;Φ p Porosity at initial pressure; μ f This refers to the viscosity of the fracturing fluid within the fracture.

[0096] Initial filtration coefficient C i for:

[0097]

[0098] Among them, C i ΔP is the filtration loss coefficient at a certain pressure. i The pressure difference at a specific pressure, in kPa; k i C represents the permeability at the initial pressure. fiLet be the compressibility coefficient under the initial pressure (kPa). -1 ;Φ i Porosity at initial pressure; μ f This refers to the viscosity of the fracturing fluid within the fracture.

[0099] Dividing equation (1) and equation (2) above, we get:

[0100]

[0101] According to the PDL filtration loss calculation formula:

[0102]

[0103] Among them, C PDL ΔP is the PDL filtration coefficient; ΔP is the pressure difference, kPa.

[0104] Combining equations (3) and (4), we can obtain:

[0105]

[0106] After sorting, we can obtain:

[0107]

[0108] in,

[0109] As can be seen from the above derivation process, the rock compression expansion table can be obtained from the above formulas (6) and (7).

[0110] The filtration loss coefficient and relative permeability curve are typically not accurately calculated from well logging data; therefore, the accuracy of these parameters affects the accuracy of oil production predictions. Conversely, the accuracy of the prediction results can be adjusted by regulating the rock compression and expansion table through the filtration loss coefficient and relative permeability curve. Based on this, in some embodiments, such as... Figure 10 As shown, the rock compression and expansion table can be determined through the following steps S50 to S80 to improve the simulation accuracy of the unconventional oil and gas hydraulic fracturing and drainage integrated simulation method.

[0111] S50: Obtain the actual historical production data of the target plot.

[0112] Historical production data refers to the actual liquid production data measured at a time that has already passed.

[0113] S60: The rock compression and expansion table is adjusted by adjusting the filtration loss coefficient and the relative permeability curve to obtain multiple compression and expansion tables; based on each compression and expansion table, the historical production data prediction value corresponding to each rock compression and expansion table is determined by using the crack dynamic propagation simulation model and the numerical simulator; wherein, the relative permeability curve is used to determine the permeability.

[0114] According to equations (6) and (7) above, the rock compression expansion table is related to the filtration loss coefficient and permeability. The compaction compression expansion table is used to predict the oil production of the target block. Therefore, the predicted value of oil production can be adjusted by adjusting the filtration loss coefficient and the relative permeability curve.

[0115] S70: Calculate the fitting effect between the predicted historical production data and the actual historical production data for each rock compression and expansion table.

[0116] The fitting effect value is used to indicate the overall accuracy of the unconventional oil and gas hydraulic fracturing and integrated production simulation method provided in this specification. Since oil production and water production are closely related, only when the fitting accuracy of both oil production and water production is high can the overall accuracy of the unconventional oil and gas hydraulic fracturing and integrated production simulation method be high. If only the fitting accuracy of oil production is high while the fitting accuracy of water production is low, then the overall accuracy of the unconventional oil and gas hydraulic fracturing and integrated production simulation method is also not high.

[0117] There are two methods for calculating the fitting effect value: 1. Fit the oil production and water production under a constant liquid production rate; 2. Fit the water production under a constant oil production rate.

[0118] This manual uses the first method as an example to illustrate S70. Figure 11 This is a diagram illustrating the predicted values ​​of historical production data and the actual values ​​of historical production data. Figure 12 This is a fitted curve between predicted historical oil production data and actual historical oil production data. Figure 13 This is a fitted curve between predicted historical moisture content and actual historical moisture content. From... Figures 11 to 13 As can be seen from the data, under the condition that the production volume fitting curve is well fitted, the oil production and water cut fitting effects are also good. Therefore, the overall accuracy of the unconventional oil and gas hydraulic fracturing and integrated production simulation method is relatively high. The future oil production of the target block can be predicted by the rock compression and expansion curve corresponding to the best production volume fitting effect.

[0119] S80: The rock compression and expansion table corresponding to the optimal fitting effect value is taken as the final rock compression and expansion table, which is used to predict the future oil production of the target block.

[0120] If the predicted value of historical production data determined by a rock compression-swelling table fits well with the actual historical production data, it indicates that the rock compression-swelling table combined with the production prediction algorithm is optimal and best reflects the formation's production patterns. Therefore, using the rock compression-swelling table with the best fit to predict the future production of the target block will result in more accurate predictions.

[0121] S40: Input the three-dimensional geological model, three-dimensional geomechanical model, and fracturing pump injection program into the fracture dynamic propagation simulation model. Input the output data of the fracture dynamic propagation simulation model and the rock compression and expansion table into the numerical simulator. The numerical simulator will simulate the changes in formation parameters during the injection of fracturing fluid into the formation during hydraulic fracturing.

[0122] Numerical simulators are computer software used in the oil and gas industry to simulate the behavior of underground oil and gas reservoirs.

[0123] The dynamic fracture propagation simulation model is used to simulate the dynamic changes of fractures based on a 3D geological model. The output of the dynamic fracture propagation simulation model is input into the numerical simulator in real time. The numerical simulator then uses a rock compression and expansion table to simulate the changes in formation parameters during fracturing fluid injection. During the simulation, the pressure values ​​used in the dynamic fracture propagation simulation are synchronized to the numerical simulator along with the output of the dynamic fracture propagation simulation model, so that the numerical simulator can select the permeability values ​​corresponding to the pressure values ​​from the rock compression and expansion table for simulation calculations.

[0124] The output data of the fracture dynamic propagation simulation model should be a set of data that reflects the various formation parameters after the target formation is affected by the fracturing pumping procedure. For example, the output data should include porosity, permeability, oil saturation, net-to-gross ratio, and pressure value corresponding to each pixel.

[0125] A three-dimensional geological model can represent the formation parameters of the target block before hydraulic fracturing. The fracture structure parameters determined by the fracturing pumping procedure can reflect the morphology of newly added fractures and the connectivity of oil and gas reservoirs during hydraulic fracturing. The rock compression and expansion table can reflect the impact of the hydraulic fracturing process on the porosity of the target block. In other words, based on the three-dimensional geological model, fracture structure parameters, and rock compression and expansion table, the formation parameters of the target formation after hydraulic fracturing can be simulated relatively accurately and in detail, so as to more accurately predict the oil production of the target block.

[0126] The three-dimensional high-resolution geological model of the mine is characterized by its small mesh size, large number of meshes, and huge computational load for direct numerical simulation. The aforementioned three-dimensional geological model is such a high-resolution model. Based on this, the three-dimensional geological model and the three-dimensional geomechanical model can be coarsened first, and then the coarsened three-dimensional geological model and the three-dimensional geomechanical model can be input into the fracture dynamic propagation simulation model along with the fracturing pump injection program for processing.

[0127] Coarsening can be achieved through attribute-controlled coarsening methods, as shown in Table 9 below.

[0128] Table 9: Attribute Control Coarsening Methods

[0129]

[0130] Coarsening refers to processing the data of several consecutive adjacent pixels in a model using coarsening methods to form a larger pixel corresponding to these pixels. By performing attribute-controlled coarsening on 3D geological models and 3D geomechanical models, the randomness of attribute distribution during coarsening can be reduced, thereby improving the accuracy of the model.

[0131] Specifically, the connection between the numerical simulator and general keywords can be achieved, while the connection between the simulation results of dynamic fracture propagation and the numerical simulator can be achieved through standardized keywords and local mesh refinement. The fracture parameters are stored in keyword groups, i.e., coarsening is achieved through keywords. Subsequent work such as historical oil or liquid production fitting and sensitivity evaluation can be directly modified in the corresponding keyword groups.

[0132] The general keywords are data coarsening processes in a 3D geological model that are encapsulated into a data structure. A large number of data instances of the general keywords are determined based on the 3D geological model, and then the corresponding data in the 3D geological model are replaced by the data instances, thereby achieving the overall coarsening process of the 3D geological model.

[0133] Before the output data of the crack dynamic propagation simulation model is input into the numerical simulator, the local mesh can be refined using normalized keywords, that is, the mesh at the crack is refined. Figure 14 This diagram illustrates the local mesh refinement of the output data from a crack dynamic propagation simulation model. The mesh shown on the left is obtained by local refinement of the mesh shown on the right. The mesh shown on the right is a magnified view of the local details of the crack in the mesh shown on the left. The blue diagonal line in the middle of the left image represents the crack.

[0134] Canonical keywords encapsulate mesh refinement operations into a data structure. This data structure identifies cracks and refines the mesh near the cracks. A large number of data instances of canonical keywords are determined based on the output data of the crack dynamic propagation simulation model. These data instances then replace the corresponding data in the output data of the crack dynamic propagation simulation model, thereby achieving localized mesh refinement.

[0135] By locally refining the output of the fracture dynamic propagation simulation model, the upper morphology of the fracture and the inter-reservoir communication status of the target block can be more accurately refined, thus facilitating a more accurate prediction of oil production.

[0136] In some embodiments, S40 is followed by S90: predicting the oil production of the target block based on simulation results after the fracturing fluid injection into the formation.

[0137] After hydraulic fracturing is completed, no further artificial pressure is applied to the well. Oil and gas automatically gush to the surface relying on the existing pressure in the formation and the pipeline network structure. After hydraulic fracturing, the pipeline network structure in the formation is basically determined and will not change during the long-term production process following hydraulic fracturing.

[0138] Since the simulation process of the fracture dynamic propagation simulation model and the numerical simulator is close to the actual changes in the formation in the target block, the simulation results after the fracturing injection into the formation are more accurate. Therefore, the oil production of the target block can be predicted more accurately based on the simulation results after the fracturing fluid injection into the formation.

[0139] Predicting the oil production of a target site can be done by predicting the oil production per unit time in the future, or by predicting the cumulative oil production of the target site in the future. Figure 15 To predict the cumulative oil production curve of a target plot over the next 10 years, the horizontal axis represents time, the vertical axis represents cumulative oil production, and the dots on the curve between 2023 and 2024 represent the actual cumulative production in history.

[0140] This manual presents an integrated simulation method for unconventional oil and gas hydraulic fracturing and production. Based on a detailed 3D geological model, it uses a full / true 3D hydraulic fracturing simulator to perform refined simulations of dynamic fracture propagation. The geological model and fracture propagation simulation results are then integrated with a high-performance reservoir numerical simulator for solution. A rock compaction / expansion table is derived, and the fracturing fluid injection process is simulated based on actual field pumping procedures. Historical data is fitted using actual production data, enabling evaluation of development effectiveness and optimization of development methods. This integrated process effectively and accurately simulates the entire process from fracturing fluid entering the formation to reverse flow production, resulting in higher accuracy in predicting oil production based on the simulation results.

[0141] This specification provides an integrated simulation device for unconventional oil and gas hydraulic fracturing and drainage, in order to achieve... Figure 1 The unconventional oil and gas hydraulic fracturing and integrated production simulation method is shown. For example... Figure 16 As shown, the device includes:

[0142] The first acquisition unit 10 is used to acquire the three-dimensional geological model and the three-dimensional geomechanical model of the target plot.

[0143] The second acquisition unit 20 is used to acquire the dynamic propagation simulation model of the fracture. The input of the dynamic propagation simulation model of the fracture is a three-dimensional geological model, a three-dimensional mechanical model, and a fracturing pump injection program.

[0144] The third acquisition unit 30 is used to acquire the rock compression and expansion table of the target plot.

[0145] The simulation unit 40 is used to input the three-dimensional geological model, the three-dimensional geomechanical model, and the fracturing pump injection program into the fracture dynamic propagation simulation model, and to input the output data of the fracture dynamic propagation simulation model and the rock compression and expansion table into the numerical simulator. The numerical simulator simulates the changes in formation parameters during the injection of fracturing fluid into the formation during hydraulic fracturing.

[0146] In some embodiments, the apparatus further includes a prediction unit for predicting the oil production of a target block based on simulation results after fracturing fluid injection into the formation.

[0147] In some embodiments, the rock compression expansion table is calculated according to the following formula: Where, k p k is the permeability at the initial pressure. i Permeability under a given pressure; C PDL PDL filtration coefficient; ΔP is the pressure difference, ΔP i Let ΔP be the initial pressure difference. p The pressure difference at a specific pressure; C fp C is the compressibility coefficient under initial pressure. fi Φ is the compressibility coefficient under a given pressure. p Porosity at initial pressure, Φ i Porosity under a given pressure.

[0148] In some embodiments, the rock compression expansion table is determined based on the filtration loss coefficient and the relative permeability curve; correspondingly, the device further includes: a fourth acquisition unit, used to acquire the actual value of historical yield data of the target plot; a processing unit, used to adjust the rock compression expansion table by adjusting the filtration loss coefficient and the relative permeability curve to obtain multiple compression expansion tables; based on each compression expansion table, using the crack dynamic propagation simulation model and the numerical simulator, to determine the predicted value of historical yield data corresponding to each rock compression expansion table; wherein, the relative permeability curve is used to determine the permeability; a calculation unit, used to calculate the fitting effect value between the predicted value of historical yield data and the actual value of historical yield data corresponding to each rock compression expansion table; and a determination unit, used to take the rock compression expansion table corresponding to the optimal fitting effect value as the final rock compression expansion table.

[0149] In some embodiments, the rock compression-expansion table includes an elastic deformation stage, an expansion stage, and an unloading stage. The elastic deformation stage corresponds to the state in which the rock deforms but has not yet cracked when the fracturing fluid is first injected into the formation. The expansion stage corresponds to the state in which the rock begins to crack and the cracks gradually increase in size and number. The unloading stage corresponds to the flowback process after the fracturing is completed.

[0150] In some embodiments, a three-dimensional geological model is determined by the following method: a structural model, a sedimentary facies model, and a strata model of the target block are established sequentially by simulation methods, and the structural model, sedimentary facies model, and strata model are used as constraints of the three-dimensional geological model. A three-dimensional geological model of the target block is established by using variogram analysis and sequential Gaussian stochastic simulation algorithms.

[0151] In some embodiments, the three-dimensional geomechanical model is determined by the following method: calculating the Poisson's ratio, Yang Shi modulus, shear modulus, bulk modulus, brittleness index, minimum horizontal principal stress, and maximum horizontal principal stress corresponding to each pixel in the three-dimensional geological model based on the P-wave transit time, S-wave transit time, and density curve obtained from well logging; and organizing the calculation results of each pixel to form a three-dimensional geomechanical model.

[0152] In some embodiments, before inputting the three-dimensional geological model and the three-dimensional geomechanical model into the fracture dynamic propagation simulation model, the model is coarsened using general keywords; accordingly, the coarsened three-dimensional geological model and the three-dimensional geomechanical model are input into the fracture dynamic propagation simulation model; and / or, before inputting the output data of the fracture dynamic propagation simulation model into the numerical simulator, the local mesh at the fracture is refined using normative keywords; accordingly, the result of the local mesh refinement is input into the numerical simulator.

[0153] The descriptions and functions of the above-mentioned devices can be understood by referring to the section on unconventional oil and gas hydraulic fracturing and integrated production simulation methods, and will not be repeated here.

[0154] This invention also provides an electronic device, such as... Figure 17 As shown, the electronic device may include a processor 1701 and a memory 1702, wherein the processor 1701 and the memory 1702 may be connected via a bus or other means. Figure 17 Taking the example of a connection between China and Israel via a bus.

[0155] Processor 1701 can be a Central Processing Unit (CPU). Processor 1701 can also be other general-purpose processors, digital signal processors (DSPs), application-specific integrated circuits (ASICs), field-programmable gate arrays (FPGAs), or other programmable logic devices, discrete gate or transistor logic devices, discrete hardware components, or combinations of the above types of chips.

[0156] Memory 1702, as a non-transitory computer-readable storage medium, can be used to store non-transitory software programs, non-transitory computer-executable programs, and modules, such as the program instructions / modules corresponding to the unconventional oil and gas hydraulic fracturing and integrated production simulation method in this embodiment of the invention (e.g., Figure 6 The first acquisition module 10, the first determination module 20, and the presentation unit 30 are shown. The processor 1701 executes various functional applications and data processing by running non-transient software programs, instructions, and modules stored in the memory 1702, thereby realizing the unconventional oil and gas hydraulic fracturing and drainage integrated simulation method in the above method embodiment.

[0157] Memory 1702 may include a program storage area and a data storage area. The program storage area may store the operating system and applications required for at least one function; the data storage area may store data created by processor 1701, etc. Furthermore, memory 1702 may include high-speed random access memory and may also include non-transitory memory, such as at least one disk storage device, flash memory device, or other non-transitory solid-state storage device. In some embodiments, memory 1702 may optionally include memory remotely located relative to processor 1701, and these remote memories may be connected to processor 1701 via a network. Examples of such networks include, but are not limited to, the Internet, intranets, local area networks, mobile communication networks, and combinations thereof.

[0158] The one or more modules are stored in the memory 1702, and when executed by the processor 1701, they perform the following: Figure 1 The embodiment shown illustrates an unconventional integrated simulation method for hydraulic fracturing and drainage of oil and gas.

[0159] The specific details of the above-mentioned electronic device can be understood by referring to the relevant descriptions and effects in the method embodiments, and will not be repeated here.

[0160] This specification also provides a computer storage medium storing computer program instructions, which, when executed, implement the steps of the above-described unconventional oil and gas hydraulic fracturing and integrated production simulation method.

[0161] This specification also provides a computer program product, comprising a computer program that, when executed by a processor, implements the steps of the aforementioned unconventional oil and gas hydraulic fracturing and integrated production simulation method.

[0162] Those skilled in the art will understand that all or part of the processes in the methods of the above embodiments can be implemented by a computer program instructing related hardware. The program can be stored in a computer-readable storage medium, and when executed, it can include the processes of the embodiments of the above methods. The storage medium can be a magnetic disk, optical disk, read-only memory (ROM), random access memory (RAM), flash memory, hard disk drive (HDD), or solid-state drive (SSD), etc.; the storage medium can also include combinations of the above types of memory.

[0163] The various embodiments in this specification are described in a progressive manner. For the same or similar parts between the various embodiments, please refer to each other. The focus of each embodiment is to describe the differences from other embodiments.

[0164] The systems, devices, modules, or units described in the above embodiments can be implemented by computer chips or entities, or by products with certain functions.

[0165] For ease of description, the above devices are described separately by function as various units. Of course, in implementing this application, the functions of each unit can be implemented in one or more software and / or hardware.

[0166] As can be seen from the above description of the embodiments, those skilled in the art can clearly understand that this application can be implemented by means of software plus necessary general-purpose hardware platforms. Based on this understanding, the technical solution of this application, in essence, or the part that contributes to the prior art, can be embodied in the form of a software product. This computer software product can be stored in a storage medium, such as ROM / RAM, magnetic disk, optical disk, etc., and includes several instructions to cause a computer device (which may be a personal computer, server, or network device, etc.) to execute certain parts of the methods of various embodiments of this application.

[0167] This application can be used in a wide variety of general-purpose or special-purpose computer system environments or configurations. For example: personal computers, server computers, handheld or portable devices, tablet devices, multiprocessor systems, microprocessor-based systems, set-top boxes, programmable consumer electronics devices, network PCs, minicomputers, mainframe computers, distributed computing environments including any of the above systems or devices, etc.

[0168] This application can be described in the general context of computer-executable instructions, such as program modules, that are executed by a computer. Generally, program modules include routines, programs, objects, components, data structures, etc., that perform a specific task or implement a specific abstract data type. This application can also be practiced in distributed computing environments where tasks are performed by remote processing devices connected via a communication network. In distributed computing environments, program modules can reside in local and remote computer storage media, including storage devices.

[0169] Although this application has been described through embodiments, those skilled in the art will know that this application has many modifications and variations without departing from the spirit of this application, and it is intended that the appended claims cover such modifications and variations without departing from the spirit of this application.

Claims

1. An integrated simulation method for unconventional oil and gas hydraulic fracturing and drainage, characterized in that, include: Obtain the three-dimensional geological model and three-dimensional geomechanical model of the target site; A dynamic fracture propagation simulation model is obtained, wherein the inputs to the dynamic fracture propagation simulation model are a three-dimensional geological model, a three-dimensional mechanical model, and a fracturing pump injection program; Obtain the rock compression and expansion table for the target site; the rock compression and expansion table is calculated using the following formula: ; ;in, Permeability under initial pressure Permeability under a given pressure; The PDL filtration coefficient; For pressure difference, The pressure difference under initial conditions. The pressure difference under a specific pressure; The compressibility coefficient under initial pressure. The compressibility coefficient under a given pressure; Porosity at initial pressure The porosity is determined under a certain pressure. Historical yield data for the target plot is obtained. Multiple compression and expansion tables are obtained by adjusting the filtration coefficient and relative permeability curve. Based on each compression and expansion table, a crack dynamic propagation simulation model and a numerical simulator are used to determine the predicted historical yield data for each table. The relative permeability curve is used to determine the permeability. The fitting effect between the predicted historical yield data and the actual historical yield data for each compression and expansion table is calculated. The compression and expansion table with the optimal fitting effect is taken as the final compression and expansion table. The three-dimensional geological model, three-dimensional geomechanical model, and fracturing pump injection program are input into the fracture dynamic propagation simulation model. The output data of the fracture dynamic propagation simulation model and the rock compression and expansion table are input into the numerical simulator. The numerical simulator simulates the changes in formation parameters during the injection of fracturing fluid into the formation in the hydraulic fracturing process.

2. The integrated simulation method for unconventional oil and gas hydraulic fracturing and drainage as described in claim 1, characterized in that, The method further includes: predicting the oil production of the target block based on simulation results after fracturing fluid injection into the formation.

3. The integrated simulation method for unconventional oil and gas hydraulic fracturing and drainage as described in claim 1, characterized in that, The rock compression and expansion table includes the elastic deformation stage, the expansion stage, and the unloading stage. The elastic deformation stage corresponds to the state in which the rock deforms but has not yet cracked when the fracturing fluid is first injected into the formation. The expansion stage corresponds to the state in which the rock gradually increases and the number of cracks after it begins to crack. The unloading stage corresponds to the flowback process after the fracturing is completed.

4. The integrated simulation method for unconventional oil and gas hydraulic fracturing and drainage according to claim 1, characterized in that, The three-dimensional geological model was determined using the following method: The structural model, sedimentary facies model, and interlayer model of the target site are established sequentially using simulation methods. The structural model, sedimentary facies model, and interlayer model are used as constraints for the three-dimensional geological model. The three-dimensional geological model of the target site is established using variogram analysis and sequential Gaussian stochastic simulation algorithms.

5. The integrated simulation method for unconventional oil and gas hydraulic fracturing and drainage according to claim 1, characterized in that, The three-dimensional geomechanical model was determined using the following method: Based on the P-wave transit time, S-wave transit time, and density curves obtained from well logging, calculate the Poisson's ratio, Yang Shi modulus, shear modulus, bulk modulus, brittleness index, minimum horizontal principal stress, and maximum horizontal principal stress corresponding to each pixel in the three-dimensional geological model. The calculation results of each pixel are organized into a three-dimensional geomechanical model.

6. The integrated simulation method for unconventional oil and gas hydraulic fracturing and drainage according to claim 1, characterized in that, Before inputting the three-dimensional geological model and the three-dimensional geomechanical model into the fracture dynamic propagation simulation model, the model is coarsened using general keywords; correspondingly, the coarsened three-dimensional geological model and the three-dimensional geomechanical model are input into the fracture dynamic propagation simulation model. And / or, Before inputting the output data of the crack dynamic propagation simulation model into the numerical simulator, the local mesh at the crack is refined using normative keywords; correspondingly, the refined local mesh result is input into the numerical simulator.

7. An integrated simulation device for unconventional oil and gas hydraulic fracturing and drainage, characterized in that, include: The first acquisition unit is used to acquire the three-dimensional geological model and three-dimensional geomechanical model of the target site; The second acquisition unit is used to acquire the dynamic propagation simulation model of the fracture. The input of the dynamic propagation simulation model of the fracture is a three-dimensional geological model, a three-dimensional mechanical model, and a fracturing pump injection program. The third acquisition unit is used to acquire the rock compression-expansion table of the target site; the rock compression-expansion table is calculated according to the following formula: ; ;in, Permeability under initial pressure Permeability under a given pressure; The PDL filtration coefficient; For pressure difference, The pressure difference under initial conditions. The pressure difference under a specific pressure; The compressibility coefficient under initial pressure. The compressibility coefficient under a given pressure; Porosity at initial pressure The porosity is determined under a certain pressure. Historical yield data for the target plot is obtained. Multiple compression and expansion tables are obtained by adjusting the filtration coefficient and relative permeability curve. Based on each compression and expansion table, a crack dynamic propagation simulation model and a numerical simulator are used to determine the predicted historical yield data for each table. The relative permeability curve is used to determine the permeability. The fitting effect between the predicted historical yield data and the actual historical yield data for each compression and expansion table is calculated. The compression and expansion table with the optimal fitting effect is taken as the final compression and expansion table. The simulation unit is used to input the three-dimensional geological model, the three-dimensional geomechanical model, and the fracturing pump injection program into the fracture dynamic propagation simulation model, and to input the output data of the fracture dynamic propagation simulation model and the rock compression and expansion table into the numerical simulator. The numerical simulator simulates the changes in formation parameters during the injection of fracturing fluid into the formation in the hydraulic fracturing process.

8. An electronic device, characterized in that, include: The system includes a memory and a processor, which are interconnected. The memory stores computer instructions, and the processor executes the computer instructions to implement the unconventional oil and gas hydraulic fracturing and drainage integrated simulation method as described in any one of claims 1 to 6.

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