Numerical simulation initialization method and system for oil-gas inverted condensate shale oil reservoir

Abstract

The invention provides a numerical simulation initialization method and system for an oil-gas inverted condensate shale oil reservoir, and the method comprises the steps: carrying out an indoor high-pressure physical property experiment, and obtaining a fluid PVT phase state; phase state fitting is carried out, and a fluid component model is established; establishing an oil reservoir model according to oil reservoir geology research cognition; collecting temperature and pressure data, and constructing a formation temperature and original formation pressure model; and numerical model establishment and initialization calculation are completed. The method can lay a foundation for enriching the theoretical research of the condensed shale oil, provides support for follow-up condensed shale oil development index optimization and adjustment countermeasures, and has important guiding significance.

Description

Technical Field

[0001] The present invention relates to the technical field of oil development, and in particular to a method and system for initializing numerical simulation of an oil and gas inverted condensate shale reservoir. Background Art

[0002] With the development of oil and gas geological theory and the continuous advancement of engineering technology, China has made major breakthroughs in the exploration and development of continental shale oil.

[0003] Among the many types of shale oil in China, there is a very special type of shale oil, which has only been found in the Bonan Depression of Shengli Jiyang Depression. Its geological conditions are characterized by a reservoir burial depth greater than 4000m, a reservoir thickness of more than 1000m, and abnormally high temperature and high pressure conditions. The C1 mole fraction of the reservoir fluid is about 70%, which belongs to the category of condensate shale oil and gas. At the same time, because the temperature and pressure conditions in the middle of the reservoir are near the critical point of the fluid phase, an abnormal form of oil and gas coexistence, inverted distribution, and oil above gas below is formed in the shale oil reservoir where the interlayer is not developed, that is, the oil phase is at the top of the reservoir, the gas phase is at the bottom of the reservoir, and there is an interface between oil and gas. At present, a horizontal well that penetrates the oil and gas interface has been deployed in this shale oil reservoir. The self-flowing period has exceeded one year, with an accumulated oil of about 15,000 tons and a accumulated gas of about 16 million cubic meters. The return rate is greater than 95%, and the wellhead pressure is still 17Mpa, showing the extremely high development potential and value of condensate shale oil and gas in this block.

[0004] The use of reservoir numerical simulation technology to predict shale oil production dynamics and the potential of remaining oil and gas resources in the reservoir plays an important role in realizing large-scale development of shale oil. However, conventional numerical simulation technology is difficult to deal with this type of condensate shale reservoir with oil and gas inversion. The reason is that in conventional simulation studies, the density of the gas phase is usually less than that of the oil phase. Even if an inverted oil and gas partition is set, the difference in oil and gas density will cause the model initialization calculation results to be unbalanced, resulting in numerical calculation errors, and it is impossible to carry out subsequent parameter optimization and development research. The formation of this type of condensate shale reservoir with oil and gas inversion is theoretically based on the premise of a specific oil and gas component composition. The formation temperature and pressure conditions must simultaneously meet the pressure higher than the maximum condensate pressure and the temperature is near the critical temperature. At the same time, it must also meet the requirements of large vertical thickness of the reservoir, large formation temperature span, and a temperature range between the two sides of the phase critical point. This state of fluid is usually called a near-critical state. Its physical properties and phase characteristics are very sensitive to temperature and pressure conditions. Slight changes in temperature or pressure can cause great changes in fluid properties. During the depletion development process, as the pressure decreases, the formation fluid will simultaneously show the characteristics of degassing in oil and oil separation in gas, further increasing the complexity of the fluid phase state. Since the conditions for the formation of such condensate shale reservoirs are relatively harsh, most domestic oil and gas fields do not have similar characteristics, and there are very few similar literature. How to construct a numerical simulation model for such condensate shale reservoirs and achieve an inverted equilibrium state of upper oil and lower gas when the model is initialized is the key issue to be solved first in the numerical simulation of such condensate shale reservoirs.

[0005] Chinese patent application CN106934084A discloses a phase fitting method for a condensate gas reservoir with bottom oil, comprising the following steps: 1) obtaining bottom oil and condensate gas from the gas reservoir respectively, and determining the molar content of the bottom oil and condensate gas respectively; 2) dividing the pseudo-components according to the components of the bottom oil and the condensate gas; 3) performing phase fitting on the bottom oil and the condensate gas according to the molar content of the pseudo-components and the pseudo-components corresponding to the bottom oil and the condensate gas. This method is to fit the oil and gas phases as two sets of fluids separately, and the formation conditions are usually at normal temperature and pressure or normal temperature and high pressure. The oil and gas phases present a distribution form of upper gas and lower oil due to the density difference, which belongs to the category of conventional condensate gas reservoirs with oil rings. This method cannot be directly applied to the inverted oil and gas distribution form described in the present invention, because the main controlling factor for the formation of oil and gas inversion is abnormally high temperature and high pressure, and the formation temperature condition is near the critical point of the phase state, and the oil and gas phase state is very sensitive to the temperature and pressure conditions. Due to the different mechanisms, directly using two sets of phase states will easily lead to the density of the upper oil phase being higher than that of the lower gas phase, and the model cannot perform phase equilibrium calculations. Moreover, using two sets of phase states is difficult to reflect the formation mechanism of this near-critical condensate reservoir. Therefore, this method is difficult to apply to condensate gas reservoirs where oil and gas coexist and are invertedly distributed.

[0006] A new method for dynamic prediction of near-critical oil and gas reservoirs is proposed in the non-patent document "Development Characteristics of Near-critical Oil and Gas Reservoirs and Oil and Gas Production Prediction", which includes the following steps: 1) Analyze the physical properties and seepage laws of near-critical oil and gas, and clarify the development mechanism of depletion development of near-critical oil and gas reservoirs; 2) Construct a generalized material balance equation, recovery degree and gas-oil ratio equation considering component changes; 3) Analyze the relationship between the recovery degree and gas-oil ratio of a near-critical oil reservoir by example, and predict the theoretical recovery rate of the reservoir with pressure reduction during depletion development. The near-critical fluid mentioned in the document is similar to the near-critical fluid described in the present invention, but the reservoir studied in the document is still a single volatile oil, and the influence of changes in temperature and pressure conditions in the actual formation on the change of fluid phase state is not considered, and the phenomenon and mechanism of oil and gas inversion are not mentioned. There is no effective solution for the phase state and numerical simulation method of condensate shale reservoirs with coexistence of oil and gas and inverted distribution.

[0007] In summary, the current numerical simulation research on condensate oil and gas mainly focuses on the study of condensate gas phase state and depletion development oil and gas dynamic characteristics. The reservoir is usually considered to be a single gas phase or oil phase, and there is no numerical simulation result for condensate shale reservoirs with inverted oil and gas distribution. Summary of the invention

[0008] In view of the above problems, the present invention is proposed to provide a method and system for initializing numerical simulation of oil and gas inverted condensate shale reservoirs that overcome the above problems or at least partially solve the above problems.

[0009] According to one aspect of the present invention, a method for initializing numerical simulation of an oil and gas inverted condensate shale reservoir is provided, the method comprising:

[0010] Conduct indoor high-pressure physical property experiments to obtain the PVT phase state of fluids;

[0011] Carry out phase fitting and establish fluid component model;

[0012] Establish reservoir model based on reservoir geological research;

[0013] Collect temperature and pressure data and construct formation temperature and original formation pressure models;

[0014] Complete the numerical model establishment and initialization calculation.

[0015] Optionally, the indoor high-voltage physical property experiment specifically includes:

[0016] Oil samples are taken from the wellhead and configured into experimental test samples according to the actual gas-oil ratio in production. Sample configuration and analysis tests are carried out in accordance with relevant national standards.

[0017] Optionally, the test contents of the experimental test include fluid component test, constant volume exhaustion test, and constant quality expansion test.

[0018] Optionally, the obtaining of the fluid PVT phase state specifically includes: fitting data parameter information of different pressure conditions in the two-phase region of each component according to experimental data to obtain the fluid PVT phase diagram.

[0019] Optionally, the data parameter information includes: liquid content, relative volume, deviation factor, phase envelope and equal condensate volume.

[0020] Optionally, the performing phase state fitting and establishing the fluid component model specifically includes:

[0021] Combining fluid components according to the PVT phase states of the fluids;

[0022] Using phase state fitting high-pressure physical property experiments, the calculation parameters of the merged fluid components are obtained and the merged component model is constructed;

[0023] The component model requires that the relative errors of the fitting results of the critical point temperature, critical point pressure and maximum condensate pressure and the PVT phase state of the fluid are all less than the error threshold;

[0024] Ensure the accuracy of the initialization of numerical simulation of oil and gas inverted condensate shale reservoirs and the subsequent retrograde condensate simulation analysis.

[0025] Optionally, the error threshold is 5%.

[0026] Optionally, the establishment of the reservoir model based on the knowledge gained from reservoir geological research specifically includes:

[0027] Construct well models;

[0028] Constructing stratigraphic models;

[0029] Construct porosity and permeability property parameter model;

[0030] Prepare basic information.

[0031] Optionally, the building of the well model specifically includes:

[0032] The well model of the actual reservoir can be established based on the actual well coordinates, trajectory, and perforation data;

[0033] For the conceptual model, the corresponding well trajectory and perforation layer can be designed according to research needs.

[0034] Optionally, the constructing of the formation model specifically includes:

[0035] According to the reservoir structure and fault data, the actual reservoir top and bottom structural surface and fault model are established;

[0036] For the conceptual model, a structural surface with a certain depth and planar distribution shape can be designed according to research needs, and the depth of the structural surface must be consistent with the actual reservoir depth.

[0037] Optionally, the constructing of the porosity and permeability property parameter model specifically includes:

[0038] According to the actual logging interpretation data, the actual reservoir porosity and permeability model is established through coarsening of porosity and permeability interpretation parameters and phase-controlled variation analysis;

[0039] Build models based on data distribution trends or set fixed values;

[0040] For the conceptual model, a porosity and permeability model with a constant value or a specific distribution law is designed according to research needs.

[0041] Optionally, the preparation of basic information specifically includes:

[0042] For the actual model, the necessary data include relative permeability data, rock compressibility data, single well perforation data, historical production data, and well production strategy;

[0043] For some special data or designs, such as local grid encryption, J function, Langmuir adsorption parameters, water body data, etc., corresponding settings can be made according to actual needs; the conceptual model and the actual model requirements are consistent.

[0044] Optionally, the collecting of temperature and pressure data and constructing a formation temperature and original formation pressure model specifically includes:

[0045] Based on the oil test data or temperature and pressure test reports of existing wells in the actual oil reservoir, obtain the temperature and pressure data of different depths of the formation, and construct the mathematical relationship between depth and formation temperature and pressure;

[0046] According to existing theories and practices, formation temperature and formation pressure increase with depth, but the temperature and formation pressure gradients are often not constant;

[0047] When constructing mathematical relationships, a unified continuous function relationship or continuous curve must be established, and segmented representation is not allowed;

[0048] Substitute the mathematical relationship into the reservoir model, obtain the distribution of grid formation temperature and pressure at different depths, and establish a three-dimensional model of formation temperature and original formation pressure.

[0049] Optionally, completing the establishment of the numerical model and initialization calculation specifically includes:

[0050] The fluid component model, the reservoir model, and the formation temperature and original formation pressure model are substituted into a component simulator to construct a component numerical model, and complete the initialization phase equilibrium calculation of the numerical simulation of the oil-gas inverted oil-gas inverted condensate shale reservoir.

[0051] The present invention also provides an oil and gas inverted condensate shale reservoir numerical simulation initialization system, the initialization system comprising:

[0052] High-pressure physical property experiment module, used to carry out indoor high-pressure physical property experiments and obtain the fluid PVT phase state;

[0053] Fluid component model building module, used to carry out phase fitting and build fluid component model;

[0054] The reservoir model building module is used to build a reservoir model based on the knowledge gained from reservoir geological research;

[0055] The formation temperature and original formation pressure model collection module is used to collect temperature and pressure data and construct the formation temperature and original formation pressure model;

[0056] The initialization calculation module is used to complete the numerical model establishment and initialization calculation.

[0057] The present invention provides a method and system for initializing numerical simulation of oil and gas inverted condensate shale reservoirs, the initialization method comprising: conducting indoor high-pressure physical property experiments to obtain fluid PVT phase states; conducting phase state fitting to establish a fluid component model; establishing a reservoir model based on reservoir geological research; collecting temperature and pressure data to construct a formation temperature and original formation pressure model; and completing numerical model establishment and initialization calculations. This can lay a foundation for enriching the theoretical research on this type of condensate shale oil, and provide support for subsequent optimization of condensate shale oil development indicators and adjustment measures, which has important guiding significance.

[0058] The above description is only an overview of the technical solution of the present invention. In order to more clearly understand the technical means of the present invention, it can be implemented according to the contents of the specification. In order to make the above and other purposes, features and advantages of the present invention more obvious and easy to understand, the specific implementation methods of the present invention are listed below. BRIEF DESCRIPTION OF THE DRAWINGS

[0059] In order to more clearly illustrate the technical solutions of the embodiments of the present invention, the accompanying drawings required for use in the description of the embodiments will be briefly introduced below. Obviously, the accompanying drawings described below are only some embodiments of the present invention. For ordinary technicians in this field, other accompanying drawings can be obtained based on these accompanying drawings without paying creative work.

[0060] Figure 1 A flowchart of a method for implementing a numerical simulation initialization method for an oil and gas inverted condensate shale reservoir provided by an embodiment of the present invention;

[0061] Figure 2 PVT phase diagram of the experimental fluid provided by the embodiment of the present invention;

[0062] Figure 3 A phase diagram of a fluid fitted after the components provided in an embodiment of the present invention are combined;

[0063] Figure 4 A condensate shale oil and gas reservoir permeability model provided in an embodiment of the present invention;

[0064] Figure 5 A condensate shale oil and gas reservoir porosity model provided in an embodiment of the present invention;

[0065] Figure 6 A graph of depth and temperature of a condensate shale oil and gas reservoir provided by an embodiment of the present invention;

[0066] Figure 7 A condensate shale oil and gas reservoir formation temperature model provided by an embodiment of the present invention;

[0067] Figure 8 The phase equilibrium calculation results of the oil and gas inverted condensate shale oil and gas reservoir provided by the embodiment of the present invention. DETAILED DESCRIPTION

[0068] 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 accompanying 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 to enable a more thorough understanding of the present disclosure and to fully convey the scope of the present disclosure to those skilled in the art.

[0069] The terms "comprises" and "having" and any variations thereof in the description embodiments, claims and drawings of the present invention are intended to cover non-exclusive inclusions, for example, including a series of steps or units.

[0070] The technical solution of the present invention is further described in detail below in conjunction with the accompanying drawings and embodiments.

[0071] A method for initializing numerical simulation of oil and gas inverted condensate shale reservoirs is proposed. Based on indoor high-pressure physical property experiments, fluid components and phase parameters are obtained, and the experimental fluid phase is fitted through the phase equation. At the same time, according to the temperature and pressure test of the mine, the temperature and pressure gradient is obtained, and the reservoir temperature and pressure equation is constructed. Finally, according to the geological knowledge of the reservoir, a three-dimensional model is constructed, and the temperature and pressure at different depths of the reservoir are calculated through the component simulator. According to the phase theory, the phase equilibrium calculation of the initial state of the model is completed through the temperature and pressure condition control, and the numerical simulation initialization of the oil and gas inverted condensate shale reservoir is realized.

[0072] Example

[0073] In a specific embodiment of the present invention, a numerical simulation initialization method for an oil and gas inverted condensate shale reservoir is provided, with an actual reservoir model as the background, and includes the following steps:

[0074] Step 1: Conduct indoor high-pressure physical property experiments to obtain the fluid PVT phase state.

[0075] Step 1 specifically includes the following steps:

[0076] Step 101, take oil samples at the wellhead and configure them into formation samples according to the actual oil well production gas-oil ratio of 1000m3 / m3.

[0077] Step 102, conduct fluid PVT test, refer to the actual formation temperature of 175 ° C and the formation pressure of 77 MPa, determine the experimental temperature and pressure conditions, the test content includes fluid component test, constant volume exhaustion test, constant quality expansion test, calculate the deviation coefficient, fluid pressure-volume relationship, exhaustion process liquid percentage, exhaustion process cumulative production and other parameters, by fitting the exhaustion experiment pressure and retrograde condensate liquid volume and deviation coefficient, relative volume, obtain the phase envelope and test fluid phase diagram (see Appendix Figure 2 ).

[0078] Step 2: Carry out phase fitting and establish a fluid component model.

[0079] Step 2 specifically includes the following steps:

[0080] Step 201, according to step 102, merge the test fluid components, and this embodiment uses the PVTi module to carry out fluid component merging and phase state fitting. In this embodiment, the experiment gives 18 fitting components, including N2, CO2, C1, C2, C3, iC4, nC4, iC5, nC5, C6, C7+, C11+, C22+, C31+, C40+, C49+, C59+, and C69+. Through component merging, they are divided into 7 components, including C1+, C2+, C3+, C5+, C9+, C16+, and C27+.

[0081] Step 202, using the PVTi module to fit the high-pressure physical property experiment after the components are combined, this embodiment uses the PR equation to carry out phase state calculation, and by adjusting the fitting parameters, the fluid phase state diagram after the components are combined is obtained (see Appendix Figure 3 ), the fitting critical temperature is 158.7°C and the critical pressure is 53.2Mpa. In step 102, the phase critical temperature is 159.5°C and the critical pressure is 54.45Mpa. The fitting critical temperature error is 0.8°C and the fitting critical pressure error is 1.25Mpa, both of which are less than 5%, meeting the error requirements.

[0082] Step 3: Establish a reservoir model based on the knowledge gained from reservoir geological studies.

[0083] This embodiment uses Petrel software to establish a reservoir model, which specifically includes the following steps:

[0084] Step 301, establishing a well model based on actual reservoir wellhead coordinates, trajectory, and perforation data.

[0085] Step 302, according to actual research needs, establish the model boundary, divide the model plane and vertical grids, and construct a grid model.

[0086] Step 303, establishing a reservoir stratigraphic model and a fault model based on the structural and fault data.

[0087] Step 304: Based on existing porosity and permeability studies, establish a porosity model for each layer (see Appendix Figure 4 ) and permeability model (Appendix Figure 5 ).

[0088] Step 305, based on the indoor rock and relative permeability test data, establish a rock compression model and an oil, gas and water three-phase relative permeability model respectively.

[0089] Step 306, setting a single well production work system, in this embodiment, it is set to produce according to a single well fixed gas volume.

[0090] Step 4: Construct the formation temperature and original formation pressure model.

[0091] Step 4 specifically includes the following steps:

[0092] Step 401: Based on the existing temperature and pressure test data of the block, the relationship between depth and temperature and pressure is constructed. Taking temperature as an example, the average formation temperature gradient is determined to be 3.1-3.3℃ / 100m through the field measured data. According to the measured temperature and depth relationship, the depth and temperature function is established (see Appendix Figure 6 ), assuming the ground temperature is 20°C, the relationship between temperature and depth is as follows:

[0093] T=-Grad(T)×depth+20

[0094] Where T is the formation temperature, °C; Grad(T) is the temperature gradient, °C / m; depth is the altitude, m.

[0095] Step 402, according to step 401, calculate the temperature and pressure field of the grids at different depths in step 3, and establish an initial formation temperature and pressure model. Taking temperature as an example, read the grid depth of the model in step 3, use the relationship described in step 401 to calculate the temperature at the corresponding depth of each grid, and complete the establishment of the initial formation temperature model (see Appendix Figure 7 )

[0096] Step 5: Initialize the calculation of phase equilibrium of the numerical model.

[0097] Substitute steps 2, 3, and 4 into the component simulator to construct a component numerical model and complete the phase equilibrium initialization calculation. This embodiment uses the E300 simulator to import the porosity and permeability model, fluid component model, phase permeability model, rock compression model, and formation temperature and pressure model into the simulator. By controlling the temperature and pressure of each grid, the phase equilibrium calculation is completed to realize the initialization of the numerical model of the condensate gas reservoir with inverted oil and gas distribution (see Appendix). Figure 8 ).

[0098] Beneficial effects: The present invention is based on the phase theory of reservoir engineering, and the implementation process conforms to the multi-component fluid phase theory system. In the initialization method of conventional oil and gas system numerical simulation, since the density of the gas phase is less than that of the oil phase, the initialization of the numerical model of oil above gas below cannot be achieved. It is usually necessary to artificially set the fluid properties for different regions, or to artificially add an impermeable barrier at the oil and gas interface to meet the oil and gas equilibrium state during initialization. However, no matter which method is used, it does not conform to the formation mechanism of oil and gas inversion of high-temperature and high-pressure thick-layer condensate shale reservoir fluids, and is affected by human intervention and lacks practical theoretical support. The present invention is based on indoor experimental testing and phase fitting to clarify the phase characteristics of the fluid and obtain the key parameters of the fluid state equation. Through the joint control of temperature and pressure, the phase changes of such shale reservoir fluids under different temperature and pressure conditions are determined, and the physical properties such as density and viscosity of fluids at different depths are calculated by temperature, pressure and phase calculation. Through indoor experiments, it is confirmed that under high temperature and high pressure conditions, the oil and gas density of the formation fluid is not much different, and the same conclusion can be obtained by carrying out numerical simulation using the method described in the present invention. Therefore, the present invention breaks the conventional understanding of gas above and oil below, and is realized through existing numerical simulation technology. The implementation process not only conforms to theoretical understanding, but also meets the actual situation of the reservoir. It can lay a foundation for enriching the theoretical research of this type of condensate shale oil, and provide support for the subsequent optimization of condensate shale oil development indicators and adjustment countermeasures, which has important guiding significance.

[0099] The above specific implementation methods further illustrate the objectives, technical solutions and beneficial effects of the present invention in detail. It should be understood that the above are only specific implementation methods of the present invention and are not intended to limit the scope of protection of the present invention. Any modifications, equivalent substitutions, improvements, etc. made within the spirit and principles of the present invention should be included in the scope of protection of the present invention.

Claims

1. A method for initializing numerical simulation of oil and gas inverted condensate shale reservoirs, characterized in that: The initialization method comprises: Conduct indoor high-pressure physical property experiments to obtain the PVT phase state of fluids; Carry out phase fitting and establish fluid component model; Establish reservoir model based on reservoir geological research; Collect temperature and pressure data and construct formation temperature and original formation pressure models; Complete the numerical model establishment and initialization calculation.

2. The method for initializing numerical simulation of oil and gas inverted condensate shale reservoir according to claim 1, characterized in that: The indoor high-voltage physical property experiment specifically includes: Oil samples are taken from the wellhead and configured into experimental test samples according to the actual gas-oil ratio in production. Sample configuration and analysis tests are carried out in accordance with relevant national standards.

3. The method for initializing numerical simulation of oil and gas inverted condensate shale reservoir according to claim 2, characterized in that: The test contents of the experimental test include fluid component test, constant volume exhaustion test and constant quality expansion test.

4. The method for initializing numerical simulation of oil and gas inverted condensate shale reservoir according to claim 1, characterized in that: The obtaining of the fluid PVT phase state specifically includes: fitting the data parameter information of different pressure conditions in the two-phase region of each component according to the experimental data to obtain the fluid PVT phase diagram.

5. The method for initializing numerical simulation of oil and gas inverted condensate shale reservoir according to claim 4, characterized in that: The data parameter information includes: liquid content, relative volume, deviation factor, phase envelope and isocondensate volume.

6. The method for initializing numerical simulation of oil and gas inverted condensate shale reservoir according to claim 1, characterized in that: The carrying out phase state fitting and establishing the fluid component model specifically includes: merging fluid components according to the PVT phase states of the fluids; Using phase state fitting high-pressure physical property experiments, the calculation parameters of the merged fluid components are obtained and the merged component model is constructed; The component model requires that the relative errors of the fitting results of the critical point temperature, critical point pressure and maximum condensate pressure and the PVT phase state of the fluid are all less than the error threshold; Ensure the accuracy of the initialization of numerical simulation of oil and gas inverted condensate shale reservoirs and the subsequent retrograde condensate simulation analysis.

7. The method for initializing numerical simulation of oil and gas inverted condensate shale reservoir according to claim 6, characterized in that: The error threshold is 5%.

8. The method for initializing numerical simulation of oil and gas inverted condensate shale reservoir according to claim 1, characterized in that: According to the knowledge gained from reservoir geological research, establishing a reservoir model specifically includes: Construct well models; Constructing stratigraphic models; Construct porosity and permeability property parameter model; Prepare basic information.

9. The method for initializing numerical simulation of oil and gas inverted condensate shale reservoir according to claim 8, characterized in that: The well model construction specifically includes: The well model of the actual reservoir can be established based on the actual well coordinates, trajectory, and perforation data; For the conceptual model, the corresponding well trajectory and perforation layer can be designed according to research needs.

10. The method for initializing numerical simulation of oil and gas inverted condensate shale reservoir according to claim 8, characterized in that: The construction of the formation model specifically includes: According to the reservoir structure and fault data, the actual reservoir top and bottom structural surface and fault model are established; For the conceptual model, a structural surface with a certain depth and planar distribution shape can be designed according to research needs, and the depth of the structural surface must be consistent with the actual reservoir depth.

11. The method for initializing numerical simulation of oil and gas inverted condensate shale reservoir according to claim 8, characterized in that: The construction of the porosity and permeability property parameter model specifically includes: According to the actual logging interpretation data, the actual reservoir porosity and permeability model is established through coarsening of porosity and permeability interpretation parameters and phase-controlled variation analysis; Build models based on data distribution trends or set fixed values; For the conceptual model, a porosity and permeability model with a constant value or a specific distribution law is designed according to research needs.

12. The method for initializing numerical simulation of oil and gas inverted condensate shale reservoir according to claim 8, characterized in that: The basic information preparation specifically includes: For the actual model, the necessary data include phase permeability data, rock compressibility data, single well perforation data, historical production data, and well production strategy; For some special data or designs, such as local grid encryption, J function, Langmuir adsorption parameters, water body data, etc., corresponding settings can be made according to actual needs; the conceptual model and the actual model requirements are consistent.

13. The method for initializing numerical simulation of oil and gas inverted condensate shale reservoir according to claim 1, characterized in that: The collecting of temperature and pressure data and constructing the formation temperature and original formation pressure model specifically includes: Based on the oil test data or temperature and pressure test reports of existing wells in the actual oil reservoir, obtain the temperature and pressure data of different depths of the formation, and construct the mathematical relationship between depth and formation temperature and pressure; According to existing theories and practices, formation temperature and formation pressure increase with depth, but the temperature and formation pressure gradients are often not constant; When constructing mathematical relationships, a unified continuous function relationship or continuous curve must be established, and segmented representation is not allowed; Substitute the mathematical relationship into the reservoir model, obtain the distribution of grid formation temperature and pressure at different depths, and establish a three-dimensional model of formation temperature and original formation pressure.

14. The method for initializing numerical simulation of oil and gas inverted condensate shale reservoir according to claim 1, characterized in that: The completion of the numerical model establishment and initialization calculation specifically includes: Substitute the fluid component model, the reservoir model, and the formation temperature and original formation pressure model into a component simulator to construct a component numerical model, and complete the initialization phase equilibrium calculation of the numerical simulation of the oil-gas inversion oil-gas inversion condensate shale reservoir.

15. A numerical simulation initialization system for oil and gas inverted condensate shale reservoirs, characterized in that: The initialization system comprises: High-pressure physical property experiment module, used to carry out indoor high-pressure physical property experiments and obtain the fluid PVT phase state; Fluid component model building module, used to carry out phase fitting and build fluid component model; The reservoir model building module is used to build a reservoir model based on the knowledge gained from reservoir geological research; The formation temperature and original formation pressure model collection module is used to collect temperature and pressure data and construct the formation temperature and original formation pressure model; The initialization calculation module is used to complete the numerical model establishment and initialization calculation.

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