Geochemical exploration forward numerical simulation method and device, computer equipment and storage medium

Abstract

The application provides a kind of geochemical exploration forward numerical simulation method, device, computer equipment and storage medium, the method includes obtaining oil and gas geology data and seismic data, determines reservoir geology model;Obtain diffusion mathematical model, aqueous phase migration mathematical model and buoyancy migration mathematical model;Based on the determined reservoir geology model, the diffusion mathematical model, the aqueous phase migration mathematical model and the buoyancy migration mathematical model are coupled, and the reservoir hydrocarbon micro leakage mathematical model is established;Based on the reservoir hydrocarbon micro leakage mathematical model, segmented simulation is carried out.Numerical simulation method is used to better reflect the actual geological conditions under the transformation of micro leakage three ways and its micro leakage concentration change, considering the influence of various geological factors, can realize the numerical simulation and visualization effect of one-dimensional, two-dimensional, three-dimensional strata space, forward oil and gas geochemical exploration formation mechanism, and consolidates the hydrocarbon vertical micro leakage theory.

Description

Technical Field

[0001] This invention relates to the field of numerical simulation technology for oil and gas exploration, and in particular to a method, apparatus, computer equipment, and storage medium for geochemical forward modeling based on a reservoir model. Background Technology

[0002] As a means of oil and gas exploration, geochemical exploration technology is based on the assumption that "hydrocarbon gases in underground oil and gas reservoirs migrate approximately vertically to the surface in weak but detectable amounts." Despite a series of successful cases over the years, many scholars in the geological community still have doubts about the formation mechanism of near-surface geochemical anomalies. There is an urgent need to strengthen the forward modeling research on the formation mechanism of geochemical anomalies. Numerical simulation is one of the methods for conducting forward modeling research. It can describe the process of vertical micro-leakage of hydrocarbons and its near-surface manifestation from a mechanistic perspective, thus consolidating the basic theory of vertical micro-leakage of hydrocarbons.

[0003] Currently, geochemical forward modeling studies generally employ a single mechanism to simulate the process from reservoir to caprock to overlying strata to the surface. Ruan Tianjian (1985) hypothesized six combinations of caprock and gas source conditions and numerically simulated anomalies formed at the surface during diffusion processes. The simulation results showed that small oilfields (narrow gas sources) exhibit top anomalies, while large oilfields (wide-ranging gas sources) show halo anomalies. Xiao Wei, Bao Zhengyu, et al. (2003), building upon previous research on hydrocarbon microleakage mechanisms, established a conceptual model of hydrocarbon microleakage and derived a kinetic model for the vertical migration of hydrocarbons. Based on this kinetic model, numerical simulations suggested that the mechanism of hydrocarbon colloidal bubble ascent is a more reasonable approach, and the equilibrium time for vertical hydrocarbon migration under different conditions was calculated. Huang et al. (2007) proposed that light hydrocarbons migrate quasi-vertically upwards via microbubbles in micelle form, establishing a quantitative model for micro-leaking loss. They also quantitatively estimated the amount of natural gas lost through caprock micro-leaking during geological history using actual gas reservoirs. Li Meng (2009, 2012) and Li Zhiwei (2012) constructed ideal single-layer and multi-layer block formation media models based on the basic concepts of vertical micro-leaking of hydrocarbons and the assumption of continuous media. Then, based on the law of conservation of mass, they established quantitative equations describing the vertical micro-leaking process of hydrocarbons within the formation media model, namely a class of reaction-convection-diffusion partial differential equations. Internationally, regarding the diffusion mechanism, Krooss et al. (1992) further considered the balance between gaseous methane and water-soluble methane in the caprock, further modifying the previous equations and calculating the diffusion amount of hydrocarbons in the sedimentary column. They compared the results with experimental data and obtained relatively consistent results. Nelson and Simmons criticized Krooss's (1992) calculations, combining the diffusion coefficient with porosity, permeability, and tortuosity for a new numerical calculation. Additionally, Jakel and Klusman (1995) and Thomas and Clouse (1990) have both studied numerical simulations of diffusion mechanisms

[81] . Ronald W. Klusman (2005, 2010) numerically simulated the vertical migration of hydrocarbons in the saturated and unsaturated zones above oil and gas reservoirs under buoyancy. He argued that the buoyancy-driven uplift mechanism of microbubbles is a dynamic hydrocarbon migration mechanism, providing support for surface geochemical phenomena observed in oil and gas exploration. Regarding the formation of surface geochemical anomalies, different scholars emphasize what they consider to be the main mechanisms in numerical simulations, resulting in relatively singular considerations. Micro-leakage varies in different strata, with different temperature, pressure, and formation water conditions, and its leakage mode changes with these conditions. Simultaneously, the sealing performance of the caprock also determines the mode and scale of micro-leakage. Therefore, in the entire formation medium system from the reservoir to the immediate caprock to the overlying strata to the surface, there must be various micro-permeability mechanisms and influencing factors.

[0004] The numerical simulation studies mentioned above only emphasize one mode of micro-leakage and consider relatively few influencing factors under geological conditions. Therefore, it is necessary to establish a numerical simulation method that considers various micro-leakage modes and their contributions, as well as geological influencing factors, to forward model the formation mechanism of oil and gas geochemical anomalies. Summary of the Invention

[0005] Therefore, it is necessary to provide a geochemical forward modeling numerical simulation method, apparatus, computer equipment, and storage medium to address the aforementioned technical problems.

[0006] A geochemical forward modeling numerical simulation method includes:

[0007] Acquire petroleum geological data and seismic data to determine reservoir geological models;

[0008] Obtain mathematical models for diffusion, water-soluble phase transport, and buoyancy transport;

[0009] Based on the established reservoir geological model, the diffusion mathematical model, the water-soluble phase transport mathematical model, and the buoyancy transport mathematical model are coupled to establish a reservoir hydrocarbon micro-leakage mathematical model;

[0010] Segmented simulations were performed based on the aforementioned mathematical model of hydrocarbon micro-leakage in the reservoir.

[0011] In one embodiment, the step of coupling the diffusion mathematical model, the water-soluble phase migration mathematical model, and the buoyancy migration mathematical model based on the established reservoir geological model to establish a reservoir hydrocarbon micro-permeability mathematical model includes:

[0012] To obtain the physical adsorption capacity of the formation, the chemical adsorption capacity of carbonate minerals, and the microbial degradation capacity;

[0013] Based on the established reservoir geological model, the diffusion mathematical model, the water-soluble phase transport mathematical model, and the buoyancy transport mathematical model are coupled together, and combined with the formation physical adsorption amount, the carbonate mineral chemical adsorption amount, and the microbial degradation amount, to establish a reservoir hydrocarbon micro-leakage mathematical model.

[0014] In one embodiment, the mathematical model for hydrocarbon micro-leakage in the reservoir is:

[0015] C=C k *α+C s *β+C f *γ-R1-R2-R3

[0016] Among them, C k C represents the concentration of hydrocarbons in microleakage due to diffusion. s C represents the concentration of hydrocarbons transported in the water-soluble phase. fR1 represents the concentration of hydrocarbons transported by buoyancy, R2 represents the total adsorption rate of hydrocarbons by formation particles, R3 represents the total adsorption rate of hydrocarbons by carbonate rocks, and R4 represents the degradation rate of hydrocarbons by microorganisms. α, β, and γ are contribution coefficients, where 0 ≤ α ≤ 1, 0 ≤ β ≤ 1, 0 ≤ γ ≤ 1, and α + β + γ = 1.

[0017] In one embodiment, the diffusion mathematical model is:

[0018]

[0019] Where c is the concentration of any substance at any point in the rectangular coordinate system, and D is the diffusion coefficient in three directions, with units of m. 2 / s, where C in the diffusion mathematical model is set as the hydrocarbon concentration C of the micro-leakage caused by diffusion. k .

[0020] In one embodiment, the mathematical model for the transport of the water-soluble phase is:

[0021]

[0022] Where, q ci V represents the flux of hydrocarbon components; ε represents the water flow rate; D represents the water content; T C represents the total dispersion factor; i The concentration of water-soluble hydrocarbons is represented by ▽. In the mathematical model of water-soluble phase transport, ▽ represents the gradient change of total hydrocarbon concentration in two-dimensional rectangular coordinates (X, Z), i.e. ;

[0023] The formula for transporting hydrocarbon components in water is:

[0024]

[0025] Where q is q ci This represents the flux of hydrocarbon components. In the formula for transporting hydrocarbon components in water, C is set as the concentration of hydrocarbons transported in the water-soluble phase, C0. s .

[0026] In one embodiment, the step of obtaining the buoyancy displacement mathematical model is as follows:

[0027] Based on Darcy's law, which is proportional to the potential gradient of each phase, we obtain the formula for calculating the linear velocity of water and gas in rock strata.

[0028] Based on the formula for calculating the linear velocities of water and gas in rock strata, the amount of hydrocarbons Q is calculated. f and concentration C f Obtain the mathematical model of buoyancy displacement;

[0029] The formulas for calculating the linear velocities of water and gas in the rock strata are as follows:

[0030]

[0031]

[0032] Among them, V g V represents the gas velocity; w K represents the rate of water flow; K represents the rock permeability; K g K represents the relative permeability of the gas. w Indicates the relative permeability of water; µ g Indicates gas viscosity; µ w Indicates the viscosity of water; Ф g Ф represents gas potential. g =P+ρgh;Ф w Indicates water potential, Ф w =P+ρgh; ▽ represents the gradient differential operator, which can calculate the gradient of variables in any of the X, Y, and Z directions, i.e.: ▽= V = Q / t, V = Sh, where Q is the gas flux, V is the volume of water or gas, S is the cross-sectional area, h is the height, and t is the time.

[0033] In one embodiment, the simulation content in the segmented simulation step based on the reservoir hydrocarbon micro-leakage mathematical model includes hydrocarbon concentration, hydrocarbon leakage rate, and leakage flux.

[0034] A geochemical forward modeling numerical simulation device based on a reservoir model includes:

[0035] The reservoir geological model acquisition module is used to acquire oil and gas geological data and seismic data to determine the reservoir geological model;

[0036] The mathematical model acquisition module is used to acquire diffusion mathematical models, water-soluble phase transport mathematical models, and buoyancy transport mathematical models;

[0037] The model coupling module is used to couple the diffusion mathematical model, the water-soluble phase transport mathematical model, and the buoyancy transport mathematical model based on the established reservoir geological model to establish a reservoir hydrocarbon micro-leakage mathematical model.

[0038] The segmented simulation module is used to perform segmented simulations based on the mathematical model of hydrocarbon micro-leakage in the reservoir.

[0039] A computer device includes a memory and a processor, the memory storing a computer program, characterized in that the processor executes the computer program to perform the following steps:

[0040] Acquire petroleum geological data and seismic data to determine reservoir geological models;

[0041] Obtain mathematical models for diffusion, water-soluble phase transport, and buoyancy transport;

[0042] Based on the established reservoir geological model, the diffusion mathematical model, the water-soluble phase transport mathematical model, and the buoyancy transport mathematical model are coupled to establish a reservoir hydrocarbon micro-leakage mathematical model;

[0043] Segmented simulations were performed based on the aforementioned mathematical model of hydrocarbon micro-leakage in the reservoir.

[0044] A computer-readable storage medium having a computer program stored thereon, the computer program performing the following steps when executed by a processor:

[0045] Acquire petroleum geological data and seismic data to determine reservoir geological models;

[0046] Obtain mathematical models for diffusion, water-soluble phase transport, and buoyancy transport;

[0047] Based on the established reservoir geological model, the diffusion mathematical model, the water-soluble phase transport mathematical model, and the buoyancy transport mathematical model are coupled to establish a reservoir hydrocarbon micro-leakage mathematical model;

[0048] Segmented simulations were performed based on the aforementioned mathematical model of hydrocarbon micro-leakage in the reservoir.

[0049] The aforementioned forward modeling numerical simulation method, apparatus, computer equipment, and storage medium for geochemical exploration effectively reflect the transformation of the three modes of micro-leakage and the changes in micro-leakage concentration under actual geological conditions. It takes into account the influence of various geological factors and can achieve numerical simulation and visualization effects of one-dimensional, two-dimensional, and three-dimensional stratigraphic space. It forward models the formation mechanism of oil and gas geochemical exploration and solidifies the theory of vertical micro-leakage of hydrocarbons. Attached Figure Description

[0050] Figure 1 This is a flowchart illustrating a geochemical forward modeling numerical simulation method based on a reservoir model in one embodiment.

[0051] Figure 2 This is a structural block diagram of a geochemical forward modeling numerical simulation device based on a reservoir model in one embodiment.

[0052] Figure 3 This is an internal structural diagram of a computer device in one embodiment;

[0053] Figure 4 This is a schematic diagram of the forward numerical simulation process for geochemical exploration based on a reservoir model in one embodiment. Detailed Implementation

[0054] To make the objectives, technical solutions, and advantages of this application clearer, the following detailed description is provided in conjunction with the accompanying drawings and embodiments. It should be understood that the specific embodiments described herein are merely illustrative and not intended to limit the scope of this application.

[0055] Example 1

[0056] A geochemical forward modeling numerical simulation method based on reservoir models is provided, such as... Figure 1 As shown, it includes:

[0057] Step 110: Obtain oil and gas geological data and seismic data to determine the reservoir geological model.

[0058] Specifically, based on oil and gas geology and seismic data, the known reservoir burial depth, oil and gas composition, caprock thickness, oil-bearing area, reservoir profile, and lithological profiles from multiple wells are identified, and the thickness of each sandstone and mudstone layer is statistically analyzed. Thus, the reservoir geological model is determined using the aforementioned geological and seismic data.

[0059] Step 120: Obtain the diffusion mathematical model, the water-soluble phase transport mathematical model, and the buoyancy transport mathematical model.

[0060] Step 130: Based on the established reservoir geological model, couple the diffusion mathematical model, the water-soluble phase transport mathematical model, and the buoyancy transport mathematical model to establish a reservoir hydrocarbon micro-leakage mathematical model.

[0061] In this embodiment, the established mathematical model for hydrocarbon micro-leakage in the reservoir includes a diffusion mathematical model, a water-soluble phase transport mathematical model, a buoyancy transport mathematical model, and a mathematical model coupling the three mechanisms.

[0062] A mathematical model of hydrocarbon micro-leakage in the reservoir was obtained. Based on the mathematical model, a corresponding computer calculation program was developed to calculate the concentration of hydrocarbon components in the reservoir through micro-leakage in the caprock, overlying strata, and Quaternary sedimentary layers.

[0063] To improve the accuracy of the model, in one embodiment, the step of coupling the diffusion mathematical model, the water-soluble phase transport mathematical model, and the buoyancy transport mathematical model based on the determined reservoir geological model to establish a reservoir hydrocarbon micro-leakage mathematical model includes: obtaining the formation physical adsorption amount, carbonate mineral chemical adsorption amount, and microbial degradation amount; and coupling the diffusion mathematical model, the water-soluble phase transport mathematical model, and the buoyancy transport mathematical model based on the determined reservoir geological model, and combining the formation physical adsorption amount, the carbonate mineral chemical adsorption amount, and the microbial degradation amount to establish a reservoir hydrocarbon micro-leakage mathematical model.

[0064] The reservoir hydrocarbon micro-leakage mathematical model in this embodiment includes a diffusion mathematical model, a water-soluble phase transport mathematical model, a buoyancy transport mathematical model, and a mathematical model coupling the three mechanisms, while simultaneously loading the physical adsorption amount of the formation, the chemical adsorption amount of carbonate minerals, and the consumption amount of surface microorganisms.

[0065] In one embodiment, the mathematical model for hydrocarbon micro-leakage in the reservoir is:

[0066] C=C k *α+C s *β+C f *γ-R1-R2-R3

[0067] Among them, C k C represents the concentration of hydrocarbons in microleakage due to diffusion. s C represents the concentration of hydrocarbons transported in the water-soluble phase. f R1 represents the concentration of hydrocarbons transported by buoyancy, R2 represents the total adsorption rate of hydrocarbons by formation particles, R3 represents the total adsorption rate of hydrocarbons by carbonate rocks, and R4 represents the degradation rate of hydrocarbons by microorganisms. α, β, and γ are contribution coefficients, where 0 ≤ α ≤ 1, 0 ≤ β ≤ 1, 0 ≤ γ ≤ 1, and α + β + γ = 1.

[0068] In one embodiment, the diffusion mathematical model is:

[0069] (1)

[0070] Where c is the concentration of any substance at any point in the rectangular coordinate system, in mg / L, and D is the diffusion coefficient in three directions, in m. 2 / s, where C in the diffusion mathematical model is set as the hydrocarbon concentration C of the micro-leakage caused by diffusion. k .

[0071] In one embodiment, the mathematical model for the transport of the water-soluble phase is:

[0072] (2)

[0073] The above calculation formula (2) is obtained by using the flux formed by the convection and dispersion of a single hydrocarbon molecule in the water-soluble phase (Bear, 1979), where q ci V represents the flux of hydrocarbon components; ε represents the water flow rate; D represents the water content; T C represents the total dispersion factor; i The concentration of water-soluble hydrocarbons is represented by ▽. In the mathematical model of water-soluble phase transport, ▽ represents the gradient change of total hydrocarbon concentration in two-dimensional rectangular coordinates (X, Z), i.e. ;

[0074] In the absence of chemical reactions and adsorption (or when adsorption sites are saturated), the mass balance equation for water-soluble hydrocarbons can be expressed as follows:

[0075] (3)

[0076] Substituting equation (2) into equation (3), we obtain the formula for the transport of hydrocarbon components in water, where q is q ci This represents the flux of hydrocarbon components. In the formula for transporting hydrocarbon components in water, C is set as the concentration of hydrocarbons transported in the water-soluble phase, C0. s .

[0077] In one embodiment, the step of obtaining the mathematical model of buoyancy transport is as follows: based on Darcy's law and the proportional relationship between the potential gradient of each phase, the linear velocity calculation formulas for water and gas in the rock strata are obtained; based on the linear velocity calculation formulas for water and gas in the rock strata, the amount of hydrocarbon Q is calculated. f and concentration C f The mathematical model of buoyancy motion is obtained.

[0078] It should be understood that, for both gases and water, Darcy's law is proportional to the potential gradient of each phase, and can be expressed as follows (according to Saeed, 1991):

[0079] The formulas for calculating the linear velocities of water and gas in rock strata are as follows:

[0080] (4)

[0081] (5)

[0082] Among them, K g K represents the relative permeability of the gas. w Indicates the relative permeability of water; µ g Indicates gas viscosity; µ w Indicates the viscosity of water; Ф g Ф represents gas potential. g =P+ρgh;Ф w Indicates water potential, Ф w =P+ρgh; ▽ represents the gradient differential operator, which can calculate the gradient of variables in any of the X, Y, and Z directions, i.e.: ▽= V = Q / t, V = Sh, Q is the gas flux, V is the volume of water or gas, S is the cross-sectional area, h is the height, and t is the time. Equations (4) and (5) represent the linear velocities of water and gas, respectively. For example, if the gas flux Q = V / t, for a cylinder, the volume V = Sh. Substituting this into the above flux equation, h / t is the linear velocity of water and gas, which is equal to Q / S. Due to the concentration C f Amount of hydrocarbons Q f Regarding, Qf It is related to linear velocity; therefore, the concentration C can be obtained. f It is also related to linear velocity.

[0083] The relative permeability of a gas depends on the saturation level of water. As water saturation decreases, gas saturation increases, and the relative permeability of the gas increases. Then, based on the oil and gas components and the saturation levels of gas and water, the amount of hydrocarbons Q can be calculated. f and concentration C f .

[0084] In addition to the three mathematical models for hydrocarbon microleakage mentioned above, the following factors and their mathematical models for the influence of hydrocarbon concentration in microleakage were also considered:

[0085] (a) Physical adsorption capacity of the formation:

[0086] The formation adsorption capacity V (cm³) was obtained by using an exponential adsorption model and data fitting. 3 The empirical formula for the relationship between / g) and formation pressure p (MPa) is as follows:

[0087] (6)

[0088] It should be understood that the above equation (6) only represents the total adsorption amount, without considering the adsorption rate. Therefore, the total adsorption rate R1 of a certain hydrocarbon by formation particles is related to the porosity, volumetric surface area, and lithology of the medium. It can be assumed to be proportional to the free hydrocarbon concentration c in the formation and proportional to the hydrocarbon concentration adsorbed on the surface of the formation particles. Inversely proportional, with a proportionality constant of - (The adsorption rate of the hydrocarbon per unit time and unit length (volume) is 1 / mt, the negative sign is because the concentration of the hydrocarbon decreases.) The adsorption process stops when the adsorption concentration approaches the adsorption capacity V. Let be the porosity of the formation medium, then:

[0089] R1=-k r ψc(VC r (7)

[0090] (II) The chemical adsorption of hydrocarbon components by carbonate minerals:

[0091] During the vertical micro-leaching of hydrocarbons, some hydrocarbons dissolve in water. The interaction between water and rock causes these hydrocarbons to enter the carbonate mineral lattice and exist in the formation in a chemisorbed state. Under the same temperature and pressure, the adsorption amounts in sandstone and mudstone exhibit a certain ratio. By obtaining the sandstone background under certain conditions, the acid hydrolysis hydrocarbon background in mudstone under the same conditions can be determined. To obtain the ratio of adsorbed hydrocarbons between sandstone and mudstone under the same conditions, the Freundlich formula was used to fit the literature data (Wang Zhenping et al., 1996):

[0092] , ,

[0093] , ,

[0094] , (8)

[0095] In the above formula (8) The values ​​represent the adsorption amounts (cm³) of methane, propane, and butane by sandstone and mudstone, respectively. 3 / 100g), p is the pressure (×133.3Pa), and the values ​​in each formula are regression coefficients.

[0096] According to the above formula, the ratio of the adsorption capacity of mudstone and sandstone for the same type of hydrocarbon can be obtained:

[0097]

[0098] (9)

[0099]

[0100] In equation (9) These represent the ratios of methane, propane, and butane adsorption amounts by mudstone and sandstone under the same conditions.

[0101] Therefore, the total adsorption rate R2 of carbonate rocks for a certain hydrocarbon can be assumed to be related to the concentration of free hydrocarbons c in the formation and the adsorption rate of the hydrocarbon in the carbonate rocks. The difference is directly proportional to - (The adsorption rate of the hydrocarbon by the carbonate rock per unit time and unit length (volume) is 1 / mt. The negative sign is because the concentration of the hydrocarbon decreases.) Let be the porosity of the formation medium, then:

[0102] R2=-ψk c c(QC c (10)

[0103] (III) The role of surface microorganisms:

[0104] Microbial activity (hydrocarbon oxidizing bacteria) is relatively strong in the surface oxidation zone, and the concentration of hydrocarbons decreases significantly when they migrate vertically; at the same time, microbial activity is greatly affected by climate. Therefore, in this invention, it is simply assumed that the degradation rate R3 of a certain hydrocarbon by microorganisms is a linear function of that hydrocarbon, that is:

[0105] R3=-ψk1c(11)

[0106] The negative sign is because the concentration of hydrocarbons has decreased. The consumption rate of the hydrocarbon by microorganisms per unit time and unit length (volume) is 1 / mt.

[0107] Therefore, after coupling the three mechanisms and considering the formation physical adsorption, carbonate mineral chemical adsorption, and microbial degradation, the hydrocarbon concentration C at any point in the coupled mathematical model can be expressed as:

[0108] C=C k *α+C s *β+C f *γ-R1-R2-R3

[0109] Where α (0≤α≤1), β (0≤β≤1), and γ (0≤γ≤1) are contribution coefficients, and α+β+γ=1

[0110] Step 140: Perform segmented simulation based on the mathematical model of hydrocarbon micro-leakage in the reservoir.

[0111] Specifically, segmented simulation is based on the fact that due to the different capping conditions and channel development of the overlying strata of oil and gas reservoirs, hydrocarbons will migrate vertically in different ways depending on the strata conditions. Dense (low porosity and permeability) rock strata without fractures will mainly migrate via diffusion, for example, by using diffusion migration equations; rock strata with high porosity and permeability will mainly migrate via water dissolution, for example, by using water dissolution migration equations; and rock strata with fractures will mainly migrate via microbubbles, for example, by using buoyancy migration equations.

[0112] Based on the aforementioned mathematical model, a computational program was developed that can not only numerically simulate single mechanisms of vertical micro-leaking of hydrocarbons, but also perform coupled numerical simulations of three mechanisms. The simulation method couples the mathematical models of diffusion, water dissolution, and microbubble mechanisms into a single model. Since the main hydrocarbon micro-leaking mechanisms may differ in different formations, the selection of contribution coefficients in the coupling equations may also vary. Segmented simulation is adopted for two reasons: First, it eliminates the influence of different main micro-leaking mechanisms, allowing for the simulation of any selected formation, with the final state of the next layer used as the initial state of the adjacent upper layer. Second, the software can use any measured point or simulated point (interpolation point) as an initial condition for simulation calculations.

[0113] This application also enables one-dimensional, two-dimensional, and three-dimensional simulation functions. Numerical simulation methods can perform one-dimensional, two-dimensional, and three-dimensional formation space simulations. The simulation content includes hydrocarbon concentration, hydrocarbon leakage rate, and leakage flux. Specifically, the simulation calculates the concentration levels at different times and distances based on mathematical models of different transport mechanisms, and then graphically represents these concentration changes.

[0114] Furthermore, this application also features simulation result visualization capabilities. The numerical simulation method not only provides numerical results but also visualizes them: ① One-dimensional simulation: distribution maps of hydrocarbon component concentrations or ratios in the strata or surface soil at any time point, and a map showing the change in concentration or ratio at a specific point in the strata over time; ② Two-dimensional simulation: distribution maps of hydrocarbon component concentrations or ratios on a vertical profile or plane at any time point, and a map showing the change in concentration or ratio at a specific point in the strata over time; ③ Three-dimensional simulation: concentration maps or ratio maps of any line, section, or volume, displayed as isosurfaces, and a map showing the change in concentration or ratio at a specific point in the spatial strata over time. The advantage of displaying three-dimensional isosurfaces is that it allows visualization of the dominant channels in three-dimensional space; the three-dimensional display of two-dimensional planar data can only show the distribution of dominant channels on the plane.

[0115] In one embodiment, the simulation content in the segmented simulation step based on the reservoir hydrocarbon micro-leakage mathematical model includes hydrocarbon concentration, hydrocarbon leakage rate, and leakage flux.

[0116] Example 2

[0117] In this embodiment, please refer to Figure 4 This paper provides a geochemical forward modeling numerical simulation method based on a reservoir model, including:

[0118] Step 1: Determine the geological model of the known oil reservoir.

[0119] Based on oil and gas geology and seismic data, the known reservoir burial depth, oil and gas composition, caprock thickness, oil-bearing area, reservoir profile, and lithological profiles of multiple wells are identified, and the thickness of each sandstone and mudstone layer is statistically analyzed.

[0120] Step 2: Establish a mathematical model for hydrocarbon micro-leakage in the reservoir, including a diffusion mathematical model, a water-soluble phase transport mathematical model, a buoyancy transport mathematical model, and a mathematical model coupling the three mechanisms.

[0121] In this embodiment, each mathematical model can simultaneously load the physical adsorption capacity of the formation, the chemical adsorption capacity of carbonate minerals, and the consumption capacity of surface microorganisms. Based on the mathematical model, a corresponding computer calculation program is developed to calculate the concentration of oil and gas components in the reservoir through the caprock, overlying strata, and Quaternary sedimentary layers via micro-seepage.

[0122] Diffusion obeys Fick's law, which, in a rectangular coordinate system, is expressed as:

[0123] (1)

[0124] Where c is the concentration of any substance at any point in the rectangular coordinate system, in mg / L, and D is the diffusion coefficient in three directions, in m. 2 / s.

[0125] Let the concentration of hydrocarbons in the diffusion-induced microleakage be C. k .

[0126] The flux of a single hydrocarbon molecule in the water-soluble phase due to convection and dispersion can be calculated using the following formula (Bear, 1979):

[0127] (2)

[0128] In the formula, q ci V represents the flux of hydrocarbon components; ε represents the water flow rate; D represents the water content; T C represents the total dispersion factor; i The concentration of water-soluble hydrocarbons is represented by ▽. In the mathematical model of water-soluble phase transport, ▽ represents the gradient change of total hydrocarbon concentration in two-dimensional rectangular coordinates (X, Z), i.e. .

[0129] In the absence of chemical reactions and adsorption (or when adsorption sites are saturated), the mass balance equation for water-soluble hydrocarbons can be expressed as follows:

[0130] Substituting equation (2) into equation (3), we obtain the following formula for the transport of hydrocarbon components in water:

[0131] (3)

[0132] q is q ci This represents the flux of hydrocarbon components. In the formula for transporting hydrocarbon components in water, C is set as the concentration of hydrocarbons transported in the water-soluble phase, C0. s .

[0133] For buoyant transport, whether for gases or water, Darcy's law is proportional to the potential gradient of each phase and can be expressed as follows (according to Saeed, 1991):

[0134] (4)

[0135] (5)

[0136] Where V g V represents the gas velocity; w K represents the rate of water flow; K represents the rock permeability; K g K represents the relative permeability of the gas. w Indicates the relative permeability of water; µ g Indicates gas viscosity; µ w Indicates the viscosity of water; Ф g Ф represents gas potential. g =P+ρgh;Ф w Indicates water potential, Ф w=P+ρgh; ▽ represents the gradient differential operator, which can calculate the gradient of variables in any of the X, Y, and Z directions, i.e.: ▽= The relative permeability of a gas depends on the saturation level of water. As water saturation decreases, gas saturation increases, and the relative permeability of the gas increases. Then, based on the oil and gas components and the saturation levels of gas and water, the amount of hydrocarbons Q can be calculated. f and concentration C f。

[0137] In addition to the three mathematical models for hydrocarbon microleakage mentioned above, the following factors and their mathematical models for the influence of hydrocarbon concentration in microleakage were also considered:

[0138] (a) Physical adsorption capacity of the formation:

[0139] The formation adsorption capacity V (cm³) was obtained by using an exponential adsorption model and data fitting. 3 The empirical formula for the relationship between / g) and formation pressure p (MPa) is as follows:

[0140] (6)

[0141] It should be noted that the above formula only represents the total adsorption amount and does not consider the adsorption rate. Therefore, the total adsorption rate R1 of a certain hydrocarbon by formation particles is related to the porosity, volumetric surface area, and lithology of the medium. It can be assumed to be directly proportional to the concentration of free hydrocarbons c in the formation and to the concentration of hydrocarbons adsorbed on the surface of the formation particles. Inversely proportional, with a proportionality constant of - (The adsorption rate of the hydrocarbon per unit time and unit length (volume) is 1 / mt, the negative sign is because the concentration of the hydrocarbon decreases.) The adsorption process stops when the adsorption concentration approaches the adsorption capacity V. Let be the porosity of the formation medium, then:

[0142] R1=-k r ψc(VC r (7)

[0143] (II) The chemical adsorption of hydrocarbon components by carbonate minerals:

[0144] During the vertical micro-leaching of hydrocarbons, some hydrocarbons dissolve in water. The interaction between water and rock causes these hydrocarbons to enter the carbonate mineral lattice and exist in the formation in a chemisorbed state. Under the same temperature and pressure, the adsorption amounts in sandstone and mudstone exhibit a certain ratio. By obtaining the sandstone background under certain conditions, the acid hydrolysis hydrocarbon background in mudstone under the same conditions can be determined. To obtain the ratio of adsorbed hydrocarbons between sandstone and mudstone under the same conditions, the Freundlich formula was used to fit the literature data (Wang Zhenping et al., 1996):

[0145]

[0146] (8)

[0147]

[0148] In the above formulas The values ​​represent the adsorption amounts (cm³) of methane, propane, and butane by sandstone and mudstone, respectively. 3 ( / 100g) The pressure is (×133.3 Pa), and the values ​​in each formula are regression coefficients.

[0149] According to the above formula, the ratio of the adsorption capacity of mudstone and sandstone for the same type of hydrocarbon can be obtained:

[0150]

[0151] (9)

[0152]

[0153] In the formula These represent the ratios of methane, propane, and butane adsorption amounts by mudstone and sandstone under the same conditions.

[0154] Therefore, the total adsorption rate R2 of a certain hydrocarbon in carbonate rocks can be assumed to be related to the concentration of free hydrocarbons c in the formation and the concentration of hydrocarbons adsorbed in the carbonate rocks. The difference is directly proportional to - (The adsorption rate of the hydrocarbon by the carbonate rock per unit time and unit length (volume) is 1 / mt. The negative sign is because the concentration of the hydrocarbon decreases.) Let be the porosity of the formation medium, then:

[0155] R2=-ψk c c(QC c (10)

[0156] (III) The role of surface microorganisms:

[0157] Microbial activity (hydrocarbon oxidizing bacteria) is relatively strong in the surface oxidation zone, and the concentration of hydrocarbons decreases significantly when they migrate vertically; at the same time, microbial activity is greatly affected by climate. Therefore, in this invention, it is simply assumed that the degradation rate R3 of a certain hydrocarbon by microorganisms is a linear function of that hydrocarbon, that is:

[0158] R3=-ψk1c (11)

[0159] The negative sign is because the concentration of hydrocarbons has decreased. The rate at which microorganisms consume the hydrocarbon per unit time and unit length (volume), 1 / mt .

[0160] Therefore, after coupling the three mechanisms and considering the formation physical adsorption, carbonate mineral chemical adsorption, and microbial degradation, the hydrocarbon concentration C at any point in the coupled mathematical model can be expressed as:

[0161] C=C k *α+C s *β+C f *γ-R1-R2-R3

[0162] Where α (0≤α≤1), β (0≤β≤1), and γ (0≤γ≤1) are contribution coefficients, and α+β+γ=1

[0163] Step 3: Segmented simulation.

[0164] In this step, a calculation program is developed based on the aforementioned mathematical model. This program can not only perform numerical simulations of a single mechanism of vertical hydrocarbon micro-leaking, but also perform coupled numerical simulations of three mechanisms. The simulation method couples the mathematical models of diffusion, water dissolution, and microbubble mechanisms into a single model. Since the main hydrocarbon micro-leaking mechanisms may differ in different formations, the selection of contribution coefficients in the coupling equations may also vary. Segmented simulation is adopted for two reasons: First, it eliminates the influence of different main micro-leaking mechanisms, allowing any formation to be selected for simulation, with the final state of the next layer used as the initial state of the adjacent upper layer. Second, the software can use any measured point or simulated point (interpolation point) as an initial condition for simulation calculations.

[0165] Example 3

[0166] A geochemical forward modeling numerical simulation device based on a reservoir model is provided, such as... Figure 2 As shown, it includes:

[0167] The reservoir geological model acquisition module 210 is used to acquire oil and gas geological data and seismic data to determine the reservoir geological model.

[0168] The mathematical model acquisition module is used to acquire diffusion mathematical models, water-soluble phase transport mathematical models, and buoyancy transport mathematical models 220;

[0169] The model coupling module 230 is used to couple the diffusion mathematical model, the water-soluble phase transport mathematical model and the buoyancy transport mathematical model based on the determined reservoir geological model to establish a reservoir hydrocarbon micro-leakage mathematical model.

[0170] The segmented simulation module 240 is used to perform segmented simulations based on the mathematical model of hydrocarbon micro-leakage in the reservoir.

[0171] In one embodiment, the model coupling module includes:

[0172] Additional quantity acquisition unit is used to acquire the physical adsorption amount of the formation, the chemical adsorption amount of carbonate minerals, and the microbial degradation amount;

[0173] The model building unit is used to couple the diffusion mathematical model, the water-soluble phase transport mathematical model, and the buoyancy transport mathematical model based on the established reservoir geological model, and combine the formation physical adsorption amount, the carbonate mineral chemical adsorption amount, and the microbial degradation amount to establish a reservoir hydrocarbon micro-leakage mathematical model.

[0174] In one embodiment, the mathematical model for hydrocarbon micro-leakage in the reservoir is:

[0175] C=C k *α+C s *β+C f *γ-R1-R2-R3

[0176] Among them, C k C represents the concentration of hydrocarbons in microleakage due to diffusion. s C represents the concentration of hydrocarbons transported in the water-soluble phase. f R1 represents the concentration of hydrocarbons transported by buoyancy, R2 represents the total adsorption rate of hydrocarbons by formation particles, R3 represents the total adsorption rate of hydrocarbons by carbonate rocks, and R4 represents the degradation rate of hydrocarbons by microorganisms. α, β, and γ are contribution coefficients, where 0 ≤ α ≤ 1, 0 ≤ β ≤ 1, 0 ≤ γ ≤ 1, and α + β + γ = 1.

[0177] In one embodiment, the diffusion mathematical model is:

[0178]

[0179] Where c is the concentration of any substance at any point in the rectangular coordinate system, and D is the diffusion coefficient in three directions, with units of m. 2 / s, where C in the diffusion mathematical model is set as the hydrocarbon concentration C of the micro-leakage caused by diffusion. k .

[0180] In one embodiment, the mathematical model for the transport of the water-soluble phase is:

[0181]

[0182] Where, q ci V represents the flux of hydrocarbon components; ε represents the water flow rate; D represents the water content; T C represents the total dispersion factor; iThe concentration of water-soluble hydrocarbons is represented by ▽. In the mathematical model of water-soluble phase transport, ▽ represents the gradient change of total hydrocarbon concentration in two-dimensional rectangular coordinates (X, Z), i.e. ;

[0183] The formula for transporting hydrocarbon components in water is:

[0184]

[0185] Where q is q ci This represents the flux of hydrocarbon components. In the formula for transporting hydrocarbon components in water, C is set as the concentration of hydrocarbons transported in the water-soluble phase, C0. s .

[0186] In one embodiment, the step of obtaining the buoyancy displacement mathematical model is as follows:

[0187] Based on Darcy's law, which is proportional to the potential gradient of each phase, we obtain the formula for calculating the linear velocity of water and gas in rock strata.

[0188] Based on the formula for calculating the linear velocities of water and gas in rock strata, the amount of hydrocarbons Q is calculated. f and concentration C f Obtain the mathematical model of buoyancy displacement;

[0189] The formulas for calculating the linear velocities of water and gas in the rock strata are as follows:

[0190]

[0191]

[0192] Among them, V g V represents the gas velocity; w K represents the rate of water flow; K represents the rock permeability; K g K represents the relative permeability of the gas. w Indicates the relative permeability of water; µ g Indicates gas viscosity; µ w Indicates the viscosity of water; Ф g Ф represents gas potential. g =P+ρgh;Ф w Indicates water potential, Ф w =P+ρgh; ▽ represents the gradient differential operator, which can calculate the gradient of variables in any of the X, Y, and Z directions, i.e.: ▽= V = Q / t, V = Sh, where Q is the gas flux, V is the volume of water or gas, S is the cross-sectional area, h is the height, and t is the time.

[0193] In one embodiment, the simulation content in the segmented simulation step based on the reservoir hydrocarbon micro-leakage mathematical model includes hydrocarbon concentration, hydrocarbon leakage rate, and leakage flux.

[0194] Specific limitations regarding the geochemical forward modeling numerical simulation apparatus can be found in the limitations of the geochemical forward modeling numerical simulation method described above, and will not be repeated here. Each module in the aforementioned geochemical forward modeling numerical simulation apparatus can be implemented entirely or partially through software, hardware, or a combination thereof. These modules can be embedded in or independent of the processor in a computer device, or stored in the memory of a computer device as software, so that the processor can call and execute the corresponding operations of each module.

[0195] Example 4

[0196] The computer equipment provided has an internal structure diagram that can be shown as follows: Figure 3 As shown, the computer device includes a processor, memory, network interface, display screen, and input devices connected via a system bus. The processor provides computational and control capabilities. The memory includes non-volatile storage media and internal memory. The non-volatile storage media stores the operating system and computer programs. The internal memory provides an environment for the operation of the operating system and computer programs stored in the non-volatile storage media. The network interface is used for communication with other computer devices. When the computer program is executed by the processor, it implements a geochemical forward modeling numerical simulation method. The display screen can be an LCD screen or an e-ink screen. The input devices can be a touch layer covering the display screen, buttons, a trackball, or a touchpad on the computer device's casing, or an external keyboard, touchpad, or mouse.

[0197] Those skilled in the art will understand that Figure 3 The structure shown is merely a block diagram of a portion of the structure related to the present application and does not constitute a limitation on the computer device to which the present application is applied. Specific computer devices may include more or fewer components than those shown in the figure, or combine certain components, or have different component arrangements.

[0198] Example 5

[0199] A computer device is provided, including a memory and a processor, the memory storing a computer program, the processor executing the computer program to perform the following steps:

[0200] Acquire petroleum geological data and seismic data to determine reservoir geological models;

[0201] Obtain mathematical models for diffusion, water-soluble phase transport, and buoyancy transport;

[0202] Based on the established reservoir geological model, the diffusion mathematical model, the water-soluble phase transport mathematical model, and the buoyancy transport mathematical model are coupled to establish a reservoir hydrocarbon micro-leakage mathematical model;

[0203] Segmented simulations were performed based on the aforementioned mathematical model of hydrocarbon micro-leakage in the reservoir.

[0204] In one embodiment, the processor, when executing a computer program, also performs the following steps:

[0205] To obtain the physical adsorption capacity of the formation, the chemical adsorption capacity of carbonate minerals, and the microbial degradation capacity;

[0206] Based on the established reservoir geological model, the diffusion mathematical model, the water-soluble phase transport mathematical model, and the buoyancy transport mathematical model are coupled together, and combined with the formation physical adsorption amount, the carbonate mineral chemical adsorption amount, and the microbial degradation amount, to establish a reservoir hydrocarbon micro-leakage mathematical model.

[0207] In one embodiment, when the processor executes the computer program, it further performs the following steps: obtaining a mathematical model of hydrocarbon micro-leakage in the reservoir, wherein the mathematical model of hydrocarbon micro-leakage in the reservoir is:

[0208] C=C k *α+C s *β+C f *γ-R1-R2-R3

[0209] Among them, C k C represents the concentration of hydrocarbons in microleakage due to diffusion. s C represents the concentration of hydrocarbons transported in the water-soluble phase. f R1 represents the concentration of hydrocarbons transported by buoyancy, R2 represents the total adsorption rate of hydrocarbons by formation particles, R3 represents the total adsorption rate of hydrocarbons by carbonate rocks, and R4 represents the degradation rate of hydrocarbons by microorganisms. α, β, and γ are contribution coefficients, where 0 ≤ α ≤ 1, 0 ≤ β ≤ 1, 0 ≤ γ ≤ 1, and α + β + γ = 1.

[0210] In one embodiment, when the processor executes the computer program, it further performs the following steps: obtaining a diffusion mathematical model, wherein the diffusion mathematical model is:

[0211]

[0212] Where c is the concentration of any substance at any point in the rectangular coordinate system, and D is the diffusion coefficient in three directions, with units of m. 2 / s, where C in the diffusion mathematical model is set as the hydrocarbon concentration C of the micro-leakage caused by diffusion. k .

[0213] In one embodiment, when the processor executes the computer program, it further performs the following steps: obtaining a mathematical model of water-soluble phase transport, wherein the mathematical model of water-soluble phase transport is:

[0214]

[0215] Where, q ci V represents the flux of hydrocarbon components; ε represents the water flow rate; D represents the water content; T C represents the total dispersion factor; i The concentration of water-soluble hydrocarbons is represented by ▽. In the mathematical model of water-soluble phase transport, ▽ represents the gradient change of total hydrocarbon concentration in two-dimensional rectangular coordinates (X, Z), i.e. ;

[0216] The formula for transporting hydrocarbon components in water is:

[0217]

[0218] Where q is q ci This represents the flux of hydrocarbon components. In the formula for transporting hydrocarbon components in water, C is set as the concentration of hydrocarbons transported in the water-soluble phase, C0. s .

[0219] In one embodiment, the processor, when executing a computer program, also performs the following steps:

[0220] Based on Darcy's law, which is proportional to the potential gradient of each phase, we obtain the formula for calculating the linear velocity of water and gas in rock strata.

[0221] Based on the formula for calculating the linear velocities of water and gas in rock strata, the amount of hydrocarbons Q is calculated. f and concentration C f Obtain the mathematical model of buoyancy displacement;

[0222] The formulas for calculating the linear velocities of water and gas in the rock strata are as follows:

[0223]

[0224]

[0225] Among them, V g V represents the gas velocity; w K represents the rate of water flow; K represents the rock permeability; K g K represents the relative permeability of the gas. w Indicates the relative permeability of water; µ g Indicates gas viscosity; µ w Indicates the viscosity of water; Ф g Ф represents gas potential. g =P+ρgh;Ф wIndicates water potential, Ф w =P+ρgh; ▽ represents the gradient differential operator, which can calculate the gradient of variables in any of the X, Y, and Z directions, i.e.: ▽= V = Q / t, V = Sh, where Q is the gas flux, V is the volume of water or gas, S is the cross-sectional area, h is the height, and t is the time.

[0226] Example 6

[0227] A computer-readable storage medium is provided on which a computer program is stored, the computer program performing the following steps when executed by a processor:

[0228] Acquire petroleum geological data and seismic data to determine reservoir geological models;

[0229] Obtain mathematical models for diffusion, water-soluble phase transport, and buoyancy transport;

[0230] Based on the established reservoir geological model, the diffusion mathematical model, the water-soluble phase transport mathematical model, and the buoyancy transport mathematical model are coupled to establish a reservoir hydrocarbon micro-leakage mathematical model;

[0231] Segmented simulations were performed based on the aforementioned mathematical model of hydrocarbon micro-leakage in the reservoir.

[0232] In one embodiment, when the computer program is executed by a processor, it also performs the following steps:

[0233] To obtain the physical adsorption capacity of the formation, the chemical adsorption capacity of carbonate minerals, and the microbial degradation capacity;

[0234] Based on the established reservoir geological model, the diffusion mathematical model, the water-soluble phase transport mathematical model, and the buoyancy transport mathematical model are coupled together, and combined with the formation physical adsorption amount, the carbonate mineral chemical adsorption amount, and the microbial degradation amount, to establish a reservoir hydrocarbon micro-leakage mathematical model.

[0235] In one embodiment, when the computer program is executed by the processor, it further performs the following steps: obtaining a mathematical model of hydrocarbon micro-leakage in the reservoir, wherein the mathematical model of hydrocarbon micro-leakage in the reservoir is:

[0236] C=C k *α+C s *β+C f *γ-R1-R2-R3

[0237] Among them, C k C represents the concentration of hydrocarbons in microleakage due to diffusion. s C represents the concentration of hydrocarbons transported in the water-soluble phase. fR1 represents the concentration of hydrocarbons transported by buoyancy, R2 represents the total adsorption rate of hydrocarbons by formation particles, R3 represents the total adsorption rate of hydrocarbons by carbonate rocks, and R4 represents the degradation rate of hydrocarbons by microorganisms. α, β, and γ are contribution coefficients, where 0 ≤ α ≤ 1, 0 ≤ β ≤ 1, 0 ≤ γ ≤ 1, and α + β + γ = 1.

[0238] In one embodiment, when the computer program is executed by a processor, it further performs the following steps: obtaining a diffusion mathematical model, wherein the diffusion mathematical model is:

[0239]

[0240] Where c is the concentration of any substance at any point in the rectangular coordinate system, and D is the diffusion coefficient in three directions, with units of m. 2 / s, where C in the diffusion mathematical model is set as the hydrocarbon concentration C of the micro-leakage caused by diffusion. k .

[0241] In one embodiment, when the computer program is executed by a processor, it further performs the following steps: obtaining a mathematical model of water-soluble phase transport, wherein the mathematical model of water-soluble phase transport is:

[0242]

[0243] Where, q ci V represents the flux of hydrocarbon components; ε represents the water flow rate; D represents the water content; T C represents the total dispersion factor; i The concentration of water-soluble hydrocarbons is represented by ▽. In the mathematical model of water-soluble phase transport, ▽ represents the gradient change of total hydrocarbon concentration in two-dimensional rectangular coordinates (X, Z), i.e. ;

[0244] The formula for transporting hydrocarbon components in water is:

[0245]

[0246] Where q is q ci This represents the flux of hydrocarbon components. In the formula for transporting hydrocarbon components in water, C is set as the concentration of hydrocarbons transported in the water-soluble phase, C0. s .

[0247] In one embodiment, when the computer program is executed by a processor, it also performs the following steps:

[0248] Based on Darcy's law, which is proportional to the potential gradient of each phase, we obtain the formula for calculating the linear velocity of water and gas in rock strata.

[0249] Based on the formula for calculating the linear velocities of water and gas in rock strata, the amount of hydrocarbons Q is calculated. f and concentration C fObtain the mathematical model of buoyancy displacement;

[0250] The formulas for calculating the linear velocities of water and gas in the rock strata are as follows:

[0251]

[0252]

[0253] Among them, V g V represents the gas velocity; w K represents the rate of water flow; K represents the rock permeability; K g K represents the relative permeability of the gas. w Indicates the relative permeability of water; µ g Indicates gas viscosity; µ w Indicates the viscosity of water; Ф g Ф represents gas potential. g =P+ρgh;Ф w Indicates water potential, Ф w =P+ρgh; ▽ represents the gradient differential operator, which can calculate the gradient of variables in any of the X, Y, and Z directions, i.e.: ▽= V = Q / t, V = Sh, where Q is the gas flux, V is the volume of water or gas, S is the cross-sectional area, h is the height, and t is the time.

[0254] 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 computer program can be stored in a non-volatile computer-readable storage medium. When executed, the computer program can include the processes of the embodiments of the above methods. Any references to memory, storage, databases, or other media used in the embodiments provided in this application can include non-volatile and / or volatile memory. Non-volatile memory can include read-only memory (ROM), programmable ROM (PROM), electrically programmable ROM (EPROM), electrically erasable programmable ROM (EEPROM), or flash memory. Volatile memory can include random access memory (RAM) or external cache memory. By way of illustration and not limitation, RAM is available in various forms, such as static RAM (SRAM), dynamic RAM (DRAM), synchronous DRAM (SDRAM), dual data rate SDRAM (DDRSDRAM), enhanced SDRAM (ESDRAM), Synchlink, DRAM (SLDRAM), RAMbus direct RAM (RDRAM), direct memory bus dynamic RAM (DRDRAM), and RAMbus dynamic RAM (RDRAM), etc.

[0255] The technical features of the above embodiments can be combined in any way. For the sake of brevity, not all possible combinations of the technical features in the above embodiments are described. However, as long as there is no contradiction in the combination of these technical features, they should be considered to be within the scope of this specification.

[0256] The embodiments described above are merely illustrative of several implementation methods of this application, and while the descriptions are relatively specific and detailed, they should not be construed as limiting the scope of the invention patent. It should be noted that those skilled in the art can make various modifications and improvements without departing from the concept of this application, and these all fall within the protection scope of this application. Therefore, the protection scope of this patent application should be determined by the appended claims.

Claims

1. A geochemical forward modeling numerical simulation method based on a reservoir model, characterized in that, include: Acquire petroleum geological data and seismic data to determine reservoir geological models; Obtain mathematical models for diffusion, water-soluble phase transport, and buoyancy transport; Based on the established reservoir geological model, the diffusion mathematical model, the water-soluble phase transport mathematical model, and the buoyancy transport mathematical model are coupled to establish a reservoir hydrocarbon micro-leakage mathematical model; A segmented simulation was performed based on the aforementioned reservoir hydrocarbon micro-leakage mathematical model; the simulation included hydrocarbon concentration, hydrocarbon leakage rate, and leakage flux. The steps for establishing a reservoir hydrocarbon micro-permeability mathematical model by coupling the diffusion mathematical model, the water-soluble phase transport mathematical model, and the buoyancy transport mathematical model based on the established reservoir geological model include: To obtain the physical adsorption capacity of the formation, the chemical adsorption capacity of carbonate minerals, and the microbial degradation capacity; Based on the established reservoir geological model, the diffusion mathematical model, the water-soluble phase transport mathematical model, and the buoyancy transport mathematical model are coupled together, and combined with the formation physical adsorption amount, the carbonate mineral chemical adsorption amount, and the microbial degradation amount, a reservoir hydrocarbon micro-leakage mathematical model is established. The mathematical model for hydrocarbon micro-leakage in the reservoir is as follows: C=C k *α+C s *β+C f *γ-R1-R2-R3 Among them, C k C represents the concentration of hydrocarbons in microleakage due to diffusion. s C represents the concentration of hydrocarbons transported in the water-soluble phase. f R1 represents the concentration of hydrocarbons transported by buoyancy, R2 represents the total adsorption rate of hydrocarbons by formation particles, R3 represents the total adsorption rate of hydrocarbons by carbonate rocks, and R4 represents the degradation rate of hydrocarbons by microorganisms. α, β, and γ are contribution coefficients, where 0 ≤ α ≤ 1, 0 ≤ β ≤ 1, 0 ≤ γ ≤ 1, and α + β + γ = 1.

2. The method according to claim 1, characterized in that, The diffusion mathematical model is as follows: Where c is the concentration of any substance at any point in the rectangular coordinate system, and D is the diffusion coefficient in three directions, with units of m. 2 / s, where c in the diffusion mathematical model is set as the hydrocarbon concentration C of the micro-leakage caused by diffusion. k .

3. The method according to claim 1, characterized in that, The mathematical model for the transport of the water-soluble phase is as follows: Where, q ci V represents the flux of hydrocarbon components; ε represents the water flow rate; D represents the water content; T C represents the total dispersion factor; i ∠ represents the concentration of water-soluble hydrocarbons, ▽ represents the gradient differential operator, and in the mathematical model of water-soluble phase transport, ∠ represents the gradient change of the total hydrocarbon concentration in two-dimensional rectangular coordinates (X, Z), i.e. ; The formula for transporting hydrocarbon components in water is: Where q is q ci This represents the flux of hydrocarbon components. In the formula for transporting hydrocarbon components in water, C is set as the concentration of hydrocarbons transported in the water-soluble phase, C0. s .

4. The method according to claim 1, characterized in that, The steps to obtain the mathematical model of buoyancy motion are as follows: Based on Darcy's law, which is proportional to the potential gradient of each phase, we obtain the formula for calculating the linear velocity of water and gas in rock strata. Based on the formula for calculating the linear velocity of water and gas in rock strata, the amount of hydrocarbon Qf and concentration Cf are calculated, and the mathematical model of buoyancy transport is obtained. The formulas for calculating the linear velocities of water and gas in the rock strata are as follows: Among them, V g V represents the gas velocity; w K represents the rate of water flow; K represents the rock permeability; K g K represents the relative permeability of the gas. w Indicates the relative permeability of water; µ g Indicates gas viscosity; µ w Indicates the viscosity of water; Ф g Ф represents gas potential. g =P+ρgh;Ф w Indicates water potential, Ф w =P+ρgh; ▽ represents the gradient differential operator, which calculates the gradient of the variable in any of the X, Y, and Z directions, i.e.: ▽= V = Q / t, V = Sh, where Q is the gas flux, V is the volume of water or gas, S is the cross-sectional area, h is the height, and t is the time.

5. A geochemical forward modeling numerical simulation device based on a reservoir model, characterized in that, include: The reservoir geological model acquisition module is used to acquire oil and gas geological data and seismic data to determine the reservoir geological model; The mathematical model acquisition module is used to acquire diffusion mathematical models, water-soluble phase transport mathematical models, and buoyancy transport mathematical models; The model coupling module is used to couple the diffusion mathematical model, the water-soluble phase transport mathematical model, and the buoyancy transport mathematical model based on the established reservoir geological model to establish a reservoir hydrocarbon micro-leakage mathematical model. The segmented simulation module is used to perform segmented simulations based on the reservoir hydrocarbon micro-leakage mathematical model. The simulation included hydrocarbon concentration, hydrocarbon leakage rate, and leakage flux; The model coupling module includes: Additional quantity acquisition unit is used to acquire the physical adsorption amount of the formation, the chemical adsorption amount of carbonate minerals, and the microbial degradation amount; The model building unit is used to couple the diffusion mathematical model, the water-soluble phase transport mathematical model, and the buoyancy transport mathematical model based on the established reservoir geological model, and combine the formation physical adsorption amount, the carbonate mineral chemical adsorption amount, and the microbial degradation amount to establish a reservoir hydrocarbon micro-leakage mathematical model. The mathematical model for hydrocarbon micro-leakage in the reservoir is as follows: C=C k *α+C s *β+C f *γ-R1-R2-R3 Among them, C k C represents the concentration of hydrocarbons in microleakage due to diffusion. s C represents the concentration of hydrocarbons transported in the water-soluble phase. f R1 represents the concentration of hydrocarbons transported by buoyancy, R2 represents the total adsorption rate of hydrocarbons by formation particles, R3 represents the total adsorption rate of hydrocarbons by carbonate rocks, and R4 represents the degradation rate of hydrocarbons by microorganisms. α, β, and γ are contribution coefficients, where 0 ≤ α ≤ 1, 0 ≤ β ≤ 1, 0 ≤ γ ≤ 1, and α + β + γ = 1.

6. A computer device comprising a memory and a processor, wherein the memory stores a computer program, characterized in that, When the processor executes the computer program, it implements the steps of the method according to any one of claims 1 to 4.

7. A computer-readable storage medium having a computer program stored thereon, characterized in that, When the computer program is executed by a processor, it implements the steps of the method according to any one of claims 1 to 4.

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