CN-114117947-B - Method, device, computer equipment and storage medium for simulating forward performance of chemical detection

CN114117947BCN 114117947 BCN114117947 BCN 114117947BCN-114117947-B

Abstract

The invention provides a method, a device, computer equipment and a storage medium for simulating a chemical detection forward modeling, wherein the method comprises the steps of obtaining oil-gas geological data and seismic data and determining an oil reservoir geological model; the method comprises the steps of obtaining a diffusion mathematical model, a water-soluble phase migration mathematical model and a buoyancy migration mathematical model, coupling the diffusion mathematical model, the water-soluble phase migration mathematical model and the buoyancy migration mathematical model based on the determined oil reservoir geological model, establishing an oil reservoir hydrocarbon micro-seepage mathematical model, and carrying out sectional simulation based on the oil reservoir hydrocarbon micro-seepage mathematical model. The three modes of transformation of micro leakage and the change of the micro leakage concentration under the actual geological conditions are reflected well by adopting a numerical simulation method, the influence of various geological factors is considered, the numerical simulation of one-dimensional, two-dimensional and three-dimensional stratum space and the visual effect thereof can be realized, the formation mechanism of oil-gas chemical exploration is forward developed, and the vertical micro leakage theory of hydrocarbons is compacted.

Inventors

WANG GUOJIAN
ZHAO KEBIN
BAO ZHENGYU
YANG JUN
YANG RUIYAN
LI WU
LU LI

Assignees

中国石油化工股份有限公司
中国石油化工股份有限公司石油勘探开发研究院

Dates

Publication Date: 20260508
Application Date: 20200828

Claims (7)

1. The utility model provides a sounding forward modeling method based on an oil reservoir model, which is characterized by comprising the following steps: acquiring oil gas geological data and seismic data, and determining an oil reservoir geological model; Acquiring a diffusion mathematical model, a water-soluble phase migration mathematical model and a buoyancy migration mathematical model; Based on the determined oil reservoir geological model, coupling the diffusion mathematical model, the water-soluble phase migration mathematical model and the buoyancy migration mathematical model, and establishing an oil reservoir hydrocarbon micro-seepage mathematical model; performing segment simulation based on the oil reservoir hydrocarbon micro-seepage mathematical model, wherein the simulation content comprises hydrocarbon concentration, hydrocarbon seepage rate and seepage flux; The step of establishing a mathematical model of oil reservoir hydrocarbon microleakage based on the determined oil reservoir geologic model, coupling the diffusion mathematical model, the water-soluble phase migration mathematical model and the buoyancy migration mathematical model, comprises the following steps: acquiring physical adsorption quantity of stratum, chemical adsorption quantity of carbonate minerals and microbial degradation quantity; based on the determined reservoir geological model, coupling the diffusion mathematical model, the water-soluble phase migration mathematical model and the buoyancy migration mathematical model, and establishing a reservoir hydrocarbon micro-seepage mathematical model by combining the physical adsorption quantity of the stratum, the chemical adsorption quantity of the carbonate mineral and the microbial degradation quantity; The mathematical model of the oil reservoir hydrocarbon micro-leakage is as follows: C=C k *α+C s *β+C f *γ-R 1 -R 2 -R 3 Wherein, C k is the hydrocarbon concentration of micro leakage of diffusion, C s is the hydrocarbon concentration of water-soluble phase migration, C f is the hydrocarbon concentration of buoyancy migration, R 1 is the total adsorption rate of stratum particles to hydrocarbon substances, R 2 is the total adsorption rate of carbonic acid rock to hydrocarbon substances, R 3 is the degradation rate of microorganisms to hydrocarbon substances, alpha, beta and gamma are contribution coefficients, alpha is more than or equal to 1, beta is more than or equal to 0 and less than or equal to 1, gamma is more than or equal to 0 and less than or equal to 1, and alpha+beta+gamma=1.
2. The method of claim 1, wherein the mathematical model of diffusion is: Wherein C is the concentration of any substance at any point in a rectangular coordinate system, D is the diffusion coefficient in three directions, and the unit is m 2 /s, and C in the diffusion mathematical model is set as the hydrocarbon concentration C k of diffusion action micro leakage.
3. The method of claim 1, wherein the mathematical model of water-soluble phase migration is: Wherein q ci represents the flux of hydrocarbon components, V represents the flow rate of water, ε represents the water content, D T represents the total dispersion coefficient, C i represents the concentration of water-soluble hydrocarbon, and V represents the gradient differentiation operator, in the mathematical model of water-soluble phase migration, represents the total concentration gradient change of hydrocarbon under the condition of two-dimensional rectangular coordinates (X, Z), namely ; The formula for transporting the hydrocarbon component in the water is as follows: Wherein q is q ci , which represents the flux of hydrocarbon components, and C in the transportation formula of hydrocarbon components in water is set as the concentration C s of hydrocarbon components transported by water-soluble phase.
4. The method of claim 1, wherein the step of obtaining a mathematical model of buoyancy migration is: obtaining a linear velocity calculation formula of water and gas in the rock stratum according to the relationship of Darcy's law and the potential gradient of each phase state in proportion; Based on a linear velocity calculation formula of water and gas in a rock stratum, calculating to obtain the quantity Qf and the concentration Cf of hydrocarbons, and obtaining the buoyancy migration mathematical model; the linear velocity calculation formula of water and gas in the rock stratum is respectively as follows: Wherein V g represents the gas velocity, V w represents the water velocity, K represents the formation permeability, K g represents the gas relative permeability, K w represents the water relative permeability, μ g represents the gas viscosity, μ w represents the water viscosity, Φ g represents the gas potential, Φ g =P+ρgh;Ф w represents the water potential, Φ w =p+pgh, and the gradient differential operator represents the gradient differential operator, and the gradient of either direction variable of X, Y, Z is calculated, namely = # 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.
5. The utility model provides a spy forward modeling device based on oil reservoir model which characterized in that includes: The oil deposit geological model acquisition module is used for acquiring oil gas geological data and seismic data and determining an oil deposit geological model; the mathematical model acquisition module is used for acquiring a diffusion mathematical model, a water-soluble phase migration mathematical model and a buoyancy migration mathematical model; the model coupling module is used for coupling the diffusion mathematical model, the water-soluble phase migration mathematical model and the buoyancy migration mathematical model based on the determined oil reservoir geological model, and establishing an oil reservoir hydrocarbon micro-seepage mathematical model; the subsection simulation module is used for carrying out subsection simulation based on the oil reservoir hydrocarbon micro-leakage mathematical model, wherein the simulation content comprises hydrocarbon concentration, hydrocarbon leakage rate and leakage flux; The model coupling module includes: An additional amount acquisition unit for acquiring physical adsorption amount of stratum, chemical adsorption amount of carbonate mineral and microbial degradation amount; The model building unit is used for coupling the diffusion mathematical model, the water-soluble phase migration mathematical model and the buoyancy migration mathematical model based on the determined oil deposit geological model, and building an oil deposit hydrocarbon micro-seepage mathematical model by combining the physical adsorption quantity of the stratum, the chemical adsorption quantity of the carbonate mineral and the microbial degradation quantity; The mathematical model of the oil reservoir hydrocarbon micro-leakage is as follows: C=C k *α+C s *β+C f *γ-R 1 -R 2 -R 3 Wherein, C k is the hydrocarbon concentration of micro leakage of diffusion, C s is the hydrocarbon concentration of water-soluble phase migration, C f is the hydrocarbon concentration of buoyancy migration, R 1 is the total adsorption rate of stratum particles to hydrocarbon substances, R 2 is the total adsorption rate of carbonic acid rock to hydrocarbon substances, R 3 is the degradation rate of microorganisms to hydrocarbon substances, alpha, beta and gamma are contribution coefficients, alpha is more than or equal to 1, beta is more than or equal to 0 and less than or equal to 1, gamma is more than or equal to 0 and less than or equal to 1, and alpha+beta+gamma=1.
6. A computer device comprising a memory and a processor, the memory storing a computer program, characterized in that the processor implements the steps of the method of any of claims 1 to 4 when the computer program is executed.
7. A computer readable storage medium, on which a computer program is stored, characterized in that the computer program, when being executed by a processor, implements the steps of the method of any of claims 1 to 4.

Description

Method, device, computer equipment and storage medium for simulating forward performance of chemical detection Technical Field The invention relates to the technical field of numerical simulation of oil and gas exploration, in particular to a method, a device, computer equipment and a storage medium for simulating a chemical detection forward model based on an oil reservoir model. Background The hydrocarbon exploration technology is used as a means of oil and gas exploration, the theoretical basis of the technology is based on the assumption that hydrocarbon gas in an underground hydrocarbon reservoir is approximately vertically moved to the earth surface in a weak but detectable amount, and although a series of successful cases are obtained for many years, many students still have a question about the near-surface abnormal formation mechanism of the oil and gas exploration in the geological world, and a forward research on the abnormal formation mechanism of the enhanced exploration is needed, wherein numerical simulation is one of methods for developing forward research, and the basic theory of the vertical micro-leakage of hydrocarbons, the near-surface display and the vertical micro-leakage of the compacted hydrocarbons can be described by the numerical simulation. Currently, for the research of chemical detection forward modeling, a single mechanism is basically adopted for modeling from oil reservoir, direct cap layer, overburden stratum and surface. Ruan Tianjian (1985) assumed 6 cap and gas source combination conditions, numerical simulations of anomalies formed in the diffusion process at the surface, the simulation results demonstrated that small fields (narrow gas sources) were top anomalies and large fields (wide gas sources) were halo anomalies. Shouwei, bao Zhengyu et al (2003) established a conceptual model of hydrocarbon microleakage based on previous human hydrocarbon microleakage mechanism studies and deduced a kinetic model of hydrocarbon vertical migration. Based on a dynamic model, the lifting of the hydrocarbon colloid bubbles is considered to be a reasonable view through numerical simulation, and the equilibrium time of vertical migration of the hydrocarbon under different conditions is calculated. Huang Zhilong et al (2007) consider that light hydrocarbons leak and migrate in a quasi-vertical direction in the form of micelles, establish a quantitative model of microleakage and quantitatively estimate the microleakage and loss of natural gas through the cap layer in the ground history period by an actual gas reservoir. Li Meng (2009,2012), li Zhi (2012) are used for constructing ideal single-layer and multi-layer building block stratum medium models based on the basic concept of vertical micro-seepage of hydrocarbons and continuous medium assumption, and then establishing a quantitative equation describing the vertical micro-seepage process of hydrocarbons in the stratum medium models, namely a reaction-convection-diffusion partial differential equation, according to the law of conservation of mass. In foreign aspects, krooss (1992) and the like further consider the balance of gas-phase methane and water-soluble-phase methane in the cover layer for a diffusion mechanism, further correct the equation of the former, calculate the diffusion amount of hydrocarbons in a deposition column and compare the diffusion amount with the actual measurement result, and obtain a relatively consistent result. Nelson and Simmons have criticized the calculations of Krooss (1992), combining diffusion coefficient with porosity, permeability, tortuosity, re-numerically calculated, and Jakel and Klusman (1995), thomas and Clouse (1990), all studied numerical simulations of diffusion mechanisms [81]. The vertical hydrocarbon migration process in the saturated zone and the unsaturated zone above the hydrocarbon reservoir under the action of a buoyancy mechanism is numerically simulated by Ronald W. Klusman (2005,2010), and the buoyancy lifting of microbubbles is considered to be a viable oil and gas migration mechanism, so that the support is provided for the earth surface geochemistry phenomena observed in oil and gas exploration. For the formation of surface chemistry anomaly, different scholars emphasize their thought main mechanism in numerical simulation, considering relatively singleness. Micro leakage is in different intervals, the temperature and pressure conditions and the formation water conditions are different, and the leakage mode changes along with the change of the conditions. The sealing properties of the cap layer also determine the manner and scale of micro-leakage. Thus, there are necessarily various modes of microleakage from the reservoir-direct cap-overburden-surface-formation medium system as a whole, as well as influencing factors. The numerical simulation research only emphasizes one mode of micro leakage, and the influence factors under geological conditions are less considered. Ther