Dynamic relative permeability simulation method for influence of fluid components on wettability and product
By simulating the fluid displacement process using a digital core model, the wetting contact angle can be dynamically determined, solving the problem of core wettability being destroyed in physical experiments and achieving more accurate relative permeability calculation.
Patent Information
- Authority / Receiving Office
- CN · China
- Patent Type
- Applications(China)
- Current Assignee / Owner
- ICORE GROUP INC
- Filing Date
- 2026-01-27
- Publication Date
- 2026-05-12
AI Technical Summary
In existing technologies, the wettability of core samples is irreversibly damaged during physical displacement experiments due to cleaning, drying, and other processes, leading to inaccurate determination of relative permeability and neglecting the actual working conditions of the reservoir.
By simulating the fluid displacement process based on a digital core model, the wetting contact angle is dynamically determined using mineral surface complexation characteristics and fluid chemical environment parameters. Combined with fluid dynamics calculations, the relative permeability of the core is accurately determined.
It improves the accuracy of core permeability, enabling a more realistic reflection of the dynamic working conditions of the reservoir and solving the errors caused by the static assumption of wettability parameters in traditional experimental methods.
Smart Images
Figure CN122016566A_ABST
Abstract
Description
Technical Field
[0001] This application relates to the field of petroleum technology, specifically to a dynamic phase permeation simulation method and product for the influence of fluid components on wettability. Background Technology
[0002] Relative permeability is a core parameter describing the flow capacity of multiphase fluids such as oil, gas, and water in the porous media of a reservoir. It plays a decisive role in reservoir productivity prediction, recovery rate estimation, and development scheme optimization. Inaccurate relative permeability can lead to significant deviations between reservoir numerical simulation results and actual production dynamics.
[0003] Currently, the relative permeability of core samples is mostly determined through physical displacement experiments. However, during physical displacement experiments, the original wettability of the core sample is irreversibly damaged by cleaning, drying, and other processes. In addition, physical displacement experiments assume that the wettability of the core sample is a constant parameter throughout the experiment, completely ignoring the actual working conditions of the reservoir, resulting in poor accuracy in determining the core permeability. Summary of the Invention
[0004] The main objective of this application is to propose a dynamic phase permeation simulation method and product for the influence of fluid components on wettability, aiming to improve the accuracy of determining core permeability.
[0005] This application provides a dynamic phase permeability simulation method for the influence of fluid components on wettability, comprising: simulating the fluid displacement process of a core sample using a digital core model; the digital core model characterizing the distribution of pores and minerals in the core sample; determining the wetting contact angle of a target mineral during the fluid displacement process based on surface complexation characteristics parameters of the target mineral and chemical environment parameters of the target fluid in contact with the target mineral; the target mineral being one of several minerals adjacent to the pores that contacts the target fluid; and determining the relative permeability of the core sample based on the wetting contact angles of each target mineral in the core sample.
[0006] In one embodiment, the fluid displacement process includes multiple time steps; determining the wetting contact angle of the target mineral based on the surface complexation characteristics of the target mineral and the chemical environment parameters of the target fluid in contact with the target mineral includes: for each time step, determining the target mineral at that time step based on the fluid distribution information of the pores at that time step; determining the wetting contact angle of the target mineral at that time step based on the surface complexation characteristics of the target mineral at that time step and the target chemical environment parameters; wherein the target chemical environment parameters are the chemical environment parameters of the target fluid in contact with the target mineral at that time step.
[0007] In one embodiment, determining the wetting contact angle of the target mineral at the time step based on the surface complexation characteristic parameters and target chemical environment parameters of the target mineral at the time step includes: determining the surface charge density of the target mineral at the time step based on the surface complexation characteristic parameters and target chemical environment parameters of the target mineral at the time step.
[0008] Based on the surface charge density of the target mineral at the specified time step, the wetting contact angle of the target mineral at the specified time step is determined.
[0009] In one embodiment, the plurality of time steps includes a first time step and a second time step; the second time step is the next time step after the first time step; the method further includes: determining, based on the fluid field data of the core sample at the end of the first time step, the fluid distribution information of the pores at the beginning of the second time step, and the chemical environment parameters of the target fluid in contact with the target mineral at the beginning of the second time step.
[0010] In one embodiment, determining the relative permeability of the core sample based on the wetting contact angle of each target mineral in the core sample includes: performing fluid dynamics calculations using the fluid field data of the core sample at the end of the first time step as initial conditions and the wetting contact angle of each target mineral at the end of the first time step as boundary conditions to obtain the fluid field data of the core sample at the end of the second time step; and determining the relative permeability of the core sample at the end of the second time step based on the fluid field data of the core sample at the end of the second time step.
[0011] In one embodiment, before simulating the fluid displacement process of the core sample using the digital core model based on the core sample, the method further includes: acquiring a three-dimensional grayscale image data volume and two-dimensional mineral composition data of the core sample; performing multimodal data fusion and registration on the three-dimensional grayscale image data volume and the two-dimensional mineral composition data to obtain the correspondence between the grayscale values and mineral phases of the core sample; and segmenting the three-dimensional grayscale image data volume based on the correspondence between the grayscale values and mineral phases of the core sample to obtain the digital core model.
[0012] This application also provides a dynamic relative permeability simulation device for the influence of fluid components on wettability. The device includes a simulation module, a first determination module, and a second determination module. The simulation module is used to simulate the fluid displacement process of the core sample based on a digital core model of the core sample. The digital core model is used to characterize the distribution of pores and minerals in the core sample. The first determination module is used to determine the wetting contact angle of the target mineral during the fluid displacement process based on the surface complexation characteristics of the target mineral and the chemical environment parameters of the target fluid in contact with the target mineral. The target mineral is a mineral in contact with the target fluid among a variety of minerals adjacent to the pores. The second determination module is used to determine the relative permeability of the core sample based on the wetting contact angle of each target mineral in the core sample.
[0013] This application also provides an electronic device, which includes a memory and a processor. The memory stores a computer program, and the processor executes the computer program to implement the above-described method.
[0014] This application also provides a computer-readable storage medium storing a computer program that, when executed by a processor, implements the above-described method.
[0015] This application also provides a computer program product stored in a computer-readable storage medium, which implements the above-described method when executed by a processor.
[0016] This application provides a dynamic phase permeation simulation method and product for the influence of fluid components on wettability. By simulating fluid displacement through a digital core model based on core samples, and utilizing the wetting contact angle determined based on mineral surface complexation characteristics and fluid chemical environment parameters, the relative permeability of the core sample can be determined, thereby improving the accuracy of core permeability determination. Attached Figure Description
[0017] Figure 1 This is a schematic flowchart of the dynamic phase permeation simulation method for the influence of fluid components on wettability provided in the embodiments of this application.
[0018] Figure 2 This is a schematic diagram of the architecture of the dynamic phase permeation simulation system for the influence of fluid components on wettability provided in the embodiments of this application.
[0019] Figure 3 This is a schematic diagram of the specific process of the dynamic phase permeation simulation method for the influence of fluid components on wettability provided in the embodiments of this application.
[0020] Figure 4This is a schematic diagram of the dynamic phase permeation simulation device for the influence of fluid components on wettability provided in the embodiments of this application.
[0021] Figure 5 This is a schematic diagram of the structure of the electronic device provided in the embodiments of this application. Detailed Implementation
[0022] The technical solutions of the embodiments of this application will be clearly described below with reference to the accompanying drawings. Obviously, the described embodiments are only some, not all, of the embodiments of this application. All other embodiments obtained by those skilled in the art based on the embodiments of this application are within the scope of protection of this application.
[0023] The terms "first," "second," etc., used in the specification and claims of this application are used to distinguish similar objects and not to describe a specific order or sequence. It should be understood that such use of data can be interchanged where appropriate so that embodiments of this application can be implemented in orders other than those illustrated or described herein, and the objects distinguished by "first," "second," etc., are generally of the same class and the number of objects is not limited; for example, a first object can be one or more. Furthermore, in the specification and claims, "and / or" indicates at least one of the connected objects, and the digit " / " generally indicates that the preceding and following objects are in an "or" relationship.
[0024] The dynamic phase permeation simulation method for the influence of fluid components on wettability provided in this application embodiment can be applied to electronic devices or the software of electronic devices. The electronic device can be a terminal or a server. In some embodiments, the terminal can be a smartphone, tablet computer, laptop computer, desktop computer, etc.; the server can be configured as an independent physical server, or as a server cluster or distributed system composed of multiple physical servers. The software can be an application that implements the dynamic phase permeation simulation method for the influence of fluid components on wettability, etc., but is not limited to the above forms.
[0025] The dynamic phase permeation simulation method for the influence of fluid components on wettability provided in this application will be described in detail below with reference to the accompanying drawings and specific embodiments.
[0026] Please see Figure 1 The dynamic phase permeation simulation method for the influence of fluid components on wettability provided in this application embodiment may include: Step S101: Based on the digital core model of the core sample, simulate the fluid displacement process of the core sample; the digital core model is used to characterize the distribution of pores and minerals in the core sample. In practice, the core sample can be scanned to obtain a three-dimensional grayscale image data volume and two-dimensional mineral composition data. Optionally, the mineral composition data may include mineral components and their contents. Then, a digital core model of the core sample can be constructed based on the three-dimensional grayscale image data volume and the two-dimensional mineral composition data. For specific implementation details, please refer to the relevant descriptions below, which will not be described here.
[0027] Then, initial simulation conditions can be defined, and the digital core model can be used as the physical carrier. The Lattice Boltzmann Method (LBM) can be used to simulate and numerically solve the two-phase flow displacement, so as to intuitively show the dynamic process of the non-wetting phase (such as injected water) displacing the wetting phase (such as crude oil).
[0028] Step S102: During the fluid displacement process, the wetting contact angle of the target mineral is determined based on the surface complexation characteristics parameters of the target mineral and the chemical environment parameters of the target fluid in contact with the target mineral; the target mineral is the mineral in contact with the target fluid among a variety of minerals adjacent to the pores. In practice, the surface complexation characteristics of the target mineral can be obtained from publicly available geochemical databases, or the surface complexation characteristics of the target mineral can be determined in advance through calibration experiments (such as potentiometric titration).
[0029] Optionally, the chemical environmental parameters of the target fluid may include at least one of the following: pH value, ion species, and concentration. In the water-oil displacement process, the target fluid may be the aqueous phase fluid that comes into contact with the target mineral.
[0030] Considering that under actual reservoir conditions, the position of the target fluid in the pores is constantly changing and the minerals in contact with the target fluid will continuously undergo chemical reactions, the minerals in contact with the target fluid and the chemical environment parameters of the target fluid will also be constantly changing.
[0031] In practical implementation, during the simulated fluid displacement process, the chemical environment parameters of the target minerals in contact with the target fluid and the target fluid itself can be dynamically updated. Furthermore, based on these dynamically updated surface complexation characteristics and the chemical environment parameters of the target fluid, the wetting contact angle of the target minerals can be dynamically updated. Specific implementation details are described below and will not be elaborated here. This approach maximizes the replication of the actual reservoir conditions, thereby improving the accuracy of core permeability determination.
[0032] Step S103: Determine the relative permeability of the core sample based on the wetting contact angle of each target mineral in the core sample.
[0033] In practice, the wetting contact angle of each target mineral can be dynamically updated as a boundary condition, and the relative permeability of the core sample can be dynamically updated through hydrodynamic calculations. For details, please refer to the relevant description below, which will not be described here.
[0034] This application embodiment uses a digital core model based on core samples to simulate fluid displacement. By utilizing the wetting contact angle determined based on mineral surface complexation characteristics and fluid chemical environment parameters, the relative permeability of the core sample can be determined, thereby improving the accuracy of core permeability determination.
[0035] Optionally, the above-described fluid displacement process includes multiple time steps. In one embodiment, the determination of the wetting contact angle of the target mineral in step S102, based on the surface complexation characteristics parameters of the target mineral and the chemical environment parameters of the target fluid in contact with the target mineral, includes: For each time step, the target mineral at that time step is determined based on the fluid distribution information in the pores at that time step. Based on the surface complexation characteristics and target chemical environment parameters of the target mineral at each time step, the wetting contact angle of the target mineral at each time step is determined; the target chemical environment parameters are the chemical environment parameters of the target fluid in contact with the target mineral at each time step.
[0036] Optionally, for each time step, the fluid distribution information of the pores at that time step may include the fluid distribution information of the pores at a target time within that time step; the chemical environment parameters of the target fluid within the pores at that time step may include the chemical environment parameters of the target fluid at the target time within that time step. Optionally, the target time may be the start time or the end time.
[0037] In practical implementation, for each time step, the mineral in contact with the target fluid at the target time step can be determined based on the fluid distribution information of the pores at that time step, thus obtaining the target mineral at that time step. Then, based on the surface complexation characteristic parameters of the target mineral and the chemical environment parameters of the target fluid in contact with the target mineral at the target time step, the wetting contact angle of the target mineral can be determined. Specific implementation details are provided in the following description and will not be elaborated here. Optionally, the surface complexation characteristic parameters may include the type of surface functional groups (such as SiOH, AlOH, MgOH, (Fe, Mg)OH, etc.), the density of surface functional groups, and the chemical reaction equilibrium constant of the surface functional groups.
[0038] Optionally, the fluid distribution information of the pores at the beginning of the initial time step and the chemical environment parameters of the target fluid in contact with the target mineral at the beginning of the initial time step can be preset values. The fluid distribution information of the pores at the end of the initial time step or at the target time of other time steps, and the chemical environment parameters at the end of the initial time step or at the target time of other time steps, can be determined based on the fluid field data of the dynamic evolution of the core sample. For specific implementation details, please refer to the relevant descriptions below, which will not be described here.
[0039] This application embodiment determines the target mineral at each time step based on the fluid distribution information of the pores at that time step; and determines the wetting contact angle of the target mineral at each time step based on the surface complexation characteristics and target chemical environment parameters of the target mineral at that time step. This takes into account the dynamic evolution of relevant parameters under actual reservoir conditions, which can improve the accuracy of determining the wetting contact angle of minerals in core samples, thereby improving the accuracy of determining core permeability based on the wetting contact angle.
[0040] In one embodiment, determining the wetting contact angle of the target mineral at a given time step based on the surface complexation characteristics parameters and target chemical environment parameters of the target mineral at that time step includes: Based on the surface complexation characteristics parameters and target chemical environment parameters of the target mineral at the time step, the surface charge density of the target mineral at the time step is determined. The wetting contact angle of the target mineral at each time step is determined based on the surface charge density of the target mineral at each time step.
[0041] In practice, the surface complexation characteristic parameters of the target mineral at a certain time step, along with the aforementioned target chemical environment parameters, can be input into a pre-established surface complexation model to obtain the surface charge density of the target mineral at that time step. Optionally, the surface complexation model can be a computational model based on first principles of thermodynamics, which can predict the electrochemical properties of the mineral-fluid interface.
[0042] Next, the calculated surface charge of the target mineral at that time step can be converted into a macroscopic wettability parameter by combining the classical DLVO theory, thus obtaining the wetting contact angle of the target mineral at that time step. Optionally, the DLVO theory is a theory used to quantitatively explain the stability of colloidal dispersion systems and describe the interaction forces between particles (or between particles and the surface).
[0043] In practice, for each time step, the surface charge density of the target mineral at the target time step can be determined based on the surface complexation characteristics parameters of the target mineral at the target time step and the chemical environment parameters of the target fluid in contact with the target mineral at the target time step; and the wetting contact angle of the target mineral at the target time step can be determined based on the surface charge density of the target mineral at the target time step.
[0044] This application embodiment determines the surface charge density of the target mineral at a given time step based on the surface complexation characteristic parameters and target chemical environment parameters of the target mineral at that time step; and determines the wetting contact angle of the target mineral at that time step based on the surface charge density of the target mineral at that time step. This can improve the accuracy of determining the wetting contact angle of minerals in core samples, thereby improving the accuracy of determining core permeability based on the wetting contact angle.
[0045] Optionally, the multiple time steps may include a first time step and a second time step; the second time step may be the next time step after the first time step. In one embodiment, the dynamic phase permeation simulation method for the influence of fluid components on wettability provided in this application further includes: Based on the fluid field data of the core sample at the end of the first time step, the fluid distribution information of the pores at the beginning of the second time step, and the chemical environment parameters of the target fluid in contact with the target mineral at the beginning of the second time step are determined.
[0046] Optionally, the fluid field data may include at least one of the pressure, flow rate, and saturation at each grid point in the digital core model. In practice, before executing the second time step, the fluid distribution information of the pores at the beginning of the second time step can be obtained by using the instantaneous convection-diffusion equation based on the fluid field data at the end of the first time step; alternatively, the chemical environment parameters of the target fluid within the pores at the beginning of the second time step can be determined using geochemical principles based on the fluid field data at the end of the first time step. Optionally, the fluid field data at the end of the first time step can be the fluid field data at the end of the first time step; the fluid field data at the beginning of the second time step can be the fluid field data at the beginning of the second time step.
[0047] Optionally, if the first time step is the initial time step of the fluid displacement process, the fluid dynamics calculation can be performed using the preset fluid field data of the core sample at the beginning of the first time step as the initial condition and the wetting contact angle of each target mineral at the beginning of the first time step as the boundary condition, to obtain the fluid field data of the core sample at the end of the first time step.
[0048] This application embodiment determines the fluid distribution information of the pores at the beginning of the second time step and the chemical environment parameters of the target fluid in contact with the target mineral at the beginning of the second time step by using the fluid field data of the core sample at the end of the first time step. This can realize the dynamic updating of fluid distribution information and chemical environment parameters during the fluid displacement process, and restore the dynamic evolution of relevant parameters under the actual working conditions of the reservoir to the greatest extent, thereby improving the accuracy of determining the core permeability.
[0049] In one embodiment, step S103 above: determining the relative permeability of the core sample based on the wetting contact angle of each target mineral in the core sample, includes: Using the fluid field data of the core sample at the end of the first time step as the initial condition and the wetting contact angle of each target mineral at the end of the first time step as the boundary condition, fluid dynamics calculations were performed to obtain the fluid field data of the core sample at the end of the second time step. Based on the fluid field data of the core sample at the end of the second time step, the relative permeability of the core sample at the end of the second time step was determined.
[0050] In practice, the fluid field data of the core sample at the end of the first time step can be used as the initial condition, and the wetting contact angle of each target mineral at the end of the first time step can be used as the boundary condition, which can be fed back to the LBM numerical solver. The LBM numerical solver can then perform the hydrodynamic calculation of the second time step based on these conditions to obtain the fluid field data at the end of the second time step.
[0051] Next, based on the fluid field data of the core sample at the end of the second time step, macroscopic parameters such as pressure, flow rate, and saturation at the core scale at the end of the second time step can be calculated through spatial integration and averaging. Finally, based on the macroscopic parameters such as pressure, flow rate, and saturation at the core scale at the end of the second time step, the relative permeability of the core sample at the end of the second time step can be calculated using Darcy's law.
[0052] In practice, based on the fluid field data of the core sample at the end of each time step, macroscopic parameters such as pressure, flow rate and saturation during the fluid displacement process can be continuously recorded. At the end of the last time step, based on the continuously recorded macroscopic parameters, the curve of the relative permeability of the core sample changing with time can be output, i.e., the relative permeability curve of the core sample.
[0053] This embodiment of the application uses the fluid field data of the core sample at the end of the first time step as the initial condition and the wetting contact angle of each target mineral at the end of the first time step as the boundary condition to perform fluid dynamics calculations, thereby obtaining the fluid field data of the core sample at the end of the second time step; and based on the fluid field data of the core sample at the end of the second time step, determines the relative permeability of the core sample at the end of the second time step. This not only ensures the stability and authenticity of the simulation of the multiphysics fluid displacement process, but also predicts the dynamic wettability evolution of minerals in the core sample under long-term water-rock interaction, thus enabling the determination of the relative permeability of the core sample that is closer to the real dynamics of the reservoir.
[0054] In one embodiment, before simulating the fluid displacement process of the core sample using the digital core model based on the core sample in step S101 above, the dynamic phase permeation simulation method for the influence of fluid components on wettability provided in this application further includes: Acquire three-dimensional grayscale image data and two-dimensional mineral composition data of core samples; Multimodal data fusion and registration were performed on the three-dimensional grayscale image data volume and the two-dimensional mineral composition data to obtain the correspondence between the grayscale values and mineral phases of the core sample; Based on the correspondence between the gray values of the core sample and the mineral phases, the three-dimensional grayscale image data volume is segmented to obtain a digital core model.
[0055] In practice, a micro-computed tomography (µCT) scanner can be used to perform high-resolution computed tomography (CT) scans on core samples to obtain three-dimensional grayscale image data of the core samples; and an X-ray diffraction (XRD) instrument can be used to analyze the same core sample or core samples from the same source to obtain two-dimensional mineral composition data of the core samples.
[0056] Next, through rigid or affine transformations, supplemented by feature point matching, multimodal data fusion and registration can be performed between the two-dimensional mineral composition data and the three-dimensional grayscale image data volume to establish a high-confidence correspondence between grayscale values and mineral phases. Subsequently, based on this correspondence, image segmentation algorithms such as the deep learning-based 3D U-Net model or threshold watershed can be used to accurately segment the three-dimensional grayscale image data volume, thereby constructing a three-dimensional digital core model containing spatial distribution information of pores and different mineral phases. Optionally, each voxel in the digital core model is explicitly labeled as a pore or a specific mineral phase (such as quartz, kaolinite, feldspar, calcite, etc.).
[0057] This application embodiment obtains a three-dimensional grayscale image data volume and two-dimensional mineral composition data of a core sample; performs multimodal data fusion and registration on the three-dimensional grayscale image data volume and the two-dimensional mineral composition data to obtain the correspondence between the grayscale values and mineral phases of the core sample; and segments the three-dimensional grayscale image data volume based on the correspondence between the grayscale values and mineral phases of the core sample to obtain a digital core model. This can improve the accuracy of establishing a digital core model, thereby improving the accuracy of simulating core permeability based on the digital core model.
[0058] In one specific embodiment, the dynamic phase permeation simulation method for the influence of fluid components on wettability provided in this application can be applied to, for example... Figure 2 The illustrated dynamic relative permeability simulation system 100 for the influence of fluid components on wettability. This system 100 may include a device group 104 for data acquisition and a computing device 106 for data processing and simulation. The device group 104 may include a µCT scanner 104a and an XRD diffractometer 104b; the computing device 106 may include a hardware processor 108 and a data storage device 110. Optionally, the data storage device 110 deploys a multi-mineral model construction module 112, a geochemical modeling model 114, and a fluid dynamics simulation module 116 for implementing the dynamic relative permeability simulation method for the influence of fluid components on wettability provided in the embodiments of this application.
[0059] In practice, the three-dimensional grayscale image data obtained by scanning the core sample using the µCT scanner 104a and the two-dimensional mineral composition data obtained by scanning the core sample using the XRD diffractometer 104b can be input into the hardware processor 108. The hardware processor 108 can call the multi-mineral model construction module 112 to construct a digital core model of the core sample based on the three-dimensional grayscale image data and the two-dimensional mineral composition data of the core sample.
[0060] Next, the hardware processor 108 can call the geochemical modeling model 114 to establish a dedicated dynamic wettability prediction model based on geochemical principles for each mineral phase in the digital core model. This wettability prediction model can predict the wetting contact angle of the mineral surface in real time based on the changes in the local fluid chemical environment in the pores and the surface complexation characteristics parameters of the mineral.
[0061] Then, the hardware processor 108 can call the fluid dynamics simulation module 116 to simulate the fluid displacement process of the core sample based on the digital core model of the core sample and using a multiphase flow LBM numerical simulator at the pore scale. During the simulation of the fluid displacement process, the hardware processor 108 can dynamically couple the aforementioned wettability prediction model with the LBM numerical simulator: track the changes in the local fluid chemical environment at each pore wall surface location in real time, and call the wettability prediction model of the corresponding mineral to calculate the wetting contact angle of the corresponding mineral at the current moment; then, the dynamically changing wetting contact angle can be used as the real-time boundary condition of the LBM numerical simulator, and the relative permeability that reflects the dynamic evolution of the wettability of the core sample can be calculated based on the simulated fluid field data.
[0062] Please combine Figure 2 and Figure 3 In one specific embodiment, the dynamic phase permeation simulation method for the influence of fluid components on wettability provided in this application may further include the following steps: Step 410: Load the digital core and wettability models of each mineral; this step loads the multi-mineral digital core model and the dynamic wettability prediction model of each mineral into the fluid dynamics simulation module 116. The fluid dynamics simulation module 116 preferably uses the Geertzmann method (LBM) as the numerical solution tool.
[0063] Step 420: Initialize fluid distribution; This step can define the initial simulation conditions, which may include the initial fluid distribution information of the pores and the initial chemical environment parameters of the target fluid within the pores.
[0064] Step 430: LBM simulation time step loop; In this step, the fluid dynamics simulation module 116 starts simulating the fluid displacement process, and at each time step of the simulated fluid displacement process, the following steps can be performed: (i) Track the local fluid chemical environment around each voxel on the surface of the pore wall; (ii) Call the dynamic wettability prediction model of the mineral corresponding to the voxel to calculate the wettability contact angle that the mineral should have at the current moment; (iii) Use this dynamically updated wettability contact angle as a real-time boundary condition and feed it back to the LBM solver for the fluid dynamics calculation of the next time step to obtain the fluid field data of the next time step; (iv) Update the simulation conditions based on the fluid field data of the next time step and return to execute step (i), and repeat this loop until the simulation duration reaches the preset simulation duration.
[0065] Step 440: Summarize historical data on flow rate, pressure, and saturation. This step summarizes the flow rate, pressure, and saturation data recorded at each time step during the simulation.
[0066] Step 450: Calculate the relative permeability based on the recorded data using Darcy's Law.
[0067] Since the wetting contact angle changes with time (or the number of injected pore volumes) during the above simulation process, the final output relative permeability result is no longer a static relative permeability curve, but a relative permeability curve that better reflects the long-term dynamics of the reservoir.
[0068] The specific implementation process of the embodiments of this application can be found in the description of the above embodiments, and will not be described here.
[0069] The dynamic phase permeability simulation method for the influence of fluid components on wettability provided in this application abandons the traditional physical experiment approach to permeability measurement and pioneers a new paradigm of obtaining dynamic wettability parameters by replacing physical experiments with geochemical prediction. By integrating micron-scale CT and XRD data, a three-dimensional digital core model that can accurately distinguish multiple minerals is constructed, and a dedicated dynamic wettability prediction model based on geochemical principles is established for each mineral, thus enabling real-time calculation of changes in mineral wetting contact angles without actual experiments. In addition, the dynamic wettability prediction model is coupled in real-time and dynamically with pore-scale fluid displacement simulation: at each time step of the simulation, the wetting contact angle of each mineral surface can be updated in real time according to the local fluid chemical environment within the pores, and the updated wetting contact angle is fed back into the fluid dynamics calculation. This two-way coupling can completely reproduce the dynamic evolution of mineral wettability with water-rock interaction at the pore scale, completely overcoming the fundamental defect of traditional experimental methods that treat rocks as homogeneous bodies and maintain static wettability. Therefore, the dynamic relative permeability simulation method for the influence of fluid components on wettability provided in this application solves the fundamental technical problem of inaccurate relative permeability prediction caused by the inability to obtain long-term, dynamic, and mineral-specific wettability parameters. It can output high-fidelity dynamic relative permeability curves, which helps to capture the wettability heterogeneity caused by uneven distribution of micro-minerals and its complex influence on seepage paths and residual oil distribution, thus significantly improving reservoir development results.
[0070] Please see Figure 4 This application embodiment also provides a dynamic phase permeation simulation device 400 for the influence of fluid components on wettability. The device 400 may include a simulation module 401, a first determination module 400, and a second determination module 403.
[0071] The simulation module 401 can be used to simulate the fluid displacement process of the core sample using a digital core model based on the core sample; the digital core model is used to characterize the distribution of pores and minerals in the core sample. The first determining module 402 is used to determine the wetting contact angle of the target mineral during the fluid displacement process based on the surface complexation characteristic parameters of the target mineral and the chemical environment parameters of the target fluid in contact with the target mineral; the target mineral is the mineral in contact with the target fluid among a variety of minerals adjacent to the pores. The second determining module 403 is used to determine the relative permeability of the core sample based on the wetting contact angle of each target mineral in the core sample.
[0072] The dynamic phase permeation simulation device for the influence of fluid components on wettability provided in this application embodiment can realize all the steps of the above-described dynamic phase permeation simulation method embodiment for the influence of fluid components on wettability, and can achieve the same technical effect. To avoid repetition, it will not be described again here.
[0073] This application also provides an electronic device, including a processor and a memory. The memory stores a program or instructions that can be executed on the processor. When the program or instructions are executed by the processor, they implement the various steps of the above-described dynamic phase permeation simulation method embodiment for the influence of fluid components on wettability and achieve the same technical effect. To avoid repetition, they will not be described again here.
[0074] Figure 5 To illustrate the hardware structure of the electronic device according to the embodiments of this application, the electronic device includes: The processor 501 can be implemented using a general-purpose central processing unit (CPU), microprocessor, application specific integrated circuit (ASIC), or one or more integrated circuits, and is used to execute relevant programs to implement the technical solutions provided in the embodiments of this application. The memory 502 can be implemented as a read-only memory (ROM), static storage device, dynamic storage device, or random access memory (RAM). The memory 502 can store the operating system and other application programs. When the technical solutions provided in the embodiments of this specification are implemented through software or firmware, the relevant program code is stored in the memory 502 and is called and executed by the processor 501 using the dynamic phase permeation simulation method for the influence of fluid components on wettability according to the embodiments of this application. The input / output interface 503 is used to implement information input and output; The communication interface 504 is used to enable communication and interaction between this electronic device and other devices. Communication can be achieved through wired means (such as USB, network cable, etc.) or wireless means (such as mobile network, WIFI, Bluetooth, etc.). Bus 505 transmits information between various components of an electronic device (e.g., processor 501, memory 502, input / output interface 503, and communication interface 504); The processor 501, memory 502, input / output interface 503, and communication interface 504 are connected to each other within the electronic device via bus 505.
[0075] The electronic device provided in this application embodiment can realize each step of the above-described dynamic phase permeation simulation method embodiment for the influence of fluid components on wettability, and can achieve the same technical effect. To avoid repetition, it will not be described again here.
[0076] This application also provides a computer-readable storage medium storing a program or instructions. When the program or instructions are executed by a processor, they implement the various steps of the above-described dynamic phase permeation simulation method embodiment for the influence of fluid components on wettability and achieve the same technical effect. To avoid repetition, they will not be described again here.
[0077] The processor is the processor in the electronic device described in the above embodiments. The computer-readable storage medium includes computer-readable storage media such as computer read-only memory (ROM), random access memory (RAM), magnetic disk, or optical disk.
[0078] This application also provides a chip, which includes a processor and a communication interface. The communication interface and the processor are coupled. The processor is used to implement the various steps of the above-described dynamic phase permeation simulation method embodiment for the influence of fluid components on wettability, and can achieve the same technical effect. To avoid repetition, it will not be described again here.
[0079] It should be understood that the chip mentioned in the embodiments of this application may also be referred to as a system-on-a-chip, system chip, chip system, or system-on-a-chip, etc.
[0080] This application provides a computer program product stored in a computer-readable storage medium. When executed by a processor, the program product implements the various steps of the above-described dynamic phase permeation simulation method embodiment for the influence of fluid components on wettability, and achieves the same technical effect. To avoid repetition, it will not be described again here.
[0081] It should be noted that, in this document, the terms "comprising," "including," or any other variations thereof are intended to cover non-exclusive inclusion, such that a process, method, article, or apparatus that comprises a list of elements includes not only those elements but also other elements not expressly listed, or elements inherent to such a process, method, article, or apparatus. Without further limitations, an element defined by the phrase "comprising one..." does not delete other identical elements present in the process, method, article, or apparatus that includes that element. Furthermore, it should be noted that the scope of the methods and apparatuses in the embodiments of this application is not limited to performing functions in the order shown or discussed, but may also include performing functions substantially simultaneously or in the reverse order, depending on the functions involved. For example, the described methods may be performed in a different order than described, and various steps may be added, omitted, or combined. Additionally, features described with reference to certain examples may be combined in other examples.
[0082] Through the above description of the embodiments, those skilled in the art can clearly understand that the methods of the above embodiments can be implemented by means of software plus necessary general-purpose hardware platforms. Of course, they can also be implemented by hardware, but in many cases the former is a better implementation method. Based on this understanding, the technical solution of this application, in essence, or the part that contributes to the prior art, can be embodied in the form of a computer software product. This computer software product is stored in a storage medium (such as ROM / RAM, magnetic disk, optical disk) and includes several instructions to cause a terminal (which may be a mobile phone, computer, server, or network device, etc.) to execute the methods of the various embodiments of this application.
[0083] The embodiments of this application have been described above with reference to the accompanying drawings. However, this application is not limited to the specific embodiments described above. The specific embodiments described above are merely illustrative and not restrictive. Those skilled in the art can make many other forms under the guidance of this application without departing from the spirit and scope of the claims, and all of these forms are within the protection scope of this application.
Claims
1. A method for simulating the dynamic phase permeation effect of fluid components on wettability, characterized in that, include: A digital core model based on the core sample is used to simulate the fluid displacement process of the core sample. The digital core model is used to characterize the distribution of pores and minerals in the core sample; During the fluid displacement process, the wetting contact angle of the target mineral is determined based on the surface complexation characteristics of the target mineral and the chemical environment parameters of the target fluid in contact with the target mineral; the target mineral is the mineral in contact with the target fluid among a variety of minerals adjacent to the pores. The relative permeability of the core sample is determined based on the wetting contact angle of each target mineral in the core sample.
2. The method as described in claim 1, characterized in that, The fluid displacement process includes multiple time steps; The determination of the wetting contact angle of the target mineral based on the surface complexation characteristics of the target mineral and the chemical environment parameters of the target fluid in contact with the target mineral includes: For each time step, the target mineral at that time step is determined based on the fluid distribution information of the pores at that time step; Based on the surface complexation characteristics parameters and target chemical environment parameters of the target mineral at the time step, the wetting contact angle of the target mineral at the time step is determined; the target chemical environment parameters are the chemical environment parameters of the target fluid in contact with the target mineral at the time step.
3. The method as described in claim 2, characterized in that, The determination of the wetting contact angle of the target mineral at the specified time step, based on the surface complexation characteristics and target chemical environment parameters of the target mineral at that time step, includes: Based on the surface complexation characteristics parameters of the target mineral at the time step and the target chemical environment parameters, the surface charge density of the target mineral at the time step is determined. Based on the surface charge density of the target mineral at the specified time step, the wetting contact angle of the target mineral at the specified time step is determined.
4. The method as described in claim 2, characterized in that, The plurality of time steps includes a first time step and a second time step; the second time step is the next time step after the first time step; the method further includes: Based on the fluid field data of the core sample at the end of the first time step, the fluid distribution information of the pores at the beginning of the second time step and the chemical environment parameters of the target fluid in contact with the target mineral at the beginning of the second time step are determined.
5. The method as described in claim 1, characterized in that, The determination of the relative permeability of the core sample based on the wetting contact angle of each target mineral in the core sample includes: Using the fluid field data of the core sample at the end of the first time step as the initial condition and the wetting contact angle of each target mineral at the end of the first time step as the boundary condition, fluid dynamics calculations are performed to obtain the fluid field data of the core sample at the end of the second time step. Based on the fluid field data of the core sample at the end of the second time step, the relative permeability of the core sample at the end of the second time step is determined.
6. The method as described in claim 1, characterized in that, Before simulating the fluid displacement process of the core sample in the digital core model based on the core sample, the method further includes: Obtain the three-dimensional grayscale image data volume and two-dimensional mineral composition data of the core sample; Multimodal data fusion and registration are performed on the three-dimensional grayscale image data volume and the two-dimensional mineral composition data to obtain the correspondence between the grayscale values and mineral phases of the core sample; Based on the correspondence between the gray values and mineral phases of the core sample, the three-dimensional grayscale image data volume is segmented to obtain the digital core model.
7. A dynamic phase permeation simulation device for the influence of fluid components on wettability, characterized in that, The device includes a simulation module, a first determination module, and a second determination module; The simulation module is used to simulate the fluid displacement process of the core sample based on a digital core model; the digital core model is used to characterize the distribution of pores and minerals in the core sample. The first determining module is used to determine the wetting contact angle of the target mineral during the fluid displacement process, based on the surface complexation characteristics parameters of the target mineral and the chemical environment parameters of the target fluid in contact with the target mineral. The target mineral is one of the various minerals adjacent to the pores that is in contact with the target fluid; The second determining module is used to determine the relative permeability of the core sample based on the wetting contact angle of each target mineral in the core sample.
8. An electronic device, characterized in that, The electronic device includes a memory and a processor, the memory storing a computer program, and the processor executing the computer program to implement the method as described in any one of claims 1 to 6.
9. A computer-readable storage medium storing a computer program, characterized in that, When the computer program is executed by a processor, it implements the method as described in any one of claims 1 to 6.
10. A computer program product, characterized in that, The computer program product is stored in a computer-readable storage medium, and when executed by a processor, the computer program product implements the method as described in any one of claims 1 to 6.