A method and device for reservoir development time-lapse seismic physical simulation experiment

Abstract

This invention belongs to the field of seismic physics simulation experiment technology, and discloses a method and equipment for time-lapse seismic physics simulation experiments in oil reservoir development. The method includes: preparing a reservoir physical model based on predetermined target oil reservoir physical parameters; encapsulating the reservoir physical model within an epoxy resin layer to form an integral physical model; and measuring time-lapse seismic experimental data under different remaining oil saturations of the reservoir physical model to establish a mapping relationship between the remaining saturation of the target oil reservoir and the time-lapse seismic data. This invention can simultaneously conduct multiple time-lapse seismic observations and measurements during experiments with different fluid displacements of the reservoir physical model, thereby obtaining time-lapse seismic experimental data at different development stages of the reservoir. By processing and analyzing the time-lapse seismic experimental data, the distribution law of remaining oil in the reservoir physical model can be characterized, thus providing a reference for oil reservoir development scheme design and offering a new experimental means for improving oil recovery.

Description

Technical Field

[0001] The embodiments of the present invention relate to the field of seismic physics simulation experimental technology, and in particular to a method, apparatus, equipment, medium and product program for seismic physics simulation experiments on reservoir development time shift. Background Technology

[0002] Currently, physical simulation experiments for reservoir displacement development are an important technical means used to simulate fluid flows such as water drive, gas drive, and chemical drive under actual reservoir conditions, as well as oil production in production wells, to help better understand and optimize the reservoir development process. Time-shift seismic exploration is an enhanced oil and gas reservoir detection method. Its basic principle is to conduct seismic exploration at different time points to obtain seismic data of the same area at different times. Then, by comparing and analyzing these data, changes in subsurface structure and fluid distribution can be identified to pinpoint the location of remaining oil after displacement, thus optimizing development strategies.

[0003] The aforementioned time-shift seismic technology is not suitable for oilfields with thin reservoirs and high water content, which is significantly different from the case studies of time-shift seismic monitoring. Therefore, it is necessary to carry out basic research on the feasibility of time-shift seismic applications, time-shift seismic acquisition methods, time-shift seismic data processing, and time-shift seismic data analysis. However, in actual oil reservoir production, due to the high cost of multiple seismic data acquisitions, it is difficult to carry out such basic research on time-shift seismic data.

[0004] In summary, how to conduct time-shift seismic feasibility studies on reservoir displacement development processes in an economical and efficient manner, establish an experimental platform capable of stably conducting relevant research, and carry out basic research work to help adjust reservoir development plans and improve reservoir recovery rates are urgent problems to be solved. Summary of the Invention

[0005] The purpose of this invention is to provide at least one experimental method and equipment for time-lapse seismic physical simulation of reservoir development. The aim is to simultaneously conduct multiple time-lapse seismic observations and measurements during experiments involving different fluid displacements in a reservoir physical model, thereby obtaining time-lapse seismic experimental data at different development stages of the reservoir. Through comparative analysis of the data, the distribution pattern of remaining oil in the reservoir physical model can be obtained, and the relationship between the remaining oil distribution and development parameters such as displacement fluid type, flow velocity, and process can be established. This helps to adjust reservoir development plans and provides a new experimental means for studying enhanced oil recovery in reservoirs.

[0006] To address the aforementioned technical problems, at least one embodiment of the present invention provides a method for time-lapse seismic physical simulation of reservoir development, comprising:

[0007] Prepare a physical model of the reservoir based on the predetermined physical property parameters of the target reservoir;

[0008] The reservoir physical model is encapsulated within an epoxy resin layer to form an integral physical model;

[0009] Time-lapsed seismic experimental data were measured at different residual oil saturation levels of the reservoir physical model to establish the mapping relationship between the residual saturation of the target reservoir and the time-lapsed seismic data.

[0010] In some embodiments, the physical properties include: reservoir structure, reservoir pore structure, fracture characterization parameters, reservoir porosity, and permeability.

[0011] In some embodiments, a time-shifted seismic physical simulation experimental method for reservoir development further includes:

[0012] The types of rock skeleton particles and clay minerals in the reservoir physical model are determined based on the reservoir structure and reservoir pore structure.

[0013] The content ratio of the rock skeleton particles to the clay minerals is determined based on the reservoir porosity and permeability.

[0014] In some embodiments, the preparation of a reservoir physical model based on predetermined target reservoir physical parameters includes:

[0015] The rock skeleton particles and the clay minerals are heated and mixed according to the specified content ratio to prepare the initial model of the reservoir physical model;

[0016] The initial model after heating and mixing is cut with fractures according to the fracture characterization parameters to prepare the reservoir physical model.

[0017] In some embodiments, the reservoir physical model is encapsulated within an epoxy resin layer to form an integral physical model, including:

[0018] Fill the water tank with epoxy resin of a first preset thickness;

[0019] After the epoxy resin dries, the reservoir physical model is placed; wherein the distance between the reservoir physical model and the left and right sides of the water tank is greater than a preset distance;

[0020] Continue filling with epoxy resin until it submerges the top of the reservoir physical model to a second preset thickness.

[0021] In some embodiments, a time-shifted seismic physical simulation experimental method for reservoir development further includes:

[0022] The residual oil saturation of the reservoir physical model is changed by connecting at least one fluid displacement system and at least one fluid separation and metering system connected to the reservoir physical model; wherein, the fluid displacement system is connected to the reservoir physical model through a first fluid pipe, the fluid separation and metering system is connected to the reservoir physical model through a second fluid pipe, and the first fluid pipe corresponds one-to-one with the fluid displacement system; the second fluid pipe corresponds one-to-one with the fluid separation and metering system.

[0023] In some embodiments, determining time-lapse seismic experimental data of the reservoir physical model at different remaining oil saturations includes:

[0024] Time-lapse seismic experimental data of the reservoir physical model at different residual oil saturation levels were acquired using a three-coordinate seismic physical simulation data acquisition system; wherein, the excitation probe and the receiving probe of the three-coordinate seismic physical simulation data acquisition system were set on the water surface of the water tank.

[0025] At least one embodiment of the present invention also provides an experimental apparatus for time-lapse seismic physical simulation of reservoir development, comprising:

[0026] The reservoir physical model preparation module is used to prepare a reservoir physical model based on the pre-determined physical property parameters of the target reservoir.

[0027] The overall physical model forming module is used to encapsulate the reservoir physical model into an epoxy resin layer to form an overall physical model.

[0028] The time-lapse seismic experimental data measurement module is used to measure time-lapse seismic experimental data under different remaining oil saturation of the reservoir physical model, so as to establish the mapping relationship between the remaining saturation of the target reservoir and the time-lapse seismic data.

[0029] At least one embodiment of the present invention also provides an electronic device, comprising: at least one processor; and a memory communicatively connected to the at least one processor; wherein the memory stores instructions executable by the at least one processor, the instructions being executed by the at least one processor to enable the at least one processor to perform the above-described method for time-lapse seismic physical simulation of reservoir development.

[0030] At least one embodiment of the present invention also provides a computer-readable storage medium storing a computer program that, when executed by a processor, implements the above-described method for time-shifted seismic physical simulation of reservoir development.

[0031] An embodiment of the present invention provides a time-lapse seismic physical simulation experimental method for reservoir development, comprising: first, preparing a reservoir physical model based on predetermined physical property parameters of a target reservoir; next, encapsulating the reservoir physical model within an epoxy resin layer to form an integral physical model; and finally, measuring time-lapse seismic experimental data of the reservoir physical model at different remaining oil saturations to establish a mapping relationship between the remaining saturation of the target reservoir and the time-lapse seismic data.

[0032] An embodiment of the present invention also provides an experimental apparatus for time-lapse seismic physics simulation of reservoir development, comprising: a reservoir physical model preparation module, used to prepare a reservoir physical model based on predetermined target reservoir physical parameters; an overall physical model forming module, used to encapsulate the reservoir physical model within an epoxy resin layer to form an overall physical model; and a time-lapse seismic experimental data measurement module, used to measure time-lapse seismic experimental data of the reservoir physical model at different remaining oil saturations, so as to establish a mapping relationship between the remaining saturation of the target reservoir and the time-lapse seismic data.

[0033] This invention enables the simultaneous conduct of multiple time-lapse seismic observations during experiments involving different fluid displacements in reservoir physical models. This allows for the acquisition of time-lapse seismic experimental data at different development stages of the reservoir. By processing and analyzing this data, the remaining oil distribution patterns in the reservoir physical model can be characterized, providing a reference for reservoir development scheme design and offering a new experimental method for improving oil recovery. Attached Figure Description

[0034] One or more embodiments are illustrated by way of example with reference to the accompanying drawings, and these illustrative descriptions do not constitute a limitation on the embodiments.

[0035] It should be noted that the accompanying drawings are for illustrative purposes only and should not be construed as limiting the scope of this patent. To better illustrate this embodiment, some components in the drawings may be omitted, enlarged, or reduced, and do not represent the actual dimensions of the product. It is understandable to those skilled in the art that some well-known structures and their descriptions may be omitted in the drawings. The same or similar reference numerals correspond to the same or similar components. The terms describing positional relationships in the drawings are for illustrative purposes only and should not be construed as limiting the scope of this patent.

[0036] Figure 1 This is a schematic flowchart of an experimental method for time-lapse seismic physical simulation of reservoir development provided by an embodiment of the present invention;

[0037] Figure 2 This is a schematic flowchart of another reservoir development time-shift seismic physical simulation experimental method provided by an embodiment of the present invention;

[0038] Figure 3This is a flowchart illustrating step 100 provided in one embodiment of the present invention;

[0039] Figure 4 This is a flowchart illustrating step 200 provided in one embodiment of the present invention;

[0040] Figure 5 This is a flowchart illustrating a time-lapse seismic physical simulation experimental method for reservoir development, provided by a specific embodiment of the present invention.

[0041] Figure 6 This is a schematic diagram of an experimental apparatus for time-lapse seismic physical simulation of reservoir development provided in an embodiment of the present invention;

[0042] Figure 7 This is a schematic diagram of the structure of an electronic device provided in another embodiment of the present invention. Detailed Implementation

[0043] To make the objectives, technical solutions, and advantages of the embodiments of the present invention clearer, the various embodiments of the present invention will be described in detail below with reference to the accompanying drawings. However, those skilled in the art will understand that many technical details are presented in the embodiments of the present invention to facilitate a better understanding of the invention. However, the technical solutions claimed in the present invention can be implemented even without these technical details and various variations and modifications based on the following embodiments. The division of the following embodiments is for ease of description and should not constitute any limitation on the specific implementation of the present invention. The various embodiments can be combined with and referenced by each other without contradiction.

[0044] First, let's introduce the technical challenges of applying time-shift seismic technology in existing technologies. It's understandable that oil reservoir development typically involves three stages: primary recovery relies on the formation's own energy to drive oil flow; secondary recovery replenishes energy by injecting water or gas into the formation to extract remaining oil; and tertiary recovery, following secondary recovery, further extracts remaining oil by injecting chemicals, gases, or heat. Therefore, improving oil recovery is crucial for oil and gas field development. Data shows that for every 1% increase in recovery rate in developed onshore oil fields, recoverable reserves can increase by several hundred million tons, equivalent to discovering a large oil field with geological reserves exceeding 1 billion tons. Oil and gas companies have conducted continuous research on improving oil recovery rates through various displacement methods, such as water-drive, gas-drive, and chemical-drive, in response to the various challenges faced in oil field development.

[0045] Time-lapse seismic surveys, also known as 4D seismic surveys, are a geophysical exploration technique primarily used to monitor changes in oil and gas reservoirs over time. This technique involves repeatedly conducting 3D seismic surveys at different time points and comparing the results to observe dynamic changes in underground reservoirs. These changes may be caused by oil and gas extraction, water injection, gas injection, carbon dioxide sequestration, or the activity of other underground fluids.

[0046] The core principles of time-shifted earthquakes include:

[0047] 3D seismic exploration: First, a detailed 3D seismic exploration is conducted to obtain seismic data under initial conditions. This data serves as a baseline for comparison with data from subsequent time points.

[0048] Repeated exploration: The same 3D seismic exploration is performed periodically on the same area over time. These repeated seismic explorations provide seismic datasets at different points in time.

[0049] Data Comparison and Analysis: By comparing seismic data from different time points, changes in underground reservoirs can be identified. These changes may manifest as variations in wave velocity, reflection coefficient, or seismic amplitude.

[0050] Time-shift seismic technology has the following main applications: monitoring changes in oil and gas reservoirs to optimize extraction strategies and improve recovery rates; assessing the effectiveness of water or gas injection to ensure its expansion within the expected area; monitoring the diffusion of injected carbon dioxide to ensure its safe storage; and understanding the dynamic changes of underground thermal reservoirs to optimize geothermal energy extraction. However, this technology also faces the following technical challenges:

[0051] The effectiveness of this method for thin reservoirs with high water content is unclear, and repeated 3D seismic exploration is costly. Furthermore, it requires processing large amounts of seismic data and performing precise comparisons and analyses. Finally, changes in the external environment may interfere with the seismic data, necessitating effective noise reduction.

[0052] Example 1:

[0053] For the reasons stated above, the reservoir development time-lapse seismic physical simulation experimental method of this embodiment can be applied to electronic devices with communication, computing, and data storage capabilities. Its specific process can be as follows: Figure 1 As shown, it includes:

[0054] Step 100: Prepare a physical model of the reservoir based on the predetermined physical property parameters of the target reservoir;

[0055] Step 200: Encapsulate the reservoir physical model within an epoxy resin layer to form an integral physical model;

[0056] Step 300: Measure the time-lapse seismic experimental data of the reservoir physical model under different residual oil saturation to establish the mapping relationship between the residual saturation of the target reservoir and the time-lapse seismic data.

[0057] An embodiment of the present invention provides a time-lapse seismic physical simulation experimental method for reservoir development, comprising: first, preparing a reservoir physical model based on predetermined physical property parameters of a target reservoir; next, encapsulating the reservoir physical model within an epoxy resin layer to form an integral physical model; and finally, measuring time-lapse seismic experimental data of the reservoir physical model at different remaining oil saturations to establish a mapping relationship between the remaining saturation of the target reservoir and the time-lapse seismic data.

[0058] Compared with existing technologies, this invention overcomes the drawbacks of high costs and difficulty in repeating time-lapse seismic data acquisition during actual reservoir development, such as the difficulty in achieving complete parameter replication. It enables the acquisition, processing, and analysis of time-lapse seismic experimental data during reservoir development and displacement processes under identical acquisition conditions, characterizing the distribution patterns of remaining oil. Furthermore, it establishes the relationship between remaining oil distribution and development parameters such as displacement fluid type, velocity, and process parameters, helping to adjust reservoir development strategies and improve reservoir recovery.

[0059] For step 100, a physical model is designed based on the physical properties of the target reservoir and the reservoir morphology to be simulated. The reservoir physical model is fabricated using powder 3D printing equipment or powder bonding pressing method, and the reservoir physical model morphology is processed according to the design drawings.

[0060] For step 200, the reservoir physical model is fixed and poured into the epoxy resin. This can be done by layer-by-layer pouring or one-time pouring, so that the reservoir physical model is completely embedded in the epoxy resin layer.

[0061] Epoxy resins are used to seal fluids in reservoir physical models, allowing them to flow in and out through pre-defined channels. Epoxy resins are a class of highly reactive and high-performance synthetic resins. They are materials cured by cross-linking reactions of epoxy compounds (epoxy groups reacting with polyols or polyamines).

[0062] The basic chemical structure of epoxy resin contains epoxy groups (-COC-). These epoxy groups react with the hardener during the resin curing process to form a three-dimensional cross-linked network structure. The curing process of epoxy resin is a chemical reaction, typically involving the reaction of epoxy groups with hardeners such as amines, acid anhydrides, and phenols to generate cross-linked polymer chains. Key characteristics of epoxy resin:

[0063] Excellent mechanical properties: It has high strength, hardness, rigidity and wear resistance.

[0064] Excellent chemical resistance: It can withstand the erosion of a variety of chemicals, such as acids, alkalis, and solvents.

[0065] Excellent electrical insulation: In electrical applications, epoxy resin is widely used in the encapsulation of electronic components and electrical appliances to provide good electrical insulation properties.

[0066] Excellent adhesion: Epoxy resin can adhere firmly to a variety of material surfaces, such as metal, glass, wood, and concrete.

[0067] Heat resistance: Epoxy resin has good heat resistance and is suitable for use in high-temperature environments.

[0068] Low shrinkage rate: Epoxy resin has low volume shrinkage during curing, which helps maintain the dimensional stability of the material.

[0069] Preferably, the epoxy resin used in this invention is an aliphatic epoxy resin (obtained by reacting aliphatic compounds (such as fatty alcohols) with epoxy compounds, which generally has good flexibility and low shrinkage).

[0070] For step 300, after the experimental equipment is fully installed, the equipment is started, and the i-th fluid displacement experiment is carried out according to the predetermined experimental plan. The oil displacement fluid is injected into the overall physical model by the fluid displacement system. The fluid begins to drive the crude oil flow within the overall physical model. The driven crude oil and other fluids gradually enter the fluid separation and metering system, where each fluid is separated and metered. When the metering equipment shows no crude oil outflow, the current displacement is considered to be over. At this time, the i-th time-shifted seismic experiment data (i at least greater than 2) is collected using the three-coordinate seismic physical simulation data acquisition system according to the same observation system.

[0071] Example 2:

[0072] In some embodiments, the physical properties include: reservoir structure, reservoir pore structure, fracture characterization parameters, reservoir porosity, and permeability.

[0073] Reservoir structure refers to the overall geometric morphology of reservoir rocks, including the arrangement, dip angle, folds, faults, and structural features of the rocks. The influence of reservoir structure is mainly reflected in the following aspects:

[0074] Spatial distribution: The size, shape and distribution of reservoirs affect the location and extent of oil and gas accumulation.

[0075] Fluid storage capacity: The structure of the reservoir determines how oil and gas are stored underground.

[0076] Flow path: The structure of fractures or pores in the reservoir affects the flow path and efficiency of oil and gas.

[0077] The pore structure of a reservoir refers to the distribution, morphology, and connectivity of pores within the reservoir. Pore structure includes the following aspects:

[0078] Porosity: refers to the ratio of pore volume to total rock volume, and is a key parameter for measuring the reservoir's ability to store oil and gas.

[0079] Pore ​​connectivity: The interconnectivity of reservoir pores has a significant impact on fluid flow. Good pore connectivity promotes oil and gas flow and increases permeability.

[0080] Pore ​​morphology: The morphology of pores (such as circular, elliptical, irregular, etc.) directly affects the fluid accumulation and flow patterns of the reservoir.

[0081] Fractures play a crucial role in many oil and gas reservoirs, providing pathways for oil and gas flow. Fracture characterization parameters include:

[0082] Crack density: The number of cracks per unit volume. A crack system with higher density has higher permeability.

[0083] Crack length: The length of a crack directly affects its fluid conduction capacity.

[0084] Crack width: The width of a crack affects the rate of fluid flow. Wider cracks have higher permeability.

[0085] Fracture orientation: The orientation (direction) of a fracture determines its impact on fluid flow. When the fracture is aligned with the flow direction of oil and gas, the fluidity is better.

[0086] Fracture connectivity: Fracture connectivity affects the migration and accumulation of oil and gas in the reservoir. When the connectivity between fractures is strong, the oil and gas flow is better.

[0087] Porosity refers to the percentage of pore volume in the total volume of a rock, and is an important parameter for measuring the reservoir's ability to store fluids (oil, gas, or water). Types of porosity include:

[0088] Effective porosity: The actual pore volume that can hold fluid, excluding pores that cannot store fluid.

[0089] Total porosity: The sum of all pores in a rock, including non-flowing pores.

[0090] Permeability is a parameter that measures the ability of a fluid (such as oil, gas, or water) to flow through rock, and is measured in millidarcy (mD) or Darcy (D). Permeability depends not only on porosity but is also influenced by factors such as pore structure, fracture system, and rock composition. Factors affecting permeability include:

[0091] Pore ​​connectivity: The better the connection between pores, the higher the permeability.

[0092] Pore ​​size and shape: The larger the pores, the lower the resistance to fluid flow and the higher the permeability.

[0093] The presence of fractures: Fractures can significantly increase reservoir permeability, especially in rocks with low porosity.

[0094] In some embodiments, see Figure 2 An experimental method for time-lapse seismic physical simulation of oil reservoir development, further comprising:

[0095] Step 400: Determine the type of rock skeleton particles and clay minerals in the reservoir physical model based on the reservoir structure and reservoir pore structure;

[0096] Step 500: Determine the content ratio of the rock skeleton particles to the clay minerals based on the reservoir porosity and permeability.

[0097] The higher the ratio of framework particles to clay minerals in a rock, the greater its porosity and permeability. Specifically:

[0098] High porosity: Since the framework particles such as quartz and feldspar are usually hard and large, the resulting pore structure is relatively open, which is conducive to increasing porosity.

[0099] High permeability: The presence of framework particles helps to form a more uniform and well-connected pore structure, thus resulting in high permeability.

[0100] High clay mineral content, low skeleton particle content:

[0101] Low porosity: The presence of clay minerals in rocks can fill or seal pores, reducing porosity.

[0102] Low permeability: Clay minerals typically result in poor pore connectivity, forming a barrier that hinders fluid flow, thus significantly reducing permeability.

[0103] By using experimental data (such as porosity and permeability) and rock physics models, the ratio of rock skeleton particles to clay minerals can be quantitatively estimated. Specifically, this can be achieved through the following steps:

[0104] In rock physics models, the relationship between porosity and permeability is used to estimate the proportion of framework grains and clay minerals in rocks. Models include the Winland R37 model (for rocks such as sandstone) and the Kozeny-Carman equation (related to pore structure and grain morphology).

[0105] By using regression analysis of experimental data (such as porosity and permeability), a quantitative relationship can be established between porosity and permeability and the content of framework particles and clay minerals.

[0106] For example, the empirical formula relating permeability and porosity can be used to inversely estimate the ratio of framework particles to clay minerals in a reservoir. For instance, if the porosity and permeability of a rock sample are known, the ratio of framework particles to clay minerals can be estimated by combining the petrological characteristics of the reservoir (such as XRD analysis results).

[0107] Rock physics models based on porosity and permeability: Some rock physics models, such as the "Bernabé model" and the "Sharma model", take into account the influence of framework particles and clay mineral content on permeability and porosity. The mineral composition ratio of rocks can be calculated through these models.

[0108] In some embodiments, see Figure 3 Step 100 includes:

[0109] Step 101: Heat and mix the rock skeleton particles and the clay minerals according to the specified content ratio to prepare the initial model of the reservoir physical model;

[0110] Specifically, clay minerals and distilled water are mixed in a preset ratio (which can be determined by the type of clay minerals) to form a clay mineral suspension; rock skeleton particles and clay mineral suspension are mixed and heated so that the clay minerals adhere to the rock skeleton particles; the rock skeleton object with clay minerals attached is filled into the sand-filling pipe to obtain the initial model of the reservoir physical model.

[0111] Step 102: Cut the initial model after heating and mixing according to the fracture characterization parameters to prepare the reservoir physical model.

[0112] In some embodiments, see Figure 4 Step 200 includes:

[0113] Step 201: Fill the water tank with epoxy resin of a first preset thickness;

[0114] Step 202: After the epoxy resin dries, place the reservoir physical model; wherein the distance between the reservoir physical model and the left and right sides of the water tank is greater than a preset distance;

[0115] Step 203: Continue filling epoxy resin until it submerges the top of the reservoir physical model to a second preset thickness.

[0116] The reservoir physical model is fixed and cast into the epoxy resin. This can be done layer by layer or in a single casting process, ensuring the reservoir physical model is completely embedded within the epoxy resin layer. The distance between the reservoir physical model and the top and bottom layers of the epoxy resin should be no less than 1 cm. That is, the second preset thickness should be no less than 1 cm, and the preferred preset distance is 3 cm.

[0117] In some embodiments, a time-shifted seismic physical simulation experimental method for reservoir development further includes:

[0118] The residual oil saturation of the reservoir physical model is changed by connecting at least one fluid displacement system and at least one fluid separation and metering system connected to the reservoir physical model; wherein, the fluid displacement system is connected to the reservoir physical model through a first fluid pipe, the fluid separation and metering system is connected to the reservoir physical model through a second fluid pipe, and the first fluid pipe corresponds one-to-one with the fluid displacement system; the second fluid pipe corresponds one-to-one with the fluid separation and metering system.

[0119] Preferably, the seismic physical model data acquisition system is a three-coordinate seismic physical simulation data acquisition system, used to acquire time-lapse seismic experimental data of the overall physical model above the water tank. Specifically, after the experimental equipment is fully installed, the equipment is started, and the i-th fluid displacement experiment is carried out according to the predetermined experimental plan. The oil displacement fluid is injected into the overall physical model by the fluid displacement system. The fluid begins to drive the crude oil flow within the overall physical model. The driven crude oil and other fluids gradually enter the fluid separation and metering system, where each fluid is separated and metered. When the metering equipment shows no crude oil outflow, the current displacement is considered to be over. At this point, the three-coordinate seismic physical simulation data acquisition system is used to acquire the i-th time-lapse seismic experimental data according to the same observation system.

[0120] In some embodiments, the fluid separation and metering system includes: a second pressure pump, a fluid separation device for different phases, a fluid metering device for different phases, and a waste liquid collection tank.

[0121] In some embodiments, the fluid displacement system connection includes: a fluid storage tank, a first pressure pump, a metering device, and a fluid capable of quantitatively injecting water, nitrogen, carbon dioxide, and a mixture of the quantitatively injectable water, nitrogen, and carbon dioxide.

[0122] In some embodiments, step 300 includes:

[0123] Time-lapse seismic experimental data at different remaining oil saturation levels of the reservoir physical model were acquired using a three-coordinate seismic physical simulation data acquisition system. The excitation and receiving probes of the three-coordinate seismic physical simulation data acquisition system were positioned on the water surface of the water tank. Then, after processing the time-lapse seismic experimental data from multiple observations using the same procedure and parameters, the distribution pattern of the remaining oil was characterized by subtracting the final imaging results, thus providing a reference for adjusting the development plan.

[0124] The ultrasonic excitation and receiving probes of the three-coordinate seismic physics simulation data acquisition system are placed close to the water surface of the tank to acquire time-lapse seismic experimental data, which can effectively reduce noise interference such as multiple waves. The time-lapse seismic experimental data observation system can be configured as a variety of seismic observation systems, such as fixed offset observation, two-dimensional seismic observation, and three-dimensional seismic observation.

[0125] Fixed offset observation is applied in 2D seismic exploration. Its basic characteristic is that the distance (offset) between the observation point (receiver) and the seismic source remains constant. The observer is arranged along a fixed line to collect information on the reflection and propagation of seismic waves. This method acquires data by fixing the source location and the receiver array, and is mainly used for seismic wave reflection exploration.

[0126] After the earthquake source generates seismic waves, these waves propagate in the underground medium and are reflected back when they encounter different strata boundaries. The receiver receives these reflected waves and records them.

[0127] Two-dimensional seismic surveys are techniques that use seismic waves to survey a two-dimensional plane on the ground or seabed. Two-dimensional seismic exploration involves arranging seismic sources and receivers along a linear path to detect underground geological structures.

[0128] In two-dimensional seismic exploration, the seismic source and receiver are arranged along a straight line, typically a single ray path (i.e., the collected seismic wave data is one-dimensional), thus obtaining a "two-dimensional" image of the subsurface structure. The seismic source sends seismic waves, which propagate through the subsurface medium and reflect back. The receiver records the data of these reflected waves, and seismic data processing techniques are then used to construct a two-dimensional image of the subsurface geological structure. Data processing and interpretation typically yield subsurface depth profiles, providing information on bedding, faults, and structures. Two-dimensional seismic exploration is relatively simple in terms of cost and data processing, making it suitable for rapid screening and exploration.

[0129] Three-dimensional seismic observation is a seismic exploration technique that provides three-dimensional images of the underground geological structure by conducting more comprehensive seismic wave detection within the underground space. Unlike two-dimensional seismic exploration, three-dimensional seismic exploration does not simply arrange seismic sources and receivers along straight lines, but rather conducts surveys through a grid system composed of multiple ray paths.

[0130] 3D seismic observation involves arranging seismic sources and receivers within a three-dimensional spatial grid. Each source and receiver records reflected wave data at different times and locations. By analyzing this seismic data from different angles, a three-dimensional image of the subsurface geological structure can be constructed. During data processing, computers combine different observational data and employ complex seismic data processing techniques (such as inversion, filtering, and velocity model construction) to generate subsurface geological models. It is primarily applied to complex oil and gas exploration, mineral exploration, and engineering surveys, especially under complex geological conditions. It can accurately depict subsurface 3D structures, analyze complex geological features such as strata, faults, and folds, and help make more accurate exploration decisions.

[0131] In a seismic exploration system, the receiving probe (also known as a seismic receiver or seismograph) and the excitation probe (also known as a seismic source) are key components that work together to collect and analyze information about the underground geological structure.

[0132] A receiving probe is a device used to receive seismic waves (especially reflected and refracted waves) and convert them into electrical signals. After signal processing, the received seismic wave information is used to construct geological models of the subsurface medium and analyze characteristics such as stratigraphic structure, lithology, and faults.

[0133] The working principle of a receiving probe is to convert the mechanical vibrations of seismic waves into electrical signals. Based on different working principles, receiving probes can be mainly classified into the following types:

[0134] Piezoelectric receiver: Through the piezoelectric effect, seismic waves act on the piezoelectric crystal, causing the crystal to generate charges, thereby generating electrical signals.

[0135] Electromagnetic receiver: Utilizing the principle of electromagnetic induction, seismic waves cause relative motion between a coil and a magnetic field, thereby generating an electrical signal.

[0136] Seismic accelerometer: Records changes in seismic waves by measuring the acceleration of vibrations.

[0137] A seismic source (excitation probe) is a device used to generate seismic waves. It induces the propagation of seismic waves by exciting vibrations in the subsurface medium (such as rock or soil). These seismic waves propagate through the subsurface medium, are reflected or refracted back, and are received and recorded by a receiving probe.

[0138] An embodiment of the present invention provides a time-lapse seismic physical simulation experimental method for reservoir development, comprising: first, preparing a reservoir physical model based on predetermined physical property parameters of a target reservoir; next, encapsulating the reservoir physical model within an epoxy resin layer to form an integral physical model; and finally, measuring time-lapse seismic experimental data of the reservoir physical model at different remaining oil saturations to establish a mapping relationship between the remaining saturation of the target reservoir and the time-lapse seismic data.

[0139] The present invention has the following beneficial effects:

[0140] (1) It overcomes the disadvantages of high cost of multiple acquisitions of time-shifted seismic data in actual reservoir development process and difficulty in repeating acquisition of complete parameters. It can acquire time-shifted seismic experimental data of reservoir development and displacement process under completely identical acquisition conditions.

[0141] (2) By processing and analyzing the time-shifted seismic experimental data collected multiple times during the reservoir development and displacement process, the distribution pattern of remaining oil can be characterized;

[0142] (3) This invention can establish the relationship between the distribution of remaining oil and development parameters such as displacement fluid type, flow rate, and process through physical model experiments, which helps to adjust the reservoir development plan and improve the reservoir recovery rate.

[0143] Example 3:

[0144] For further explanation of the plan, see Figure 5 The present invention also provides a specific implementation method for a time-shifted seismic physical simulation experiment method for oil reservoir development, which specifically includes the following contents.

[0145] S1: Create and process reservoir physical models, and saturate the physical models with crude oil;

[0146] Specifically, firstly, a physical model is designed based on the reservoir morphology to be simulated, and then the reservoir physical model is fabricated using powder 3D printing equipment or powder bonding pressing method. Finally, the reservoir physical model is processed according to the design drawings.

[0147] Next, the prepared reservoir physical model is immersed in a container filled with crude oil, and a vacuum method is used to saturate the model with crude oil. First, an appropriate crude oil sample is selected, preferably crude oil or simulated oil similar to the target reservoir, to ensure that its physical properties such as viscosity and density match those of the oil in the actual reservoir.

[0148] Carefully immerse the reservoir physical model into a container filled with crude oil. This container can be a transparent glass or plastic tank for easy observation. Ensure the model is completely submerged in the crude oil, avoiding any air bubbles or areas not covered by crude oil.

[0149] Connect the container and vacuum equipment via appropriate piping. Ensure the system is well-sealed and free of air leaks. Turn on the vacuum pump and gradually extract the air from the container, reducing the pressure inside. As the pressure decreases, the gas inside the reservoir model will be gradually removed. In a vacuum environment, due to the lower external pressure, the gas inside the model will be expelled, and crude oil will permeate into the pores of the model, gradually replacing the air or other gases. This process simulates the flow and accumulation of oil and gas. The vacuum treatment needs to be maintained for a certain period until the model is completely saturated, ensuring that the reservoir model is completely filled with crude oil and that the pores no longer contain any gas.

[0150] After vacuuming is complete, the pressure inside the container can be gradually restored to normal levels. If simulating a high-pressure reservoir environment is required, the pressure can also be adjusted at this stage. The following points should be noted during the above process:

[0151] Before using this method, ensure that the porosity of the reservoir model matches that of the actual reservoir to avoid uneven distribution of crude oil within the model.

[0152] During the vacuuming process, it is important to control the rate of pressure change to avoid damage to the model or container caused by rapid pressure changes.

[0153] The properties of crude oil have a significant impact on experimental results. Crude oil types that match the actual oil reservoirs should be selected, especially in terms of viscosity, density, and fluidity.

[0154] S2: Encapsulate the reservoir physical model within an epoxy resin layer to form a complete model;

[0155] The reservoir physical model is fixed and poured into the epoxy resin, with the distance between the reservoir physical model and the top and bottom layers of the epoxy resin not less than 1 cm.

[0156] S3: After making a hole on the side of the model to a certain depth, drill vertically to the top surface of the reservoir physical model;

[0157] After the epoxy resin has fully cured, holes are drilled to a certain depth on the side of the epoxy resin model, and then vertically drilled to the top surface of the reservoir physical model. At one end of the model, n drilling points Z1-Zn are set to simulate injection wells, and at the other end, m drilling points C1-Cm are set to simulate development wells, where n≥1 and m≥1.

[0158] S4: Connect the physical model after the hole is opened to the fluid displacement system and the fluid separation and metering system through pipes;

[0159] Drilling points Z1-Zn are connected to the fluid displacement system via pipelines, and drilling points C1-Cm are connected to the fluid separation and metering system. The fluid displacement system can quantitatively inject different types of fluids such as water, nitrogen, and carbon dioxide, and can accurately measure the amount of fluid injected. The fluid displacement system can simulate different reservoir development schemes, such as fluid displacement at different flow rates and using different fluid displacement methods. The fluid separation and metering system can separate the displaced crude oil, water, nitrogen, and other fluids, and can accurately measure each type of fluid.

[0160] S5: Immerse the physical model (an integral model consisting of a reservoir physical model and epoxy resin) in a water tank filled with water;

[0161] The physical model is submerged in a water tank filled with clean water (the water tank should contain air bubbles removed), and the water level is at least 1 cm higher than the physical model.

[0162] S6: Conduct the i-th fluid displacement experiment. After the displacement is completed, use the three-coordinate seismic physical simulation data acquisition system to collect the i-th time-shifted seismic experiment data according to the same observation system.

[0163] The ultrasonic excitation and receiving probes of the three-coordinate seismic physics simulation data acquisition system are placed close to the water surface of the tank to acquire time-shifted seismic experimental data, which can effectively reduce noise interference such as multiple waves.

[0164] The i-th fluid displacement experiment is conducted first. Once no crude oil remains to be measured in the fluid separation and metering system, the current fluid displacement cycle is considered complete, and time-lapse seismic data acquisition can begin. The ultrasonic excitation and receiving probes of the three-coordinate seismic physical simulation data acquisition system are placed close to the water surface of the tank for time-lapse seismic data acquisition, effectively reducing noise interference such as multiple waves. The observation system can be configured as various seismic observation systems, including fixed-offset observation, two-dimensional seismic observation, and three-dimensional seismic observation.

[0165] In addition, when conducting the i-th fluid displacement experiment, the reservoir development schemes such as different types of fluid displacement, different flow rates of fluid displacement, and different methods of fluid displacement can be simulated by adjusting the fluid displacement system. This helps to establish the relationship between the remaining oil distribution and development parameters such as displacement fluid type, flow rate, and process, and helps to adjust the reservoir development scheme.

[0166] S7: Process and analyze experimental seismic data collected multiple times to characterize the distribution pattern of remaining oil in the model and propose adjustments to the development plan to improve recovery rate.

[0167] After processing time-shifted seismic experimental data from multiple observations using the same procedures and parameters, the distribution pattern of remaining oil can be characterized by subtracting the final imaging results, thus providing a reference for adjusting development plans.

[0168] An embodiment of the present invention provides a time-lapse seismic physical simulation experimental method for reservoir development, comprising: first, preparing a reservoir physical model based on predetermined physical property parameters of a target reservoir; next, encapsulating the reservoir physical model within an epoxy resin layer to form an integral physical model; and finally, measuring time-lapse seismic experimental data of the reservoir physical model at different remaining oil saturations to establish a mapping relationship between the remaining saturation of the target reservoir and the time-lapse seismic data.

[0169] Specifically, this invention combines two experimental methods—reservoir development physical simulation and seismic physical simulation—to form a time-lapse seismic physical simulation experimental method for reservoir development. This method includes the following steps: fabricating and processing a reservoir physical model; encapsulating the reservoir physical model within an epoxy resin layer; drilling holes vertically to the top surface of the model after opening holes on its side; connecting the perforated physical model to a fluid displacement system and a fluid separation and metering system; immersing the physical model in a water-filled tank to conduct displacement experiments; collecting time-lapse seismic experimental data using the same observation system after each displacement; and processing and analyzing the collected seismic data to characterize the distribution pattern of remaining oil in the model. This method can establish the relationship between the distribution of remaining oil and development parameters such as displacement fluid type, flow rate, and process parameters, helping to adjust reservoir development plans and improve reservoir recovery.

[0170] Compared with existing technologies, this invention overcomes the disadvantages of high cost of multiple acquisitions of time-lapse seismic data in actual reservoir development processes and difficulty in repeating acquisitions of complete parameters. It can acquire, process and analyze time-lapse seismic experimental data of reservoir development and displacement processes under completely identical acquisition conditions, and characterize the distribution law of remaining oil.

[0171] In addition, this invention can establish the relationship between the distribution of remaining oil and development parameters such as displacement fluid type, flow rate, and process, which helps to adjust reservoir development plans and improve reservoir recovery.

[0172] Example 4:

[0173] Another embodiment of the present invention relates to an experimental apparatus for time-lapse seismic physics simulation of oil reservoir development. The implementation details of this experimental apparatus are described below. The following details are provided for ease of understanding and are not essential for implementing this solution. A schematic diagram of the experimental apparatus for time-lapse seismic physics simulation of oil reservoir development in this embodiment can be seen as follows: Figure 6 As shown, there are reservoir physical model preparation module 801, overall physical model formation module 802, and time-shifted seismic experimental data measurement module 803.

[0174] The reservoir physical model preparation module 801 is used to prepare a reservoir physical model based on the pre-determined physical property parameters of the target reservoir.

[0175] The overall physical model forming module 802 is used to encapsulate the reservoir physical model into an epoxy resin layer to form an overall physical model.

[0176] The time-lapse seismic experimental data measurement module 803 is used to measure the time-lapse seismic experimental data of the reservoir physical model under different remaining oil saturation, so as to establish the mapping relationship between the remaining saturation of the target reservoir and the time-lapse seismic data.

[0177] In some embodiments, the physical properties include: reservoir structure, reservoir pore structure, fracture characterization parameters, reservoir porosity, and permeability.

[0178] In some embodiments, an experimental apparatus for time-lapse seismic physical simulation of reservoir development further includes:

[0179] The type determination module is used to determine the type of rock skeleton particles and clay minerals of the reservoir physical model based on the reservoir structure and reservoir pore structure.

[0180] The content ratio determination module is used to determine the content ratio of the rock skeleton particles to the clay minerals based on the reservoir porosity and permeability.

[0181] In some embodiments, the reservoir physical model preparation module 801 includes:

[0182] An initial model preparation unit is used to heat and mix the rock skeleton particles and the clay minerals according to the content ratio to prepare the initial model of the reservoir physical model;

[0183] The reservoir physical model preparation unit is used to cut fractures in the heated and mixed initial model according to the fracture characterization parameters in order to prepare the reservoir physical model.

[0184] In some embodiments, the overall physical model forming module 802 includes:

[0185] The first unit is filled with epoxy resin for filling the water tank with epoxy resin of a first preset thickness.

[0186] An oil reservoir physical model placement unit is used to place the oil reservoir physical model after the epoxy resin has dried; wherein the distance between the oil reservoir physical model and the left and right sides of the water tank is greater than a preset distance;

[0187] The second unit is filled with epoxy resin to continue filling the epoxy resin until it submerges the top of the reservoir physical model to a second preset thickness.

[0188] In some embodiments, an experimental apparatus for time-lapse seismic physical simulation of reservoir development further includes:

[0189] A residual oil saturation changing module is used to change the residual oil saturation of the reservoir physical model through at least one fluid displacement system connected to the reservoir physical model and at least one fluid separation and metering system; wherein, the fluid displacement system is connected to the reservoir physical model through a first fluid pipe, the fluid separation and metering system is connected to the reservoir physical model through a second fluid pipe, and the first fluid pipe corresponds one-to-one with the fluid displacement system; the second fluid pipe corresponds one-to-one with the fluid separation and metering system.

[0190] In some embodiments, the time-shifted seismic experimental data determination module 803 includes:

[0191] The time-lapse seismic experimental data measurement unit is used to acquire time-lapse seismic experimental data of the reservoir physical model under different remaining oil saturation through a three-coordinate seismic physical simulation data acquisition system; wherein, the excitation probe and the receiving probe of the three-coordinate seismic physical simulation data acquisition system are set on the water surface of the water tank.

[0192] An embodiment of the present invention provides an experimental apparatus for time-lapse seismic physics simulation of oil reservoir development, comprising: an oil reservoir physical model preparation module, used to prepare an oil reservoir physical model based on predetermined target oil reservoir physical parameters; an overall physical model forming module, used to encapsulate the oil reservoir physical model within an epoxy resin layer to form an overall physical model; and a time-lapse seismic experimental data measurement module, used to measure time-lapse seismic experimental data of the oil reservoir physical model at different remaining oil saturations, so as to establish a mapping relationship between the remaining saturation of the target oil reservoir and the time-lapse seismic data.

[0193] Compared with existing technologies, this invention overcomes the disadvantages of high cost of multiple acquisitions of time-lapse seismic data in actual reservoir development processes and difficulty in repeating acquisitions of complete parameters. It can acquire, process and analyze time-lapse seismic experimental data of reservoir development and displacement processes under completely identical acquisition conditions, and characterize the distribution law of remaining oil.

[0194] In addition, this invention can establish the relationship between the distribution of remaining oil and development parameters such as displacement fluid type, flow rate, and process, which helps to adjust reservoir development plans and improve reservoir recovery.

[0195] It is worth mentioning that all modules involved in this embodiment are logical modules. In practical applications, a logical unit can be a physical unit, a part of a physical unit, or a combination of multiple physical units. Furthermore, to highlight the innovative aspects of this invention, this embodiment does not introduce units that are not closely related to solving the technical problem proposed by this invention; however, this does not mean that other units are absent from this embodiment.

[0196] Example 5:

[0197] Another embodiment of the present invention relates to an electronic device, such as Figure 7 As shown, the electronic device specifically includes the following:

[0198] Processor 1201, memory 1202, communications interface 1203, and bus 1204;

[0199] The processor 1201, memory 1202, and communication interface 1203 communicate with each other via bus 1204; the communication interface 1203 is used to realize information transmission between server-side devices and user-side devices and other related devices.

[0200] The processor 1201 is used to call the computer program in the memory 1202. When the processor executes the computer program, it implements all the steps in the reservoir development time-shift seismic physical simulation experimental method in the above embodiment. For example, when the processor executes the computer program, it implements the following steps:

[0201] Prepare a physical model of the reservoir based on the predetermined physical property parameters of the target reservoir;

[0202] The reservoir physical model is encapsulated within an epoxy resin layer to form an integral physical model;

[0203] Time-lapsed seismic experimental data were measured at different residual oil saturation levels of the reservoir physical model to establish the mapping relationship between the residual saturation of the target reservoir and the time-lapsed seismic data.

[0204] In some embodiments, the physical properties include: reservoir structure, reservoir pore structure, fracture characterization parameters, reservoir porosity, and permeability.

[0205] In some embodiments, a time-shifted seismic physical simulation experimental method for reservoir development further includes:

[0206] The types of rock skeleton particles and clay minerals in the reservoir physical model are determined based on the reservoir structure and reservoir pore structure.

[0207] The content ratio of the rock skeleton particles to the clay minerals is determined based on the reservoir porosity and permeability.

[0208] In some embodiments, the preparation of a reservoir physical model based on predetermined target reservoir physical parameters includes:

[0209] The rock skeleton particles and the clay minerals are heated and mixed according to the specified content ratio to prepare the initial model of the reservoir physical model;

[0210] The initial model after heating and mixing is cut with fractures according to the fracture characterization parameters to prepare the reservoir physical model.

[0211] In some embodiments, the reservoir physical model is encapsulated within an epoxy resin layer to form an integral physical model, including:

[0212] Fill the water tank with epoxy resin of a first preset thickness;

[0213] After the epoxy resin dries, the reservoir physical model is placed; wherein the distance between the reservoir physical model and the left and right sides of the water tank is greater than a preset distance;

[0214] Continue filling with epoxy resin until it submerges the top of the reservoir physical model to a second preset thickness.

[0215] In some embodiments, a time-shifted seismic physical simulation experimental method for reservoir development further includes:

[0216] The residual oil saturation of the reservoir physical model is changed by connecting at least one fluid displacement system and at least one fluid separation and metering system connected to the reservoir physical model; wherein, the fluid displacement system is connected to the reservoir physical model through a first fluid pipe, the fluid separation and metering system is connected to the reservoir physical model through a second fluid pipe, and the first fluid pipe corresponds one-to-one with the fluid displacement system; the second fluid pipe corresponds one-to-one with the fluid separation and metering system.

[0217] In some embodiments, determining time-lapse seismic experimental data of the reservoir physical model at different remaining oil saturations includes:

[0218] Time-lapse seismic experimental data of the reservoir physical model at different residual oil saturation levels were acquired using a three-coordinate seismic physical simulation data acquisition system; wherein, the excitation probe and the receiving probe of the three-coordinate seismic physical simulation data acquisition system were set on the water surface of the water tank.

[0219] The memory and processor are connected via a bus, which can include any number of interconnecting buses and bridges, connecting various circuits of one or more processors and memories. The bus can also connect various other circuits, such as peripheral devices, voltage regulators, and power management circuits, which are well known in the art and will not be described further herein. The bus interface provides an interface between the bus and the transceiver. The transceiver can be a single element or multiple elements, such as multiple receivers and transmitters, providing a unit for communicating with various other devices over a transmission medium. Data processed by the processor is transmitted over the wireless medium via an antenna, which further receives data and transmits it to the processor.

[0220] The processor manages the bus and general processing, and also provides various functions, including timing, peripheral interfaces, voltage regulation, power management, and other control functions. Memory is used to store data used by the processor during operation.

[0221] Example 6:

[0222] Another embodiment of the present invention relates to a computer-readable storage medium storing a computer program. When executed by a processor, the computer program implements the steps in the above-described embodiment of the reservoir development time-lapse seismic physical simulation experimental method, the steps including:

[0223] Prepare a physical model of the reservoir based on the predetermined physical property parameters of the target reservoir;

[0224] The reservoir physical model is encapsulated within an epoxy resin layer to form an integral physical model;

[0225] Time-lapsed seismic experimental data were measured at different residual oil saturation levels of the reservoir physical model to establish the mapping relationship between the residual saturation of the target reservoir and the time-lapsed seismic data.

[0226] In some embodiments, the physical properties include: reservoir structure, reservoir pore structure, fracture characterization parameters, reservoir porosity, and permeability.

[0227] In some embodiments, a time-shifted seismic physical simulation experimental method for reservoir development further includes:

[0228] The types of rock skeleton particles and clay minerals in the reservoir physical model are determined based on the reservoir structure and reservoir pore structure.

[0229] The content ratio of the rock skeleton particles to the clay minerals is determined based on the reservoir porosity and permeability.

[0230] In some embodiments, the preparation of a reservoir physical model based on predetermined target reservoir physical parameters includes:

[0231] The rock skeleton particles and the clay minerals are heated and mixed according to the specified content ratio to prepare the initial model of the reservoir physical model;

[0232] The initial model after heating and mixing is cut with fractures according to the fracture characterization parameters to prepare the reservoir physical model.

[0233] In some embodiments, the reservoir physical model is encapsulated within an epoxy resin layer to form an integral physical model, including:

[0234] Fill the water tank with epoxy resin of a first preset thickness;

[0235] After the epoxy resin dries, the reservoir physical model is placed; wherein the distance between the reservoir physical model and the left and right sides of the water tank is greater than a preset distance;

[0236] Continue filling with epoxy resin until it submerges the top of the reservoir physical model to a second preset thickness.

[0237] In some embodiments, a time-shifted seismic physical simulation experimental method for reservoir development further includes:

[0238] The residual oil saturation of the reservoir physical model is changed by connecting at least one fluid displacement system and at least one fluid separation and metering system connected to the reservoir physical model; wherein, the fluid displacement system is connected to the reservoir physical model through a first fluid pipe, the fluid separation and metering system is connected to the reservoir physical model through a second fluid pipe, and the first fluid pipe corresponds one-to-one with the fluid displacement system; the second fluid pipe corresponds one-to-one with the fluid separation and metering system.

[0239] In some embodiments, determining time-lapse seismic experimental data of the reservoir physical model at different remaining oil saturations includes:

[0240] Time-lapse seismic experimental data of the reservoir physical model at different residual oil saturation levels were acquired using a three-coordinate seismic physical simulation data acquisition system; wherein, the excitation probe and the receiving probe of the three-coordinate seismic physical simulation data acquisition system were set on the water surface of the water tank.

[0241] The various embodiments in this specification are described in a progressive manner. Similar or identical parts between embodiments can be referred to interchangeably. Each embodiment focuses on its differences from other embodiments. In particular, hardware + program embodiments are relatively simple in description because they are fundamentally similar to method embodiments; relevant parts can be referred to the descriptions in the method embodiments.

[0242] The foregoing has described specific embodiments of this specification. Other embodiments are within the scope of the appended claims. In some cases, the actions or steps recited in the claims may be performed in a different order than that shown in the embodiments and may still achieve the desired result. Furthermore, the processes depicted in the drawings do not necessarily require the specific or sequential order shown to achieve the desired result. In some embodiments, multitasking and parallel processing are possible or may be advantageous.

[0243] While this invention provides method operation steps as shown in the embodiments or flowcharts, more or fewer operation steps may be included based on conventional or non-inventive labor. The order of steps listed in the embodiments is merely one possible execution order among many and does not represent the only possible execution order. In actual device or client product execution, the method can be executed in the order shown in the embodiments or drawings or in parallel (e.g., in a parallel processor or multi-threaded processing environment).

[0244] This invention is described with reference to flowchart illustrations and / or block diagrams of methods, apparatus (systems), and computer program products according to embodiments of the invention. It will be understood that each block of the flowchart illustrations and / or block diagrams, and combinations of blocks in the flowchart illustrations and / or block diagrams, can be implemented by computer program instructions. These computer program instructions can be provided to a processor of a general-purpose computer, special-purpose computer, embedded processor, or other programmable data processing apparatus to produce a machine, such that the instructions, which execute via the processor of the computer or other programmable data processing apparatus, generate instructions for implementing the flowchart illustrations and / or block diagrams. Figure 1 One or more processes and / or boxes Figure 1 A device that provides the functions specified in one or more boxes.

[0245] These computer program instructions may also be stored in a computer-readable storage medium that can direct a computer or other programmable data processing device to function in a particular manner, such that the instructions stored in the computer-readable storage medium produce an article of manufacture including instruction means, which are implemented in a process Figure 1 One or more processes and / or boxes Figure 1 The function specified in one or more boxes.

[0246] These computer program instructions may also be loaded onto a computer or other programmable data processing equipment to cause a series of operational steps to be performed on the computer or other programmable equipment to produce a computer-implemented process, thereby providing instructions that execute on the computer or other programmable equipment for implementing the process. Figure 1 One or more processes and / or boxes Figure 1 The steps of the function specified in one or more boxes.

[0247] Specific embodiments have been used to illustrate the principles and implementation methods of this invention. The descriptions of the embodiments above are only for the purpose of helping to understand the method and core ideas of this invention. At the same time, for those skilled in the art, there will be changes in the specific implementation methods and application scope based on the ideas of this invention. Therefore, the content of this specification should not be construed as a limitation of this invention.

Claims

1. A seismic physical simulation experimental method for reservoir development time-lapse, characterized in that, include: Prepare a physical model of the reservoir based on the predetermined physical property parameters of the target reservoir; The reservoir physical model is encapsulated within an epoxy resin layer to form an integral physical model; Time-lapsed seismic experimental data were measured at different residual oil saturation levels of the reservoir physical model to establish the mapping relationship between the residual saturation of the target reservoir and the time-lapsed seismic data.

2. The experimental method for time-lapse seismic physical simulation of reservoir development according to claim 1, characterized in that, The physical properties include: reservoir structure, reservoir pore structure, fracture characterization parameters, reservoir porosity, and permeability.

3. The experimental method for time-lapse seismic physical simulation of reservoir development according to claim 2, characterized in that, Also includes: The types of rock skeleton particles and clay minerals in the reservoir physical model are determined based on the reservoir structure and reservoir pore structure. The content ratio of the rock skeleton particles to the clay minerals is determined based on the reservoir porosity and permeability.

4. The experimental method for time-lapse seismic physical simulation of reservoir development according to claim 3, characterized in that, The preparation of a reservoir physical model based on predetermined target reservoir property parameters includes: The rock skeleton particles and the clay minerals are heated and mixed according to the specified content ratio to prepare the initial model of the reservoir physical model; The initial model after heating and mixing is cut with fractures according to the fracture characterization parameters to prepare the reservoir physical model.

5. The experimental method for time-lapse seismic physical simulation of reservoir development according to claim 1, characterized in that, The reservoir physical model is encapsulated within an epoxy resin layer to form a complete physical model, including: Fill the water tank with epoxy resin of a first preset thickness; After the epoxy resin dries, the reservoir physical model is placed; wherein the distance between the reservoir physical model and the left and right sides of the water tank is greater than a preset distance; Continue filling with epoxy resin until it submerges the top of the reservoir physical model to a second preset thickness.

6. The experimental method for time-lapse seismic physical simulation of reservoir development according to claim 5, characterized in that, Also includes: The residual oil saturation of the reservoir physical model is changed by connecting at least one fluid displacement system and at least one fluid separation and metering system connected to the reservoir physical model; wherein, the fluid displacement system is connected to the reservoir physical model through a first fluid pipe, the fluid separation and metering system is connected to the reservoir physical model through a second fluid pipe, and the first fluid pipe corresponds one-to-one with the fluid displacement system; the second fluid pipe corresponds one-to-one with the fluid separation and metering system.

7. The experimental method for time-lapse seismic physical simulation of reservoir development according to claim 5, characterized in that, The time-lapse seismic experimental data of the reservoir physical model under different remaining oil saturation levels were determined, including: Time-lapse seismic experimental data of the reservoir physical model at different residual oil saturation levels were acquired using a three-coordinate seismic physical simulation data acquisition system; wherein, the excitation probe and the receiving probe of the three-coordinate seismic physical simulation data acquisition system were set on the water surface of the water tank.

8. An experimental apparatus for simulating the time-lapse seismic motion of oil reservoir development, characterized in that, include: The reservoir physical model preparation module is used to prepare a reservoir physical model based on the pre-determined physical property parameters of the target reservoir. The overall physical model forming module is used to encapsulate the reservoir physical model into an epoxy resin layer to form an overall physical model. The time-lapse seismic experimental data measurement module is used to measure time-lapse seismic experimental data under different remaining oil saturation of the reservoir physical model, so as to establish the mapping relationship between the remaining saturation of the target reservoir and the time-lapse seismic data.

9. An electronic device, characterized in that, include: At least one processor; as well as, A memory communicatively connected to the at least one processor; wherein, The memory stores instructions that can be executed by the at least one processor to enable the at least one processor to perform the reservoir development time-shift seismic physical simulation experimental method as described in any one of claims 1 to 7.

10. A computer-readable storage medium storing a computer program, characterized in that, When the computer program is executed by the processor, it implements the reservoir development time-shift seismic physical simulation experimental method as described in any one of claims 1 to 7.

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