An experimental device for testing water production profile of heterogeneous reservoir sand and evaluating water control effect of compartment filling and application thereof

Abstract

The present application belongs to the technical field of oil and gas development and exploitation engineering, and particularly relates to an experimental device for testing sand-water production profile of heterogeneous reservoir and evaluating water control effect of compartment filling and application thereof. The experimental device comprises a gas supply system, a constant-flow liquid supply system, a data measurement and collection system, a reservoir simulation unit device, a wellbore simulation unit device and a wellbore sand-water production profile quantitative monitoring device. The wellbore simulation unit device is embedded into the reservoir simulation unit device, and the wellbore sand-water production profile quantitative monitoring device is placed in the wellbore simulation unit device. The experimental device can be used for heterogeneous reservoirs, fractured reservoirs and complex depletion patterns, can visually simulate the flow rule of multiphase fluid (oil / gas / water / sand), can test the sand-water production profile of heterogeneous reservoir and evaluate the effect of compartment filling, and can provide experimental basis support for efficient development of oil wells.

Description

Technical Field

[0001] This invention belongs to the technical field of oil and gas development and extraction engineering, specifically relating to an experimental device for testing sand-water production profiles in heterogeneous reservoirs and evaluating the water control effect of compartment filling, and its application. Background Technology

[0002] Loose sandstone reservoirs suffer from severe sand production problems, especially after multiple rounds of sand production control. Near-wellbore reservoirs exhibit various forms of sand production deficits, which are quite complex and severely restrict the effectiveness of sand control. Simultaneously, these reservoirs are highly heterogeneous, facing challenges related to water production and high water cut in oil and gas wells. In actual production, there is a problem of co-production of sand and water. Sand production induces changes in the near-wellbore reservoir structure, which in turn affects the distribution of oil, gas, and water inflow fields, leading to the dynamic evolution of the sand-water production profile.

[0003] Given the increasingly serious problem of water production in oil and gas fields and the urgent need for water stabilization and reduction, horizontal well water control technology has developed rapidly. Based on traditional variable density completion, center tubing, and ICD technologies, recent years have seen the innovative development of new AICD, staged and segmented sand-water synergistic control, particle packing for supersaturated water reduction in fractured reservoirs, and horizontal well compartment / continuous packing for sand control and water control. This has gradually formed a series of sand and water control technologies based on three principles and categories: reservoir horizontal wellbore pressure-energy regulation, staged and segmented sand-water synergistic control in heterogeneous reservoirs, and near-wellbore reservoir oil-water flow resistance regulation. The application of existing water control technologies and sand-water synergistic control technologies all rely on accurate understanding of the water production profile and sand-water production profile.

[0004] The open-hole horizontal well compartmentalized sand and water control technology is based on the existing open-hole gravel packing process. It utilizes specialized tools and equipment such as packers, expandable tubing, multi-stage completion tools, flow control equipment, and bypass isolation separators to divide the open-hole section into multiple independent compartments. Different gravel sizes are filled according to different formation properties, and different sand and water control technologies can be applied to different compartments as needed, thus achieving more precise sand and water control. When there is no need for compartmentalization in the open-hole section, the integrated sand and water control string can be filled as a whole by lowering a sealing cylinder; when compartmentalization is required, a central tube and packers are used for isolation and sealing, thereby achieving mechanical isolation of the small annulus (e.g., Figure 1 (As shown).

[0005] Currently, multi-segment compartmentalized packing technology for sand and water control in open-hole horizontal wells is gradually being applied both domestically and internationally. However, due to the complex actual reservoir conditions of loose sandstone, the compartmentalized packing process for water and sand control struggles to fully consider reservoir heterogeneity and inter-layer flow phenomena. This hinders a comprehensive understanding of the sand and water production profile and its dynamic evolution in open-hole horizontal wells, preventing the revelation of lateral seepage characteristics in near-wellbore reservoirs under different physical properties, and hindering the development of evaluation and optimization methods for the effectiveness of horizontal segment compartmentalization. Furthermore, there are currently no mature methods for optimizing the number, length, location, and associated process parameters of compartmentalized packing sections in open-hole horizontal wells. To achieve experimental simulation of oil-water flow phenomena under different reservoir physical properties and to evaluate the effectiveness of compartmentalization, laboratory experimental simulation is essential, effective, and intuitive.

[0006] The main problems currently existing include:

[0007] (1) For multiphase flow simulation of heterogeneous reservoirs, existing experimental equipment is unable to accurately reproduce the heterogeneous characteristics (such as fracture distribution and abrupt changes in permeability) of fractured carbonate and fractured tight sandstone reservoirs. This results in significant differences between simulated oil / gas / water / sand flow around and crossflow phenomena and those of real reservoirs. For example, the migration paths of oil and water, and oil, gas and water during the compartmentation process of horizontal wells in heterogeneous reservoirs cannot be dynamically visualized, which restricts the optimized design and practical application of water and sand control technologies (such as compartmentalized filling).

[0008] (2) Regarding the dynamic monitoring of sand-water production profiles, existing experimental systems lack distributed observation and quantitative description of the multiphase sand-water transport process. Traditional methods can only infer reservoir dynamics from the total wellhead flow rate, and cannot accurately obtain key parameters such as sand-water transport rates and sand particle size distribution in different reservoir sections into the wellbore. For example, during the implementation of compartmentalized packing technology in open-hole horizontal wells, the differences in the contribution of different reservoir locations to sand-water production cannot be quantitatively characterized, resulting in a lack of experimental support for compartmentalized packing technology parameters (such as gravel gradation and packing strength).

[0009] (3) For near-wellbore reservoir-wellbore coupling, existing experimental systems cannot realize the experimental simulation of the synergistic mechanism of multiphase flow and sand and water control. In gas-water / oil-water / oil-gas-water multiphase flow experiments, existing devices are not adaptable enough to changes in wellbore inclination angle and diameter, making it difficult to quantify the relationship between sand and water production and fluid viscosity and velocity. For example, the sand and water production and sand blockage patterns caused by differences in fluid velocity in different sections of horizontal wells have not been clearly defined experimentally, which limits the precise design of differentiated sand control processes (such as screen assembly and selection of packing materials). Summary of the Invention

[0010] The purpose of this invention is to address the aforementioned deficiencies by providing an experimental device and its application for testing sand-water production profiles and evaluating the water control effect of compartmentalized filling in heterogeneous reservoirs. This experimental device enables full-process experimental simulation of sand-water production, sand and water control, compartmentalized filling, and production optimization under different reservoir types and wellbore inclination angles. It can visually simulate the flow patterns of multiphase fluids (oil / gas / water / sand) in heterogeneous reservoirs, fractured reservoirs, and complex void morphologies, and conduct experiments on testing sand-water production profiles and evaluating the effect of compartmentalized filling in heterogeneous reservoirs, providing experimental foundation support for efficient oil well development.

[0011] This invention is mainly used to simulate the flow and migration of oil, gas and water in heterogeneous reservoirs such as homogeneous / heterogeneous loose sandstone, homogeneous / fractured carbonate rock, and fractured tight sandstone into wellbores with different inclination angles (vertical wells / directional wells / horizontal wells); the staged and segmented oil and water seepage and bypass processes in heterogeneous reservoirs; the production processes of fluids and formation sands into wellbores of different types of reservoirs; the sand and water control processes in horizontal wells with different inclination angles and diameters; and the experimental simulation of reservoir sand and water production and related formation sand and water production profiles. It can conduct experiments to evaluate the water control effect of compartmentalized filling in open-hole horizontal wells, and can achieve visualization and quantitative description of the experimental process and morphology.

[0012] Terminology Explanation:

[0013] 1. Compartmentalized filling: The process of dividing the open hole section of a horizontal well into several independent sections ("compartments"), and each section is individually filled with gravel or chemical sand control.

[0014] 2. Sand-water production: During the mining process, sand particles (rock fragments) in the formation sand layer are carried into the wellbore along with crude oil, water and other fluids.

[0015] 3. Sand and water production profile: The quantity and proportion of sand and liquid produced at different locations in the near-wellbore reservoir.

[0016] The technical solution of this invention is as follows:

[0017] An experimental device for testing sand-water production profiles in heterogeneous reservoirs and evaluating the water control effect of compartmentalized filling includes an air supply system, a constant flow liquid supply system, a data measurement and acquisition system, a reservoir simulation unit device (MFS), a wellbore simulation unit device (WSU), and a wellbore sand-water production profile quantitative monitoring device.

[0018] The wellbore simulation unit device can be embedded into the reservoir simulation unit device at any different tilt angle; the wellbore sand and water production profile quantitative monitoring device is placed in the wellbore simulation unit device.

[0019] The reservoir simulation unit (MFS) is the core module, mainly used to implement the simulation of heterogeneous reservoirs.

[0020] This experimental device, through its innovative design, allows the wellbore simulation unit to be embedded into the reservoir simulation unit at any different tilt angle. It can simulate the fluid flow process outside the horizontal wellbore in heterogeneous reservoirs with different inclinations, and more realistically simulate the interaction effects between the wellbore and the reservoir, such as sand transport, fluid flow around the wellbore, and sand layer blockage. It also works in conjunction with a number of sensors in the data measurement and acquisition system to collect data in real time.

[0021] The quantitative monitoring device for sand and water production profiles in wellbores addresses the current inability to quantitatively characterize sand and water production profiles in horizontal wells of heterogeneous reservoirs. Its design aims to monitor flow rate, pressure, and sand content in different sections of the wellbore, thereby obtaining a quantitative description of sand and water production. It can dynamically monitor and collect sand and water flowing into the wellbore from different locations within the reservoir, thus achieving a quantitative description of sand and water production.

[0022] The gas supply system includes an air compressor, a gas storage tank, gas supply pipelines, and control switches. If there is a need for two-phase or three-phase (oil-gas-water) experiments, the gas supply system must be connected. By connecting a high-pressure gas source, two-phase gas-liquid flow (such as in fractured carbonate gas reservoirs) can be simulated.

[0023] The constant-flow fluid supply system includes a horizontal flow pump, a fluid collector, a fluid supply pipeline, and a control switch. As an auxiliary module, the constant-flow fluid supply system primarily provides sand-carrying water and forms a circulation system for the main device of the full-process simulation experiment of sand production-filling-production. The fluid collector is used to collect the liquid flowing out of the wellbore. The storage tank circulates sand-carrying water to the reservoir simulation unit device through the horizontal flow pump, forming a closed loop of sand production-filling-production. The flow rate of the horizontal flow pump is adjusted to match different experimental stages (such as low sand ratio filling and high sand ratio production).

[0024] The data measurement and acquisition system includes pressure sensors, flow sensors, and a computer acquisition terminal. It is used for dynamic data acquisition and recording during the experiment. The flow sensors and pressure sensors are mainly located at the inlet of the reservoir simulation unit, key side locations, and pipelines at the outlets of the wellbore simulation unit and the reservoir simulation unit. The flow and pressure data are then integrated via the computer acquisition terminal, and a sampling frequency (e.g., once per second) is set to record dynamic changes in real time.

[0025] The reservoir simulation unit (MFS) consists of a cubic chamber with viewing windows at the front and rear, and the cubic chamber is equipped with a sealing cover that can be bolted to it. The main body of the reservoir simulation unit is movably connected to a fixed support.

[0026] The extrusion filling process can be observed through the viewing window of the cubic chamber, and reservoir flow, filling, and sand-water production profiles can be observed after the experiment.

[0027] The fixed support is made of rectangular steel pipes or channel steel welded together, possessing good rigidity and stability. It provides basic support for the entire reservoir simulation unit device, bearing the weight of the main body of the device above and the loads from movement. The fixed support is used to fix the main body of the reservoir simulation unit device, which can be rotated on the fixed support, facilitating sand filling, cleaning and drainage, device maintenance and repair, and experimental orientation changes, thereby improving the operability and maintenance efficiency of the experimental device.

[0028] At least two cuboid packing plates, each 5 cm thick and matching the internal dimensions of the cubic tank, are installed within the tank. These packing plates can be placed parallel or perpendicularly within the tank to reduce the lateral filling thickness of the reservoir, depending on the experimental requirements. This forces potential oil-water migration phenomena in the reservoir simulation unit to the reservoir surface, facilitating observation of experimental phenomena and meeting the experimental needs of simulated reservoirs of varying thicknesses.

[0029] Fluid displacement ports a are evenly distributed at the top and bottom of the main body of the reservoir simulation unit device, and a tee is provided at each fluid displacement port a; fluid displacement ports b are evenly distributed at the left and right ends of the main body.

[0030] Five fluid displacement ports a can be provided at the top and bottom of the main body. Each fluid displacement port a is equipped with a tee to meet the requirements of multiphase flow. Three fluid displacement ports b can be provided at the left and right ends of the main body respectively.

[0031] Both fluid displacement ports a and b are connected to the gas supply system and the constant flow liquid supply system respectively via gas supply lines and liquid supply lines. Pressure sensors and flow sensors are installed on both the gas supply lines and the liquid supply lines, enabling accurate simulation of flow rates at different locations. The entire reservoir simulation unit can withstand pressures up to 5 MPa.

[0032] The main body of the wellbore simulation unit (WSU) is a simulated wellbore mold, in which a flexible connecting pipe is built-in.

[0033] The flexible connecting pipe serves to connect the wellbore simulation unit and the reservoir simulation unit; it also acts as a fluid outlet. One end of the flexible connecting pipe, of a certain length, connects to the fluid displacement port b, while the other end is embedded within the wellbore simulation unit. The remaining portion is pre-embedded in the formation sand within the cubic chamber of the reservoir simulation unit, simulating horizontal wellbores in heterogeneous reservoirs with varying inclinations. The dimensions of the simulation wellbore mold match the diameter of the fluid displacement port a. A sealing buckle is provided at one end of the simulation wellbore mold.

[0034] The wellbore simulation unit also includes a simulated screen, simulated casing, and simulated tubing. All three components can be integrated into a simulated wellbore mold; for example, the simulated screen can be screwed into the mold. The simulated screen can be made of stainless steel or alloy, with an aperture of 0.1-2.0 mm and a mesh size of 20-200 mesh.

[0035] The wellbore simulation unit (WSU) can be used alone to simulate the open hole wellbore by placing a simulated wellbore mold in the reservoir simulation unit, or it can be combined with the matching simulated casing and simulated screen to simulate different well completion methods.

[0036] The aforementioned wellbore sand and water production profile quantitative monitoring device includes a central support pipe, a diaphragm group, a hose, and a data acquisition device; the diaphragm group consists of diaphragms whose size matches the inner diameter of the simulated wellbore mold, and the outer edge of the diaphragm is provided with an annular groove, in which an expansion rubber ring is embedded.

[0037] The hose can be used for water discharge. The expansion ring allows the partition to better fit the inner wall of the simulated well mold, ensuring the partition's airtightness.

[0038] Each partition has a perforation at its center that matches the outer diameter of the central support tube; each partition also has a hole that matches the outer diameter of the hose, through which the hose is connected to the partition; a data acquisition device is installed on the hose.

[0039] Each septum can be flexibly adjusted along the axial direction of the central support pipe via perforations; it can also be adjusted and fixed using common detachable fixing methods such as threads or clips. The septum assembly can be flexibly set in high and low permeability sections according to experimental needs. For example, with a central support pipe length of 1m, the spacing between the septums built into the simulated wellbore mold can be set to 50cm in the high permeability section and 100cm in the low permeability section. It can support the simulation of 3 to 10 sections within the wellbore. By combining the adjustable septums with independent flow sensing channels, the production flow distribution of each permeability section at different times can be obtained, thereby obtaining the sand-water production profile, revealing the influence of reservoir heterogeneity on fluid migration patterns, and providing experimental basis for sand-water control in heterogeneous reservoirs.

[0040] The data acquisition unit can be a flow sensor used to monitor flow data. Furthermore, a high-precision flow meter (error ≤1%) can be selected as the flow sensor to achieve real-time flow monitoring in the wellbore channel. The data acquisition unit integrates a data aggregation module at the end of the central support pipe to achieve real-time data acquisition and recording.

[0041] In this invention, the experimental apparatus for testing the sand-water production profile of heterogeneous reservoirs and evaluating the water control effect of compartment filling includes a fluid displacement port a equipped with a perforated diverter plate A that matches the transverse dimensions of the cubic tank chamber; a fluid displacement port b equipped with a perforated diverter plate B that matches the longitudinal dimensions of the cubic tank chamber (this longitudinal dimension refers to the longitudinal dimension parallel to the left or right end of the cubic tank chamber); and diverter holes are uniformly arranged on the perforated diverter plate A and the perforated diverter plate B.

[0042] The perforated flow divider is mainly used to disperse the incoming fluid, ensuring a uniform flow into the simulated reservoir. There are two perforated flow dividers (A and B). Different perforated flow dividers are placed at the fluid displacement ports a and b according to different experimental requirements. For example, perforated flow divider A is used when injecting fluid from the top and bottom of the reservoir simulation unit body, while perforated flow divider B is used when injecting fluid from the left and right ends of the reservoir simulation unit body.

[0043] In this invention, in the experimental apparatus for testing the sand-water production profile of heterogeneous reservoirs and evaluating the water control effect of compartment filling, the dimensions of the cubic tank are 150cm×50cm×50cm; the dimensions of the packer are 150cm×50cm×5cm.

[0044] The dimensions of the perforated diverter plate A are 150cm×50cm×5cm; the dimensions of the perforated diverter plate B are 50cm×50cm×5cm.

[0045] In this invention, the experimental apparatus for testing the sand-water production profile of heterogeneous reservoirs and evaluating the water control effect of compartment filling includes trapezoidal support frames at both ends of the main bearing base of the fixed support. Each trapezoidal support frame consists of two legs and upper and lower crossbeams. The upper crossbeam of the right trapezoidal support frame is equipped with a rotating support bearing seat, and the right side of the reservoir simulation unit body is movably connected to the fixed support via bolts and this rotating support bearing seat. The upper crossbeam of the left trapezoidal support frame is equipped with a rotating support bearing seat and a drive motor, and the left side of the reservoir simulation unit body is movably connected to the fixed support via a corresponding coupling and this rotating support bearing seat, ensuring smooth transmission. Universal casters with brakes are located at the four corners of the bottom of the fixed support, facilitating the movement and positioning of the device. The wheel brake design ensures secure fixation during operation, preventing equipment displacement.

[0046] In this invention, the experimental apparatus for testing the sand-water production profile of heterogeneous reservoirs and evaluating the water control effect of compartment filling includes a hollow threaded connecting rod as the central support tube. The central support tube is made of stainless steel or carbon fiber composite material, with a pressure resistance ≥5MPa. The central support tube supports the entire wellbore sand-water production profile quantitative monitoring device, serving as the axial support framework for the diaphragm assembly. The hollow interior of the central support tube can, as needed, house wire grooves and air pressure channels.

[0047] The thickness of the partition is 5~15mm; the partition material is aluminum alloy or engineering plastic.

[0048] The expansion ring has a double-layer structure: the inner layer is silicone, which has high elasticity; the outer layer is nitrile rubber, which is corrosion-resistant. The expansion ring has an expansion diameter change rate of ≥30% and a sealing pressure of 0.5~3MPa.

[0049] The experimental apparatus for testing sand-water production profiles and evaluating the water control effect of compartment filling in heterogeneous reservoirs described in this invention can simulate bottom water / edge water by adjusting the inlet.

[0050] Cracks can be simulated by pre-burying the fishing line and then pulling it out.

[0051] The rectangular packer of the reservoir simulation unit device can be used to adjust the thickness of the simulated reservoir, bringing the reservoir phenomenon closer to the surface. The oil and water migration phenomenon in the reservoir-wellbore coupling simulation unit can be observed through the viewing window to obtain the reservoir sand-water production profile.

[0052] The experimental apparatus for testing sand-water production profiles and evaluating the effect of compartmentalized filling in heterogeneous reservoirs, as described in this invention, can simulate the open-hole wellbore by embedding a simulated wellbore mold in the reservoir simulation unit according to the designed compartmentalized filling water control scheme. Simultaneously, a simulated open-hole horizontal well compartmentalized filling string, consisting of simulated screen pipes and simulated casing, is placed inside the simulated wellbore mold, and a spacer assembly is used as the packer in the compartmentalized filling technology. This simulates the application effect evaluation experiment of compartmentalized filling sand and water control. Experimental phenomena are observed through a visualization window, and the sand-water production profile after hierarchical compartmentalization of the heterogeneous reservoir is obtained through a wellbore sand-water production profile quantitative monitoring device, allowing for the evaluation of the effect of the compartmentalized filling sand-water synergistic control technology.

[0053] Specifically, the aforementioned experimental device for testing sand-water production profiles and evaluating the water control effect of compartmentalized filling in heterogeneous reservoirs can be used for simulation experiments of dynamic changes in the seepage capacity of sand control layer at the production end of loose sandstone heterogeneous reservoirs, adaptive simulation experiments of dynamic sand production and filling in fracture-deficient coupled reservoirs, simulation experiments of sand-water production and control in oil wells under bottom water / edge water conditions in loose sandstone heterogeneous reservoirs, simulation experiments of oil-water migration without filling in horizontal wells in loose sandstone heterogeneous reservoirs, simulation experiments of sand-water production profiles of compartmentalized filling in horizontal wells in loose sandstone heterogeneous reservoirs, or evaluation experiments of compartmentalized filling in horizontal wells in loose sandstone heterogeneous reservoirs.

[0054] The beneficial effects of this invention are as follows: The experimental device for testing sand-water production profiles and evaluating the water control effect of compartmentalized filling in heterogeneous reservoirs described in this invention can simulate the flow and migration processes of oil, gas, and water in different reservoirs to wellbores with different inclination angles, simulate the near-wellbore oil-water seepage and flow around the reservoir in heterogeneous horizontal wells, simulate different reservoirs and reservoir sand production deficit morphologies, and simulate the actual reservoir compression filling process, thus realizing the simulation of the entire process of sand production-filling-production. Through the flexible combination of the structure of each simulation unit device, it can simulate sand-water production profile testing experiments in heterogeneous loose sandstone reservoirs, as well as compartmentalized filling experiments in open-hole horizontal wells and sand and water control experiments after compartmentalized filling.

[0055] For example, this invention employs a modular design for reservoir simulation units, allowing independent adjustment of physical properties (porosity, permeability, sand grain size) and geometric morphology (fracture angle, void size). By configuring different proportions of formation sand and adding certain consolidating agents within the reservoir simulation unit, different reservoir physical properties can be simulated to achieve the simulation of reservoirs such as carbonate reservoirs and tight sandstone reservoirs. It also supports three-dimensional filling profile observation, thereby quantifying the relationship between sand-water production and fluid viscosity and velocity, providing accurate experimental data for optimizing differentiated water control and sand control processes. It transforms geological layers and fluid flow characteristics into mathematical models, enabling effective reservoir simulation and helping to evaluate water drive effectiveness and develop optimized oil recovery strategies. It achieves flexible control over reservoir permeability differences, fracture distribution, and void morphology, including simulation of sand-water production profile testing in heterogeneous loose sandstone reservoirs such as bottom water / edge water reservoirs, fracture network reservoirs, and complex sand-producing void reservoirs.

[0056] More importantly, this invention, through its innovative design, allows the wellbore simulation unit to be embedded into the reservoir simulation unit at any different tilt angle. This enables the simulation of fluid flow processes outside the horizontal wellbore in heterogeneous reservoirs with different inclinations, and more realistically simulates the interaction effects between the wellbore and the reservoir, such as sand transport, fluid flow around the wellbore, and sand layer blockage. It also works in conjunction with numerous sensors in the data measurement and acquisition system to collect data in real time.

[0057] Furthermore, the wellbore simulation unit, reservoir simulation unit, and sealing cover are all connected using a quick-release structure, ensuring the overall sealing of the device while allowing for rapid disassembly.

[0058] The experimental setup also features an innovative quantitative monitoring device for wellbore sand and water production profiles. This device enables dynamic monitoring and collection of sand and water flowing into the wellbore from different locations within the reservoir, thereby obtaining sand and water production profiles and providing a quantitative description of sand and water production. This provides a basis for near-wellbore reservoir compartmentalized filling sand and water control and sand and water synergistic control technologies.

[0059] The specific explanation is as follows:

[0060] (1) The experimental setup described herein can reproduce the reservoir-wellbore coupling effect through flexible adjustment of the wellbore simulation unit and the reservoir simulation unit. Combined with a constant flow fluid supply closed loop, it achieves visualization and data quantification of sand-water migration through a visual window, multi-sensor (flow / pressure) real-time acquisition, and computer analysis, thereby obtaining a sand-water production profile. It realizes the sand-water production profile test experiment of loose sandstone heterogeneous reservoir and the evaluation experiment of compartmentalized filling water control effect. The simulation function is comprehensive and conforms to the actual reservoir conditions. The main device of the reservoir simulation unit can simulate different types of complex reservoirs, which is more in line with the actual reservoir conditions in the oilfield. The experimental results can effectively support the application of sand-water synergistic control in loose sandstone heterogeneous reservoirs and the sand and water control technology of compartmentalized filling in open-hole horizontal wells.

[0061] The collaborative wellbore simulation unit, capable of being embedded into reservoir simulation unit devices at any angle, can simulate the entire process of sand and water production, sand and water control, compartmentalized filling, and production optimization under heterogeneous reservoir conditions such as homogeneous / heterogeneous loose sandstone, fractured carbonate rock, and tight sandstone, at different wellbore inclination angles (vertical / directional / horizontal wells). It supports gas-water, oil-water, and oil-gas-water multiphase flow experiments and is equipped with a high-precision visualization observation unit to visualize near-wellbore reservoir flow around and channeling phenomena, providing experimental basis for horizontal well compartmentalized filling water control optimization and fractured reservoir sand control design. It supports the verification of sand and water control processes with different permeability ranges and completion methods, providing an efficient and safe physical experimental platform for optimizing field sand control schemes.

[0062] (2) The experimental device described above can be modularly divided into wellbore simulation units. By designing that the position of each partition in the partition group can be flexibly adjusted, the flow of near-well reservoir at different locations into the wellbore and the dynamic monitoring and collection of inflowing sand and water can be realized, thereby obtaining the sand and water production profile, and realizing the dynamic monitoring and quantitative description of sand and water production, providing a basis for near-well reservoir compartmentalized filling sand and water control and sand and water synergistic control technology.

[0063] (3) The experimental device has a wide range of applications and is universal. Through the flexible combination of reservoir and wellbore units, it can realize the sand-water production profile test of heterogeneous reservoirs and the evaluation of water control effect of compartment filling. These include production experiments of heterogeneous reservoir injection and production wells with and without screen pipes, dynamic sand production-filling adaptive experiments of fracture-deficient coupled reservoirs, simulation methods of sand-water production and control experiments of oil wells under edge water / bottom water conditions, as well as compartment filling experiments and evaluation of the effect after compartment filling. The experimental process and results are more in line with the field conditions, and realize the visualization observation of oil and water migration and the quantitative acquisition of sand-water production profiles under different reservoir and oil well conditions, providing experimental support for differentiated and refined sand control and water control design. Attached Figure Description

[0064] Figure 1 A schematic diagram of multi-section compartmentalized filling for sand control and water control in open-hole horizontal wells.

[0065] Figure 2 This is a system flowchart of the experimental apparatus (RFS) for testing sand-water production profiles and evaluating water control effects in heterogeneous reservoirs as described in this invention.

[0066] Figure 3 This is a schematic diagram of the main structure of the reservoir simulation unit.

[0067] Figure 4 This is a schematic diagram of the main body of the reservoir simulation unit placed on a fixed support.

[0068] Figure 5 This is a schematic diagram of the structure of perforated flow divider plate A and perforated flow divider plate B.

[0069] Figure 6 This is a schematic diagram of the main structure of the wellbore simulation unit (WSU).

[0070] Figure 7 This is a schematic diagram of a device for quantitative monitoring of sand and water production profiles in wellbore.

[0071] Figure 8 This is a schematic diagram of the experimental setup used for simulating the dynamic changes in seepage capacity between the sand control layer and the reservoir at the produced end of a heterogeneous sandstone reservoir.

[0072] Figure 9 This is a schematic diagram of the assembly structure of the simulated casing, simulated screen, and gravel in the wellbore simulation unit.

[0073] Figure 10 This is a schematic diagram of the experimental setup used for simulating the seepage process in the near-wellbore reservoir and sand control layer at the production end.

[0074] Figure 11 This is a schematic diagram of bottom water / side water.

[0075] In the diagram, 1 is a cubic chamber, 2 is a simulated wellbore mold, 3 is a horizontal flow pump, 4 is an air storage tank, 5 is an air compressor, 6 is a fluid drive outlet b, 7 is a flexible connecting pipe, 8 is a fluid drive outlet a, 9 is a tee, 10 is a pressure sensor, 11 is a flow sensor, 12 is an injection wellbore, 13 is a liquid collector, 14 is a produced wellbore, 15 is an inclined simulated wellbore mold I; 16 is an inclined simulated wellbore mold II, 17 is a reservoir simulation unit device, 18 is a control switch, and 19 is a long... 20 is a cuboid partition plate, 21 is a viewing window, 22 is a sealing cover plate, 23 is a rotating support bearing seat, 24 is a drive motor, 25 is a fixed bracket, 26 is a caster wheel, 27 is a perforated diverter plate A, 28 is a perforated diverter plate B, 29 is a simulated wellbore mold, 30 is a simulated screen pipe, 31 is a central support pipe, 32 is a partition plate, 33 is a flexible hose, 34 is a data acquisition device, 35 is a perforation, 36 is an expansion ring, 37 is a simulated casing, and 38 is a simulated tubing. Detailed Implementation

[0076] The technical solution of the present invention will now be described in detail with reference to the accompanying drawings.

[0077] Example 1

[0078] The experimental apparatus for testing the sand-water production profile of heterogeneous reservoirs and evaluating the water control effect of compartment filling includes an air supply system, a constant flow liquid supply system, a data measurement and acquisition system, a reservoir simulation unit device 17 (MFS), a wellbore simulation unit device (WSU), and a wellbore sand-water production profile quantitative monitoring device.

[0079] The wellbore simulation unit device can be embedded into the reservoir simulation unit device 17 at any different tilt angle, and can simulate the fluid flow process outside the horizontal wellbore of heterogeneous reservoirs with different inclinations.

[0080] The wellbore sand and water production profile quantitative monitoring device is placed in the wellbore simulation unit device. It can dynamically monitor and collect the sand and water flowing into the wellbore from different locations in the reservoir, thereby obtaining the sand and water production profile and realizing the quantitative description of sand and water production.

[0081] The air supply system includes an air compressor 5, an air tank 4, an air supply pipeline, and a control switch 18.

[0082] The constant flow liquid supply system includes a horizontal flow pump 3, a liquid collector 13, a liquid supply pipeline, and a control switch 18.

[0083] The data measurement and acquisition system includes a pressure sensor 10, a flow sensor 11, and a computer acquisition terminal.

[0084] The reservoir simulation unit device 17 consists of a cubic chamber 1 (150cm × 50cm × 50cm) with viewing windows at the front and rear. This cubic chamber 1 is equipped with a sealing cover 21 that can be bolted on. It can be tightened with eight bolts 25, and the mating joints are sealed with sealing rings. The main body of the reservoir simulation unit device 17 is movably connected to a fixed support 24.

[0085] The main load-bearing base of the fixed bracket 24 has trapezoidal support frames at both ends, each consisting of two legs and upper and lower crossbeams. The upper crossbeam of the right trapezoidal support frame is equipped with a rotary support bearing seat 22. The right side of the main body of the reservoir simulation unit device 17 is movably connected to the fixed bracket 24 via bolts and this rotary support bearing seat 22. The upper crossbeam of the left trapezoidal support frame is equipped with a rotary support bearing seat 22 and a drive motor 23. The left side of the main body of the reservoir simulation unit device 17 is movably connected to the fixed bracket 24 via a corresponding coupling and this rotary support bearing seat 22, ensuring smooth transmission. Universal casters 25 with brakes are located at the four corners of the bottom of the fixed bracket 24, facilitating the movement and positioning of the device. The wheel brake design ensures secure fixation during operation, preventing equipment displacement. The fixed bracket 24 is made of welded rectangular steel pipe or channel steel.

[0086] The extrusion filling process can be observed through the viewing window 20 of the cubic chamber 1, and the reservoir flow, filling and sand-water production profiles can be observed after the experiment.

[0087] At least two cuboid partitions 19, each 5 cm thick and matching the internal dimensions of the cubic chamber 1 (dimensions 150 cm × 50 cm × 5 cm), are installed inside the cubic chamber 1. The cuboid partitions 19 can be placed parallel or perpendicularly inside the cubic chamber 1.

[0088] Fluid displacement ports a8 are evenly distributed at the top and bottom of the main body of the reservoir simulation unit device 17, and a tee 9 is provided at each fluid displacement port a8; fluid displacement ports b6 are evenly distributed at the left and right ends of the main body.

[0089] Five fluid displacement ports a 8 can be provided at the top and bottom of the main body. Each fluid displacement port a 8 is equipped with a tee 9 to meet the requirements of multiphase flow. Three fluid displacement ports b 6 can be provided at the left and right ends of the main body respectively.

[0090] The fluid displacement ports a8 and b6 are connected to the gas supply system and the constant flow liquid supply system respectively via gas supply lines and liquid supply lines. Both the gas supply lines and the liquid supply lines are equipped with pressure sensors 10 and flow sensors 11, enabling accurate simulation of flow rates at different locations. The entire reservoir simulation unit can withstand pressures up to 5 MPa.

[0091] The fluid displacement port a8 is equipped with a perforated diversion plate A26 (150cm×50cm×5cm) that matches the transverse dimensions of the interior of the cubic chamber 1.

[0092] The fluid displacement port b 6 is equipped with a perforated diversion plate B 27 (50cm×50cm×5cm) that matches the longitudinal dimensions of the interior of the cubic tank 1.

[0093] Diverting holes are evenly arranged on the perforated diverting plate A 26 and the perforated diverting plate B 27.

[0094] According to the experimental protocol, when injecting fluid from the top and bottom ends of the main body of the reservoir simulation unit device 17, a perforated flow divider plate A 26 is used. When injecting fluid from the left and right ends of the main body of the reservoir simulation unit device 17, a perforated flow divider plate B 27 is used.

[0095] The main body of the wellbore simulation unit (WSU) is a simulated wellbore mold 28, in which a flexible connecting pipe 7 is built-in.

[0096] A flexible connecting pipe 7 of a certain length can be connected at one end to the fluid displacement port b 6, and the other end is built into the wellbore simulation unit device. The remaining part is pre-embedded in the formation sand filled in the cubic chamber 1 of the main body of the reservoir simulation unit device, realizing the simulation of horizontal wellbores of different inclinations and heterogeneous reservoirs. The size of the simulation wellbore mold 28 matches the diameter of the fluid displacement port a 8. A sealing buckle is provided at the port of one end of the simulation wellbore mold 28.

[0097] The wellbore simulation unit also includes a simulated screen pipe 29, a simulated casing 37, and a simulated tubing 38. The simulated screen pipe 29, simulated casing 37, and simulated tubing 38 can all be housed within the simulated wellbore mold 28. The simulated screen pipe 29 is screwed into the simulated wellbore mold 28.

[0098] The wellbore simulation unit can be flexibly assembled into an open-hole wellbore simulation unit or a screen pipe-wellbore simulation unit.

[0099] The open-hole wellbore simulation unit uses a wellbore mold 28 with densely perforated holes to simulate an open-hole horizontal well. The diameter of the densely perforated holes ranges from 0.01 to 2.0 mm and can be customized according to experimental requirements. Since it is used to simulate the open-hole wellbore, it needs to withstand the pressure of the simulated reservoir above; therefore, the thickness should be around 2 mm, and the material should be stainless steel or corrosion-resistant to avoid affecting the experiment.

[0100] The screen-tube-wellbore simulation unit consists of multiple simulated screen tubes 29, connected by high-strength bolts to form a detachable modular wellbore structure. It supports the rapid construction of various well types, including vertical, horizontal, and directional wells, and can be flexibly adjusted according to experimental needs.

[0101] The simulated screen tube 29 is made of stainless steel or corrosion-resistant alloy, simulating the mechanical strength and pressure resistance (≥5MPa) of a real wellbore. The surface of the simulated screen tube 29 has uniformly distributed dense pores with a diameter of 0.1~2.0mm, simulating the sand-blocking function of an actual screen tube and supporting screening requirements of different precisions (e.g., 20~200 mesh). The segmented simulated screen tubes 29 can be connected via threaded interfaces or flanges for easy and quick replacement or adjustment of screen tube parameters.

[0102] The wellbore sand and water production profile quantitative monitoring device includes a central support pipe 30, a diaphragm group, a hose 32, and a data acquisition unit; the diaphragm group consists of diaphragms 31 whose size matches the inner diameter of the simulated wellbore mold 28, and the outer edge of the diaphragm 31 is provided with an annular groove, and an expansion rubber ring 36 is embedded in the annular groove.

[0103] The central support tube 30 is a hollow threaded connecting rod; the material of the central support tube 30 is stainless steel or carbon fiber composite material, with a pressure resistance ≥5MPa. The central support tube 30 serves as the axial support frame for the partition assembly. The hollow interior of the central support tube 30 can be fitted with wire grooves and air pressure channels as needed.

[0104] The thickness of the partition 31 is 5~15mm; the material of the partition 31 is aluminum alloy or engineering plastic.

[0105] The expansion ring 36 has a double-layer structure: the inner layer is silicone, which has high elasticity; the outer layer is nitrile rubber, which is corrosion resistant. The expansion ring 36 has an expansion diameter change rate of ≥30% and a sealing pressure of 0.5~3MPa.

[0106] The hose 32 can be used for water discharge. The expansion ring 36 allows the partition 31 to better fit the inner wall of the simulated well mold 28, ensuring the sealing of the partition.

[0107] Each partition 31 has a perforation 34 at its center that matches the outer diameter of the central support tube 30; each partition 31 also has a hole 35 that matches the outer diameter of the hose 32, through which the hose 32 is connected to the partition 31; a data acquisition device 33 is installed on the hose 32.

[0108] Each partition 31 can be flexibly adjusted along the axial direction of the central support tube 30 through the perforation 34; it can be adjusted and fixed by common detachable fixing methods such as threads or clips.

[0109] The data acquisition unit 33 can be a flow sensor used to monitor flow data. Furthermore, the flow sensor can be a high-precision flow meter (error ≤1%) to achieve real-time flow monitoring in the wellbore channel.

[0110] The specific method for using the experimental apparatus is as follows:

[0111] I. Reservoir Simulation Unit Device

[0112] Adjustable cuboid packing plates 19 can be inserted into the cubic chamber 1 according to the needs of experimental simulation, to adapt to different reservoir thickness requirements.

[0113] Subsequently, the flow interface configuration is connected, with 5 fluid displacement ports a 8 and 3 fluid displacement ports b 6 connected to the liquid supply line and / or gas supply line to control the multiphase fluid input.

[0114] Finally, the top cover was tightened with eight bolts, and the sealing ring was used to ensure airtightness. A pressure resistance test (5MPa) was then conducted on the reservoir simulation unit to check its sealing performance and structural stability.

[0115] II. Wellbore Simulation Unit Device

[0116] First, based on the experimental requirements, select the corresponding horizontal well simulation unit, injection-production well simulation unit, and wellbore simulation units with different inclinations.

[0117] If there is no need for a screen pipe, install a simulated wellbore mold 28 with dense holes to simulate an open-hole horizontal wellbore and simulate the open-hole well wall.

[0118] If a sieve tube experiment is required, select the required simulated sieve tube 29 and assemble it modularly by connecting it with threads or flanges.

[0119] Then, the wellbore simulation unit is installed and embedded. Formation sand is buried in the reservoir simulation unit, and the wellbore simulation unit is embedded in the reservoir simulation unit to simulate the interaction between the real wellbore and the reservoir.

[0120] Simultaneously, a quantitative monitoring device for sand and water production profile in the well is placed, and a partition 31 is used for segmented sealing. An independent data acquisition unit 33 is connected to monitor the independent flow rate of each section in the well, thereby obtaining the sand and water production profile.

[0121] III. Quantitative Monitoring Device for Wellbore Sand and Water Production Profile

[0122] In use, the spacing of the septa 31 is first adjusted according to the reservoir permeability distribution (e.g., 1m in high-permeability section and 0.5m in low-permeability section). Independent flow monitoring of different sections of the wellbore is achieved through the segmented sealing of the septa 31; it supports various well completion methods such as simulated open-hole wells, casing completions, and screen sand control.

[0123] After the reservoir simulation unit device 17 and the wellbore simulation unit device are assembled and placed, the wellbore sand and water production profile quantitative monitoring device is inserted into the simulated wellbore mold 28 of the horizontal well simulation unit to ensure that the central support pipe 30 is coaxial with the simulated wellbore mold 28.

[0124] After the fluid flows in through the inlet, reservoir phenomena are observed through reservoir visualization. Using the multi-channel horizontal well seepage dynamic monitoring data acquisition device 33 for each compartment 21, the flow rate at each location is determined, obtaining the reservoir production profile. Simultaneously, the sand production rate of each section can be collected, obtaining the sand production profile and the sand-water co-production profile.

[0125] Each compartment 21 has its own independently connected hose 32 to a data acquisition unit 33, enabling real-time data transmission and recording. This solves the core problems of inflexible segmentation, low data accuracy, and inability to quantitatively monitor seepage in horizontal wells, providing a highly reliable experimental tool for complex reservoir development and sand control technology optimization.

[0126] IV. Data Analysis and Optimization

[0127] Real-time observation of reservoir sand-water migration is achieved by recording sand body distribution and fracture blockage phenomena through a visual window, combined with sensor data to correlate dynamic behavior. A red fluid (with tracer added) is used to displace high-permeability sections, while pure water (simulating formation water) is used to displace low-permeability sections. Fluid flow through different permeability sections is observed, and displacement dynamics are recorded. Reservoir oil-water seepage and bypass processes are observed through the reservoir unit visual window. After displacement is complete, core samples are taken at the interface between high-permeability and low-permeability sections or at key locations where bypass phenomena are concentrated. Reservoir morphology is observed, and flow rates at different reservoir locations are recorded and analyzed, resulting in sand-water production profiles after hierarchical and compartmentalized classification of heterogeneous reservoirs. When screens are present, the sand-blocking efficiency (inlet / outlet sand ratio) and filling layer permeability (pressure drop-flow rate relationship) are calculated to plot production decay curves, evaluate the long-term effects of different sand control schemes, and then adjust screen parameters (pore size, density), filling material type, or displacement strategy based on experimental results to set sand and water control schemes.

[0128] Example 2

[0129] The experimental setup described above was used to conduct a simulation experiment on the dynamic changes in seepage capacity between the sand control layer and the reservoir at the produced end of a heterogeneous sandstone reservoir. The operation is as follows:

[0130] During the experiment, the extraction wellbore 14 and the injection wellbore 12 should be placed first. The extraction wellbore 14 and the injection wellbore 12 are the simulated wellbore mold 28. The extraction wellbore 14 and the injection wellbore 12 are fixed to the buckle at the bottom of the cubic chamber 1.

[0131] The formation sand was simulated according to the design scheme and then consolidated.

[0132] The experimental simulation principle of the seepage process of the near-wellbore reservoir and sand control layer at the production end is as follows: Figure 10 As shown.

[0133] When displacement is carried out from the fluid displacement port a8 as the injection port, a tracer is added. The oil and water flow and reservoir depletion morphology of the oil well in the vertical state are observed through the visual window 20. The spatial evolution of oil and water front expansion, sand accumulation and sand control layer blockage during the injection and production process of vertical / horizontal wells is captured in real time, providing a direct basis for optimizing sand control technology.

[0134] Meanwhile, different sand control schemes can be simulated through injection and production wells. By comparing the long-term sand control efficiency and seepage maintenance capacity of different sand control schemes (such as screen pipe precision, packing sand particle size, and fracturing proppant type) in heterogeneous reservoirs, the optimal sand control parameter combination can be directly selected. A schematic diagram of the screen pipe and gravel in the wellbore simulation unit is attached. Figure 9 As shown.

[0135] Simultaneously, the void morphology caused by sand production in the reservoir can be observed. The simulated reservoir unit can flexibly adjust its thickness, length, size, and shape to intuitively simulate different sand production void morphologies (large pores, honeycomb-like structures, earthworm-like burrows) and reservoirs with different physical properties (heterogeneous structures). After the experiment, the reservoir can be longitudinally dissected to observe the longitudinal filling and sand production profiles, and it is easier to observe the sand and gravel mixing morphology during the sand-carrying production process. The experimental process and results are more consistent with the field conditions.

[0136] Example 3

[0137] An adaptive simulation experiment of dynamic sand production-filling in fracture-deficit coupled reservoirs was conducted using the aforementioned experimental setup. The operation is as follows:

[0138] Within the reservoir simulation unit device 17, a fishing line pre-embedded extraction method is designed, using high-strength fishing lines (0.2~0.5mm in diameter) to simulate fractures of different opening sizes.

[0139] A complex fracture network is achieved through multiple parallel / intersecting arrangements and proppant filling. The fracture aperture (0.1~2mm) and seepage characteristics are simulated to accurately simulate the entire process of sand production and filling in fractured reservoirs.

[0140] Before filling the simulated stratum sand, the fishing line is laid in the cubic chamber 1 according to the designed trajectory (vertical / horizontal / inclined), and both ends are fixed to the reserved holes on the side wall of the cubic chamber 1 to ensure that it runs through the entire simulation area.

[0141] In a cubic chamber 1 measuring 150×50×50cm, the fishing line can be introduced from the fluid displacement port a8 at the top and bottom, or through the viewing window 20. It is secured at multiple points using bolt holes on the steel outer wall to ensure the fracture extension direction forms the required angle with the wellbore (horizontal / inclined). The fracture width (0.1-2mm) is controlled by adjusting the fishing line diameter (single or bundled) and the amount of sand rebound after extraction. Different particle sizes of proppant (such as ceramsite) are filled into the fracture channels to simulate the seepage differences between filled and unfilled fractures.

[0142] Example 4

[0143] The experimental setup described above was used to conduct a simulation experiment on the production and control of sand-water in oil wells under bottom water / edge water conditions in heterogeneous sandstone reservoirs. The operation is as follows:

[0144] Experimental simulations of the initial bottom water morphology (thickness 0.05-0.5m) and dynamic conical process of the reservoir are as follows: Figure 10 As shown, the bottom water breakthrough time is then predicted, and the sand-water production profile within the reservoir is obtained. For example, the bottom water morphology is obtained as follows: Figure 11 As shown, the XY coordinate axes are plotted based on the bottom water morphology.

[0145] like Figure 10 As shown, the bottom water inrush pattern is divided into five segments, and the positions of the fluid displacement ports a and 8 from left to right are 2r and 2r respectively. e / 5、4r e / 5、6r e / 5、8r e / 5、2r e At each fluid displacement port a8, t0 is displaced at a flow rate of v0. Then, the third fluid displacement port a8 on the left continues to displace t0 at a flow rate of v0. Finally, t0+t1 is displaced at a flow rate of v1, where v0=h0 / t0 and v1=h w / t1 is used to simulate the initial bottom water morphology of bottom water reservoirs.

[0146] Other types of bottom water can be calculated using this method.

[0147] After the experiment, the experimental data were recorded and the impact of bottom water morphology on sand and water production in oil wells was analyzed to guide the application of sand and water control technology in oil wells in bottom water reservoirs.

[0148] At the same time, this method can be used to simulate water avoidance height and, by changing the location of oil wells and setting reservoir baffles, to simulate reservoir mudstone interlayers and oil wells with different inclinations.

[0149] Example 5

[0150] The experimental setup described above was used to conduct a simulation experiment on the unfilled oil-water migration in a horizontal well in a heterogeneous sandstone reservoir. The operation was as follows:

[0151] To consider whether the oil-water seepage and flow around the reservoir can be observed, the reservoir thickness is affected. A cuboid packing plate 19 is set in the cubic cell 1 to reduce the simulated reservoir thickness and force the phenomenon toward the reservoir surface.

[0152] Based on the reservoir simulation requirements, reservoirs with different permeability ranges are simulated by mixing different proportions of formation sand.

[0153] Without any filling measures, a wellbore simulation unit device is placed in the well to observe the oil and water migration phenomenon in the reservoir under the condition of no filling. The flow rate at different locations in the reservoir is quantitatively monitored using a wellbore sand and water production profile quantitative monitoring device.

[0154] Example 6

[0155] The experimental setup described above was used to conduct a simulation experiment on the sand-water production profile of a horizontal well in a heterogeneous sandstone reservoir. The operation was as follows:

[0156] Based on the permeability range designed in the experimental scheme, different formation sands were mixed to form simulated reservoirs with different permeabilities. Simulated bottom sand was laid starting from the bottom of cubic chamber 1, filling the interior with simulated formation sand and consolidating it to form a formation with a certain strength. After one layer was laid, a second layer was laid, and so on, until the wellbore simulation unit was placed at the preset position. Laying continued until the simulated bottom sand filled the entire unit. Finally, formation sand was laid in the gaps between cubic chambers 1. Subsequently, the reservoir was consolidated and saturated with crude oil, and the reservoir unit was sealed to simulate the initial state of the oil layer. At this point, the simulated formation was completed.

[0157] Schematic diagram of reservoir filling at different permeabilities in open-hole horizontal wells as shown in the figure. Figure 8 As shown. Subsequently, a well sand and water production profile quantitative monitoring device is inserted into the simulated wellbore mold 28. The expansion rubber ring is used to separate and seal the open hole well wall, dividing the interior of the simulated open hole well wall into multiple segments.

[0158] During the displacement phase, red fluid (with tracer added) was used to displace the high-permeability section, and pure water (simulating formation water) was used to displace the low-permeability section. The flow of fluid through different permeability sections was observed, and the displacement dynamics were recorded.

[0159] The reservoir oil and water seepage and flow around can be observed through the viewing window 20.

[0160] After displacement is completed, core samples are taken at the interface between high-permeability and low-permeability sections or at key locations where flow around the reservoir is concentrated. The reservoir morphology is observed, the flow rate at different locations in the reservoir is recorded and analyzed, and the sand-water production profile of the heterogeneous reservoir is obtained after classification and compartmentalization.

[0161] Example 7

[0162] An evaluation experiment on compartmentalized filling of horizontal wells in heterogeneous sandstone reservoirs was conducted using the aforementioned experimental setup. The operation was as follows:

[0163] Based on the experimental simulation results of the oil-water seepage and flow around the heterogeneous reservoir in a graded and compartmentalized manner, a compartmentalized filling design is established, and a compartmentalized water control design is carried out.

[0164] According to the designed compartmentalized water control scheme, a simulated wellbore mold 28 is buried in the cubic chamber 1. At the same time, an open-hole horizontal well compartmentalized filling string consisting of a simulated screen pipe 29, a simulated casing 37, and a simulated tubing 38 is placed in the simulated wellbore mold 28. A spacer 31 is used as a sealing plate in the compartmentalized technology. The application effect evaluation experiment of simulated compartmentalized filling for sand and water control is carried out.

[0165] The experimental phenomena were observed through the viewing window 20. The sand and water production profile of the heterogeneous reservoir after classification and compartmentation was obtained through the wellbore sand and water production profile quantitative monitoring device. The effect of the compartment filling sand and water synergistic control technology was evaluated.

[0166] As can be seen from the above embodiments, the experimental apparatus of the present invention can simulate heterogeneous reservoirs such as fractured reservoirs and bottom water / edge water reservoirs by setting various working conditions such as without screens, fractures, and bottom water. Simultaneously, it can also simulate experiments on compartmentalized filling of open-hole horizontal wells and the evaluation of the effects after compartmentalized filling.

[0167] This experimental setup can realistically simulate the complex conditions of an oilfield, and can systematically reflect the sand-water migration characteristics and water control filling effect of heterogeneous sandstone reservoirs under complex wellbore structures. It provides an experimental basis and simulation method for sand-water production profile testing and the application of compartmentalized filling water control technology in heterogeneous reservoirs.

Claims

1. The application of an experimental device for testing sand-water production profiles and evaluating the water control effect of compartmentalized filling in heterogeneous reservoirs, characterized in that, This experimental setup is used for simulation experiments on the dynamic changes of sand control layer-reservoir seepage capacity at the production end of heterogeneous sandstone reservoirs, adaptive simulation experiments on dynamic sand production-filling of fracture-deficit coupled reservoirs, simulation experiments on sand and water production and control of oil wells under bottom water / edge water conditions in heterogeneous sandstone reservoirs, simulation experiments on oil and water migration without filling in horizontal wells in heterogeneous sandstone reservoirs, simulation experiments on sand and water production profiles of horizontal wells with compartmentalized filling in heterogeneous sandstone reservoirs, or evaluation experiments on compartmentalized filling in horizontal wells in heterogeneous sandstone reservoirs. The experimental setup includes a gas supply system, a constant flow liquid supply system, a data measurement and acquisition system, a reservoir simulation unit, a wellbore simulation unit, and a wellbore sand and water production profile quantitative monitoring device. The wellbore simulation unit device is embedded in the reservoir simulation unit device; the wellbore sand and water production profile quantitative monitoring device is placed in the wellbore simulation unit device. The air supply system includes an air compressor, an air tank, air supply pipelines, and control switches; The constant flow liquid supply system includes a horizontal flow pump, a liquid collector, a liquid supply pipeline, and a control switch; The data measurement and acquisition system includes a pressure sensor, a flow sensor, and a computer acquisition terminal; The reservoir simulation unit device is a cubic chamber with viewing windows at the front and rear. The cubic chamber is equipped with a detachable sealing cover. The main body of the reservoir simulation unit device is movably connected to a fixed support. At least two rectangular partitions, each 5 cm thick and matching the internal dimensions of the cubic tank, are installed inside the cubic tank. Fluid displacement ports a are evenly distributed at the top and bottom of the main body of the reservoir simulation unit device, and a tee is provided at each fluid displacement port a. Fluid displacement ports b are evenly distributed at the left and right ends of the main body. Both fluid displacement port a and fluid displacement port b are connected to the gas supply system and the constant flow liquid supply system respectively through gas supply lines and liquid supply lines; both the gas supply lines and the liquid supply lines are equipped with pressure sensors and flow sensors. The main body of the wellbore simulation unit device is a simulated wellbore mold, and a flexible connecting pipe is built into the simulated wellbore mold; The wellbore simulation unit device also includes a simulated screen pipe, a simulated casing, and a simulated tubing; The wellbore sand and water production profile quantitative monitoring device includes a central support pipe, a diaphragm group, a hose, and a data acquisition device; the diaphragm group consists of diaphragms whose size matches the inner diameter of the simulated wellbore mold, and the outer edge of the diaphragm is provided with an annular groove, in which an expansion rubber ring is embedded; Each of the partitions has a perforation at its center that matches the outer diameter of the central support tube; each partition also has a hole of a size that matches the outer diameter of the hose, through which the hose is connected to the partition; a data acquisition device is installed on the hose.

2. The application of the experimental device for testing sand-water production profiles and evaluating water control effects in heterogeneous reservoirs according to claim 1, characterized in that, The fluid displacement port a is equipped with a perforated diversion plate A that matches the transverse dimension of the cubic tank; the fluid displacement port b is equipped with a perforated diversion plate B that matches the longitudinal dimension of the cubic tank; diversion holes are evenly arranged on the perforated diversion plate A and the perforated diversion plate B.

3. The application of the experimental device for testing sand-water production profiles and evaluating water control effects in heterogeneous reservoirs according to claim 1, characterized in that, The dimensions of the cubic chamber are 150cm×50cm×50cm; the dimensions of the partition are 150cm×50cm×5cm.

4. The application of the experimental device for testing sand-water production profiles and evaluating the water control effect of compartmentalized filling in heterogeneous reservoirs according to claim 2, characterized in that, The dimensions of the perforated diverter plate A are 150cm×50cm×5cm; the dimensions of the perforated diverter plate B are 50cm×50cm×5cm.

5. The application of the experimental device for testing sand-water production profiles and evaluating water control effects in heterogeneous reservoirs according to claim 1, characterized in that, The two ends of the main bearing base of the fixed support are trapezoidal support frames, which are composed of two legs and upper and lower crossbeams; the upper crossbeam of the trapezoidal support frame at the right end is provided with a rotary support bearing seat, and the right side of the main body of the reservoir simulation unit is movably connected to the fixed support by bolts and the rotary support bearing seat. The upper crossbeam of the trapezoidal support frame at the left end is equipped with a rotary support bearing seat and a drive motor. The left side of the main body of the reservoir simulation unit is movably connected to the fixed bracket via a corresponding coupling and the rotary support bearing seat.

6. The application of the experimental apparatus for testing sand-water production profiles and evaluating water control effects in heterogeneous reservoirs according to claim 1, characterized in that, Each of the four corners at the bottom of the fixed bracket is equipped with a swivel wheel with a brake.

7. The application of the experimental apparatus for testing sand-water production profiles and evaluating water control effects in heterogeneous reservoirs according to claim 1, characterized in that, The central support tube is a hollow threaded connecting rod; the material of the central support tube is stainless steel or carbon fiber composite material.

8. The application of the experimental apparatus for testing sand-water production profiles and evaluating water control effects in heterogeneous reservoirs according to claim 1, characterized in that, The thickness of the partition is 5~15mm; the partition material is aluminum alloy or engineering plastic.

9. The application of the experimental apparatus for testing sand-water production profiles and evaluating water control effects in heterogeneous reservoirs according to claim 1, characterized in that, The expansion ring has a double-layer structure, with an inner layer of silicone and an outer layer of nitrile rubber.

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