Tracer-based horizontal well segmented liquid production profile visual simulation experiment device and interpretation and evaluation method

Abstract

The invention relates to a tracer-based horizontal well subsection liquid production profile visual simulation experiment device and interpretation and evaluation method, and the experiment device comprises a fluid injection and control module which comprises a plurality of sets of independent fluid injection units and can independently regulate and control the oil-water phase injection flow of each horizontal well subsection; the formation fluid simulation and pretreatment module comprises a core holder and a mixing tank and is used for simulating formation liquid production and realizing uniform mixing of oil and water; the simulation shaft and tracer agent module adopts a transparent simulation shaft structure to integrate a tracer agent carrier, and supports segmented tracer release and flow process visual observation; the data acquisition and post-processing module is used for analyzing the concentration data of the tracer agent and calculating the liquid production profile and the water content of each section based on an inversion algorithm; physical simulation and quantitative interpretation of the horizontal well segmented liquid production process can be achieved, and a reliable experimental platform is provided for liquid production profile evaluation and tracer performance research.

Description

Technical Field

[0001] This invention belongs to the field of oil and gas field reservoir monitoring technology, specifically relating to a visual simulation experimental device for horizontal well segmented production profiles based on tracers, as well as interpretation and evaluation methods. Background Technology

[0002] Horizontal well technology has become a key technology for the efficient development of oil and gas fields, especially unconventional oil and gas reservoirs. However, after horizontal wells are put into production, challenges such as reservoir heterogeneity and bottom water and edge water erosion lead to a sharp increase in well water cut, which seriously affects development efficiency and economic benefits. Accurately grasping the production status of each section of the horizontal well (i.e., the production profile), including oil production, water production, and water cut in each section, is a prerequisite for implementing effective water control and oil stabilization measures.

[0003] Currently, obtaining production profiles in the field mainly relies on technologies such as production logging (PLT), distributed fiber optic monitoring (DTS / DAS), and tracer monitoring. Among these, production logging must be carried out during well shut-in, resulting in temporary production interruptions; fiber optic logging relies on specialized equipment, and key components are mainly imported; equipment deployment often requires large-scale modifications to the downhole tubing structure and strict restrictions on fluid velocity and flow pattern; furthermore, the reliance on ultra-high precision optoelectronic hardware and complex signal processing algorithms for fiber optic logging signal demodulation significantly increases application costs; these limitations restrict the practical application of traditional logging methods.

[0004] Tracer monitoring technology is an economical and efficient monitoring method. Especially with the development of slow-release tracers, this technology can achieve real-time dynamic monitoring of oil and gas reservoirs throughout their entire lifecycle at low cost. It has already been successfully applied in areas such as production profile interpretation, water breakthrough monitoring, and fracturing effect evaluation. However, current research and application of tracer monitoring technology both domestically and internationally have three significant limitations: 1. Research methods largely rely on numerical simulation and field tests; the accuracy of numerical simulation results depends on the correctness of the model, while field tests are costly, involve many uncontrollable factors, and are difficult to replicate. 2. There is a lack of large-scale physical simulation experimental devices capable of realistically simulating the complex flow environment of horizontal wellbores; this deficiency makes it difficult to directly observe the complex oil-water two-phase flow process within the wellbore and the transport, mixing, and release kinetics of tracers within it. 3. Existing studies on the effects of temperature, salinity, and pH on tracer release performance are mostly conducted under static conditions, neglecting the fluid flow effects in actual production processes. Therefore, the accuracy and applicability of the results obtained from static experiments still need further verification.

[0005] In summary, although tracer monitoring technology has been successfully applied in the field, the lack of a systematic experimental verification process makes the reliability and accuracy of the interpretation results uncertain to some extent, especially under ultra-long horizontal wells and complex completion conditions. Summary of the Invention

[0006] To address at least one of the problems in the prior art, the present invention aims to provide a visual simulation experimental device and interpretation and evaluation method for horizontal well segmented production profiles based on tracers. This solves the problem of the lack of systematic experimental verification in the prior art, especially under conditions of ultra-long horizontal wells and complex completions, which leads to uncertainty in the reliability and accuracy of the interpretation results. The invention enables intuitive study of fluid dynamics, qualitative evaluation of the effects of flow rate, temperature, salinity, and pH on tracer release performance, and physical verification of the horizontal well segmented production profile and water cut interpretation algorithm.

[0007] To achieve the above objectives, the present invention adopts the following technical solution: A tracer-based visualization simulation device for segmented production profiles in horizontal wells includes: The simulated wellbore and tracer module includes a transparent simulated wellbore with a solid tracer disposed inside; the simulated wellbore is used to simulate horizontal well sections. The formation fluid simulation and pretreatment module includes a mixing device and a core holder, which are connected by a connecting pipe. The core holder is connected to the transparent simulated wellbore through a first pipe, and a first flow meter is installed on the first pipe. The formation fluid simulation and pretreatment module is used to realize oil-water mixing and simulate formation fluid production. The fluid injection and control module includes an oil-phase fluid injection unit and an aqueous-phase fluid injection unit. The oil-phase fluid injection unit and the aqueous-phase fluid injection unit are respectively connected to a second pipe and a third pipe, respectively, and the fourth pipe is connected to the mixing device. A second flow meter, a third flow meter, and a fourth flow meter are respectively installed on the second pipe, the third pipe, and the fourth pipe. The fluid injection and control module is used to inject oil-phase fluid and aqueous-phase fluid into the transparent simulated wellbore. The data acquisition and post-processing module includes a collection tank, which is connected to the transparent wellbore via a fifth pipe and is equipped with a concentration analyzer; a fifth flow meter is installed on the fifth pipe; the concentration analyzer is connected to a data processing unit; the data acquisition and post-processing module is used to acquire tracer concentration and invert the production profile and water cut of the horizontal well segments.

[0008] Preferably, the oil phase fluid injection unit includes a first displacement pump and an oil storage tank connected in sequence. The first displacement pump is connected to the oil storage tank through an eighth pipe, and a first regulating valve is installed on the eighth pipe. The oil storage tank is connected to the fourth pipe through a second pipe, and a first valve is installed on the second pipe. The first valve is located between the oil storage tank and the second flow meter. The aqueous fluid injection unit includes a second displacement pump and a water storage tank connected in sequence. The second displacement pump is connected to the water storage tank through a sixth pipe, and a second regulating valve is installed on the sixth pipe. The water storage tank is connected to the fourth pipe through a third pipe, and a second valve is installed on the third pipe. The second valve is located between the water storage tank and the third flow meter.

[0009] Preferably, an integrated tracer release unit is provided inside the transparent simulated wellbore. The integrated tracer release unit includes a tubing, the tracer carrier, the protective sleeve, and the screen. An inflow channel is formed on the side wall of the tubing, and the tracer carrier is wrapped around it. The tracer carrier has perforations on its side wall, and is filled with the solid tracer. The tracer carrier has a solid tracer filling port, and the protective sleeve and the screen are sequentially fitted on its outside. Filter holes are formed on the side wall of the protective sleeve. The transparent simulated well casing is fitted with a heating sleeve and equipped with a high-speed camera; The mixing device is equipped with a mixing tank, the mixing tank has an internal cavity, and a stirrer is installed inside the cavity.

[0010] Preferably, the simulated wellbore and tracer module, the formation fluid simulation and pretreatment module, and the fluid injection and control module form a segmented experimental group, and the segmented experimental group is set to at least two; the multiple transparent simulated wellbores of the multiple simulated wellbore and tracer modules are connected in sequence; The oil pipe is provided with a male connection end and a female connection end at both ends, and the male connection end and the female connection end extend to the outside of both ends of the transparent simulated wellbore; the male connection end and the female connection end of adjacent oil pipes are connected by the couplings respectively; The transparent simulated wellbore has end faces at both ends, and through holes are opened on the end faces. The two ends of the oil pipe are sealed to the inner wall of the through holes and extend to the outside of the transparent simulated wellbore through the through holes. The high-speed camera is configured to be at least two, and the high-speed camera is respectively installed on the outside of each of the transparent simulated well barrels; The collection tank is connected to the waste tank via a seventh pipe.

[0011] A method for interpreting the product profile, based on the above-mentioned experimental setup, includes the following steps: Step S11: Clean the displacement pump, the oil storage tank, the water storage tank, the mixing device, the core holder, the transparent simulated wellbore, the integrated tracer release unit, the liquid collection tank, the waste liquid tank, and the connecting pipes. Step S12: Fill each of the tracer carriers with different types of oil-soluble and water-soluble solid tracers; Step S13: Start the oil phase fluid injection unit and the water phase fluid injection unit to simulate the staged fluid production process of a horizontal well; Step S14: Monitor the injection flow rate and total output flow rate of each segmented experimental group in real time; and collect fluid samples through the collection tank at set time intervals. Step S15: Analyze the tracer concentration in the fluid sample using the concentration analyzer, and obtain the tracer concentration-time curve using the data processing unit; Step S16: Based on the principle of mass conservation and the inversion algorithm, calculate the liquid production profile and water content of each segmented experimental group.

[0012] Preferably, the inversion algorithm calculates the production rate of the horizontal well segments based on the following formula:

[0013]

[0014] In the formula, This represents the oil production of segment i on day j, expressed in m³ / d. The water production of segment i on day j is expressed in m³ / d. The steady-state concentration of the oil tracer in segment i on day j is given in μg / L. The steady-state concentration of the water tracer in segment i on day j is given in μg / L. This represents the daily liquid production on day j, in m³ / d. The total concentration of the oil-water tracer on day j is expressed in μg / L. The water cut of the horizontal well sections is calculated based on the following formula:

[0015] In the formula, The moisture content of segment i on day j is expressed in percent.

[0016] A method for evaluating the effect of fluid flow rate on the sustained-release performance of solid tracers, implemented based on the above-mentioned experimental setup, includes the following steps: Step S21: Clean the displacement pump, the oil storage tank, the water storage tank, the mixing device, the core holder, the transparent simulated wellbore, the integrated tracer release unit, the liquid collection tank, the waste liquid tank, and the connecting pipes. Step S22: The solid tracer to be evaluated is loaded into the tracer carrier, and the integrated tracer release unit is installed inside the transparent simulated wellbore; Step S23: The solid tracer is flushed with fluid at a preset flow rate, and fluid samples are collected periodically through the collection tank; Step S24: Analyze the concentration of the tracer in the fluid sample using the concentration analyzer, and calculate the cumulative release amount of the solid tracer using the data processing unit; Step S25: Replace the solid tracer in the tracer carrier with a new solid tracer of the same batch to be evaluated; change the preset flow rate of the fluid, and repeat steps S23 and S24 at each new preset flow rate. Step S26: Based on the tracer concentration data obtained under different flow rate conditions, the data processing unit plots the release curve of the solid tracer under different preset flow rates, and analyzes the influence of the flow rate of the fluid on the sustained-release performance of the solid tracer.

[0017] A method for evaluating the effect of fluid temperature on the sustained-release performance of solid tracers, implemented based on the above-mentioned experimental setup, includes the following steps: Step S31: Clean the displacement pump, the oil storage tank, the water storage tank, the mixing device, the core holder, the transparent simulated wellbore, the integrated tracer release unit, the liquid collection tank, the waste liquid tank, and the connecting pipes. Step S32: The solid tracer to be evaluated is loaded into the tracer carrier, and the integrated tracer release unit is installed inside the transparent simulated wellbore; Step S33: Heat the solid tracer to a preset temperature using the heating jacket, flush the solid tracer with a fluid at a preset flow rate, and periodically collect fluid samples through the collection tank; Step S34: Analyze the concentration of the tracer in the fluid sample using the concentration analyzer, and calculate the cumulative release amount of the solid tracer using the data processing unit; Step S35: Replace the solid tracer in the tracer carrier with a new solid tracer of the same batch to be evaluated; change the preset temperature of the heating jacket, and repeat steps S33 and S34. Step S36: Based on the tracer concentration data obtained under different temperature fluid conditions, the data processing unit plots the release curves of the solid tracer at different temperatures, and analyzes the influence of temperature on the sustained-release performance of the solid tracer.

[0018] A method for evaluating the effect of fluid salinity on the sustained-release performance of solid tracers, implemented based on the above-mentioned experimental setup, includes the following steps: Step S41: Clean the displacement pump, the oil storage tank, the water storage tank, the mixing device, the core holder, the transparent simulated wellbore, the integrated tracer release unit, the liquid collection tank, the waste liquid tank, and the connecting pipes. Step S42: The solid tracer to be evaluated is loaded into the tracer carrier, and the integrated tracer release unit is installed inside the transparent simulated wellbore; Step S43: Prepare simulated formation water with a preset salinity and inject it into the water storage tank. Use a fluid with a preset flow rate to flush the solid tracer and periodically collect fluid samples through the collection tank. Step S44: Analyze the concentration of the tracer in the fluid sample using the concentration analyzer, and calculate the cumulative release amount of the solid tracer using the data processing unit; Step S45: Replace the solid tracer in the tracer carrier with a new solid tracer of the same batch to be evaluated; change the preset salinity of the simulated formation water, and repeat steps S43 and S44. Step S46: Based on the tracer concentration data obtained under different salinity fluid conditions, the data processing unit plots the release curves of the solid tracer under different salinities, and analyzes the influence of salinity on the sustained-release performance of the solid tracer.

[0019] A method for evaluating the effect of fluid pH on the sustained-release performance of solid tracers, implemented based on the above-mentioned experimental setup, includes the following steps: Step S51: Clean the displacement pump, the oil storage tank, the water storage tank, the mixing device, the core holder, the transparent simulated wellbore, the integrated tracer release unit, the liquid collection tank, the waste liquid tank, and the connecting pipes. Step S52: The solid tracer to be evaluated is loaded into the tracer carrier, and the integrated tracer release unit is installed inside the transparent simulated wellbore; Step S53: Prepare simulated formation water with a preset pH value and inject it into the water storage tank. Rinse the solid tracer with fluid at a preset flow rate and periodically collect fluid samples through the collection tank. Step S54: Analyze the concentration of the tracer in the fluid sample using the concentration analyzer, and calculate the cumulative release amount of the solid tracer using the data processing unit; Step S55: Replace the solid tracer in the tracer carrier with a new solid tracer of the same batch to be evaluated; change the preset pH value of the simulated formation water, and repeat steps S53 and S54. Step S56: Based on the tracer concentration data obtained under different pH fluid conditions, the data processing unit plots the release curves of the solid tracer at different pH values, and analyzes the influence of pH value on the sustained-release performance of the solid tracer.

[0020] The present invention has the following advantages due to the adoption of the above technical solutions: 1. The present invention provides a visualization simulation experimental device and interpretation and evaluation method for horizontal well segmented production profiles based on tracers. The experimental device includes a fluid injection and control module, a formation fluid simulation and pretreatment module, a simulated wellbore and tracer module, and a data acquisition and post-processing module connected sequentially by pipelines, forming a complete closed-loop experimental system. The fluid injection and control module is equipped with independent oil phase and water phase fluid injection units. The oil phase and water phase fluid injection units are respectively equipped with displacement pumps, oil tanks or water tanks, regulating valves and flow meters, which are used to independently inject oil phase and water phase fluids into the corresponding horizontal well segments, and can independently control the oil and water phase injection flow rates of each horizontal well segment. The formation fluid simulation and pretreatment module includes a core holder and a mixing device for simulating formation production and achieving uniform oil-water mixing. The simulated wellbore and tracer module adopts a transparent simulated wellbore structure and integrates a tracer carrier, supporting the visualization and observation of segmented tracer release and flow processes. The data acquisition and post-processing module analyzes tracer concentration data and calculates the production profile and water cut of each segment based on an inversion algorithm. This addresses the lack of systematic experimental verification in existing technologies, especially under conditions of ultra-long horizontal wells and complex completions, which leads to uncertainties in the reliability and accuracy of interpretation results. It enables intuitive study of fluid dynamics, qualitative assessment of the effects of flow velocity, temperature, salinity, and pH on tracer release performance, and physical verification of the horizontal well segmented production profile and water cut interpretation algorithm. It achieves physical simulation and quantitative interpretation of the horizontal well segmented production process, providing a reliable experimental platform for production profile evaluation and tracer performance research.

[0021] 2. The present invention provides a visual simulation experimental device and interpretation and evaluation method for horizontal well segmented production profiles based on tracers. The simulation wellbore and tracer module, formation fluid simulation and pretreatment module, and fluid injection and control module form segmented experimental groups, which can be configured in multiple ways. Multiple independent oil and water phase fluid injection units within these segmented experimental groups can independently control the oil and water phase injection flow rates of multiple horizontal well segments, thereby achieving accurate simulation and independent control of heterogeneous production profiles in horizontal wells. Attached Figure Description Figure 1 This is a schematic diagram of the structure of a tracer-based horizontal well segmented production profile visualization simulation experimental device provided in an embodiment of the present invention.

[0022] Figure 2 This is a schematic diagram of the simulated wellbore and tracer module of a horizontal well segmented production profile visualization simulation experimental device based on tracer provided in an embodiment of the present invention.

[0023] Figure 3This is a cross-sectional view of the simulated wellbore and tracer module of a horizontal well segmented production profile visualization simulation experimental device based on tracer, provided in an embodiment of the present invention.

[0024] Figure 4 This is a schematic diagram of the tracer carrier of a tracer-based horizontal well segmented production profile visualization simulation experimental device provided in an embodiment of the present invention.

[0025] Figure 5 This is a flowchart of a method for interpreting the product profile provided in an embodiment of the present invention.

[0026] Figure 6 This is a flowchart of an embodiment of the present invention, which provides a method for evaluating the effect of fluid flow rate on the sustained-release performance of solid tracers.

[0027] Figure 7 This is a flowchart of an embodiment of the present invention, which provides a method for evaluating the effect of fluid temperature on the sustained-release performance of solid tracers.

[0028] Figure 8 This is a flowchart of an embodiment of the present invention, which provides a method for evaluating the effect of fluid salinity on the sustained-release performance of solid tracers.

[0029] Figure 9 This is a flowchart of an embodiment of the present invention, which provides a method for evaluating the effect of fluid pH on the sustained-release performance of solid tracers.

[0030] Marked in the attached diagram: 101. First displacement pump; 102. Second displacement pump; 111. First regulating valve; 112. Second regulating valve; 121. Oil storage tank; 122. Water storage tank; 131. First valve; 132. Second valve; 141. Second flow meter; 142. Third flow meter; 151. Fourth flow meter; 201. Mixing device; 206. Core holder; 211. First flow meter; 301. Male connector; 302. Oil pipe; 303. Screen; 304. Protective sleeve; 305. Solid tracer; 306. Inflow channel; 307. Connection. 308. Hoop, 309. Female connector, 310. Solid tracer filling port, 311. Tracer carrier, 312. Hole, 313. High-speed camera, 314. Fifth flow meter, 315. Transparent simulated wellbore, 401. Heating jacket, 402. Liquid collection tank, 403. Waste liquid tank, 404. Concentration analyzer, 405. Data processing unit, 501. First pipe, 502. Second pipe, 503. Third pipe, 504. Fourth pipe, 505. Fifth pipe, 506. Sixth pipe, 507. Seventh pipe, 508. Eighth pipe. Detailed Implementation

[0031] To make the objectives, technical solutions, and advantages of this invention clearer, the technical solutions of this invention will be clearly and completely described below with reference to the accompanying drawings. Obviously, the described embodiments are only some, not all, of the embodiments of this invention. All other embodiments obtained by those skilled in the art based on the embodiments of this invention without creative effort are within the scope of protection of this invention.

[0032] In the description of this invention, it should be noted that the terms "upper", "lower", "front", "rear", etc., indicate the orientation or positional relationship based on the orientation or positional relationship shown in the accompanying drawings. They are only for the convenience of describing this invention and simplifying the description, and do not indicate or imply that the system or element referred to must have a specific orientation, or be constructed and operated in a specific orientation. Therefore, they should not be construed as limitations on this invention. The arrow direction in the figure represents the direction of liquid flow.

[0033] In the description of this invention, it should be noted that, unless otherwise explicitly specified and limited, the terms "assembly," "setup," and "connection" should be interpreted broadly. For example, they can refer to a fixed connection, a detachable connection, or an integral connection; they can refer to a mechanical connection or an electrical connection; they can refer to a direct connection or an indirect connection through an intermediate medium; and they can refer to the internal connection of two components. Those skilled in the art can understand the specific meaning of the above terms in this invention based on the specific circumstances.

[0034] This invention provides a visualization simulation experimental device for horizontal well segmented production profiles based on tracers, along with interpretation and evaluation methods. The experimental device includes a fluid injection and control module, a formation fluid simulation and pretreatment module, a simulated wellbore and tracer module, and a data acquisition and post-processing module. It can realistically simulate the actual water production process in each segment of a horizontal well and can quantitatively calculate the production profile and water cut of the horizontal well segments. It is suitable for studying the effects of fluids with different temperatures, salinities, pH values, and flow rates on the release performance of solid tracers.

[0035] The embodiments of the present invention will now be described in detail with reference to the accompanying drawings.

[0036] Example 1 Please refer to Figure 1 The horizontal well segmented production profile visualization simulation experimental device based on tracer provided in this embodiment includes a simulation wellbore and tracer module, a formation fluid simulation and pretreatment module, a fluid injection and control module, and a data acquisition and post-processing module. The simulated wellbore and tracer module includes a transparent simulated wellbore 314, inside which a solid tracer 305 is placed; the simulated wellbore is used to simulate horizontal well sections; The formation fluid simulation and pretreatment module includes a mixing device 201 and a core holder 206, which are connected by a connecting pipe. The core holder 206 is connected to a transparent simulated wellbore 314 via a first pipe 501, and a first flow meter 211 is installed on the first pipe 501. The formation fluid simulation and pretreatment module is used to achieve oil-water mixing and simulate formation fluid production. The fluid injection and control module includes an oil phase fluid injection unit and an aqueous phase fluid injection unit. The oil phase fluid injection unit and the aqueous phase fluid injection unit are connected to a fourth pipe 504 via a second pipe 502 and a third pipe 503, respectively. The fourth pipe 504 is connected to a mixing device 201. A second flow meter 141, a third flow meter 142, and a fourth flow meter 151 are installed on the second pipe 502, the third pipe 503, and the fourth pipe 504, respectively. The fluid injection and control module is used to inject oil phase fluid and aqueous phase fluid into the transparent simulated wellbore 314. The data acquisition and post-processing module includes a collection tank 401, which is connected to the transparent wellbore 314 via a fifth pipe 505 and is equipped with a concentration analyzer 403; a fifth flow meter 313 is installed on the fifth pipe 505; the concentration analyzer 403 is connected to the data processing unit 404; the data acquisition and post-processing module is used to acquire the tracer concentration and invert the production profile and water cut of the horizontal well segment.

[0037] This embodiment of the tracer-based horizontal well segmented production profile visualization simulation experimental device comprises a fluid injection and control module, a formation fluid simulation and pretreatment module, a simulated wellbore and tracer module, and a data acquisition and post-processing module. This system realistically simulates the actual water production process in each segment of a horizontal well during production. It is suitable for quantitatively calculating the production profile and water cut of horizontal well segments and for systematically studying the effects of various environmental factors such as flow rate, temperature, salinity, and pH on the release performance of solid tracer 305.

[0038] Connection interfaces can be installed at the ends of the pipes, and connections between modules can be achieved through the connections between these interfaces.

[0039] Specifically, the oil phase fluid injection unit includes a first displacement pump 101 and an oil storage tank 121 connected in sequence. The first displacement pump 101 is connected to the oil storage tank 121 through an eighth pipe 508, and a first regulating valve 111 is installed on the eighth pipe 508. The oil storage tank 121 is connected to a fourth pipe 504 through a second pipe 502, and a first valve 131 is installed on the second pipe 502. The first valve 131 is located between the oil storage tank 121 and a second flow meter 141. The aqueous fluid injection unit includes a second displacement pump 102 and a water storage tank 122 connected in sequence. The second displacement pump 102 is connected to the water storage tank 122 through a sixth pipe 506, and a second regulating valve 112 is installed on the sixth pipe 506. The water storage tank 122 is connected to a fourth pipe 504 through a third pipe 503, and a second valve 132 is installed on the third pipe 503. The second valve 132 is located between the water storage tank 122 and a third flow meter 142.

[0040] Please refer to the reference. Figures 1 to 4 Specifically, an integrated tracer release unit is installed inside the transparent simulated wellbore 314. The integrated tracer release unit includes a tubing 302, a tracer carrier 310, a protective sleeve 304, and a screen 303. An inflow channel 306 is opened on the side wall of the tubing 302, and the tracer carrier 310 is wrapped around it. An aperture 311 is opened on the side wall of the tracer carrier 310, and solid tracer 305 is filled inside it. A solid tracer filling port 309 is provided at one end of the tracer carrier 310, and the protective sleeve 304 and the screen 303 are sequentially wrapped around it. Filter holes are opened on the side wall of the protective sleeve 304. A heating sleeve 315 is fitted over the outside of the transparent simulated well shaft 314, and a high-speed camera 312 is installed thereon. The mixing device 201 is equipped with a mixing tank, the interior of which is provided with a cavity, and a stirrer is installed inside the cavity.

[0041] Specifically, the simulated wellbore and tracer module, the formation fluid simulation and pretreatment module, and the fluid injection and control module form a segmented experimental group, with at least two segmented experimental groups; multiple transparent simulated wellbores 314 of multiple simulated wellbore and tracer modules are connected in sequence; The two ends of the tubing 302 are respectively provided with a male connection end 301 and a female connection end 308, which extend to the outside of the two ends of the transparent simulated wellbore 314; the male connection end 301 and the female connection end 308 of adjacent tubing 302 are connected by couplings 307 respectively. The transparent simulated wellbore 314 has end faces at both ends, and through holes are opened on the end faces. The two ends of the tubing 302 are sealed and connected to the inner wall of the through holes, and extend to the outside of the transparent simulated wellbore 314 through the through holes. At least two high-speed cameras 312 are provided, with each high-speed camera 312 installed on the outside of each transparent simulated well shaft 314; The collection tank 401 is connected to the waste tank 402 via the seventh pipe 507.

[0042] Specifically, all connecting pipes in the device are pressure-resistant pipes that can withstand the experimental design pressure using existing technology.

[0043] The connection interface is set as a self-sealing connection interface of existing technology. The simulated wellbore and tracer module, formation fluid simulation and pretreatment module, fluid injection and control module and data acquisition and post-processing module are sealed together through pipelines, regulating valves and self-sealing connection interfaces to form a closed loop experimental system.

[0044] Each flow meter 141 has a range of 0.1~100 mL / min, and each displacement pump adopts a high-precision plunger pump or injection pump with existing technology, with a range of 0.01~50 mL / min and a maximum working pressure of not less than 10MPa.

[0045] The displacement pump and its control system are connected to the fluid injection and control module through the liquid injection channel, providing liquid displacement conditions for the transparent simulated wellbore 314.

[0046] The simulated wellbore and tracer module includes a transparent wellbore 314 and a flow meter 313. The inlet and outlet ends of the simulated wellbore and tracer module are connected to the formation fluid simulation and preprocessing module and the data acquisition and postprocessing module through pressure-resistant pipes, respectively.

[0047] The tracer carrier 310 is internally filled with oil-soluble or water-soluble solid tracer 305, and externally covered by a protective sleeve 304 with filter holes and a sieve 303. The tracer carrier 310 is designed with a detachable structure, which facilitates the replacement of different types of solid tracers 305 for evaluation experiments to investigate the effect of fluid flushing on tracer release performance; The transparent simulated wellbore 314 allows researchers to directly observe the fluid flow and diffusion process of the solid tracer 304 within it. The transparent simulated wellbore 314 is made of a high-strength transparent material, such as polymethyl methacrylate (PMMA, commonly known as acrylic) or polycarbonate (PC). This material combines excellent optical transparency, necessary mechanical strength, and good chemical resistance, meeting the process requirements for direct visualization of the fluid flow within the transparent simulated wellbore 314 during experiments.

[0048] The outer ring of the transparent simulated wellbore 314 is fitted with a heating sleeve 315 and a high-speed camera 312. The heating sleeve 315 is used to simulate different formation temperature environments. The high-speed camera 312 is used to record the fluid flow state inside the transparent simulated wellbore 314, that is, to record the flow state in the transparent simulated wellbore 314 on video. The image data is synchronously transmitted to the data acquisition instrument for storage and post-processing analysis.

[0049] The experimental group was divided into five sections. The five fluid injection and control modules were equipped with ten independent fluid injection units, namely, five oil phase fluid injection units and five water phase fluid injection units.

[0050] The transparent simulated wellbore 314 of each horizontal well simulation segment is connected end to end by pressure-resistant pipes to form a continuous simulated wellbore 314. Five transparent simulated wellbore 314 are connected in series to simulate the segmentation of the horizontal well; each transparent simulated wellbore 314 represents an independent horizontal well segment, each horizontal well segment represents a horizontal well producing layer, and all transparent simulated wellbore 314 are connected by pressure-resistant pipes.

[0051] Five oil and water phase fluid injection units correspond one-to-one with five series-connected transparent simulated wellbores 314, used to independently control and monitor the oil and water flow rates injected into the transparent simulated wellbores 314 of each horizontal well segment. Each oil and water phase fluid injection unit includes an oil storage tank 121 and a water storage tank 122, with a regulating valve and a flow meter installed sequentially on the outlet pipeline of each tank. By independently adjusting the opening of the regulating valve on each pipeline, the oil and water phase flow rates flowing into the transparent simulated wellbore 314 of the corresponding horizontal well segment can be independently controlled. The flow meter is used to monitor the fluid flow rate through the storage tank in real time, achieving precise control of the oil-water ratio entering each segment. A fourth flow meter 151 is installed at the outlet of each oil and water phase fluid injection unit to monitor the total flow rate of the mixed fluid entering the transparent simulated wellbore 314 of each horizontal well segment.

[0052] The five formation fluid simulation and pretreatment modules include five sets of core holders 206 connected in parallel and a mixing device 201. The five core holders 206 can be used to fix and accommodate core samples of different sizes, including full-size cores with a diameter of 100 mm and standard core columns with a diameter of 25 mm, to simulate the fluid production process in actual formations and the entry of real oil-water mixtures into the wellbore. The mixing device 201 is equipped with a stirring structure to uniformly mix the oil and water two-phase fluids, simulating the simultaneous production of oil and water in a horizontal well. Flow meters on both sides of the mixing device 201 and the core holders 206 are used to monitor the fluid flow rate in the mixing device 201 and the fluid flow rate through the core in real time, respectively.

[0053] An oil pipe 302 is installed inside the transparent simulated wellbore 314. The two ends of the oil pipe 302 are respectively provided with a male connection end 301, a female connection end 308 and a coupling 307, which are used to realize the interconnection of the transparent simulated wellbore 314 of adjacent horizontal well sections.

[0054] The tubing 302, coupling 307, screen 303, protective sleeve 304, tracer carrier 310, transparent simulated wellbore 314, and heating sleeve 315 are set as coaxial cylindrical components.

[0055] The solid tracer filling port 309 is configured as an annular groove. The solid tracer 305 is in granular form and is filled within the tracer carrier 310.

[0056] The inflow channel 306, filter holes and orifices 311 are all circular and are evenly arranged in multiples.

[0057] The protective sleeve 304 has multiple holes 311, forming a fluid flow channel. During its flow, the formation fluid passes sequentially through the screen 303 and the holes 311 of the protective sleeve 304, then comes into contact with the solid tracer 305 within the tracer carrier 310, achieving controlled release of the solid tracer 305. A heat jacket 315 is fitted over the transparent simulated wellbore 314 to provide a controllable temperature environment for the experimental system, simulating tracer release behavior under different formation temperature conditions. A fifth flow meter 313 monitors the total fluid flow through all the series-connected transparent simulated wellbores 314, i.e., the total production of the simulated horizontal well.

[0058] The concentration analyzer 403 can be an inductively coupled plasma mass spectrometer (ICP-MS) using existing technology. The data processing unit 404 can be a data analyzer using existing technology. The fluid produced during the experiment is collected in the collection tank 401, and the waste liquid is temporarily stored in the waste liquid tank 402. After sampling from the collection tank 401, the collected fluid sample is analyzed using an inductively coupled plasma mass spectrometer to obtain the tracer concentration; and the data analyzer receives the concentration data, and based on the concentration data and the principle of mass conservation, executes a preset production profile inversion algorithm to calculate the production profile, oil production, water production, and water cut of the transparent simulated wellbore 314 corresponding to each horizontal well segment.

[0059] The collection tank 401 and the waste liquid tank 402 constitute a sample collection and waste liquid recovery unit. The collection tank 401 is connected to the outlet of the simulated well and the tracer module through a pipeline and is used to collect the sample solution after the experiment. The waste liquid tank 402 is used to recover the experimental waste liquid to ensure that the experimental process meets environmental protection requirements.

[0060] Example 2 Please refer to the reference. Figures 1 to 5 The method for interpreting the product profile provided in this embodiment is based on the experimental apparatus described in Embodiment 1 and includes the following steps: Step S11: Cleaning displacement pump 101, oil storage tank 121, water storage tank 122, mixing device 201, core holder 206, transparent simulated wellbore 314, integrated tracer release unit, liquid collection tank 401, waste liquid tank 402 and connecting pipes. Step S12: Fill each tracer carrier 310 with different types of oil-soluble and water-soluble solid tracers 305; Step S13: Start the oil phase fluid injection unit and the water phase fluid injection unit to simulate the staged fluid production process of a horizontal well; Step S14: Monitor the injection flow rate and total output flow rate of each segmented experimental group in real time; and collect fluid samples through the collection tank 401 at set time intervals. Step S15: Analyze the tracer concentration in the fluid sample using the concentration analyzer 403, and obtain the tracer concentration-time curve using the data processing unit 404; Step S16: Based on the principle of mass conservation and the inversion algorithm, calculate the liquid production profile and water content of each segmented experimental group.

[0061] Specifically, step S16 includes: Step S161, Production Profile Calculation: The inversion algorithm calculates the production rate of the horizontal well segments based on the following formula.

[0062]

[0063] In the formula, This represents the oil production of segment i on day j, expressed in m³ / d. The water production of segment i on day j is expressed in m³ / d. The steady-state concentration of the oil tracer in segment i on day j is given in μg / L. The steady-state concentration of the water tracer in segment i on day j is given in μg / L. This represents the daily liquid production on day j, in m³ / d. The total concentration of the oil-water tracer on day j is expressed in μg / L. Since the production of a horizontal well is fixed, the horizontal well is considered to be in stable production, and the tracer concentration obtained is the steady-state concentration data.

[0064] Step S162, Result Verification: Verify the calculated results. and The data were compared with those recorded by the second flow meter 141 and the third flow meter 142 to verify the correctness of the simulation experiment.

[0065] Step S163, Moisture content calculation: Based on the calculation obtained in the above steps... and The water cut of each horizontal well section on a given day can be calculated using the following formula:

[0066] In the formula, The moisture content of segment i on day j is expressed in percent.

[0067] Specifically, step S11, device cleaning and preparation, involves sequentially cleaning the fluid injection and control module, formation fluid simulation and pretreatment module, simulation wellbore and tracer module, and data acquisition and post-processing module with distilled water, including the collection tank 401 and waste tank 402, as well as the pressure-resistant pipes between modules. The inlets and outlets for all liquids and solids in the experimental apparatus are also cleaned, ensuring all connections are sealed. After cleaning, the entire experimental apparatus is dried to ensure no residual impurities or liquid remain inside.

[0068] Between steps S11 and S12, step S111, core sample preparation and loading, is performed: a full-size reservoir core sample with perforation structure is prepared by pre-drilling or mechanical drilling; the pre-drilling method forms holes by removing the mold after molding; the mechanical drilling method uses a drill bit of a specific diameter to drill holes at a predetermined depth at the end of the core; the prepared core sample is loaded into the corresponding core holder 206 and fixed.

[0069] Step S12, Preparation and Filling of Solid Tracer: Includes: Step S121, Preparation of water-soluble solid tracer: Weigh a specific mass of epoxy resin 506 and a fluorobenzoic acid tracer (such as 2-fluorobenzoic acid, 2,6-difluorobenzoic acid, etc.), mix them evenly, and then put them into a Schott bottle. Soften the mixture in an oven to a low-viscosity liquid state. Add the curing agent maleic anhydride, stir until completely dissolved, and then pour the mixture into a polytetrafluoroethylene mold. Place the mold in a drying oven again to cure. After cooling to room temperature, demold to obtain the cured water-soluble solid tracer 305. Five different types of water-soluble solid tracer 305 can be prepared using this method.

[0070] Step S122, Preparation of oil-soluble solid tracers: The above-mentioned fluorobenzoic acid tracers are replaced with perfluoroaromatic tracers (such as perfluorotoluene, perfluoroxylene, etc.), and the remaining steps are the same as the preparation process of water-soluble tracers, to obtain five different types of oil-soluble solid tracers 305. The prepared oil-soluble and water-soluble solid tracers 305 are combined in pairs into five groups, and respectively filled into tracer carriers 310 in transparent simulated wellbore 314.

[0071] In step S12, five different types of oil-soluble and water-soluble solid tracers 305 are filled into the tracer carrier 310 in the transparent simulated wellbore 314 corresponding to the five target horizontal well sections.

[0072] In step S13, the water and oil injection flow rates and ratios in the transparent simulated wellbore 314 corresponding to the target horizontal well segment are set, and the data acquisition and post-processing module is checked to ensure normal operation. The fluid injection unit is started to simulate the inflow process of formation fluid through the horizontal well segment.

[0073] Step S13 includes: Step S131, Formation oil and formation water preparation and injection: High-viscosity mineral oil (such as white oil) is selected as the simulated formation oil. The density and viscosity can be adjusted by mixing different grades of white oil. Then it is loaded into the oil storage tank 121. The simulated formation water is based on distilled water or deionized water. According to the conventional formation water salinity data, inorganic salts such as sodium chloride and calcium chloride are added in proportion. After stirring until completely dissolved and clarified, it is loaded into the water storage tank 122.

[0074] Step S132, Horizontal Well Stable Production Simulation: Start the first displacement pump 101 and the second displacement pump 102, open all valves and the mixing tank, so that the oil and water two-phase fluids are evenly mixed and flow into the transparent simulation wellbore 314 to simulate the stable production conditions of the horizontal well, and adjust the temperature value of the heating jacket 315 to simulate the downhole temperature environment; by adjusting the first valve 131 and the second valve 132, the difference in production volume of each horizontal well segment is simulated, and the production of each horizontal well segment is monitored using the fourth flow meter 151.

[0075] Step S14: Obtaining the production volume of horizontal well segments: Real-time monitoring of the flow rate values ​​of each flow meter in each segment of the experimental group; recording the data of the second flow meter 141 and the third flow meter 142 as the daily oil and water production of each horizontal well segment; synchronously recording the reading of the fourth flow meter 151 of each segment as the daily total production volume of each horizontal well segment; and monitoring the daily total production volume of all horizontal well segments through the fifth flow meter 313.

[0076] In step S14, the fluid flow status is observed through the visualized transparent simulated wellbore 314, and the data of each flow meter are monitored and recorded in real time; fluid samples are collected from the collection tank 401 periodically.

[0077] In step S15, tracer concentration data is acquired: the concentration of each tracer in the fluid sample is determined by an inductively coupled plasma mass spectrometer 403 correlation analysis device, and the tracer concentration-time change curve is obtained.

[0078] In step S16, based on the tracer concentration data and the fluid flow records of the transparent simulated wellbore 314 corresponding to each horizontal well segment, the production profile and water cut in the target horizontal well segment corresponding to each transparent simulated wellbore 314 are calculated based on the principle of mass conservation and the inversion algorithm.

[0079] Example 3 Please refer to the reference. Figures 1 to 5 and Figure 6 The method for evaluating the effect of fluid flow rate on the sustained-release performance of solid tracers provided in this embodiment is based on the experimental apparatus described in Embodiment 1 and includes the following steps: Step S21: Cleaning displacement pump 101, oil storage tank 121, water storage tank 122, mixing device 201, core holder 206, transparent simulated wellbore 314, integrated tracer release unit, liquid collection tank 401, waste liquid tank 402 and connecting pipes. Step S22: The solid tracer 305 to be evaluated is loaded into the tracer carrier 310, and the integrated tracer release unit is installed in the transparent simulated wellbore 314; Step S23: The solid tracer 305 is flushed with fluid at a preset flow rate, and fluid samples are collected periodically through the collection tank 401. Step S24, tracer concentration monitoring: The tracer concentration in the fluid sample is analyzed by the concentration analyzer 403, and the cumulative release of the solid tracer 305 is calculated by the data processing unit 404; Step S25: Replace the solid tracer 305 in the tracer carrier 310 with a new solid tracer of the same batch to be evaluated; change the preset flow rate of the fluid, and repeat steps S23 and S24 at each new preset flow rate. Step S26, Flow rate influence analysis: Based on the tracer concentration data obtained under different flow rate conditions, the data processing unit 404 plots the release curves of the solid tracer 305 under different preset flow rates, and analyzes the influence of the flow rate of the fluid on the sustained release performance of the solid tracer 305.

[0080] Specifically, the operation process of step S21 can be the same as that of step S11. Here, the influence of the fluid flow rate on the sustained-release performance of the solid tracer 305 is analyzed; the influence of the sustained-release performance refers to the release rate of the solid tracer.

[0081] Step S22, Preparation and filling of solid tracer: Select one of the solid tracers 305 to be evaluated prepared in step S12 and fill it into the tracer carrier 310 in the transparent simulated wellbore 314 before each group of experiments.

[0082] The operation process of step S22 can be the same as that of step S12.

[0083] Between step S21 and step S22, step S111 is performed.

[0084] Step S23 includes: Step S231, Formation oil and formation water preparation and injection: Formation oil simulation uses high-viscosity mineral oil (such as white oil). The physical properties can be adjusted by mixing different grades of white oil before being loaded into oil storage tank 121. Formation water simulation uses distilled water or deionized water as the base liquid. According to the actual formation water salinity data, an appropriate amount of inorganic salts such as sodium chloride and calcium chloride are added to prepare the solution. After stirring until completely dissolved and clarified, it is loaded into water storage tank 122.

[0085] Step S232, Horizontal Well Production Status Simulation and Flow Rate Control: When evaluating the oil-soluble solid tracer 305, start the first displacement pump 101, open the first regulating valve 111, the first valve 131, and the mixing tank to allow mineral oil to flow into the transparent simulated wellbore 314; when evaluating the water-soluble solid tracer 305, start the second displacement pump 102, open the second regulating valve 112, the second valve 132, and the mixing tank to allow formation water to flow into the transparent simulated wellbore 314; by adjusting the opening of the first valve 131 (or the second valve 132), the fluid flow rate is changed, and the flow rate conditions for flushing the solid tracer 305 are monitored in real time using the fourth flow meter 151.

[0086] In step S25, the fluid flow rate is changed by altering the opening of the regulating valve. Steps S23 and S24 are repeated to obtain the relationship between the release amount of solid tracer and time at different flow rates.

[0087] In step S26, the cumulative release data of solid tracer 305 under different fluid flow rates are collected, the release curve of solid tracer 305 is plotted, and the influence of fluid flushing velocity on the sustained release performance of solid tracer 305 is investigated.

[0088] Example 4 Please refer to the reference. Figures 1 to 5 and Figure 7 The method for evaluating the effect of fluid temperature on the sustained-release performance of solid tracers provided in this embodiment is based on the experimental apparatus described in Embodiment 1 and includes the following steps: Step S31: Cleaning displacement pump 101, oil storage tank 121, water storage tank 122, mixing device 201, core holder 206, transparent simulated wellbore 314, integrated tracer release unit, liquid collection tank 401, waste liquid tank 402 and connecting pipes. Step S32: The solid tracer 305 to be evaluated is loaded into the tracer carrier 310, and the integrated tracer release unit is installed in the transparent simulated wellbore 314; Step S33: Heat to a preset temperature through heating jacket 315, flush solid tracer 305 with fluid at a preset flow rate, and periodically collect fluid samples through collection tank 401; Step S34: Analyze the concentration of tracer in the fluid sample using the concentration analyzer 403, and calculate the cumulative release amount of solid tracer 305 using the data processing unit 404; Step S35: Replace the solid tracer 305 in the tracer carrier 310 with a new solid tracer of the same batch to be evaluated; change the preset temperature of the heating jacket 315, and repeat steps S33 and S34. Step S36, Temperature Influence Analysis: Based on the tracer concentration data obtained under different temperature fluid conditions, the release curves of solid tracer 305 at different temperatures are plotted by the data processing unit 404 to analyze the influence of temperature on the sustained-release performance of solid tracer 305.

[0089] Specifically, the operation process of step S31 can be the same as that of step S11. The operation process of step S32 can be the same as that of step S12 or step S22.

[0090] Between step S31 and step S32, step S111 is performed.

[0091] Step S35, Setting different temperature conditions: By adjusting the heating jacket 315, different fluid temperature conditions are set, such as 50℃, 70℃, and 90℃, and multiple sets of temperature-controlled flushing experiments are carried out in sequence.

[0092] Example 5 Please refer to the reference. Figures 1 to 5 and Figure 8 The method for evaluating the effect of fluid salinity on the sustained-release performance of solid tracers provided in this embodiment is based on the experimental apparatus described in Embodiment 1 and includes the following steps: Step S41: Cleaning displacement pump 101, oil storage tank 121, water storage tank 122, mixing device 201, core holder 206, transparent simulated wellbore 314, integrated tracer release unit, liquid collection tank 401, waste liquid tank 402 and connecting pipes. Step S42: The solid tracer 305 to be evaluated is loaded into the tracer carrier 310, and the integrated tracer release unit is installed in the transparent simulated wellbore 314; Step S43: Prepare simulated formation water with a preset salinity and inject it into the water storage tank 122. Use a fluid with a preset flow rate to flush the solid tracer 305 and collect fluid samples periodically through the collection tank 401. Step S44: Analyze the concentration of tracer in the fluid sample using the concentration analyzer 403, and calculate the cumulative release amount of solid tracer 305 using the data processing unit 404; Step S45: Replace the solid tracer 305 in the tracer carrier 310 with a new solid tracer of the same batch to be evaluated; change the preset salinity of the simulated formation water, and repeat steps S43 and S44. Step S46, Salinity Influence Analysis: Based on the tracer concentration data obtained under different salinity fluid conditions, the release curves of solid tracer 305 under different salinities are plotted by the data processing unit 404 to analyze the influence of salinity on the sustained-release performance of solid tracer 305.

[0093] Specifically, the operation process of step S41 can be the same as that of step S11. The operation process of step S42 can be the same as that of step S12 or step S22.

[0094] Between step S41 and step S42, step S111 is performed.

[0095] Step S45: Setting different salinity conditions: Prepare simulated formation water with different salinities (i.e., mineralization), such as mineralization of 5000 mg / L, 7500 mg / L, and 10000 mg / L, and conduct multiple sets of salinity condition comparison experiments in sequence.

[0096] Example 6 Please refer to the reference. Figures 1 to 5 and Figure 9 The method for evaluating the effect of fluid pH on the sustained-release performance of solid tracers provided in this embodiment is based on the experimental apparatus described in Embodiment 1 and includes the following steps: Step S51: Cleaning displacement pump 101, oil storage tank 121, water storage tank 122, mixing device 201, core holder 206, transparent simulated wellbore 314, integrated tracer release unit, liquid collection tank 401, waste liquid tank 402 and connecting pipes. Step S52: The solid tracer 305 to be evaluated is loaded into the tracer carrier 310, and the integrated tracer release unit is installed in the transparent simulated wellbore 314; Step S53: Prepare simulated formation water with a preset pH value and inject it into the water storage tank 122. Use a fluid with a preset flow rate to flush the solid tracer 305 and collect fluid samples periodically through the collection tank 401. Step S54: Analyze the concentration of tracer in the fluid sample using the concentration analyzer 403, and calculate the cumulative release amount of solid tracer 305 using the data processing unit 404; Step S55: Replace the solid tracer 305 in the tracer carrier 310 with a new solid tracer of the same batch to be evaluated; change the preset pH value of the simulated formation water, and repeat steps S53 and S54. Step S56, pH value influence analysis: Based on the tracer concentration data obtained under different pH fluid conditions, the release curves of solid tracer 305 under different pH values ​​are plotted by the data processing unit 404 to analyze the influence of pH value on the sustained release performance of solid tracer 305.

[0097] Specifically, the operation process of step S51 can be the same as that of step S11. The operation process of step S52 can be the same as that of step S12 or step S22.

[0098] Between step S51 and step S52, step S111 is performed.

[0099] Step S55: Setting different pH conditions: Prepare simulated formation water with different pH values, such as pH 5.0, pH 7.0, and pH 9.0, and conduct multiple sets of pH condition comparison experiments in sequence.

[0100] Finally, it should be noted that the above embodiments are only used to illustrate the technical solutions of the present invention, and not to limit them; although the present invention has been described in detail with reference to the foregoing embodiments, those skilled in the art should understand that modifications can still be made to the technical solutions described in the foregoing embodiments, or equivalent substitutions can be made to some of the technical features; and these modifications or substitutions do not cause the essence of the corresponding technical solutions to deviate from the spirit and scope of the technical solutions of the embodiments of the present invention.

Claims

1. A visual simulation experimental device for horizontal well segmented production profiles based on tracers, characterized in that, include: The simulated wellbore and tracer module includes a transparent simulated wellbore (314), inside which a solid tracer (305) is disposed; the simulated wellbore is used to simulate horizontal well sections; The formation fluid simulation and pretreatment module includes a mixing device (201) and a core holder (206), which are connected by a connecting pipe; the core holder (206) is connected to the transparent simulated wellbore (314) through a first pipe (501), and a first flow meter (211) is installed on the first pipe (501); the formation fluid simulation and pretreatment module is used to realize oil-water mixing and simulate formation fluid production; The fluid injection and control module includes an oil phase fluid injection unit and an aqueous phase fluid injection unit. The oil phase fluid injection unit and the aqueous phase fluid injection unit are respectively connected to a second pipe (502) and a third pipe (503) and a fourth pipe (504), respectively. The fourth pipe (504) is connected to the mixing device (201). A second flow meter (141), a third flow meter (142), and a fourth flow meter (151) are respectively installed on the second pipe (502), the third pipe (503), and the fourth pipe (504). The fluid injection and control module is used to inject oil phase fluid and aqueous phase fluid into the transparent simulated wellbore (314). The data acquisition and post-processing module includes a collection tank (401), which is connected to the transparent wellbore (314) via a fifth pipe (505) and is equipped with a concentration analyzer (403); a fifth flow meter (313) is installed on the fifth pipe (505); the concentration analyzer (403) is connected to a data processing unit (404); the data acquisition and post-processing module is used to acquire tracer concentration and invert the production profile and water cut of the horizontal well segment.

2. The tracer-based horizontal well segmented production profile visualization simulation experimental device according to claim 1, characterized in that, The oil phase fluid injection unit includes a first displacement pump (101) and an oil storage tank (121) connected in sequence. The first displacement pump (101) is connected to the oil storage tank (121) through an eighth pipe (508), and a first regulating valve (111) is installed on the eighth pipe (508). The oil storage tank (121) is connected to the fourth pipe (504) through a second pipe (502), and a first valve (131) is installed on the second pipe (502). The first valve (131) is located between the oil storage tank (121) and the second flow meter (141). The aqueous fluid injection unit includes a second displacement pump (102) and a water storage tank (122) connected in sequence. The second displacement pump (102) is connected to the water storage tank (122) through a sixth pipe (506), and a second regulating valve (112) is installed on the sixth pipe (506). The water storage tank (122) is connected to the fourth pipe (504) through a third pipe (503), and a second valve (132) is installed on the third pipe (503). The second valve (132) is located between the water storage tank (122) and the third flow meter (142).

3. The tracer-based horizontal well segmented production profile visualization simulation experimental device according to claim 2, characterized in that, An integrated tracer release unit is provided inside the transparent simulated wellbore (314). The integrated tracer release unit includes an oil pipe (302), the tracer carrier (310), the protective sleeve (304), and the screen (303). An inflow channel (306) is opened on the side wall of the oil pipe (302), and the tracer carrier (310) is wrapped around it. An eyelet (311) is opened on the side wall of the tracer carrier (310), and the solid tracer (305) is filled inside. The tracer carrier (310) is provided with a solid tracer filling port (309), and the protective sleeve (304) and the screen (303) are sequentially wrapped around it. Filter holes are opened on the side wall of the protective sleeve (304). The transparent simulated well casing (314) is covered with a heating sleeve (315) and a high-speed camera (312) is installed. The mixing device (201) is provided with a mixing tank, the interior of which is provided with a cavity, and a stirrer is provided inside the cavity.

4. The tracer-based horizontal well segmented production profile visualization simulation experimental device according to claim 3, characterized in that, The simulated wellbore and tracer module, the formation fluid simulation and pretreatment module, and the fluid injection and control module form a segmented experimental group, and the segmented experimental group is set to at least two; the multiple transparent simulated wellbores (314) of the multiple simulated wellbore and tracer modules are connected in sequence; The oil pipe (302) is provided with a male connection end (301) and a female connection end (308) at both ends, and the male connection end (301) and the female connection end (308) extend to the outside of both ends of the transparent simulated wellbore (314); the male connection end (301) and the female connection end (308) of adjacent oil pipes (302) are connected by the coupling (307); The transparent simulated wellbore (314) has end faces at both ends, and through holes are opened on the end faces. The two ends of the oil pipe (302) are respectively sealed to the inner wall of the through hole and extend to the outside of the transparent simulated wellbore (314) through the through hole. The high-speed camera (312) is configured to be at least two, and the high-speed camera (312) is respectively installed on the outside of each of the transparent simulated well barrels (314). The collection tank (401) is connected to the waste tank (402) via the seventh pipe (507).

5. A method for interpreting a product fluid profile, characterized in that, Based on the experimental apparatus as described in claim 4, and including the following steps: Step S11: Clean the displacement pump (101), the oil storage tank (121), the water storage tank (122), the mixing device (201), the core holder (206), the transparent simulated wellbore (314), the integrated tracer release unit, the liquid collection tank (401), the waste liquid tank (402), and the connecting pipes; Step S12: Fill each of the tracer carriers (310) with different types of oil-soluble and water-soluble solid tracers (305); Step S13: Start the oil phase fluid injection unit and the water phase fluid injection unit to simulate the staged fluid production process of a horizontal well; Step S14: Monitor the injection flow rate and total output flow rate of each segmented experimental group in real time; and collect fluid samples through the collection tank (401) at set time intervals; Step S15: Analyze the tracer concentration in the fluid sample using the concentration analyzer (403), and obtain the tracer concentration-time curve using the data processing unit (404); Step S16: Based on the principle of mass conservation and the inversion algorithm, calculate the liquid production profile and water content of each segmented experimental group.

6. The method for interpreting the product profile according to claim 5, characterized in that, The inversion algorithm calculates the production rate of horizontal well segments based on the following formula: In the formula, This represents the oil production of segment i on day j, expressed in m³ / d. The water production of segment i on day j is expressed in m³ / d. The steady-state concentration of the oil tracer in segment i on day j is given in μg / L. The steady-state concentration of the water tracer in segment i on day j is given in μg / L. This represents the daily liquid production on day j, in m³ / d. The total concentration of the oil-water tracer on day j is expressed in μg / L. The water cut of the horizontal well sections is calculated based on the following formula: In the formula, The moisture content of segment i on day j is expressed in percent.

7. A method for evaluating the effect of fluid flow rate on the sustained-release performance of solid tracers, characterized in that, Based on the experimental apparatus as described in claim 4, and including the following steps: Step S21: Clean the displacement pump (101), the oil storage tank (121), the water storage tank (122), the mixing device (201), the core holder (206), the transparent simulated wellbore (314), the integrated tracer release unit, the liquid collection tank (401), the waste liquid tank (402), and the connecting pipes; Step S22: The solid tracer (305) to be evaluated is loaded into the tracer carrier (310), and the integrated tracer release unit is installed in the transparent simulated wellbore (314); Step S23: The solid tracer (305) is flushed with fluid at a preset flow rate, and fluid samples are collected periodically through the collection tank (401); Step S24: Analyze the concentration of the tracer in the fluid sample using the concentration analyzer (403), and calculate the cumulative release of the solid tracer (305) using the data processing unit (404); Step S25: Replace the solid tracer (305) in the tracer carrier (310) with a new solid tracer of the same batch to be evaluated; change the preset flow rate of the fluid, and repeat steps S23 and S24 at each new preset flow rate; Step S26: Based on the tracer concentration data obtained under different flow rate conditions, the data processing unit (404) plots the release curve of the solid tracer (305) under different preset flow rates, and analyzes the influence of the flow rate of the fluid on the sustained release performance of the solid tracer (305).

8. A method for evaluating the effect of fluid temperature on the sustained-release performance of solid tracers, characterized in that, Based on the experimental apparatus as described in claim 4, and including the following steps: Step S31: Clean the displacement pump (101), the oil storage tank (121), the water storage tank (122), the mixing device (201), the core holder (206), the transparent simulated wellbore (314), the integrated tracer release unit, the liquid collection tank (401), the waste liquid tank (402), and the connecting pipes; Step S32: The solid tracer (305) to be evaluated is loaded into the tracer carrier (310), and the integrated tracer release unit is installed in the transparent simulated wellbore (314); Step S33: Heat to a preset temperature through the heating jacket (315), flush the solid tracer (305) with a fluid at a preset flow rate, and periodically collect fluid samples through the collection tank (401); Step S34: Analyze the concentration of the tracer in the fluid sample using the concentration analyzer (403), and calculate the cumulative release of the solid tracer (305) using the data processing unit (404); Step S35: Replace the solid tracer (305) in the tracer carrier (310) with a new solid tracer of the same batch to be evaluated; change the preset temperature of the heating jacket (315), and repeat steps S33 and S34. Step S36: Based on the tracer concentration data obtained under different temperature fluid conditions, the data processing unit (404) plots the release curves of the solid tracer (305) at different temperatures, and analyzes the influence of temperature on the sustained-release performance of the solid tracer (305).

9. A method for evaluating the effect of fluid salinity on the sustained-release performance of solid tracers, characterized in that, Based on the experimental apparatus as described in claim 4, and including the following steps: Step S41: Clean the displacement pump (101), the oil storage tank (121), the water storage tank (122), the mixing device (201), the core holder (206), the transparent simulated wellbore (314), the integrated tracer release unit, the liquid collection tank (401), the waste liquid tank (402), and the connecting pipes; Step S42: The solid tracer (305) to be evaluated is loaded into the tracer carrier (310), and the integrated tracer release unit is installed in the transparent simulated wellbore (314); Step S43: Prepare simulated formation water with a preset salinity and inject it into the water storage tank (122). The solid tracer (305) is flushed by a fluid with a preset flow rate, and fluid samples are collected periodically through the collection tank (401). Step S44: Analyze the concentration of the tracer in the fluid sample using the concentration analyzer (403), and calculate the cumulative release of the solid tracer (305) using the data processing unit (404); Step S45: Replace the solid tracer (305) in the tracer carrier (310) with a new solid tracer of the same batch to be evaluated; change the preset salinity of the simulated formation water, and repeat steps S43 and S44. Step S46: Based on the tracer concentration data obtained under different salinity fluid conditions, the release curves of the solid tracer (305) under different salinities are plotted by the data processing unit (404), and the influence of salinity on the sustained-release performance of the solid tracer (305) is analyzed.

10. A method for evaluating the effect of fluid pH on the sustained-release performance of solid tracers, characterized in that, Based on the experimental apparatus as described in claim 4, and including the following steps: Step S51: Clean the displacement pump (101), the oil storage tank (121), the water storage tank (122), the mixing device (201), the core holder (206), the transparent simulated wellbore (314), the integrated tracer release unit, the liquid collection tank (401), the waste liquid tank (402), and the connecting pipes; Step S52: The solid tracer (305) to be evaluated is loaded into the tracer carrier (310), and the integrated tracer release unit is installed in the transparent simulated wellbore (314); Step S53: Prepare simulated formation water with a preset pH value and inject it into the water storage tank (122). The solid tracer (305) is flushed by a fluid with a preset flow rate, and fluid samples are collected periodically through the collection tank (401). Step S54: Analyze the concentration of tracer in the fluid sample using the concentration analyzer (403), and calculate the cumulative release of the solid tracer (305) using the data processing unit (404); Step S55: Replace the solid tracer (305) in the tracer carrier (310) with a new solid tracer of the same batch to be evaluated; change the preset pH value of the simulated formation water, and repeat steps S53 and S54. Step S56: Based on the tracer concentration data obtained under different pH fluid conditions, the release curves of the solid tracer (305) under different pH values ​​are plotted by the data processing unit (404), and the influence of pH value on the sustained release performance of the solid tracer (305) is analyzed.

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