Distributed acoustic sensing injection-production simulation experimental device and experimental method

Abstract

This application discloses a distributed acoustic sensing injection-production simulation experimental device and method, relating to the field of fluid acoustic testing. The wellbore module includes a casing and tubing housed within it; the injection module includes a liquid storage assembly and a liquid pumping assembly; the gas injection module includes a gas compression assembly; the manifold module includes a liquid distribution pipe, a gas distribution pipe, a gas-liquid separator, and multiple hoses; the liquid and gas distribution pipes have multiple liquid and gas branch pipes along their length, and the casing has multiple corresponding branch pipes. Each liquid and gas branch pipe is connected to the input end of a branch pipe via a hose, and the output end of the branch pipe is connected to the tubing; the output end of the tubing is connected to the gas-liquid separator; optical fibers are laid on the outer wall of the tubing and connected to a distributed acoustic sensing monitoring device. This application realizes independent multi-point injection control along the wellbore and distributed real-time monitoring of the entire wellbore, used for wellbore injection-production simulation experiments.

Description

Technical Field

[0001] This application relates to the field of acoustic testing technology for fluids, and in particular to a distributed acoustic wave sensing injection and sampling simulation experimental device and method. Background Technology

[0002] In the fields of oil and gas production and wellbore monitoring, real-time, continuous, and large-scale dynamic information is crucial for improving well development efficiency and reducing risks. Traditional downhole monitoring methods mainly rely on point sensors (such as electronic pressure gauges and thermometers) or periodic measuring tools (such as production logging instruments). However, these methods have significant limitations: point sensors can only provide discrete data at specific locations within the wellbore, resulting in limited monitoring coverage and making it difficult to comprehensively reflect the flow status of the entire wellbore; while periodic measuring tools cannot achieve real-time monitoring, resulting in time lags in data acquisition and an inability to provide timely warnings for sudden events (such as sand production or wellbore collapse).

[0003] In recent years, Distributed Acoustic Sensing (DAS) technology, as an emerging acoustic measurement method, has shown broad application prospects in downhole acoustic signal acquisition, multiphase flow identification, sand production monitoring, and fracturing effect evaluation due to its advantages of continuous monitoring throughout the wellbore, high spatiotemporal resolution, and real-time response. However, the actual application effect of DAS technology is highly dependent on the generation mechanism, propagation characteristics, and coupling relationship between downhole acoustic signals and fluid media and wellbore structure. Currently, systematic experimental studies on the acoustic response in the wellbore under different injection and production conditions (such as single-phase liquid, single-phase gas, gas-liquid two-phase flow, and variable temperature conditions) are still relatively lacking. Moreover, most existing experimental devices are difficult to achieve independent injection control at multiple points along the wellbore and synchronous acquisition of distributed acoustic signals throughout the wellbore, which limits the quantitative application and mechanism verification of DAS technology in complex downhole environments.

[0004] Therefore, there is an urgent need for an experimental simulation device that can accurately simulate real downhole working conditions in an indoor environment and perform high-precision, high-resolution real-time acoustic response monitoring of processes such as multiphase flow, sand production, and fracturing in the wellbore based on distributed acoustic wave sensing technology, so as to be used for acoustic wave-flow mechanism research, DAS monitoring technology verification, and downhole tool development. Summary of the Invention

[0005] This application provides a distributed acoustic wave sensing injection and sampling simulation experimental device and method, which solves the problems mentioned in the background art.

[0006] In a first aspect, embodiments of this application provide a distributed acoustic wave sensing injection-sampling simulation experimental device, comprising: A wellbore module includes a casing for simulating a real wellbore structure and tubing disposed within the casing; The liquid injection module includes a liquid storage component for storing and heating liquid and a liquid pumping component for providing injection power to the liquid, wherein the output end of the liquid storage component is connected to the input end of the liquid pumping component. The gas injection module includes a gas compression assembly for providing a stable gas source; The manifold module includes a liquid distribution pipe, a gas distribution pipe, a gas-liquid separator, and multiple hoses; The monitoring module includes a distributed acoustic wave sensing monitoring device, multiple sensors, and a pressure monitoring component; The liquid pumping assembly has its output end connected to the input end of the liquid distribution pipe, which has multiple liquid branch pipes along its length. The gas compression assembly has its output end connected to the input end of the gas distribution pipe, which has multiple gas branch pipes along its length. The casing has multiple branch pipes corresponding to the liquid and gas branch pipes along its length. The output end of each liquid branch pipe is connected to the first input end of the corresponding branch pipe via a corresponding hose. The output end of each gas branch pipe is connected to the second input end of the corresponding branch pipe via a corresponding hose. The output end of each branch pipe is connected to an oil pipe inside the casing. The output end of the oil pipe is connected to the input end of the gas-liquid separator; an optical fiber is disposed on the outer wall of the oil pipe and connected to the distributed acoustic wave sensing and monitoring device; multiple sensors are disposed on the liquid distribution pipe, gas distribution pipe, branch pipe and sleeve, and are signal-connected to the distributed acoustic wave sensing and monitoring device; the pressure monitoring component includes a first pressure gauge and a second pressure gauge; the first pressure gauge is disposed between the output end of the gas compression component and the input end of the gas distribution pipe; the second pressure gauge is disposed between the output end of the liquid pumping component and the input end of the liquid distribution pipe, and both the first pressure gauge and the second pressure gauge are signal-connected to the distributed acoustic wave sensing and monitoring device.

[0007] In conjunction with the first aspect, in one possible implementation, the plurality of sensors include a first temperature sensor disposed on the liquid distribution pipe and the gas distribution pipe, a second temperature sensor disposed on the branch pipe, and a third temperature sensor disposed on the sleeve.

[0008] In conjunction with the first aspect, in one possible implementation, the output end of the gas-liquid separator is connected to the input end of the liquid storage component.

[0009] In conjunction with the first aspect, in one possible implementation, the manifold module further includes a flow regulator disposed on each of the liquid manifolds and each of the gas manifolds for adjusting and displaying the flow rate of the medium.

[0010] In conjunction with the first aspect, in one possible implementation, a first mass flow meter is provided between the output end of the gas compression assembly and the input end of the gas distribution pipe, and a second mass flow meter is provided between the output end of the liquid pumping assembly and the input end of the liquid distribution pipe.

[0011] In conjunction with the first aspect, in one possible implementation, the sleeve is also provided with multiple emergency drain valves for discharging fluid.

[0012] Secondly, embodiments of this application provide a distributed acoustic sensing wellbore injection-production simulation experimental method, employing the aforementioned distributed acoustic sensing injection-production simulation experimental device, comprising the following steps: S1: Preparation and Rinsing Steps Inject liquid into the storage unit, close the emergency drain valve, and start the heating functions of the gas compression unit, liquid pumping unit, and storage unit; the liquid pumping unit draws liquid from the storage unit, pressurizes it, and delivers it to the liquid distribution pipe; the gas compression unit injects compressed air into the gas distribution pipe; open the corresponding flow regulators on each liquid branch pipe and each gas branch pipe to allow liquid and gas to flow through hoses, branch pipes, and oil pipes to wet and clean the internal pipelines of the device; S2: Basic Data Acquisition Steps Once the flow regulators on each liquid and gas distribution pipe show stable values, and the liquid and gas distribution pipes are fully filled with the corresponding medium, with a small amount of liquid returning to the gas-liquid separator, the temperature and pressure data from the first, second, and third temperature sensors, the first pressure gauge, and the second pressure gauge are collected using a distributed acoustic wave sensing monitoring device and optical fiber as baseline reference values. S3: Gas-Liquid Two-Phase Flow Simulation Test Procedure Adjust the flow regulators on each gas branch pipe and each liquid branch pipe to set different gas injection flow rates and liquid injection flow rates; after the values ​​displayed by the flow regulators stabilize, record the changes in the acoustic signal inside the casing through a distributed acoustic wave sensing monitoring device to evaluate the acoustic response characteristics of the casing under different gas-liquid two-phase injection flow rate combinations. S4: Test Procedure under Variable Temperature Conditions Adjust the heating temperature of the liquid storage component, keep the opening of the flow regulators on each gas pipe and each liquid pipe constant, and record the changes in the casing acoustic signal under different temperature conditions through a distributed acoustic wave sensing monitoring device. S5: Single-phase liquid simulation test procedure Close the gas compression assembly and the flow regulators on each gas branch pipe, open the exhaust valve of the liquid storage assembly, and adjust the power of the liquid pumping assembly to exhaust the gas and fill the casing with liquid. After the flow regulators on each liquid branch pipe display values ​​stabilize, record the changes in the acoustic signal in the casing through the distributed acoustic wave sensing monitoring device as the basic response of the single-phase liquid. Adjust the flow regulators on each liquid branch pipe to set different liquid injection flow rates. After the values ​​displayed by the flow regulators stabilize, record the changes in the casing acoustic signal under different liquid injection flow rates using a distributed acoustic wave sensing monitoring device. Keep the flow regulator opening on each liquid pipe constant, adjust the heating temperature of the liquid storage component, set different temperature conditions, and after the temperature stabilizes, record the changes in the casing acoustic signal under different temperature conditions through a distributed acoustic wave sensing monitoring device. The above steps were used to evaluate the casing acoustic response characteristics of single-phase liquid under different injection flow rates and temperatures. S6: Single-phase gas simulation test procedure Open the valves of the gas compression assembly, gas-liquid separator, flow regulators on each gas branch pipe, and emergency drain valve on the casing. Close the liquid pump assembly and flow regulators on each liquid branch pipe to drain the liquid from the casing and fill it with gas. After the flow regulators on each gas branch pipe display values ​​stabilize, record the changes in the acoustic signal in the casing using a distributed acoustic wave sensing monitoring device as the basic response of the single-phase gas. Adjust the flow regulators on each gas branch pipe to set different gas injection flow rates. After the values ​​displayed by the flow regulators stabilize, record the changes in the acoustic signal inside the casing under different gas injection flow rates using a distributed acoustic wave sensing monitoring device. The above steps were used to evaluate the casing acoustic response characteristics of single-phase gas under different injection flow rates.

[0013] In conjunction with the second aspect, in one possible implementation, the rinsing time is 5-10 minutes.

[0014] In conjunction with the second aspect, in one possible implementation, the liquid pumping assembly provides a liquid flow rate adjustment range of 0-140 L / min, and the gas compression assembly provides a gas flow rate adjustment range of 0-480 L / min, for simulating the injection conditions of liquids, gases, and gas-liquid mixtures.

[0015] In conjunction with the second aspect, in one possible implementation, the reservoir assembly is equipped with an electric heating tube to provide a temperature regulation range of 0-100°C to simulate different formation temperature conditions; optical fibers are spirally arranged around the outer wall of the tubing to enhance the sensitivity of acoustic signal acquisition.

[0016] One or more technical solutions provided in the embodiments of this application have at least the following technical effects: The distributed acoustic sensing injection-production simulation experimental device provided in this application embodiment, by setting up a liquid distribution pipe with multiple liquid branch pipes along its length and a gas distribution pipe with multiple gas branch pipes along its length, and using multiple branch pipes to connect each liquid branch pipe and each gas branch pipe to the tubing inside the casing, realizes multi-point, independent, and controllable liquid and gas injection along the wellbore, which can accurately simulate complex downhole segmented injection or production conditions; at the same time, by laying optical fibers on the tubing and connecting them to a distributed acoustic sensing monitoring device, combined with a first temperature sensor and a second temperature sensor set on the liquid distribution pipe, gas distribution pipe, branch pipes and casing, it achieves multi-point, independent, and controllable liquid and gas injection along the wellbore, which can accurately simulate complex downhole segmented injection or production conditions; The system, consisting of a sensor, a third temperature sensor, a first pressure gauge, and a second pressure gauge, constructs a distributed real-time monitoring network for the entire wellbore. This overcomes the limitations of traditional point sensors, which have limited monitoring range and cannot provide real-time early warnings for periodic measurement tools. It enables high-resolution, real-time, and continuous acoustic signal acquisition and temperature and pressure parameter monitoring for single-phase liquids, single-phase gases, gas-liquid two-phase flows, and flow states under varying temperature conditions within the wellbore. This provides a reliable simulation platform and accurate data support for studying downhole flow patterns, analyzing the mechanisms of sudden events such as sand production and wellbore instability, and conducting indoor verification of new monitoring tools. It effectively improves the accuracy and comprehensiveness of wellbore injection-production simulation experiments. Attached Figure Description

[0017] To more clearly illustrate the technical solutions in the embodiments of this application, the accompanying drawings used in the description of the embodiments of this application will be briefly introduced below. Obviously, the accompanying drawings described below are some embodiments of this application. For those skilled in the art, other drawings can be obtained based on these drawings without creative effort.

[0018] Figure 1 A schematic diagram of the structure of the distributed acoustic wave sensing injection and sampling simulation experimental device provided in the embodiments of this application; Figure 2 This is a schematic diagram of the structure of the liquid manifold and gas manifold provided in the embodiments of this application; Figure 3 This is a schematic diagram of the structure of an optical fiber provided in an embodiment of this application.

[0019] Icons: 1-Wellbore Module; 11-Casing; 111-Emergency Drain Valve; 12-Tubing; 13-Branch Pipe; 2-Injection Module; 21-Storage Component; 22-Liquid Pumping Component; 3-Gas Injection Module; 31-Gas Compression Component; 4-Manifold Module; 41-Liquid Distribution Pipe; 42-Gas Distribution Pipe; 43-Gas-Liquid Separator; 44-Hose; 45-Liquid Branch Pipe; 46-Gas Branch Pipe; 47-Flow Regulator; 5-Monitoring Module; 51-Distributed Acoustic Sensing Monitoring Device; 52-Sensor; 521-First Temperature Sensor; 522-Second Temperature Sensor; 523-Third Temperature Sensor; 53-First Pressure Gauge; 54-Second Pressure Gauge; 6-First Mass Flow Meter; 7-Fiber Optic Fiber; 8-Second Mass Flow Meter. Detailed Implementation

[0020] The technical solutions of the embodiments of this application 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 application. Based on the embodiments of this application, all other embodiments obtained by those skilled in the art without creative effort are within the scope of protection of this application.

[0021] In the description of the embodiments of this application, it should be noted that the terms "center," "upper," "lower," "left," "right," "vertical," "horizontal," "inner," and "outer," etc., indicate the orientation or positional relationship based on the orientation or positional relationship shown in the accompanying drawings. They are used only for the convenience of describing the embodiments of this application and for simplifying the description, and do not indicate or imply that the device 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 application. The terms "first," "second," and "third" are used for descriptive purposes only and should not be construed as indicating or implying relative importance. Furthermore, the terms "installed," "connected," and "linked" should be interpreted broadly. For example, they can refer to a fixed connection, a detachable connection, or an integral connection; a mechanical connection or a signal connection; a direct connection or an indirect connection through an intermediate medium; or a connection within two components. Those skilled in the art can understand the specific meaning of the above terms in the embodiments of this application according to the specific circumstances.

[0022] This application provides a distributed acoustic wave sensing injection and sampling simulation experimental device, such as... Figures 1 to 3As shown. This distributed acoustic sensing injection-production simulation experimental device includes a wellbore module 1, a liquid injection module 2, a gas injection module 3, a manifold module 4, and a monitoring module 5. The wellbore module 1 includes a casing 11 for simulating the structure of a real wellbore and an oil pipe 12 installed inside the casing 11; the liquid injection module 2 includes a liquid storage component 21 for storing and heating liquid and a liquid pumping component 22 for providing injection power to the liquid, with the output end of the liquid storage component 21 connected to the input end of the liquid pumping component 22; the gas injection module 3 includes a gas compression component 31 for providing a stable gas source; the manifold module 4 includes a liquid distribution pipe 41, a gas distribution pipe 42, a gas-liquid separator 43, and multiple hoses 44; the monitoring module 5 includes a distributed acoustic sensing monitoring device 51, multiple sensors 52, and a pressure monitoring component; wherein, the output end of the liquid pumping component 22 is connected to the input end of the liquid distribution pipe 41, and the liquid distribution pipe 41 is provided with multiple liquid branch pipes 45 along its length; the output end of the gas compression component 31 is connected to the input end of the gas distribution pipe 42, and the gas distribution pipe 44... 2. Multiple gas distribution pipes 46 are arranged along its length; multiple branch pipes 13 corresponding to liquid distribution pipes 45 and gas distribution pipes 46 are arranged along its length of the sleeve 11; the output end of each liquid distribution pipe 45 is connected to the first input end of the corresponding branch pipe 13 through a corresponding hose 44; the output end of each gas distribution pipe 46 is connected to the second input end of the corresponding branch pipe 13 through a corresponding hose 44; the output end of each branch pipe 13 is connected to the oil pipe 12 inside the sleeve 11; the output end of the oil pipe 12 is connected to the input end of the gas-liquid separator 43; an optical fiber 7 is disposed on the outer wall of the oil pipe 12 and connected to the distributed acoustic wave sensing and monitoring device 51; multiple sensors 52 are disposed on the liquid distribution pipe 41, gas distribution pipe 42, branch pipes 13 and sleeve 11 and are signal connected to the distributed acoustic wave sensing and monitoring device 51; the pressure monitoring component includes a first pressure gauge 53 and a second pressure gauge 54. The first pressure gauge 53 is located between the output end of the gas compression assembly 31 and the input end of the gas distribution pipe 42; the second pressure gauge 54 is located between the output end of the liquid pumping assembly 22 and the input end of the liquid distribution pipe 41. The first pressure gauge 53 is used to monitor the gas phase injection pressure at the output end of the gas injection module 3 in real time, providing a reference for pressure regulation at each node downstream of the gas branch pipe 46; the second pressure gauge 54 is used to monitor the liquid phase injection pressure at the output end of the liquid injection module 2 in real time, ensuring that the liquid medium enters the liquid distribution pipe 41 at a stable and controllable pressure. By setting pressure monitoring components at key nodes at the injection source, the pressure state of the gas-liquid two-phase medium in the initial stage of injection can be accurately controlled, providing reliable basic data support for subsequent flow regulation of each branch pipe, multiphase flow pressure field analysis in the casing 11, and pressure response research under different injection conditions, thereby further improving the accuracy and controllability of the injection-production profile simulation experiment.

[0023] Specifically, the pressure monitoring component can be a pressure gauge, pressure sensor, or other pressure measurement element known in the art.

[0024] In this embodiment, the distributed acoustic wave sensing and monitoring device 51 integrates an optical signal demodulation module and a multi-channel data acquisition card.

[0025] It should be noted that the distributed acoustic wave sensing injection-production simulation experimental device provided in this application embodiment, by setting up a liquid distribution pipe 41 with multiple liquid branch pipes 45 arranged along its length and a gas distribution pipe 42 with multiple gas branch pipes 46 arranged along its length, and using multiple branch pipes 13 to connect each liquid branch pipe 45 and each gas branch pipe 46 to the oil tubing 12 in the casing 11, realizes multi-point, independent and controllable liquid injection and gas injection along the wellbore, and can accurately simulate complex downhole segmented injection or production conditions; at the same time, by laying optical fiber 7 on the oil tubing 12 and connecting it to the distributed acoustic wave sensing monitoring device 51, combined with the first optical fiber 7 arranged on the liquid distribution pipe 41, gas distribution pipe 42, branch pipe 13 and casing 11, the device achieve ... A distributed real-time monitoring network for the entire wellbore is constructed using a temperature sensor 521, a second temperature sensor 522, a third temperature sensor 523, a first pressure gauge 53, and a second pressure gauge 54. This network overcomes the limitations of traditional point sensors, which have limited monitoring range and cannot provide real-time early warnings for periodic measurement tools. It enables high-resolution, real-time, and continuous acoustic signal acquisition and temperature and pressure parameter monitoring of single-phase liquids, single-phase gases, gas-liquid two-phase flows, and flow states under varying temperature conditions within the wellbore. This provides a reliable simulation platform and accurate data support for the study of downhole flow patterns, the mechanism analysis of sudden events such as sand production and wellbore instability, and the indoor verification of new monitoring tools, effectively improving the accuracy and comprehensiveness of wellbore injection and production simulation experiments.

[0026] Specifically, this application includes eight branch pipes 13, and correspondingly, eight liquid branch pipes 45 and eight gas branch pipes 46. This number is designed based on the scale of conventional indoor wellbore simulation experiments, adapting to the segmented requirements along the flow path of 0-10m simulated wellbores, while also taking into account the resolution of experimental monitoring and the controllability of operation: the eight-segment partitioning can realize an independent injection / monitoring node every 1-1.25m along the wellbore axis, which avoids insufficient flow path monitoring accuracy due to too few segments, and also prevents the problems of increased manifold control complexity and experimental data redundancy caused by too many segments.

[0027] In this embodiment, the plurality of sensors 52 include a first temperature sensor 521 disposed on the liquid distribution pipe 41 and the gas distribution pipe 42, a second temperature sensor 522 disposed on the branch pipe 13, and a third temperature sensor 523 disposed on the sleeve 11.

[0028] This application embodiment constructs a stepped temperature monitoring network from the injection source to the inside of the casing 11 by setting a first temperature sensor 521 on the liquid distribution pipe 41 and the gas distribution pipe 42, a second temperature sensor 522 on the branch pipe 13, and a third temperature sensor 523 on the casing 11. Specifically, the first temperature sensor 521 is used to monitor the initial temperature of the injected medium in the main pipeline (i.e., the liquid distribution pipe 41 and the gas distribution pipe 42) in real time; the second temperature sensor 522 is used to obtain the node temperature of the medium before it merges into the branch pipe 13; and the third temperature sensor 523 is used to sense the temperature distribution of the fluid in the annulus region between the casing 11 and the tubing 12. Therefore, this application can accurately track the temperature change pattern of the fluid along the injection path, providing high-resolution measured data support for analyzing the heat conduction effect in the wellbore, the phase change characteristics of multiphase flow, and the temperature field distribution under different injection conditions, thereby further improving the refined monitoring capability of wellbore injection-production profile simulation experiments.

[0029] In this embodiment, the output end of the gas-liquid separator 43 is connected to the input end of the liquid storage component 21.

[0030] In this embodiment, the manifold module 4 further includes flow regulators 47 disposed on each liquid branch pipe 45 and each gas branch pipe 46 for adjusting and displaying the medium flow rate, thereby realizing independent and precise control and real-time monitoring of the injection flow rate of each liquid branch pipe 45 and each gas branch pipe 46. On the one hand, by adjusting the flow regulators 47 on each liquid branch pipe 45 and each gas branch pipe 46, the liquid or gas injection flow rate of different branches can be flexibly set, thereby accurately simulating complex working conditions such as heterogeneous segmented injection and selective production in the well. On the other hand, the display function configured on each flow regulator 47 can directly read real-time flow data, making it convenient for operators to grasp the medium distribution status of each liquid branch pipe 45 and each gas branch pipe 46 in a timely manner. This multi-point independent control design not only greatly improves the flexibility and accuracy of the wellbore injection profile simulation, but also provides reliable hardware support and direct experimental data source for studying the wellbore gas-liquid two-phase flow response characteristics under different flow rate combinations and verifying the flow distribution theoretical model.

[0031] In this embodiment, a first mass flow meter 6 is installed between the output end of the gas compression assembly 31 and the input end of the gas distribution pipe 42, and a second mass flow meter 8 is installed between the output end of the liquid pumping assembly 22 and the input end of the liquid distribution pipe 41, achieving high-precision real-time measurement of the total gas phase injection volume and the total liquid phase injection volume. Specifically, the first mass flow meter 6 is used to accurately measure the total flow rate of the gas phase medium injected into the gas distribution pipe 42, providing an upstream total volume reference for the flow regulators 47 on each gas branch pipe 46; the second mass flow meter 8 is used to accurately measure the total flow rate of the liquid phase medium injected into the liquid distribution pipe 41, providing an upstream total volume reference for the flow regulators 47 on each liquid branch pipe 45. By installing high-precision mass flow meters at the injection source, the total gas and liquid medium volume entering the manifold system can be accurately calibrated, effectively eliminating measurement errors caused by pressure fluctuations or changes in medium characteristics, ensuring the accuracy of flow regulation in each branch pipe and the reliability of data from subsequent wellbore multiphase flow simulation experiments, thereby providing higher-quality input data support for injection-production profile analysis.

[0032] In this embodiment, the casing 11 is also equipped with multiple emergency drain valves 111 for discharging fluid, providing flexible safety assurance and operating condition switching methods for experimental operations. During the experimental preparation phase, the residual medium inside the casing 11 can be quickly drained by opening the emergency drain valves 111, facilitating cleaning or replacement of the experimental fluid. During the experiment, if abnormal pressure or equipment failure occurs, the emergency drain valves 111 can be quickly opened to achieve emergency pressure relief, effectively protecting the wellbore module 1 and monitoring equipment. When switching operating conditions for single-phase flow testing, the emergency drain valves 111 can accelerate the draining of the original medium inside the casing 11, shortening the experimental preparation time. This multi-point arrangement of emergency drain valves 111 significantly improves the operational flexibility, emergency response capability, and operating condition switching efficiency of the experimental device.

[0033] This application provides a distributed acoustic sensing wellbore injection-production simulation experimental method, which uses the aforementioned distributed acoustic sensing injection-production simulation experimental device and includes the following steps: S1: Preparation and Rinsing Steps Liquid is injected into the storage assembly 21, the emergency drain valve 111 is closed, and the heating functions of the gas compression assembly 31, the liquid pumping assembly 22, and the storage assembly 21 are activated. The liquid pumping assembly 22 draws liquid from the storage assembly 21, pressurizes it, and delivers it to the liquid distribution pipe 41. The gas compression assembly 31 injects compressed air into the gas distribution pipe 42. The corresponding flow regulators 47 on each liquid branch pipe 45 and each gas branch pipe 46 are opened, allowing liquid and gas to flow through the hose 44, branch pipe 13, and oil pipe 12 to wet and clean the internal piping of the device.

[0034] S2: Basic Data Acquisition Steps Once the flow regulators 47 on each liquid manifold 45 and each gas manifold 46 display stable values, and the liquid distribution pipe 41 and gas distribution pipe 42 are fully filled with the corresponding medium, with a small amount of liquid returning to the gas-liquid separator 43, temperature and pressure data from the first temperature sensor 521, the second temperature sensor 522, the third temperature sensor 523, the first pressure gauge 53, and the second pressure gauge 54 are collected via the distributed acoustic wave sensing monitoring device 51 and the optical fiber 7 as baseline reference values.

[0035] S3: Gas-Liquid Two-Phase Flow Simulation Test Procedure Adjust the flow regulators 47 on each gas branch pipe 46 and each liquid branch pipe 45 to set different gas injection flow rates and liquid injection flow rates. After the values ​​displayed by the flow regulators 47 stabilize, record the changes in the acoustic signal inside the sleeve 11 through the distributed acoustic wave sensing and monitoring device 51 to evaluate the acoustic response characteristics of the sleeve 11 under different gas-liquid two-phase injection flow rate combinations.

[0036] S4: Test Procedure under Variable Temperature Conditions Adjust the heating temperature of the liquid storage component 21, keep the opening of the flow regulator 47 on each gas branch pipe 46 and the flow regulator 47 on each liquid branch pipe 45 unchanged, and record the changes in the acoustic signal of the sleeve 11 under different temperature conditions through the distributed acoustic wave sensing and monitoring device 51.

[0037] S5: Single-phase liquid simulation test procedure Close the flow regulators 47 on the gas compression assembly 31 and each gas branch pipe 46, open the exhaust valve of the liquid storage assembly 21, and adjust the power of the liquid pumping assembly 22 to exhaust the gas and fill the sleeve 11 with liquid. After the flow regulators 47 on each liquid branch pipe 45 display stable values, record the changes in the acoustic signal in the sleeve 11 using the distributed acoustic wave sensing monitoring device 51 as the basic response of the single-phase liquid. Adjust the flow regulators 47 on each liquid branch pipe 45 to set different liquid injection flow rates. After the values ​​displayed by the flow regulators 47 stabilize, record the changes in the acoustic signal of the sleeve 11 under different liquid injection flow rates using the distributed acoustic wave sensing monitoring device 51. Keep the opening of the flow regulators 47 on each liquid branch pipe 45 constant, adjust the heating temperature of the liquid storage assembly 21 to set different temperature conditions, and after the temperature stabilizes, record the changes in the acoustic signal of the sleeve 11 under different temperature conditions using the distributed acoustic wave sensing monitoring device 51. Through the above steps, evaluate the acoustic response characteristics of the sleeve 11 under different injection flow rates and temperature conditions for single-phase liquid.

[0038] S6: Single-phase gas simulation test procedure Open the valves of the gas compression assembly 31, the gas-liquid separator 43, the flow regulators 47 on each gas branch pipe 46, and the emergency drain valve 111 on the casing 11. Close the liquid pump assembly 22 and the flow regulators 47 on each liquid branch pipe 45 to drain the liquid from the casing 11 and fill it with gas. After the flow regulators 47 on each gas branch pipe 46 show stable values, record the changes in the acoustic signal within the casing 11 using the distributed acoustic wave sensing monitoring device 51 as the basic response of the single-phase gas. Adjust the flow regulators 47 on each gas branch pipe 46 to set different gas injection flow rates. After the values ​​displayed by the flow regulators 47 stabilize, record the changes in the acoustic signal within the casing 11 under different gas injection flow rates using the distributed acoustic wave sensing monitoring device 51. Through the above steps, evaluate the acoustic response characteristics of the casing 11 under different injection flow rate conditions for single-phase gas.

[0039] It should be noted that the distributed acoustic sensing wellbore injection and production simulation experimental method provided in this application constructs a full-condition simulation system covering single-phase liquid, single-phase gas, and gas-liquid two-phase flow through the complete experimental process from S1 to S6. This method relies on the flow regulators 47 on each liquid manifold 45 and each gas manifold 46 to achieve independent and precise control of the gas injection flow rate and liquid injection flow rate, enabling the simulation of complex downhole flow states under different combinations of gas-liquid two-phase injection flow rates. By adjusting the heating temperature of the storage component 21, accurate simulation of different formation temperature conditions within the range of 0-100°C is achieved, providing a controllable experimental environment for studying the influence of temperature on fluid behavior within the wellbore. In terms of monitoring capabilities, this method uses a distributed acoustic wave sensing monitoring device 51 and optical fiber 7 to collect real-time changes in acoustic wave signals within the casing 11. Combined with baseline reference values ​​of temperature and pressure collected by the first temperature sensor 521, the second temperature sensor 522, the third temperature sensor 523, and the first pressure gauge 53 and the second pressure gauge 54, a multi-parameter fusion distributed monitoring network is constructed. This network can capture the acoustic wave response characteristics of the wellbore under different injection conditions in high resolution and continuous real-time. Through this method, the acoustic wave response of single-phase liquids under different injection flow rates and temperatures, the acoustic wave response of single-phase gas under different injection flow rates, and the acoustic wave response characteristics of gas-liquid two-phase flow under different flow rate combinations can be systematically evaluated. This provides reliable experimental data support for multiphase flow identification, sand production monitoring, fracturing effect evaluation, and wellbore integrity analysis, effectively improving the accuracy and comprehensiveness of wellbore injection-production simulation experiments.

[0040] In this embodiment, the rinsing time is 5-10 minutes, which can fully and effectively clean and wet the internal pipelines of the device during the experimental preparation stage.

[0041] In this embodiment, the liquid pumping component 22 provides a liquid flow rate adjustment range of 0-140 L / min, and the gas compression component 31 provides a gas flow rate adjustment range of 0-480 L / min, used to simulate the injection conditions of liquids, gases, and gas-liquid mixtures. Through the wide-range flow rate adjustment capabilities of the liquid pumping component 22 and the gas compression component 31, continuous and precise control from low to high flow rates is achieved, covering various actual downhole conditions: the low flow rate range can be used to simulate low-production wells or the stable seepage state in the initial stage of injection, while the medium-to-high flow rate range can be used to simulate high-production wells, fracturing operations, or gas lift oil production, and other high-flow-rate injection scenarios. The wide gas-liquid flow rate adjustment range not only improves the simulation realism of different gas-liquid mixture injection conditions but also provides a flexible and controllable experimental means to study the effects of flow rate changes on the transformation of multiphase flow patterns, sand production critical conditions, and pressure wave response laws in the wellbore, further expanding the application scenarios of this device under complex mining conditions.

[0042] In this embodiment, the reservoir assembly 21 is equipped with two sets of 6 kW electric heating tubes, providing a wide temperature adjustment range of 0-100°C to simulate different formation temperature conditions. Simultaneously, the optical fiber 7 is spirally arranged around the outer wall of the tubing 12 to enhance the sensitivity of acoustic signal acquisition. Through the synergistic heating of the two sets of electric heating tubes, the reservoir assembly 21 can quickly respond and accurately maintain the target temperature, achieving accurate simulation of different thermodynamic environments from normal to high-temperature formations. This provides controllable experimental conditions for studying the influence of temperature on the flow regime transitions of single-phase liquids, single-phase gases, and gas-liquid two-phase flows within the wellbore. The spiral arrangement of the optical fiber 7 on the tubing 12 increases the effective sensing length and spatial coverage angle between the optical fiber 7 and the fluid, thereby significantly improving the sensitivity of the distributed acoustic sensing monitoring device 51 in capturing weak acoustic signals, fluid disturbances, and vibration modes such as sand production within the wellbore. All equipment is connected using high-pressure hoses (44), ensuring the sealing and operational safety of the entire system under various pressure conditions and injection scenarios across a wide temperature range of 0-100°C. Through the synergistic effect of the aforementioned wide-range temperature control capability, high-sensitivity acoustic wave acquisition technology, and reliable pressure-bearing connection design, this method can more realistically recreate the complex downhole environment, providing high-quality experimental data support for key tasks such as multiphase flow identification, sand production monitoring, and fracturing effect evaluation.

[0043] In one embodiment of this application, the liquid storage assembly 21 is an electrically heated liquid storage tank, the liquid pumping assembly 22 is a plunger pump, and the gas compression assembly 31 is a variable frequency air compressor. The branch pipe 13 is a Y-shaped branch pipe.

[0044] The various embodiments in this specification are described in a progressive manner. For the same or similar parts between the various embodiments, please refer to each other. Each embodiment focuses on describing the differences from other embodiments.

[0045] The above embodiments are only used to illustrate the technical solutions of this application, and are not intended to limit this application. Although this application 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 or all of the technical features therein. Such modifications or substitutions do not cause the essence of the corresponding technical solutions to deviate from the scope of the technical solutions of this application.

Claims

1. A distributed acoustic wave sensing injection-sampling simulation experimental device, characterized in that, include: A wellbore module includes a casing for simulating a real wellbore structure and tubing disposed within the casing; The liquid injection module includes a liquid storage component for storing and heating liquid and a liquid pumping component for providing injection power to the liquid, wherein the output end of the liquid storage component is connected to the input end of the liquid pumping component. The gas injection module includes a gas compression assembly for providing a stable gas source; The manifold module includes a liquid distribution pipe, a gas distribution pipe, a gas-liquid separator, and multiple hoses; The monitoring module includes a distributed acoustic wave sensing monitoring device, multiple sensors, and a pressure monitoring component. The liquid pumping assembly has its output end connected to the input end of the liquid distribution pipe, which has multiple liquid branch pipes along its length. The gas compression assembly has its output end connected to the input end of the gas distribution pipe, which has multiple gas branch pipes along its length. The casing has multiple branch pipes corresponding to the liquid and gas branch pipes along its length. The output end of each liquid branch pipe is connected to the first input end of the corresponding branch pipe via a corresponding hose. The output end of each gas branch pipe is connected to the second input end of the corresponding branch pipe via a corresponding hose. The output end of each branch pipe is connected to an oil pipe inside the casing. The output end of the oil pipe is connected to the input end of the gas-liquid separator; an optical fiber is disposed on the outer wall of the oil pipe and connected to the distributed acoustic wave sensing and monitoring device; multiple sensors are disposed on the liquid distribution pipe, gas distribution pipe, branch pipe and sleeve, and are signal-connected to the distributed acoustic wave sensing and monitoring device; the pressure monitoring component includes a first pressure gauge and a second pressure gauge; the first pressure gauge is disposed between the output end of the gas compression component and the input end of the gas distribution pipe; the second pressure gauge is disposed between the output end of the liquid pumping component and the input end of the liquid distribution pipe, and both the first pressure gauge and the second pressure gauge are signal-connected to the distributed acoustic wave sensing and monitoring device.

2. The distributed acoustic wave sensing injection and acquisition simulation experimental device according to claim 1, characterized in that, The plurality of sensors include a first temperature sensor disposed on the liquid distribution pipe and the gas distribution pipe, a second temperature sensor disposed on the branch pipe, and a third temperature sensor disposed on the sleeve.

3. The distributed acoustic wave sensing injection and sampling simulation experimental device according to claim 2, characterized in that, The output end of the gas-liquid separator is connected to the input end of the liquid storage component.

4. The distributed acoustic wave sensing injection-sampling simulation experimental device according to claim 3, characterized in that, The manifold module also includes a flow regulator disposed on each of the liquid manifolds and each of the gas manifolds for adjusting and displaying the flow rate of the medium.

5. The distributed acoustic wave sensing injection-sampling simulation experimental device according to claim 4, characterized in that, A first mass flow meter is installed between the output end of the gas compression assembly and the input end of the gas distribution pipe, and a second mass flow meter is installed between the output end of the liquid pumping assembly and the input end of the liquid distribution pipe.

6. The distributed acoustic wave sensing injection-sampling simulation experimental device according to claim 4, characterized in that, The casing is also equipped with multiple emergency drain valves for discharging fluid.

7. A distributed acoustic sensing wellbore injection-production simulation experimental method, employing the distributed acoustic sensing injection-production simulation experimental device as described in claim 6, characterized in that, Includes the following steps: S1: Preparation and Rinsing Steps Inject liquid into the storage unit, close the emergency discharge valve, and start the heating functions of the gas compression unit, liquid pumping unit, and storage unit; the liquid pumping unit draws liquid from the storage unit, pressurizes it, and delivers it to the liquid distribution pipe; the gas compression unit injects compressed air into the gas distribution pipe; Open the corresponding flow regulators on each liquid and gas branch pipe to allow the liquid and gas to flow through the hoses, branch pipes and oil pipes to wet and clean the internal pipelines of the device. S2: Basic Data Acquisition Steps Once the flow regulators on each liquid and gas distribution pipe show stable values, and the liquid and gas distribution pipes are fully filled with the corresponding medium, with a small amount of liquid returning to the gas-liquid separator, the temperature and pressure data from the first, second, and third temperature sensors, the first pressure gauge, and the second pressure gauge are collected using a distributed acoustic wave sensing monitoring device and optical fiber as baseline reference values. S3: Gas-Liquid Two-Phase Flow Simulation Test Procedure Adjust the flow regulators on each gas branch pipe and each liquid branch pipe to set different gas injection flow rates and liquid injection flow rates; after the values ​​displayed by the flow regulators stabilize, record the changes in the acoustic signal inside the casing through a distributed acoustic wave sensing monitoring device to evaluate the acoustic response characteristics of the casing under different gas-liquid two-phase injection flow rate combinations. S4: Test Procedure under Variable Temperature Conditions Adjust the heating temperature of the liquid storage component, keep the opening of the flow regulators on each gas pipe and each liquid pipe constant, and record the changes in the casing acoustic signal under different temperature conditions through a distributed acoustic wave sensing monitoring device. S5: Single-phase liquid simulation test procedure Close the gas compression assembly and the flow regulators on each gas branch pipe, open the exhaust valve of the liquid storage assembly, and adjust the power of the liquid pumping assembly to exhaust the gas and fill the casing with liquid. After the flow regulators on each liquid branch pipe display values ​​stabilize, record the changes in the acoustic signal in the casing through the distributed acoustic wave sensing monitoring device as the basic response of the single-phase liquid. Adjust the flow regulators on each liquid branch pipe to set different liquid injection flow rates. After the values ​​displayed by the flow regulators stabilize, record the changes in the casing acoustic signal under different liquid injection flow rates using a distributed acoustic wave sensing monitoring device. Keep the flow regulator opening on each liquid branch pipe constant, adjust the heating temperature of the liquid storage component, set different temperature conditions, and after the temperature stabilizes, record the changes in the casing acoustic signal under different temperature conditions through a distributed acoustic wave sensing monitoring device; through the above steps, evaluate the casing acoustic wave response characteristics of single-phase liquid under different injection flow rates and different temperature conditions. S6: Single-phase gas simulation test procedure Open the valves of the gas compression assembly, gas-liquid separator, flow regulators on each gas branch pipe, and emergency drain valve on the casing. Close the liquid pump assembly and flow regulators on each liquid branch pipe to drain the liquid from the casing and fill it with gas. After the flow regulators on each gas branch pipe display values ​​stabilize, record the changes in the acoustic signal in the casing using a distributed acoustic wave sensing monitoring device as the basic response of the single-phase gas. Adjust the flow regulators on each gas branch pipe to set different gas injection flow rates. After the values ​​displayed by the flow regulators stabilize, record the changes in acoustic signals inside the bushing under different gas injection flow rates using a distributed acoustic wave sensing monitoring device. Through the above steps, evaluate the acoustic response characteristics of the bushing under different injection flow rate conditions for single-phase gas.

8. The distributed acoustic sensing wellbore injection-production simulation experimental method according to claim 7, characterized in that, In step S1, the rinsing time is 5-10 minutes.

9. The distributed acoustic sensing wellbore injection-production simulation experimental method according to claim 7, characterized in that, The liquid pumping unit provides a liquid flow rate adjustment range of 0-140 L / min, and the gas compression unit provides a gas flow rate adjustment range of 0-480 L / min, for simulating the injection conditions of liquids, gases, and gas-liquid mixtures.

10. The distributed acoustic sensing wellbore injection-production simulation experimental method according to claim 7, characterized in that, The reservoir assembly is equipped with an electric heating element, providing a temperature adjustment range of 0-100°C to simulate different formation temperature conditions; optical fibers are spirally arranged around the outer wall of the tubing to enhance the sensitivity of acoustic signal acquisition.

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