Simulation system and method for chemical reaction hydrocarbon generation heat release and steam flooding

Abstract

The application discloses a chemical reaction hydrocarbon generation heat release steam flooding simulation system and method, wherein the chemical reaction hydrocarbon generation heat release steam flooding simulation system comprises a reservoir simulation device, an injection device, a metering device and a data processing device; the reservoir simulation device is filled with quartz sand as a simulation core, and the simulation core stores crude oil and water; the injection device comprises a steam injection assembly and a reactant injection assembly; the metering device comprises an oil phase metering unit for metering oil production; and the data processing device is used for processing the measurement results of the metering device. Through the system, the needs of reactant substances and injection parameters at different stages of heavy oil development can be determined, thereby providing reliable theoretical guidance for the development of heavy oil reservoirs.

Description

Technical Field

[0001] This invention belongs to the field of heavy oil reservoir development technology, specifically relating to a simulation system and method for chemical reaction hydrocarbon generation exothermic synergistic steam drive. Background Technology

[0002] Heavy oil is a type of high-viscosity, high-density crude oil, typically referring to crude oil with a viscosity exceeding 50 mPa·s or a density greater than 0.92 g / cm³. Due to its extremely poor fluidity, it is close to solid asphalt at room temperature and requires specialized extraction techniques. Current heavy oil thermal recovery methods face technological bottlenecks and are no longer sufficient to effectively develop newly added and remaining heavy oil resources with low reserves, poor crude oil properties, and complex geological conditions. Furthermore, they suffer from problems such as low thermal efficiency and high carbon emissions.

[0003] Patent application number CN202210914693.X discloses an in-situ directional chemical reaction-assisted steam flooding method and its application. This patent utilizes the exothermic properties of in-situ directional chemical reaction to propose releasing a large amount of heat through chemical reaction in a downhole reactor to reduce the viscosity of heavy oil and improve the recovery rate of heavy oil reservoirs. However, this method relies on existing physical simulation equipment for heavy oil development, making it difficult to conduct indoor physical simulation experiments for research and to clarify the heat and hydrocarbon requirements at different stages of heavy oil development. Summary of the Invention

[0004] To address the aforementioned deficiencies or shortcomings, this invention provides a chemical reaction-induced hydrocarbon generation exothermic synergistic steam drive simulation system and method, aiming to solve the technical problem that existing technologies cannot clearly define the heat and hydrocarbon requirements at different stages of heavy oil development.

[0005] To achieve the above objectives, the first aspect of the present invention provides a chemical reaction hydrocarbon generation exothermic synergistic steam drive simulation system, comprising:

[0006] The reservoir simulation device is filled with quartz sand as a simulated core, and the simulated core contains crude oil and water.

[0007] The injection device includes a steam injection assembly and a reactant injection assembly. The steam injection assembly is connected to the inlet of the reservoir simulation device and is used to inject water vapor into the reservoir simulation device. The reactant injection assembly is connected to the inlet of the reservoir simulation device and is used to inject reactants into the reservoir simulation device.

[0008] The metering device is connected to the outlet of the reservoir simulation device and includes an oil phase metering unit for measuring oil production.

[0009] The data processing device is communicatively connected to both the metering device and the injection device, and is configured as follows:

[0010] According to the preset ratio, the steam injection component and the reactant injection component inject water vapor and reactants into the reservoir simulation device, respectively;

[0011] The injection parameters of the injection unit are determined based on the oil production rate.

[0012] In this embodiment of the invention, determining the injection parameters of the injection device based on the oil production includes:

[0013] The degree of crude oil recovery is determined based on the oil production and the recovery rate calculation formula; the recovery rate calculation formula is as follows: In the formula, R To determine the degree of extraction; Let be the oil production at time t; To bind water saturation; Pore ​​volume;

[0014] Plot a curve showing the change in the degree of crude oil recovery based on the degree of crude oil recovery and the injection volume of the injection unit;

[0015] The injection parameters are determined based on the recovery rate curve, which includes the amount of reactant injected and the amount of steam injected.

[0016] In this embodiment of the invention, the metering device further includes a water phase metering unit for measuring the amount of produced water, and the data processing device is further configured to: plot a water cut change curve based on the oil production, the injection amount of the injection device, and the first water production measured by the water phase metering unit; and determine the injection parameters based on the recovery degree change curve, which further includes: determining the injection parameters based on the recovery degree change curve and the water cut change curve.

[0017] In this embodiment of the invention, the injection device further includes an oil phase injection component, which is connected to the inlet of the reservoir simulation device. Before the steam injection component and the reactant injection component inject water vapor and reactants into the reservoir simulation device according to a preset ratio, the device further includes:

[0018] Control the oil phase injection component to inject crude oil into the reservoir simulation device;

[0019] The bound water saturation is determined based on the second product water volume measured by the aqueous phase metering unit and the bound water calculation formula; wherein, the bound water calculation formula is: In the formula, To restrict water saturation, For pore volume, This is the second water production volume.

[0020] In this embodiment of the invention, the reservoir simulation device includes a reaction tube and a sand-filling tube. A valve is installed on the pipeline between the reaction tube and the sand-filling tube. A catalyst is installed in the reaction tube and is used to connect the steam injection component and the reactant injection component. A simulated rock core is installed in the sand-filling tube and is used to connect the metering device.

[0021] In this embodiment of the invention, the wall of the sand-filled pipe is provided with multiple detection interfaces, which are arranged sequentially along the length of the sand-filled pipe. Each interface is provided with a temperature sensor and a pressure sensor. The data processing device is communicatively connected to each temperature sensor and pressure sensor. The simulated core includes multiple filling layers arranged sequentially along the length of the sand-filled pipe, and the quartz sand mesh size of each filling layer is set to be different.

[0022] In this embodiment of the invention, the chemical reaction hydrocarbon generation exothermic synergistic steam drive simulation system further includes a six-way valve, with each port of the six-way valve being connected to the steam injection component, the reactant injection component, and the reservoir simulation device respectively; the chemical reaction hydrocarbon generation exothermic synergistic steam drive simulation system also includes a back pressure valve, which is located between the reservoir simulation device and the metering device.

[0023] To achieve the above objectives, a second aspect of the present invention provides a method for simulating the exothermic reaction-induced hydrocarbon generation combined with steam drive, comprising:

[0024] Reservoir models are constructed using reservoir simulation devices;

[0025] Determine the bound water saturation of the reservoir model;

[0026] Water vapor and reactants are injected into the reservoir simulation device via an injection device;

[0027] The oil production, water production, and gas production at the outlet of the reservoir simulation device are recorded using a metering device.

[0028] Based on oil production, water production, gas production, and bound water saturation, respectively plot the recovery degree curve and the water cut curve.

[0029] In this embodiment of the invention, constructing a reservoir model using a reservoir simulation device includes:

[0030] Different mesh sizes of quartz sand are layered within the reservoir simulation device to construct a simulated core.

[0031] Evacuate the reservoir simulation device;

[0032] Liquid water was injected into the reservoir simulation device until the simulated core was saturated with water;

[0033] Crude oil was injected into the reservoir simulation device until the simulated core was saturated with oil.

[0034] In this embodiment of the invention, determining the bound water saturation of the reservoir model includes:

[0035] Obtain the mass of the simulated core before and after water saturation;

[0036] The pore volume of the simulated core was determined based on its mass before and after water saturation.

[0037] The bound water saturation is determined based on the pore volume, the water production measured by the metering device, and the bound water calculation formula; the bound water calculation formula is as follows: In the formula, To restrict water saturation, For pore volume, This is the second water production volume.

[0038] Through the above technical solutions, the chemical reaction hydrocarbon generation exothermic synergistic steam drive simulation system and method provided in the embodiments of the present invention have the following beneficial effects:

[0039] When using the aforementioned chemical reaction-induced hydrocarbon generation and exothermic synergistic steam drive simulation system, the dynamic process of chemical reaction-induced hydrocarbon generation and exothermic synergistic steam drive under different geological conditions can be simulated. This clarifies the requirements for reactants and injection parameters at different stages of heavy oil development, thus providing reliable theoretical guidance for heavy oil reservoir development. The reservoir simulation device simulates the physical environment of actual reservoirs. Its interior is constructed using quartz sand to create simulated cores. By selecting the properties of the quartz sand, reservoir geological characteristics with different permeabilities and porosities can be constructed. The injection device injects steam, chemical reaction fluids, and other necessary fluids into the reservoir simulation device. By controlling parameters such as injection pressure, flow rate, and temperature, different injection conditions during actual development are simulated. The metering and data processing devices are used to meter and analyze the injection parameters of oil production, steam, and reactants, thereby optimizing the selection of injection parameters based on oil production.

[0040] Other features and advantages of the present invention will be described in detail in the following detailed description section. Attached Figure Description

[0041] The accompanying drawings are provided to illustrate the invention and form part of the specification. They are used together with the following detailed description to explain the invention, but do not constitute a limitation thereof. In the drawings:

[0042] Figure 1 This is a schematic diagram of a chemical reaction hydrocarbon generation exothermic synergistic steam drive simulation system according to an embodiment of the present invention;

[0043] Figure 2 This is a flowchart of a chemical reaction hydrocarbon generation exothermic synergistic steam drive simulation method according to an embodiment of the present invention;

[0044] Figure 3 This is a pressure change curve according to an embodiment of the present invention;

[0045] Figure 4 This is a graph showing the extraction degree and moisture content according to an embodiment of the present invention;

[0046] Figure 5 This is a graph showing the extraction degree and moisture content according to another embodiment of the present invention;

[0047] Figure 6 This is a graph showing the extraction rate versus reactant injection rate according to an embodiment of the present invention.

[0048] Explanation of reference numerals in the attached figures

[0049] Detailed Implementation

[0050] The specific embodiments of the present invention will be described in detail below with reference to the accompanying drawings. It should be understood that the specific embodiments described herein are for illustration and explanation only and are not intended to limit the present invention.

[0051] The chemical reaction hydrocarbon generation exothermic synergistic steam drive simulation system of the present invention is described below with reference to the accompanying drawings.

[0052] like Figure 1 As shown, the present invention provides a chemical reaction hydrocarbon generation exothermic synergistic steam drive simulation system, wherein the chemical reaction hydrocarbon generation exothermic synergistic steam drive simulation system includes:

[0053] The reservoir simulation device is filled with quartz sand as a simulated core, and the simulated core contains crude oil and water.

[0054] The injection device includes a steam injection assembly and a reactant injection assembly. The steam injection assembly is connected to the inlet of the reservoir simulation device and is used to inject water vapor into the reservoir simulation device. The reactant injection assembly is connected to the inlet of the reservoir simulation device and is used to inject reactants into the reservoir simulation device.

[0055] Metering device 5 is connected to the outlet of the reservoir simulation device and includes an oil phase metering unit for measuring oil production.

[0056] Data processing device 3 is communicatively connected to metering device 5 and injection device respectively, and is configured as follows:

[0057] According to the preset ratio, the steam injection component and the reactant injection component inject water vapor and reactants into the reservoir simulation device, respectively;

[0058] The injection parameters of the injection unit are determined based on the oil production rate.

[0059] When using the aforementioned chemical reaction-induced hydrocarbon generation and exothermic synergistic steam drive simulation system, the dynamic process of chemical reaction-induced hydrocarbon generation and exothermic synergistic steam drive under different geological conditions can be simulated. This clarifies the requirements for reactants and injection parameters at different stages of heavy oil development, thus providing reliable theoretical guidance for heavy oil reservoir development. The reservoir simulation device simulates the physical environment of actual reservoirs. It constructs simulated cores using quartz sand, and by selecting the properties of the quartz sand, reservoir geological characteristics with different permeabilities and porosities can be constructed. The injection device injects steam, chemical reaction fluids, and other necessary fluids into the reservoir simulation device, and simulates different injection conditions during actual development by controlling parameters such as injection pressure, flow rate, and temperature. The metering device 5 and data processing device 3 are used to meter and analyze the injection parameters of oil production, steam, and reactants, thereby optimizing the injection parameters based on oil production.

[0060] Specifically, the steam injection assembly includes a first injection pump 1 and a steam generator 2. The first injection pump 1 is connected to the input end of the steam generator 2 via a pipeline and is used to deliver water or a specific working fluid into the steam generator 2. The steam generator 2 then converts the input working fluid into high-temperature and high-pressure steam through a heating device. The generated steam enters the reservoir simulation device through an output pipeline to simulate the steam injection state during the on-site steam drive process.

[0061] Furthermore, a pressure regulating valve and a flow meter can be installed on the pipeline between the steam generator 2 and the reservoir simulation device. The pressure regulating valve can precisely control the steam injection pressure according to experimental requirements, while the flow meter monitors the instantaneous and cumulative steam flow in real time, providing accurate steam injection data support for subsequent data processing and parameter optimization.

[0062] Specifically, the reactant injection assembly includes a second injection pump 6 and a reactant piston container 7. The second injection pump 6 is connected to the input end of the reactant piston container 7 via a pipeline, and is used to stably deliver the reaction fluid in the reactant piston container 7 to the reservoir simulation device. The reactant piston container 7 uses an internal piston structure to seal and store the reaction fluid, preventing the fluid from exchanging substances with the external environment or experiencing pressure loss during transportation, and ensuring that the composition and pressure state of the reaction fluid injected into the reservoir simulation device meet the experimental design requirements.

[0063] Specifically, the injection device also includes an aqueous phase injection assembly and an oil phase injection assembly, used to inject liquid water and crude oil into the reservoir simulation device, respectively.

[0064] In this embodiment of the invention, the reservoir simulation device includes a reaction pipe 9 and a sand-filling pipe 11. A valve 10 is installed on the pipeline between the reaction pipe 9 and the sand-filling pipe 11. A catalyst is installed in the reaction pipe 9 and it is used to connect the steam injection component and the reactant injection component. A simulated core is installed in the sand-filling pipe 11 and it is used to connect the metering device 5. The reaction pipe 9 and the sand-filling pipe 11 are set up independently. By installing a catalyst in the reaction pipe 9, the reactants can undergo a pre-chemical reaction before entering the sand-filling pipe 11, generating hydrocarbons with oil displacement capabilities and releasing heat of reaction. The simulated core in the sand-filling pipe 11 is used to simulate the pore structure and rock properties of the actual oil reservoir. When the reacted fluid (including generated hydrocarbons, hot fluids, etc.) enters the sand-filling pipe 11, the heat generated by the reaction reduces the viscosity of the heavy oil. The generated hydrocarbons mix with the heavy oil, further reducing its viscosity, thereby improving the recovery rate.

[0065] Specifically, a sampling port is also provided at the end of the reaction tube 9, through which the reaction temperature, pressure and composition of the products can be monitored.

[0066] In this embodiment of the invention, multiple detection interfaces are provided on the wall of the sand-filled pipe 11, arranged sequentially along the length of the sand-filled pipe 11. Each interface is equipped with a temperature sensor and a pressure sensor, and the data processing device 3 is communicatively connected to each temperature sensor and pressure sensor. By setting multiple detection interfaces, the temperature and pressure changes at different locations within the sand-filled pipe 11 can be monitored in real time. Multiple temperature measurements can clarify the heat transfer process generated by the chemical reaction in the sand-filled core, and multiple pressure measurements can clarify the flow characteristics of the fluid within the core.

[0067] In this embodiment of the invention, the simulated core includes multiple filling layers arranged sequentially along the length of the sand-filling pipe 11. The quartz sand mesh size of each filling layer is set differently to more accurately simulate the actual reservoir environment.

[0068] In this embodiment of the invention, the chemical reaction hydrocarbon generation exothermic synergistic steam drive simulation system also includes a six-way valve 8, with each port of the six-way valve 8 connected to the steam injection assembly, the reactant injection assembly, and the reservoir simulation device respectively.

[0069] In this embodiment of the invention, the chemical reaction hydrocarbon generation exothermic synergistic steam drive simulation system also includes a back pressure valve 4, which is located between the reservoir simulation device and the metering device 5. The back pressure valve 4 is used to control the pressure of the fluid and prevent backflow. Specifically, the back pressure valve 4 is equipped with a back pressure pump to form a back pressure system, which, together with the metering device 5, can simulate the process of thermal-hydrocarbon-vapor synergistic oil displacement inside a heavy oil reservoir.

[0070] In this embodiment of the invention, the crude oil recovery rate can be calculated using this system. The specific operation and calculation process are as follows:

[0071] The reservoir simulation device was evacuated and saturated with water. The simulated core weights m0 and m1 before and after water saturation were measured, and the pore volume of the simulated core was calculated. and Porosity. Specifically:

[0072]

[0073] In the formula, Pore ​​volume, unit: cm³ 3 m1 is the core weight after water saturation, in g; m0 is the core weight before water saturation, in g. This is the density of water, expressed in g / cm³. 3 .

[0074]

[0075] In the formula, Porosity, expressed as % Pore ​​volume, unit: cm³ 3 ; This represents the total volume of the core, in cm³. 3 .

[0076] Oil is saturated using water flooding to establish bound water, and then aged at reservoir temperature to calculate the bound water saturation. Used to simulate reservoir conditions; specifically:

[0077]

[0078] In the formula, The bound water saturation is expressed in % (%). Pore ​​volume, unit: cm³ 3 ; The volume of water displaced from the core (secondary water production), in cm³. 3 .

[0079] The catalyst in the chemical reaction is placed into the reaction tube 9, and the internal volume of the device is adjusted so that the catalyst is completely filled inside the device.

[0080] Turn on the steam generator 2, set the steam temperature to the temperature required for the experiment, and after the generated steam reaches the preset temperature, continuously inject high-temperature steam into the reaction tube 9.

[0081] The reactants and steam are continuously injected into the reaction tube 9 using the second injection pump 6 to begin simulating the chemical reaction process. The reaction temperature, pressure, and product composition are monitored through a sampling port at the end of the reaction tube 9. Once the reaction reaches the preset temperature and pressure, valve 10 is opened to connect the reaction tube 9 to the sand-filling tube 11.

[0082] Steam generated by steam generator 2, heat generated by chemical reaction, and hydrocarbons are injected into sand-filled pipe 11 through first injection pump 1 and second injection pump 6 to simulate the process of heat-hydrocarbon-gas synergistic oil displacement in deep reservoir.

[0083] During the experiment, the detection data of the temperature sensor and pressure sensor were recorded, as well as the oil production, water production and gas production in the outlet metering device 5.

[0084] By monitoring the temperature at various points along the sand-filled pipe, the temperature field changes inside the core can be obtained. Based on the temperature changes at each point, the heat released by the chemical reaction can be transferred within the core.

[0085] By monitoring the pressure at various points along the sand-filled pipe, the changes in the pressure field inside the core can be obtained. Based on the pressure changes at each point, the flow patterns of displacement media such as steam and hydrocarbons in the core can be analyzed.

[0086] By recording oil production, water production, and gas production, the production status at each stage of the experiment can be obtained. The water content at different times can be calculated from the oil and water production at different times, and a water content curve can be plotted. The current displacement status of the core can be determined based on the water content.

[0087]

[0088] In the formula, f w Moisture content, in percentages (%) The instantaneous oil production at time t is expressed in cm³. 3 ; The instantaneous water production at time t is expressed in cm³. 3 .

[0089] After the sand-filled pipe 11 stops producing oil, the back pressure at the outlet is released to end the experiment. The recovery rate at different times is calculated and the experimental data is processed.

[0090]

[0091] In the formula, R represents the recovery rate, expressed as a percentage (%). The cumulative oil production at time t is expressed in cm³. The bound water saturation is expressed in % (%). The value represents the pore volume, expressed in cm³.

[0092] Determining the injection parameters of the injection unit based on oil production includes:

[0093] Plot a curve showing the change in the degree of crude oil recovery based on the degree of crude oil recovery and the injection volume of the injection unit;

[0094] The injection parameters are determined based on the recovery rate curve, which includes the amount of reactant injected and the amount of steam injected.

[0095] In this embodiment of the invention, the metering device 5 further includes a water phase metering unit for measuring the produced water volume, and the data processing device 3 is further configured to: plot a water cut change curve based on the oil production, the injection volume of the injection device, and the first produced water volume measured by the water phase metering unit; determining the injection parameters based on the recovery degree change curve further includes: determining the injection parameters based on the recovery degree change curve and the water cut change curve. Specifically, in the crude oil extraction process, a high recovery degree and a low water cut are usually pursued. The recovery degree and water cut under different injection parameters can be compared using these two curves to determine the injection parameters corresponding to the highest recovery rate and the lowest water cut.

[0096] like Figure 2 As shown, in order to achieve the above objectives, a second aspect of the present invention provides a method for simulating the exothermic reaction-induced hydrocarbon generation combined with steam drive, comprising:

[0097] S100, a reservoir model is constructed using a reservoir simulation device;

[0098] S200, determine the bound water saturation of the reservoir model;

[0099] S300 injects water vapor and reactants into the reservoir simulation device through the injection device;

[0100] S400 records the oil production, water production, and gas production at the outlet of the reservoir simulation device through metering device 5;

[0101] For S500, curves showing the changes in recovery rate and water cut are plotted based on oil production, water production, gas production, and bound water saturation.

[0102] In this embodiment of the invention, step S100, constructing a reservoir model using a reservoir simulation device, includes:

[0103] S110, different mesh sizes of quartz sand are layered in the reservoir simulation device to construct a simulated core;

[0104] S120, evacuate the reservoir simulation device;

[0105] S130, inject liquid water into the reservoir simulation device until the simulated core is saturated with water;

[0106] S130, inject crude oil into the reservoir simulation device until the simulated core is saturated with oil.

[0107] In this embodiment of the invention, step S200, determining the bound water saturation of the reservoir model, includes:

[0108] S210, obtain the mass of the simulated core before and after water saturation;

[0109] S220, the pore volume of the simulated core is determined based on the mass of the simulated core before and after water saturation.

[0110] S230, the bound water saturation is determined based on the pore volume, the water production rate measured by metering device 5, and the bound water calculation formula; wherein, the bound water calculation formula is: In the formula, To restrict water saturation, For pore volume, This is the second water production volume.

[0111] Specifically, in the above-mentioned chemical reaction hydrocarbon generation exothermic synergistic steam drive simulation system, the maximum temperature resistance of the sand-filled pipe 11 is 350℃, the pressure resistance is 50MPa, the diameter of the simulated rock core inside the sand-filled pipe 11 is 2.5cm, the length is 30cm, the core permeability is 2500mD, the experimental temperature is 150℃, the crude oil used in the experiment is extra-heavy crude oil from the mine, and the viscosity of the crude oil at 50℃ is 38422mPa·s; the maximum injection pressure of the first injection pump 1 and the second injection pump 6 is 50MPa; the steam generator 2 can generate steam at a maximum temperature of 300℃; the capacity of the reactant storage piston is 1000mL, the maximum temperature resistance is 350℃, and the pressure resistance is 50MPa.

[0112] Based on the above system and method, the first group of physical simulation experiments on the synergistic steam drive and exothermic hydrogenesis through chemical reaction was conducted. After evacuating the simulated core to saturate it with water, the core pore volume was measured to be 50 cm³. 3 The porosity was 33.95%; the bound water saturation was calculated to be 16% after saturation with oil. The catalyst was placed in reaction tube 9; steam generator 2 was turned on, and the steam temperature was set to 250℃. High-temperature steam was injected into reaction tube 9 using a first high-precision injection pump at an injection rate of 2.0 mL / min. Simultaneously, reactants were injected into reaction tube 9 using a second injection pump 6 at an injection rate of 1.0 mL / min to ensure the continuous and efficient chemical reaction. Subsequently, the heat and hydrocarbons generated by the chemical reaction, along with the steam generated by steam generator 2, entered sand-filled tube 11 to begin the oil displacement experiment. Temperature, pressure, outlet oil production, water production, and gas production were recorded at different times during the reaction. After oil production ceased at the outlet of sand-filled tube 11, the outlet backpressure was released, ending the experiment. The recovery rate was calculated at different times, and the experimental data were processed. The final recovery rate was 63.50%. The pressure change curve during the experiment is shown below. Figure 3 As shown, the extraction degree and moisture content curves are as follows: Figure 4 As shown. It should be noted that, Figure 4 The injection volume is the amount of steam injected. Figure 4 The curves in the middle are all experimental results from core displacement experiments, with steam as the main displacement medium.

[0113] Based on the above system and method, a second set of physical simulation experiments on the synergistic steam drive and exothermic hydrogenesis through chemical reaction was conducted. After evacuating the simulated core to saturation with water, the core pore volume was measured to be 50 cm³. 3 The porosity was 33.95%; the bound water saturation was calculated to be 16% after oil saturation. The catalyst was placed in reaction tube 9; steam generator 2 was turned on, and the steam temperature was set to 250℃. High-temperature steam was injected into reaction tube 9 using a first high-precision injection pump at an injection rate of 2.0 mL / min, while reactants were injected into reaction tube 9 simultaneously using a second injection pump 6 at an injection rate of 2.0 mL / min to ensure continuous and efficient chemical reaction. Subsequently, the heat and hydrocarbons generated by the chemical reaction, along with the steam generated by steam generator 2, entered sand-filled tube 11 to begin the oil displacement experiment. Temperature, pressure, outlet oil production, water production, and gas production were recorded at different times during the reaction. After oil production ceased at the outlet of sand-filled tube 11, the outlet backpressure was released, ending the experiment. The recovery rate was calculated at different times, and the experimental data were processed. The final recovery rate was 70.49%, and the recovery rate and water cut curves are shown below. Figure 5 As shown.

[0114] like Figure 6 As shown, physical simulation experiments of chemical reaction hydrocarbon generation exothermic synergistic steam drive were conducted based on the above system and method at different reactant injection rates. The recovery rates were obtained for no reactant injection and reactant injection rates of 1 mL / min, 2 mL / min, and 3 mL / min. The optimal reactant injection rate can be determined based on the recovery rate. The recovery rate was 56.32% with no reactant injection, 63.50% with a reactant injection rate of 1 mL / min, 70.49% with a reactant injection rate of 2 mL / min, and 72.31% with a reactant injection rate of 3 mL / min. Considering all factors, the recovery rate was relatively high at 2 mL / min, and the amount of reactant injected was small. Therefore, the optimal reactant injection rate was determined to be 2 mL / min. The recovery rate curves at different reactant injection rates are shown in the figure. Figure 6 As shown.

[0115] The two sets of experiments above yielded recovery rates at different reactant injection rates, demonstrating that the chemical reaction-induced hydrocarbon generation and exothermic synergistic steam drive simulation system and method of this invention can obtain recovery rate data by adjusting the reactant injection rate. Similarly, changing other injection parameters, such as temperature, pressure, and porosity of the simulated core, allows for the conduct of multiple comparative experiments. This further helps researchers comprehensively explore the effects of different injection parameters and geological environment on the development effectiveness of chemical reaction-induced hydrocarbon generation and exothermic synergistic steam drive, providing richer experimental evidence and theoretical support for optimizing injection schemes in actual oilfield development.

[0116] In the description of this invention, it should be understood that the terms "first" and "second" are used for descriptive purposes only and should not be construed as indicating or implying relative importance or implicitly specifying the number of indicated technical features. Thus, a feature defined as "first" or "second" may explicitly or implicitly include at least one of that feature. In the description of this invention, "a plurality of" means at least two, such as two, three, etc., unless otherwise explicitly specified.

[0117] In this invention, unless otherwise explicitly specified and limited, the terms "installation," "connection," "linking," and "fixing," etc., should be interpreted broadly. For example, they can refer to a fixed connection, a detachable connection, or an integral part; they can refer to a mechanical connection, an electrical connection, or a connection that allows communication between them; they can refer to a direct connection or an indirect connection through an intermediate medium; they can refer to the internal communication of two components or the interaction between two components, unless otherwise explicitly limited. Those skilled in the art can understand the specific meaning of the above terms in this invention according to the specific circumstances.

[0118] In the description of this specification, the references to terms such as "one embodiment," "some embodiments," "example," "specific example," or "some examples," etc., indicate that a specific feature, structure, material, or characteristic described in connection with that embodiment or example is included in at least one embodiment or example of the present invention. In this specification, the illustrative expressions of the above terms do not necessarily refer to the same embodiment or example. Furthermore, the specific features, structures, materials, or characteristics described may be combined in any suitable manner in one or more embodiments or examples. Moreover, without contradiction, those skilled in the art can combine and integrate the different embodiments or examples described in this specification, as well as the features of different embodiments or examples.

[0119] Although embodiments of the present invention have been shown and described above, it is understood that the above embodiments are exemplary and should not be construed as limiting the present invention. Those skilled in the art can make changes, modifications, substitutions and variations to the above embodiments within the scope of the present invention.

Claims

1. A chemical reaction hydrocarbon generation exothermic synergistic steam drive simulation system, characterized in that, The chemical reaction hydrocarbon generation exothermic synergistic steam drive simulation system includes: A reservoir simulation device, wherein the reservoir simulation device is filled with quartz sand as a simulated core, and the simulated core contains crude oil and water; An injection device includes a steam injection assembly and a reactant injection assembly. The steam injection assembly is connected to the inlet of the reservoir simulation device and is used to inject water vapor into the reservoir simulation device. The reactant injection assembly is connected to the inlet of the reservoir simulation device and is used to inject reactants into the reservoir simulation device. Metering device (5), the metering device (5) is connected to the outlet of the reservoir simulation device, and includes an oil phase metering unit for measuring oil production; A data processing device (3) is communicatively connected to the metering device (5) and the injection device, and is configured to: According to the preset ratio, the steam injection component and the reactant injection component inject water vapor and reactants into the reservoir simulation device, respectively; The injection parameters of the injection unit are determined based on the oil production rate. The reservoir simulation device includes a reaction tube (9) and a sand-filling tube (11). A valve (10) is installed on the pipeline between the reaction tube (9) and the sand-filling tube (11). A catalyst is installed in the reaction tube (9) and is used to connect the steam injection assembly and the reactant injection assembly. The simulated core is installed in the sand-filling tube (11) and is used to connect the metering device (5).

2. The chemical reaction hydrocarbon generation exothermic synergistic steam drive simulation system according to claim 1, characterized in that, The process of determining the injection parameters of the injection device based on the oil production includes: The degree of crude oil recovery is determined based on the oil production and the recovery rate calculation formula; the recovery rate calculation formula is as follows: In the formula, R To determine the degree of extraction; Let be the oil production at time t; To bind water saturation; Pore ​​volume; Plot a curve showing the change in the degree of crude oil recovery based on the degree of crude oil recovery and the injection volume of the injection unit; The injection parameters are determined based on the recovery rate curve, which includes the amount of reactant injected and the amount of steam injected.

3. The chemical reaction hydrocarbon generation exothermic synergistic steam drive simulation system according to claim 2, characterized in that, The metering device (5) also includes a water phase metering unit for measuring the amount of produced water, and the data processing device (3) is further configured to: plot a water content change curve based on the amount of oil produced, the amount injected by the injection device and the first amount of produced water measured by the water phase metering unit; The step of determining the injection parameters based on the recovery degree change curve further includes: determining the injection parameters based on the recovery degree change curve and the water cut change curve.

4. The chemical reaction hydrocarbon generation exothermic synergistic steam drive simulation system according to claim 3, characterized in that, The injection device further includes an oil phase injection component, which is connected to the inlet of the reservoir simulation device. Before the step of controlling the steam injection component and reactant injection component to inject water vapor and reactants into the reservoir simulation device according to a preset ratio, the following steps are also included: Control the oil phase injection component to inject crude oil into the reservoir simulation device; The bound water saturation is determined based on the second product water volume measured by the aqueous phase metering unit and the bound water calculation formula; wherein, the bound water calculation formula is: In the formula, To restrict water saturation, For pore volume, This is the second water production volume.

5. The chemical reaction hydrocarbon generation exothermic synergistic steam drive simulation system according to claim 1, characterized in that, The sand-filling pipe (11) has multiple detection interfaces on its wall. The multiple detection interfaces are arranged sequentially along the length of the sand-filling pipe (11). Each interface is equipped with a temperature sensor and a pressure sensor. The data processing device (3) is connected to each of the temperature sensors and the pressure sensors in communication. And / or, the simulated core includes multiple filling layers arranged sequentially along the length of the sand-filling pipe (11), and the quartz sand mesh size of each filling layer is set to be different.

6. The chemical reaction hydrocarbon generation exothermic synergistic steam drive simulation system according to any one of claims 1 to 3, characterized in that, The chemical reaction hydrocarbon generation exothermic synergistic steam drive simulation system also includes a six-way valve (8), and each valve port of the six-way valve (8) is connected to the steam injection component, the reactant injection component and the reservoir simulation device respectively; And / or, the chemical reaction hydrocarbon generation exothermic synergistic steam drive simulation system further includes a back pressure valve (4), which is located between the reservoir simulation device and the metering device (5).

7. A method for simulating the exothermic reaction-induced hydrocarbon generation combined with steam drive, characterized in that, The chemical reaction hydrocarbon generation exothermic synergistic steam drive simulation method is applied to the chemical reaction hydrocarbon generation exothermic synergistic steam drive simulation system according to any one of claims 1 to 6, including: Reservoir models are constructed using reservoir simulation devices; Determine the bound water saturation of the reservoir model; Water vapor and reactants are injected into the reservoir simulation device via an injection device; The oil production, water production and gas production at the outlet of the reservoir simulation device are recorded by the metering device (5); Based on oil production, water production, gas production, and bound water saturation, respectively plot the recovery degree curve and the water cut curve.

8. The method for simulating the exothermic chemical reaction-induced hydrocarbon generation combined with steam drive according to claim 7, characterized in that, The construction of the reservoir model using the reservoir simulation device includes: Different mesh sizes of quartz sand are layered within the reservoir simulation device to construct a simulated core. Evacuate the reservoir simulation device; Liquid water was injected into the reservoir simulation device until the simulated core was saturated with water; Crude oil was injected into the reservoir simulation device until the simulated core was saturated with oil.

9. The method for simulating the exothermic chemical reaction-induced hydrocarbon generation combined with steam drive according to claim 8, characterized in that, The determination of the bound water saturation of the reservoir model includes: Obtain the mass of the simulated core before and after water saturation; The pore volume of the simulated core was determined based on its mass before and after water saturation. The bound water saturation is determined based on the pore volume, the water production measured by the metering device (5), and the bound water calculation formula; wherein, the bound water calculation formula is: In the formula, To restrict water saturation, For pore volume, This is the second water production volume.

Images