Thickened oil watering gathering and transportation optimization method, system and device based on analogue simulation
By constructing a simulation model of a heavy oil-water blending and transportation system and optimizing the heavy oil-water blending parameters, the problems of scaling and corrosion in pipelines during heavy oil transportation were solved, thereby improving the stability and economy of the heavy oil-water blending system.
Patent Information
- Authority / Receiving Office
- CN · China
- Patent Type
- Applications(China)
- Current Assignee / Owner
- PETROCHINA CO LTD
- Filing Date
- 2024-11-19
- Publication Date
- 2026-05-19
AI Technical Summary
Existing technologies are insufficient to flexibly handle the water-mixing transportation conditions of different heavy oil products, resulting in problems such as severe scaling and corrosion in pipelines, easy oil-water separation, and high dehydration load. Furthermore, existing methods are insufficient to determine the optimal operating parameters.
By constructing a simulation model of a heavy oil-water blending and transportation system, collecting system parameters and the viscosity-temperature relationship of the mixture, determining the minimum water blending amount and feasible operating conditions, and optimizing the water blending temperature and flow rate to reduce energy consumption.
This method enables the determination of the optimal water blending temperature and amount under different heavy oil conditions, reducing system energy consumption and heat loss, and improving the stability and economy of heavy oil water blending transportation.
Smart Images
Figure CN122065482A_ABST
Abstract
Description
Technical Field
[0001] This application belongs to the field of heavy oil gathering and transportation technology, and in particular relates to a simulation-based optimization method, system and device for heavy oil water blending gathering and transportation. Background Technology
[0002] With the increasing global demand for crude oil and the gradual depletion of conventional crude oil reserves, the rational exploitation of heavy oil has become particularly important. Compared to conventional petroleum, heavy oil has a higher content of macromolecules such as gums and asphaltenes, and is characterized by high density, high viscosity, and poor fluidity. Long-distance pipeline transportation requires special transport processes, which brings great challenges to the exploitation and transportation of heavy oil.
[0003] In recent years, numerous scholars have conducted research on the issue of water-blended heavy oil transportation. However, current research focuses on obtaining the optimal operating parameters of water-blended heavy oil collection systems, including the optimal water blending temperature and volume under different produced fluid conditions. The following problems still exist in the heavy oil transportation process:
[0004] (1) The composition of heavy oil determines its physical properties such as viscosity, density, and rheology, which affects the ease and effectiveness of heavy oil mixed with water for transportation. The proportion of water mixed determines the stability and economy of heavy oil mixed with water transportation. Generally speaking, the higher the proportion of water mixed, the lower the viscosity and resistance of the heavy oil, but it will also increase water consumption and the difficulty of treatment.
[0005] (2) During the water-mixing transportation process, a large amount of hot water or activated water needs to be added to the extra-heavy oil. If necessary, a demulsifier should be added to inhibit further emulsification of the extra-heavy oil and water during pipeline transportation. If the optimal transportation conditions are unknown during the transportation process, and water is mixed and the temperature is increased based solely on experience, problems such as severe scaling and corrosion of the pipeline, easy separation of oil and water, and high dehydration load can easily occur as the amount of water mixed and the temperature of the water mixed increases.
[0006] (3) Existing methods for determining the optimal transport parameters are relatively absolute or singular, based only on the water blending ratio or water blending temperature within a small range, making it difficult to flexibly cope with the working conditions of heavy oil water blending transport for different oil products.
[0007] (4) When studying the many flow parameters of heavy oil mixed with water transportation, it is difficult to find the optimal operating conditions, including the water mixing ratio and water mixing temperature for heavy oils of different viscosities.
[0008] Existing research on the operational conditions of water-mixed transportation of heavy and extra-heavy oil is not comprehensive and struggles to flexibly address the transportation of different heavy oil products mixed with water. Therefore, it is necessary to construct a water-mixing optimization model for the gathering and transportation system to effectively obtain the operating parameters of the heavy oil water-mixed oil gathering system. Summary of the Invention
[0009] The purpose of this application is to provide a simulation-based method, system, and device for optimizing heavy oil water-mixed transportation parameters. By constructing a water-mixing optimization model for the gathering and transportation system, the operating parameters of the heavy oil water-mixed oil gathering system are obtained, including the optimal water mixing temperature and water mixing amount under different produced fluid conditions, thereby solving the problems faced in heavy oil water-mixed transportation.
[0010] To achieve the above objectives, this application provides the following technical solution:
[0011] A simulation-based optimization method for gathering and transporting heavy oil mixed with water includes:
[0012] Collect parameters of the pipeline network and equipment of the heavy oil-water blending gathering and transportation system, and conduct tests on the physical properties of the produced fluid, the quality of the blended water, and the viscosity-temperature relationship of the heavy oil-water mixture;
[0013] Multiple combined operating conditions were obtained by using the temperature and water content of the heavy oil-water mixture as variables, and the minimum water addition was determined based on the multiple combined operating conditions.
[0014] Based on the comparison of minimum water injection volume and the adjustment of various combined working conditions, several feasible water injection conditions that meet the wellhead back pressure boundary range and the produced fluid inlet temperature boundary range are obtained.
[0015] Based on the temperature drop and pressure drop along the route under feasible water-mixing conditions, the water-mixing parameters are adjusted to obtain the water-mixing condition with the lowest energy consumption.
[0016] Furthermore, the parameters of the heavy oil blending and gathering system pipeline network and equipment include oil gathering pipeline parameters, wellhead parameters, outlet and inlet temperatures of the heating furnace, and outlet pressure of the blending pump.
[0017] Furthermore, the physical properties of the produced liquid include density, water content, gas composition, liquid phase viscosity-temperature relationship, pour point, and wax content.
[0018] Furthermore, the test of the viscosity-temperature relationship of the heavy oil-water mixture includes plotting the relationship between the viscosity of the heavy oil-water mixture and temperature and water content, and determining the inversion point and viscosity reduction boundary of the heavy oil-water mixture based on the relationship plot.
[0019] Furthermore, before determining the minimum water injection volume, the operating parameters of the produced material are collected to determine the wellhead back pressure boundary range and the temperature boundary range of the produced fluid entering the station.
[0020] Furthermore, the operating parameters of the produced material include the flow rate of the produced material, the gas-liquid ratio of the produced material, the water content of the produced material, and the environmental parameters along the oil gathering pipeline network.
[0021] Furthermore, the wellhead backpressure boundary range is determined based on the requirements of the upstream oil production system.
[0022] Furthermore, the temperature range of the produced fluid entering the station is determined based on the properties of the produced fluid and the requirements of downstream processing.
[0023] Furthermore, multiple combined operating conditions are obtained by using the temperature and water content of the heavy oil-water mixture as variables. Based on these combined operating conditions, the minimum water addition is determined, including:
[0024] Multiple combinations of temperature and water content of heavy oil-water mixtures are determined based on the viscosity-temperature relationship and phase reversal point parameters.
[0025] The minimum water addition amount is determined based on the water addition temperature, water addition amount, water quality, scaling trend of the oil collection pipeline, and the impact of water addition amount on the oil-water flow pattern in the oil collection pipeline for each combination of working conditions.
[0026] Furthermore, based on the minimum water injection ratio comparison and adjustment of various combined operating conditions, several feasible water injection conditions that satisfy the wellhead back pressure boundary range and the produced fluid inlet temperature boundary range were obtained, including:
[0027] For combined operating conditions where the water dosage is lower than the minimum water dosage, water is added according to the minimum water dosage. The hydraulic and thermal properties of the oil collecting pipeline after water addition are calculated to obtain the back pressure at the inlet and the inlet temperature at the outlet of the oil collecting pipeline.
[0028] When the back pressure at the inlet of the oil gathering pipeline and the inlet temperature at the outlet are within the wellhead back pressure boundary range and the produced fluid inlet temperature boundary range, respectively, the corresponding combination of working conditions is determined to be a feasible water-mixing working condition.
[0029] When the back pressure at the inlet of the oil gathering pipeline is not within the wellhead back pressure boundary, or the inlet temperature at the outlet of the oil gathering pipeline is not within the produced fluid inlet temperature boundary, the water injection parameters for this combined working condition are adjusted according to the temperature and back pressure constraints until a feasible water injection working condition is obtained.
[0030] Furthermore, based on the temperature drop and pressure drop along the route under feasible water-mixing conditions, the water-mixing parameters are adjusted to obtain the water-mixing conditions with minimum energy consumption, including:
[0031] Based on the temperature drop and pressure drop along the line for each feasible water mixing condition, the water mixing temperature and water mixing flow rate of the corresponding feasible water mixing condition are adjusted to obtain multiple optimized water mixing conditions.
[0032] Calculate and compare the energy consumption of all optimized and feasible water-incorporation conditions to determine the water-incorporation condition with the lowest energy consumption.
[0033] This application also discloses a simulation-based optimized system for gathering and transporting heavy oil mixed with water, comprising:
[0034] The parameter acquisition unit is used to collect parameters of the pipeline network and equipment of the heavy oil-water blending gathering and transportation system, and to test the physical properties of the produced fluid, the quality of the blended water, and the viscosity-temperature relationship of the heavy oil-water mixture.
[0035] The water addition determination unit is used to obtain multiple combined operating conditions by using the temperature and water content of the heavy oil and water mixture as variables, and to determine the minimum water addition based on the multiple combined operating conditions;
[0036] The operating condition adjustment unit, based on the minimum water injection volume comparison and adjustment of various combined operating conditions, obtains multiple feasible water injection conditions that meet the wellhead back pressure boundary range and the produced fluid inlet temperature boundary range.
[0037] The optimal operating condition unit adjusts the water mixing parameters based on the temperature drop and pressure drop along the route of feasible water mixing conditions to obtain the water mixing condition with the lowest energy consumption.
[0038] This application also discloses an electronic device, including a memory and a processor, wherein the memory stores a computer program or instructions, and when the computer program or instructions are executed by the processor, they are used to implement at least the above-described method.
[0039] This application also discloses a computer-readable storage medium storing a computer program or instructions, which, when executed by a processor, are at least used to implement the above-described method.
[0040] This application also discloses a computer program product stored in a computer-readable storage medium, which, when executed by a processor, is used to implement at least the above-described method.
[0041] The technical effects and advantages of this application are as follows:
[0042] 1. The simulation-based optimization method for heavy oil water blending and gathering in this application can effectively obtain the operating parameters of the heavy oil water blending and gathering system, including the optimal water blending temperature and water blending amount under different produced fluid conditions.
[0043] 2. This application considers the characteristic that as the water mixing temperature increases, the water mixing volume of the system decreases, resulting in increased gas consumption and reduced power consumption in the water mixing oil collection system. Based on the analysis of the operation law of the heavy oil water mixing and transportation process in the field and the energy consumption characteristics of the oil collection system, a water mixing optimization method for a specific heavy oil collection system is proposed.
[0044] 3. The solution proposed in this application is very effective in determining the optimal water mixing temperature and water mixing amount for the transportation of heavy oil with different viscosities and for the transportation of extra-heavy oil with water.
[0045] Other features and advantages of this application will be set forth in the description which follows, and will be apparent in part from the description, or may be learned by practicing the application. The objectives and other advantages of this application may be realized and obtained by means of the structures pointed out in the description, claims and drawings. Attached Figure Description
[0046] Figure 1 This is a flowchart of the simulation-based optimization method for heavy oil water blending and gathering and transportation proposed in this application. Detailed Implementation
[0047] 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 embodiments of this application, and not all embodiments. 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.
[0048] like Figure 1 As shown, this application provides a simulation-based optimization method for gathering and transporting heavy oil mixed with water, including:
[0049] S1: Collect parameters of the pipeline network and equipment of the heavy oil-water blending and transportation system, and conduct tests on the physical properties of the produced fluid, the quality of the blended water, and the viscosity-temperature relationship of the heavy oil-water mixture.
[0050] Collect parameters of the oil gathering pipeline (e.g., pipeline length, inner diameter, wall thickness, wall roughness, overall heat transfer coefficient, starting pressure, and ending pressure), wellhead parameters (e.g., wellhead coordinates, wellhead pressure, wellhead temperature, oil volume, gasoline ratio, water cut, and elevation), furnace outlet and inlet temperatures, and water pump outlet pressure. Then test parameters such as the density, water cut, gas composition, viscosity-temperature relationship, pour point, and wax content of the produced fluid, and conduct water quality tests. Simultaneously, analyze the scaling characteristics and patterns of the added water. Then, test the viscosity-temperature relationship of the heavy oil-water mixture, and plot the relationship between viscosity, temperature, and water cut of the heavy oil-water mixture. Analyze the viscosity variation law of the heavy oil-water mixture based on the relationship plot, and determine the inversion point and the boundary of significant viscosity reduction in the heavy oil-water mixture.
[0051] S2: Collect the operating parameters of the produced material and determine the wellhead back pressure boundary range.
[0052] Collect the flow rate, gas-liquid ratio, water cut, and environmental parameters along the oil gathering pipeline network. Based on the requirements of the upstream oil production system of the oil gathering pipeline, determine the boundary range of wellhead back pressure.
[0053] S3: Determine the temperature range of the produced fluid entering the station.
[0054] Based on the properties of the produced fluid and the requirements of downstream processing, the temperature boundary range of the produced fluid entering the station is determined.
[0055] S4: Using the temperature and water content of the heavy oil-water mixture as variables, obtain multiple combined operating conditions, and determine the minimum water addition amount based on the multiple combined operating conditions.
[0056] Based on the viscosity-temperature relationship and phase reversal point parameters of the heavy oil-water mixture, n (n≥2) combination operating conditions with the temperature and water content of the heavy oil-water mixture as variables are initially determined. For each combination operating condition, based on operating parameters such as produced material temperature and gas-liquid flow rate, and following the principle of energy and mass conservation of water injection at the wellhead, the water injection temperature and water injection amount for each combination operating condition are determined. Combining the water quality, the analysis of the scaling trend of the oil gathering pipeline after water injection under different operating conditions, and the influence of small water injection amount on the oil-water flow pattern in the oil gathering pipeline, the minimum water injection amount is determined.
[0057] S5: Based on the minimum water addition, the temperature and pressure along the route under the combined working conditions are compared and adjusted to obtain multiple feasible water addition conditions.
[0058] Based on the constraint of minimum water injection, each combination of working conditions is compared and confirmed. For combinations with water injection amounts lower than the minimum, water is injected according to the minimum amount. The hydraulic and thermal properties of the oil gathering pipeline after water injection are calculated to obtain the back pressure at the inlet and the inlet temperature at the outlet of the oil gathering pipeline. When the back pressure at the inlet and the inlet temperature at the outlet of the oil gathering pipeline are within the wellhead back pressure boundary and the produced fluid inlet temperature boundary, respectively, the corresponding combination of working conditions is determined to be a feasible water injection condition. When the back pressure at the inlet of the oil gathering pipeline is not within the wellhead back pressure boundary, or the inlet temperature at the outlet of the oil gathering pipeline is not within the produced fluid inlet temperature boundary, the temperature and pressure change curves along the water injection pipeline and the oil gathering pipeline of this combination of working conditions are analyzed. Based on the temperature and back pressure constraints, the water injection parameters of this combination of working conditions are fine-tuned until n feasible water injection conditions are obtained.
[0059] S6: Adjust the water mixing parameters based on the temperature drop and pressure drop along the line under feasible water mixing conditions to obtain the optimal water mixing conditions.
[0060] After completing the calculations for n feasible water mixing conditions, the temperature drop and pressure drop along each link of the pipeline under the n feasible water mixing conditions are calculated according to the power consumption calculation formulas for the heating furnace and pump. Based on the distribution law of temperature drop and pressure drop along the pipeline under each feasible water mixing condition, and in accordance with the principle of preventing excessive pipeline temperature drop caused by excessive water mixing temperature or excessive pipeline pressure drop caused by excessive water mixing flow, the water mixing parameters of the feasible water mixing conditions are finely adjusted to obtain m new (2≤m≤n) optimized water mixing conditions. The energy consumption of the optimized water mixing conditions and feasible water mixing conditions is calculated, and the total system energy consumption under n+m optimized water mixing conditions and feasible water mixing conditions is plotted. The water mixing condition with the minimum energy consumption is taken as the optimal water mixing condition.
[0061] This application also provides a simulation-based optimized system for gathering and transporting heavy oil mixed with water, including:
[0062] The parameter acquisition unit is used to collect parameters of the pipeline network and equipment of the heavy oil-water blending gathering and transportation system, and to test the physical properties of the produced fluid, the quality of the blended water, and the viscosity-temperature relationship of the heavy oil-water mixture.
[0063] The water addition determination unit is used to determine the minimum water addition based on multiple combinations of operating conditions of the temperature and water content of the heavy oil-water mixture;
[0064] The operating condition adjustment unit is used to compare and adjust various combinations of operating conditions based on the minimum water injection volume to obtain multiple feasible water injection conditions that meet the wellhead back pressure boundary range and the produced fluid inlet temperature boundary range.
[0065] The operating condition optimization unit is used to adjust the water mixing parameters based on the temperature drop and pressure drop along the line under feasible water mixing conditions, so as to obtain the optimal water mixing conditions.
[0066] This application also provides an electronic device, including a memory and a processor, wherein the memory stores a computer program or instructions, and when the computer program or instructions are executed by the processor, they are used to implement at least the above-described method.
[0067] This application also provides a computer-readable storage medium storing a computer program or instructions, which, when executed by a processor, are at least used to implement the above-described method.
[0068] This application also provides a computer program product stored in a computer-readable storage medium, which, when executed by a processor, is used to implement at least the above-described method.
[0069] Example
[0070] Taking the optimization of the gathering and transportation system in the Ji 7 well area of the Jiqing Demonstration Zone in Xinjiang Uygur Autonomous Region as an example, the viscosity of heavy oil in the Ji 7 well area ranges from 2000 to 15000 mps, the freezing point of crude oil is below 10℃, and the comprehensive water content reaches 80%. Before optimization, the on-site water injection temperature was too conservative, with a water injection outlet temperature of 60℃ and a temperature drop of 30℃ in the water injection pipeline system. Among them, the temperature drop along the pipeline (from the joint station to the wellhead) before water injection was 21.5℃, accounting for 72% of the total temperature drop, indicating significant heat loss along the pipeline. After optimization using the method of this application, the comprehensive water content decreased by 4-8% in different viscosity regions after water injection, the actual operating water injection temperature decreased by 10-15℃, and the return oil temperature at the joint station decreased by 3-5℃. After optimizing the water injection volume of the individual wells belonging to the water injection pipelines of Ji 7 well area (Nos. 1, 2, 3, 4, 5, and 7), the water injection volume was reduced by 845 m³ / h. 3 The system's average daily gas consumption was approximately 19,848 m³ / d. 3 / d decreased to 16989m 3 / d, saving 1.04 million cubic meters of natural gas annually, a gas saving rate of 14%.
[0071] In summary, this application comprehensively considers the characteristics of water-blended oil gathering systems, where the water content decreases as the water blending temperature increases, resulting in increased gas consumption and reduced power consumption. Combined with the operational patterns of heavy oil water-blended gathering and transportation processes in the field and the energy consumption characteristics of the oil gathering system, it can effectively obtain the optimal water blending temperature and quantity under different produced fluid conditions. This approach is highly effective in determining the optimal water blending temperature and quantity for water-blended transportation of heavy oil and extra-heavy oil of different viscosities.
[0072] Finally, it should be noted that the above description is only a preferred embodiment of this application and is 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 can still modify the technical solutions described in the foregoing embodiments or make equivalent substitutions for some of the technical features. Any modifications, equivalent substitutions, improvements, etc., made within the spirit and principles of this application should be included within the protection scope of this application.
Claims
1. A simulation-based optimization method, system, and apparatus for gathering and transporting heavy oil mixed with water, characterized in that, include: Collect parameters of the pipeline network and equipment of the heavy oil-water blending gathering and transportation system, and conduct tests on the physical properties of the produced fluid, the quality of the blended water, and the viscosity-temperature relationship of the heavy oil-water mixture; Multiple combined operating conditions are obtained by using the temperature and water content of the heavy oil-water mixture as variables, and the minimum water addition is determined based on the multiple combined operating conditions; Based on the comparison and adjustment of the minimum water injection volume and the various combined operating conditions, multiple feasible water injection conditions that meet the wellhead back pressure boundary range and the produced fluid inlet temperature boundary range are obtained. Based on the temperature drop and pressure drop along the route of the feasible water mixing conditions, the water mixing parameters are adjusted to obtain the water mixing condition with the minimum energy consumption.
2. The optimization method according to claim 1, characterized in that, The parameters of the heavy oil blending and gathering system pipeline network and equipment include oil gathering pipeline parameters, wellhead parameters, outlet and inlet temperatures of the heating furnace, and outlet pressure of the blending pump.
3. The optimization method according to claim 1, characterized in that, The properties of the produced fluid include density, water content, gas composition, liquid phase viscosity-temperature relationship, pour point, and wax content.
4. The optimization method according to claim 1, characterized in that, The test of the viscosity-temperature relationship of the heavy oil-water mixture includes plotting the relationship between the viscosity of the heavy oil-water mixture and temperature and water content, and determining the inversion point and viscosity reduction boundary of the heavy oil-water mixture based on the relationship plot.
5. The optimization method according to claim 1, characterized in that, Before determining the minimum water addition, collect the operating parameters of the produced material, determine the wellhead back pressure boundary range, and determine the produced fluid inlet temperature boundary range.
6. The optimization method according to claim 5, characterized in that, The produced operating parameters include the produced flow rate, the produced gas-liquid ratio, the produced water content, and the environmental parameters along the oil gathering pipeline network.
7. The optimization method according to claim 5, characterized in that, The wellhead back pressure boundary range is determined according to the requirements of the upstream oil production system.
8. The optimization method according to claim 5, characterized in that, The temperature range of the produced fluid entering the station is determined based on the properties of the produced fluid and the requirements of downstream processing.
9. The optimization method according to claim 1, characterized in that, The process involves using the temperature and water content of the heavy oil-water mixture as variables to obtain multiple combined operating conditions, and determining the minimum water addition amount based on these multiple combined operating conditions, including: Multiple combinations of temperature and water content of heavy oil-water mixtures are determined based on the viscosity-temperature relationship and phase reversal point parameters. The minimum water addition amount is determined based on the water addition temperature, water addition amount, water quality, scaling trend of the oil collection pipeline, and the impact of water addition amount on the oil-water flow pattern in the oil collection pipeline for each combination of working conditions.
10. The optimization method according to claim 1, characterized in that, Based on the minimum water injection ratio comparison and adjustment of each of the combined operating conditions, multiple feasible water injection conditions are obtained that satisfy the wellhead back pressure boundary range and the produced fluid inlet temperature boundary range, including: For combined operating conditions where the water dosage is lower than the minimum water dosage, water is added according to the minimum water dosage. The hydraulic and thermal properties of the oil collecting pipeline after water addition are calculated to obtain the back pressure at the inlet and the inlet temperature at the outlet of the oil collecting pipeline. When the back pressure at the inlet of the oil gathering pipeline and the inlet temperature at the outlet are respectively within the boundary range of the wellhead back pressure and the boundary range of the produced fluid inlet temperature, the corresponding combination of working conditions is determined to be a feasible water-mixing working condition. When the back pressure at the inlet of the oil gathering pipeline is not within the wellhead back pressure boundary range, or the inlet temperature at the outlet of the oil gathering pipeline is not within the produced fluid inlet temperature boundary range, the water injection parameters for this combined working condition are adjusted according to the temperature and back pressure constraints until a feasible water injection working condition is obtained.
11. The optimization method according to claim 1, characterized in that, The process of adjusting the water injection parameters based on the temperature drop and pressure drop along the route under the feasible water injection conditions to obtain the water injection condition with minimum energy consumption includes: Based on the temperature drop and pressure drop along the line for each of the feasible water mixing conditions, the water mixing temperature and water mixing flow rate of the corresponding feasible water mixing conditions are adjusted to obtain multiple optimized water mixing conditions. Calculate and compare the energy consumption of all optimized and feasible water-incorporation conditions to determine the water-incorporation condition with the lowest energy consumption.
12. A simulation-based optimized system for gathering and transporting heavy oil mixed with water, characterized in that, include: The parameter acquisition unit is used to collect parameters of the pipeline network and equipment of the heavy oil-water blending gathering and transportation system, and to test the physical properties of the produced fluid, the quality of the blended water, and the viscosity-temperature relationship of the heavy oil-water mixture. The water addition determination unit is used to obtain multiple combined operating conditions by using the temperature and water content of the heavy oil and water mixture as variables, and to determine the minimum water addition based on the multiple combined operating conditions; The operating condition adjustment unit, based on the minimum water injection volume comparison and adjustment of each of the combined operating conditions, obtains multiple feasible water injection conditions that satisfy the wellhead back pressure boundary range and the produced fluid inlet temperature boundary range. The operating condition optimization unit adjusts the water mixing parameters based on the temperature drop and pressure drop along the route of the feasible water mixing conditions to obtain the water mixing condition with the minimum energy consumption.
13. An electronic device comprising a memory and a processor, characterized in that, The memory stores a computer program or instructions, which, when executed by the processor, are used to implement at least the method described in any one of claims 1-11.
14. A computer-readable storage medium, characterized in that, The computer-readable storage medium stores a computer program or instructions, which, when executed by a processor, are at least used to implement the method described in any one of claims 1-11.
15. A computer program product, said computer program product being stored in a computer-readable storage medium, characterized in that, When the computer program product is executed by a processor, it is used to implement at least the method described in any one of claims 1-11.