An injection and production method and system based on carbon dioxide storage in oil recovery process

Abstract

The present invention discloses a method and system for injection and production based on the amount of carbon dioxide stored during oil recovery, relating to the field of carbon dioxide recovery in low-permeability oil reservoirs. The method comprises: establishing numerical models for injection and production coupling and continuous injection and production in a five-point well pattern based on actual data from oilfields and mines; determining a target injection and production method based on injection and production process parameters obtained through simulation tests at the same carbon dioxide injection rate within a set period; determining a target injection and production half-cycle ratio and a target injection and production cycle based on injection and production process parameters obtained through simulation tests at different injection and production half-cycles within a set period using the numerical model corresponding to the target injection and production method; and determining a carbon dioxide injection rate at which the carbon dioxide storage amount is maximized based on injection and production process parameters obtained through simulation tests at the target injection and production half-cycle ratio and target injection and production cycle using the numerical model corresponding to the target injection and production method. The present invention can improve oilfield recovery efficiency.

Description

Technical Field

[0001] The present invention relates to the field of carbon dioxide recovery in low permeability oil reservoirs, and in particular to an injection and production method and system based on the amount of carbon dioxide stored in the recovery process. Background Art

[0002] CO2 geological storage is increasingly attracting attention from the oil industry, but at this stage, research on CO2 underground storage is mainly applied to saline layers, depleted oil and gas reservoirs, and deep coal seams with no commercial mining value in sedimentary basins. Simple storage causes an imbalance in the income and expenditure of investment, greatly increasing labor costs and economic expenses. Although CO2 flooding can effectively utilize CO2 and displace crude oil while allowing CO2 to be buried to a certain extent, current research on CO2 flooding is mainly based on the perspective of improving oil field recovery, ignoring the current status of CO2 underground storage, and ultimately causing the CO2 storage effect to deteriorate. Therefore, optimizing the injection and production method, increasing the CO2 storage amount, and improving the reservoir development effect are of great significance to the development of low permeability reservoirs and the realization of CO2 geological storage. The injection and production method for the maximum CO2 storage amount in the CO2 flooding process provided by the present invention optimizes the injection and production method, injection and production half-cycle ratio, injection and production cycle, and gas injection rate in the CO2 flooding process, while improving the oil field recovery degree, achieving the maximum CO2 storage, so as to achieve the goal of both economic benefits and storage effect. The practicality of the proposed injection-production method was verified by comparing the results with conventional CO2 flooding using numerical simulation techniques and actual field data. This method resolves the conflict between oil recovery and CO2 storage. This method combines accuracy and cost-effectiveness, and is intuitive and simple, making it of great significance for the development of low-permeability reservoirs and for addressing the greenhouse effect. Summary of the Invention

[0003] The purpose of the present invention is to provide an injection and production method and system based on the carbon dioxide storage volume in the oil displacement process, which can improve the oil field recovery efficiency.

[0004] To achieve the above object, the present invention provides the following solutions:

[0005] A method for injection and recovery based on the amount of carbon dioxide stored in an oil recovery process, the method comprising:

[0006] Based on actual data from oil fields and mines, numerical models for coupled injection and production using a five-point well pattern and a numerical model for continuous injection and production using a five-point well pattern were established; the actual data from the oil fields and mines included permeability, porosity, mid-layer depth, formation pressure, crude oil viscosity, rock compressibility, and reservoir temperature;

[0007] Determine a target injection-production mode based on injection-production process parameters obtained from simulation tests of the numerical model of the five-point well pattern injection-production coupling and the numerical model of the five-point well pattern continuous injection-production at the same carbon dioxide injection rate within a set period; the injection-production process parameters include airless oil production time, airless oil production degree, carbon dioxide injection rate, and carbon dioxide sweep coefficient;

[0008] Determining a target injection-production half-cycle ratio and a target injection-production cycle based on injection-production process parameters obtained by simulation tests under different injection-production half-cycles within the set cycle using a numerical model corresponding to the target injection-production mode;

[0009] The carbon dioxide injection rate when the carbon dioxide storage capacity is maximum is determined based on the injection and production process parameters obtained by simulation experiments under the target injection and production half-cycle ratio and the target injection and production cycle according to the numerical model corresponding to the target injection and production mode.

[0010] Optionally, determining the target injection-production mode based on injection-production process parameters obtained by simulation tests under the same carbon dioxide injection volume within a set period based on the numerical model of the five-point well pattern injection-production coupling and the numerical model of the five-point well pattern continuous injection-production specifically includes:

[0011] Comparing the injection-production process parameters obtained by simulation tests of the numerical model of the five-point well network injection-production coupling and the numerical model of the five-point well network continuous injection-production under the same carbon dioxide injection volume within a set period to obtain a comparison result;

[0012] According to the comparison result, the injection-production method with a long gasless oil production time, a large gasless oil production degree, and a large carbon dioxide injection amount is determined as the target injection-production method.

[0013] Optionally, determining a target injection-production half-cycle ratio and a target injection-production cycle based on injection-production process parameters obtained by simulation tests at different injection-production half-cycles within the set cycle according to a numerical model corresponding to the target injection-production mode specifically includes:

[0014] Determining a target injection-production half-cycle ratio according to injection-production process parameters obtained by simulation tests under different injection-production half-cycles within the set period using a numerical model corresponding to the target injection-production mode;

[0015] The target injection-production cycle is determined according to injection-production process parameters obtained by simulation tests of a numerical model corresponding to the target injection-production mode at the same carbon dioxide injection volume in different injection-production cycles based on the target injection-production half-cycle ratio.

[0016] Optionally, the different injection-production half-cycles within the set period are injection cycles and production cycles within the set period obtained according to different injection-production half-cycle ratios.

[0017] Optionally, the injection-production half-cycle ratio is 1:1, 1:2 or 2:1.

[0018] An injection-production system based on carbon dioxide storage during oil displacement, the system comprising:

[0019] A numerical model building module is used to build a numerical model of five-point well network injection-production coupling and a numerical model of five-point well network continuous injection-production based on actual data from the oil field; the actual data from the oil field includes permeability, porosity, mid-oil layer depth, formation pressure, crude oil viscosity, rock compressibility and reservoir temperature;

[0020] a target injection-production mode determination module, configured to determine a target injection-production mode based on injection-production process parameters obtained by simulation experiments using the numerical model of the five-point well pattern injection-production coupling and the numerical model of the five-point well pattern continuous injection-production at the same carbon dioxide injection rate within a set period; the injection-production process parameters include airless oil production time, airless oil production degree, carbon dioxide injection rate, and carbon dioxide sweep coefficient;

[0021] a target injection-production cycle determination module, configured to determine a target injection-production half-cycle ratio and a target injection-production cycle based on injection-production process parameters obtained by simulation experiments under different injection-production half-cycles within the set cycle using a numerical model corresponding to the target injection-production mode;

[0022] The injection rate determination module is used to determine the carbon dioxide injection rate when the carbon dioxide storage capacity is maximum based on the injection and production process parameters obtained by simulation experiments under the target injection and production half-cycle ratio and the target injection and production cycle using a numerical model corresponding to the target injection and production method.

[0023] An electronic device includes a memory and a processor, wherein the memory is used to store a computer program, and the processor runs the computer program to enable the electronic device to perform the above-mentioned injection and production method based on the carbon dioxide storage amount in the oil recovery process.

[0024] A computer-readable storage medium stores a computer program, which, when executed by a processor, implements the above-mentioned injection and production method based on the amount of carbon dioxide stored in the oil recovery process.

[0025] According to the specific embodiments provided by the present invention, the present invention discloses the following technical effects:

[0026] The present invention provides a method for injection and production based on the amount of carbon dioxide stored in an oil recovery process. The method comprises: establishing a numerical model for injection and production coupling of a five-point well network and a numerical model for continuous injection and production of a five-point well network based on actual data from an oilfield; the actual data from the oilfield including permeability, porosity, mid-oil layer depth, formation pressure, crude oil viscosity, rock compressibility, and reservoir temperature; determining a target injection and production mode based on injection and production process parameters obtained by simulation tests of the numerical model for injection and production coupling of the five-point well network and the numerical model for continuous injection and production of the five-point well network at the same carbon dioxide injection rate within a set period; the injection and production process parameters including airless oil production time, airless production degree, carbon dioxide injection rate, and carbon dioxide sweep coefficient; determining a target injection and production half-cycle ratio and a target injection and production cycle based on injection and production process parameters obtained by simulation tests of the numerical model corresponding to the target injection and production mode at different injection and production half-cycles within a set period; and determining a carbon dioxide injection rate at which the carbon dioxide storage amount is maximized based on injection and production process parameters obtained by simulation tests of the numerical model corresponding to the target injection and production mode at the target injection and production half-cycle ratio and target injection and production cycle. The present invention improves the oil field recovery rate by determining the maximum CO2 storage amount during the CO2 flooding process in a low permeability oil reservoir, thereby achieving the purpose of CO2 storage. BRIEF DESCRIPTION OF THE DRAWINGS

[0027] In order to more clearly illustrate the embodiments of the present invention or the technical solutions in the prior art, the following briefly introduces the drawings required for use in the embodiments. Obviously, the drawings described below are only some embodiments of the present invention. For ordinary technicians in this field, other drawings can be obtained based on these drawings without paying any creative work.

[0028] Figure 1 This is a flow chart of the injection-production method based on the amount of carbon dioxide stored in the oil recovery process of the present invention;

[0029] Figure 2 A schematic diagram of a five-point well pattern homogenization model provided in an embodiment of the present invention;

[0030] Figure 3 Crude oil flow diagrams for different development modes provided by the embodiments of the present invention; (a) is a crude oil flow diagram for coupled injection and production, and (b) is a crude oil flow diagram for continuous injection and production;

[0031] Figure 4 Schematic diagrams of the degree of gasless production and the gas-oil ratio for different injection and production half-cycles for an injection and production cycle of 120 days provided in an embodiment of the present invention; wherein (a) is a schematic diagram of the degree of gasless production and the gas-oil ratio for an injection and production cycle ratio of 1:2, (b) is a schematic diagram of the degree of gasless production and the gas-oil ratio for an injection and production cycle ratio of 1:1, and (c) is a schematic diagram of the degree of gasless production and the gas-oil ratio for an injection and production cycle ratio of 2:1;

[0032] Figure 5 Schematic diagrams of recovery degree and gas-oil ratio for different injection-production half-cycle ratios (180 days and 240 days) provided by an embodiment of the present invention; (a) is a schematic diagram of recovery degree and gas-oil ratio for an injection-production cycle of 180 days, and (b) is a schematic diagram of recovery degree and gas-oil ratio for an injection-production cycle of 240 days;

[0033] Figure 6 Schematic diagram of the degree of recovery and sweep coefficient of gasless oil production at different injection rates under the optimal injection-production cycle and injection-production cycle ratio provided by an embodiment of the present invention;

[0034] Figure 7 This is a module diagram of the injection and production system based on the carbon dioxide storage volume during the oil recovery process of the present invention.

[0035] Explanation of symbols:

[0036] Numerical model establishment module - 1, target injection and production method determination module - 2, target injection and production cycle determination module - 3, gas injection rate determination module - 4. DETAILED DESCRIPTION

[0037] The following will clearly and completely describe the technical solutions in the embodiments of the present invention in conjunction with the accompanying drawings. Obviously, the described embodiments are only part of the embodiments of the present invention, not all of the embodiments. Based on the embodiments of the present invention, all other embodiments obtained by ordinary technicians in this field without making creative efforts are within the scope of protection of the present invention.

[0038] The purpose of the present invention is to provide an injection and production method and system based on the carbon dioxide storage volume in the oil displacement process, which can improve the oil field recovery efficiency.

[0039] In order to make the above-mentioned objects, features and advantages of the present invention more obvious and easy to understand, the present invention is further described in detail below with reference to the accompanying drawings and specific embodiments.

[0040] Example 1

[0041] like Figure 1 As shown, the present invention provides an injection and production method based on the amount of carbon dioxide stored in the oil recovery process, the method comprising:

[0042] Step S1: Based on actual data from the oil field, a numerical model of five-point well network injection and production coupling and a numerical model of five-point well network continuous injection and production are established; the actual data from the oil field include permeability, porosity, mid-oil layer depth, formation pressure, crude oil viscosity, rock compressibility and reservoir temperature.

[0043] As an implementation method, a numerical simulation method is applied to establish a numerical model of injection-production coupling of a five-point well network and a numerical model of continuous injection-production of a five-point well network. The model parameters are shown in Table 1.

[0044] Table 1 Model parameters

[0045] Permeability (mD) 6 Porosity (%) 14 Depth of middle oil layer (m) 3000 Formation pressure (MPa) 35 Crude oil viscosity (mP.S) 2 Rock compressibility (1 / MPa) 0.00003 Reservoir temperature (℃) 86.6

[0046] The minimum miscible pressure range of the model is 28.7 MPa, the number of grids is 41×41×1, the grid step size is 10 m, and the injection and production well spacing is 262 m.

[0047] Step S2: Determine a target injection-production method based on injection-production process parameters obtained by simulation tests using the numerical model of the five-point well pattern injection-production coupling and the numerical model of the five-point well pattern continuous injection-production at the same carbon dioxide injection rate within a set period; the injection-production process parameters include gasless oil production time, gasless production degree, carbon dioxide injection rate, and carbon dioxide sweep coefficient.

[0048] As an implementation method, the injection-production coupling numerical model and the continuous injection-production numerical model established in step S1 are used to compare and analyze the gasless oil production time, CO2 injection volume before gas is seen, gasless production degree and sweep coefficient under the two production methods while ensuring that the gas injection volume within the two injection-production cycles is equal. An oil recovery method with the longest gasless oil production time, the most CO2 injection and the greatest production degree is selected as the target injection-production method.

[0049] S2 specifically includes:

[0050] Step S21: comparing the injection-production process parameters obtained by simulation tests of the numerical model of the five-point well pattern injection-production coupling and the numerical model of the five-point well pattern continuous injection-production under the same carbon dioxide injection volume within a set period to obtain a comparison result.

[0051] Step S22: According to the comparison result, the injection-production mode with a long gasless oil production time, a large gasless oil production degree, and a large carbon dioxide injection amount is determined as the target injection-production mode.

[0052] As an implementation method, injection-production coupling is to inject gas first and then produce; in order to make the injection-production coupling the same as the gas injection volume in the continuous injection-production cycle, the gas injection volume must be twice that of the continuous injection-production when injecting gas during injection-production coupling, because there is no gas injection in the second half of the injection-production coupling cycle. The gas channeling stage is divided into: gasless oil production stage, initial gas stage, gas channeling development stage and complete gas channeling stage. The gasless production degree is the ratio of the cumulative oil production of the production well when it only produces oil but not gas during the gasless oil production stage to the total amount of crude oil in the formation. The injection-production coupling numerical model established by step S1 sets the injection-production coupling cycle to 120 days, that is, 60 days of gas injection and 60 days of production, and the daily injection volume per day during the gas injection period is 3000m3 , and continue until the production well begins to produce gas; to ensure that the gas injection volume is equal within the cycle, the daily injection volume for continuous injection and production is 1500m 3 , compare the gasless oil production time, gasless production degree, CO2 injection volume and sweep coefficient when continuous injection and production sees gas, and select an injection and production method with a higher gasless production degree, a later gas appearance time and the largest CO2 injection volume as the target injection and production method.

[0053] Step S3: Determining a target injection-production half-cycle ratio and a target injection-production cycle based on injection-production process parameters obtained by simulation tests at different injection-production half-cycles within the set period using a numerical model corresponding to the target injection-production mode; wherein the different injection-production half-cycles within the set period are injection cycles and production cycles within the set period obtained based on different injection-production half-cycle ratios. The injection-production half-cycle ratio is 1:1, 1:2, or 2:1.

[0054] As one embodiment, using the target injection-production method selected in step S2, the gasless oil production time, gasless oil recovery degree, and CO2 storage capacity of different injection-production half-cycles within the total injection-production cycle of 120 days are analyzed to select the optimal injection-production half-cycle ratio. This optimal injection-production half-cycle ratio is then applied to different total injection-production cycles, and the optimal injection-production half-cycle ratio is optimized for the entire cycle; specifically, the cycle is set to 120 days.

[0055] S3 specifically includes:

[0056] Step S31: determining a target injection-production half-cycle ratio according to injection-production process parameters obtained by simulation tests of a numerical model corresponding to the target injection-production mode at different injection-production half-cycles within the set cycle.

[0057] Specifically, different injection-production cycle ratios (1:1, 1:2 and 2:1) were changed, and the gasless production degree, gasless oil production time, CO2 injection volume and sweep coefficient under different injection-production cycle ratios of injection-production coupling were compared. The injection-production half-cycle ratio with the highest gasless production degree and the most CO2 injection was selected as the target injection-production half-cycle ratio.

[0058] Step S32: Determine the target injection-production cycle according to the injection-production process parameters obtained by simulation tests of the numerical model corresponding to the target injection-production mode at the same carbon dioxide injection volume in different injection-production cycles based on the target injection-production half-cycle ratio.

[0059] Specifically, while keeping the total injection volume within a single cycle unchanged (the longer the gas injection cycle, the smaller the daily injection volume and the greater the daily oil production), the optimal injection-production half-cycle ratio is substituted into different cycles (120 days, 180 days and 240 days). Then, by analyzing and comparing the CO2 injection volume, gasless production degree and sweep coefficient, the optimal production cycle is selected as the target injection-production cycle.

[0060] Step S4: Determine the carbon dioxide injection rate when the carbon dioxide storage capacity is maximum based on the injection and production process parameters obtained by simulation experiments under the target injection and production half-cycle ratio and the target injection and production cycle using the numerical model corresponding to the target injection and production mode.

[0061] As an implementation method, the target injection-production cycle and target injection-production cycle ratio selected in step S3 are set as the cyclic production cycle of the numerical model corresponding to the target injection-production method. By controlling the variable principle, the injection rate of carbon dioxide is changed, and a numerical model corresponding to the target injection-production method is established. While ensuring that only the injection rate changes, the effects of different injection rates on the gasless oil production time, gasless production degree, sweep coefficient and CO2 injection amount of the numerical model are analyzed, and an injection rate that is most suitable for the target oil reservoir is determined, that is, the carbon dioxide injection rate, so that this rate can not only help delay the gas appearance time of the oil reservoir, but also keep the gasless production degree of the oil reservoir within an efficient and reasonable range, and achieve maximum CO2 storage.

[0062] In practical application, firstly, according to the low permeability reservoir data as shown in Table 1, a five-point well pattern injection-production coupling and continuous injection-production numerical model is established, as shown in Figure 2 The modeling parameters are shown in Table 1. Based on the established injection-production coupling model, the injection-production cycle was set to 120 days and the injection-production half-cycle was set to 60 days. The numerical model was driven until gas began to appear. The gasless oil production time, gasless recovery degree, CO2 injection volume, and CO2 sweep coefficient of the injection-production coupling and continuous injection-production were recorded. Through comparative analysis, a production method that can both improve the recovery degree of low-permeability reservoirs and achieve maximum CO2 storage was selected, as shown in Table 2.

[0063] Table 2 Statistics of different production methods of five-point well network

[0064]

[0065]

[0066] Table 2 shows that the injection-production coupling development method can significantly improve the gas-free recovery of low permeability reservoirs. Figure 3 It can be seen that injection-production coupled with periodic production can effectively expand the CO2 sweep coefficient, delay the time of gas emergence, and increase the underground storage of CO2.

[0067] Based on the optimized injection-production coupling development mode, the injection-production cycle ratio of the injection-production coupling is changed to achieve the goals of short injection and long production, balanced injection and production, and long injection and short production. The gasless oil production time, gasless production degree, CO2 cumulative injection volume and sweep coefficient charts with different injection-production cycle ratios are obtained, as shown in Figure 2. Figure 4 The detailed data are shown in Table 3.

[0068] Table 3 Statistical table of data characterization results of different injection-production half-cycle ratios of five-point well network

[0069]

[0070] according to Figure 4 It can be seen that before gas is generated, the gas-oil ratio remains constant, and the recovery curve shows an upward trend. After gas is generated, the gas-oil ratio begins to increase rapidly, and the upward trend in recovery slows. The results of optimizing the injection-production half-cycle for a 120-day period show that the gasless production time, recovery degree, and sweep coefficient for an unbalanced injection-production cycle are all greater than those for a balanced one, but the CO2 injection rate for short injection and long production is much lower than that for a balanced injection-production cycle. When the injection-production half-cycle is 2:1 (long injection and short production), the gasless production degree is maximized, the gasless production time is longest, and the cumulative CO2 injection rate is also the largest. This is consistent with the goal of improving recovery in low-permeability reservoirs while simultaneously achieving maximum CO2 storage, achieving both efficiency and storage benefits.

[0071] In order to further select the optimal injection-production cycle, the control variable method was used, keeping other model parameters unchanged, and the injection-production cycle was changed to 180 days and 240 days respectively. The gasless oil production time, gasless production degree, CO2 injection volume and sweep coefficient of different cycles (120d, 180d and 240d) with the same injection-production half-cycle ratio (2:1) were compared. Figure 5 By comparing various data, the optimal production cycle is selected, as shown in Table 4.

[0072] Table 4 Statistical table of characterization results of the same injection-production half-cycle ratio data of the five-point method well network

[0073]

[0074] From the data characterization results of the five-point method well network with the same injection-production half-cycle ratio (2:1), it can be analyzed that: when the total injection volume in a single cycle remains unchanged (240000m 3 ), the longer the injection cycle, the smaller the daily injection volume and the lower the daily oil production. Although the gasless oil production time increases with the injection-production cycle, the gasless recovery degree and sweep coefficient decrease with the injection-production cycle. The cumulative CO2 injection volume and gasless recovery degree do not reach a reasonable match. Moreover, the longer the injection-production cycle, the greater the gap between the final investment and benefits. A comprehensive analysis combining the CO2 storage effect and reservoir development effect shows that a 120-day injection-production coupling injection-production cycle can effectively increase the gasless recovery degree and expand the CO2 sweep coefficient while achieving efficient CO2 storage.

[0075] The optimal injection-production half-cycle ratio of 2:1 and the optimal injection-production cycle of 120 days were set as model parameters. The injection rate was changed and the effects of different injection rates on the development effect of low permeability reservoirs and CO2 injection volume were compared. A reasonable injection rate was optimized to provide reference opinions for oilfield production, as shown in Table 5 and Figure 6 shown.

[0076] Table 5 Statistical table of characterization results of different gas injection rates of five-point well pattern

[0077]

[0078] When the gas injection velocity is less than 8000m 3 With the increase of gas injection rate, the gasless production degree and sweep coefficient of the five-point well pattern increase, and the cumulative CO2 injection volume increases significantly; when the gas injection rate is greater than 8000m 3 As the injection rate increases, the degree of gasless production and the sweep coefficient begin to decrease, the time to see gas is advanced with the increase of injection rate, and the cumulative injection volume of CO2 also gradually decreases. The injection rate is not the higher the better. Too high a rate will increase production costs and cause gas channeling in advance, which is not conducive to the storage of CO2. Therefore, 8000m3 / day is recommended. 3 It will not cause too high production costs, but can greatly improve the degree of gas-free production and increase the storage capacity of CO2.

[0079] Furthermore, the injection and production method for maximizing the CO2 storage capacity during CO2 flooding in low-permeability reservoirs provided by the present invention was applied to the 89-11 area of ​​the Gao 89 block reservoir in the Shengli Zhenglizhuang Oilfield. This reservoir is located in the middle of the Jinjia-Zhenglizhuang-Fanjia nose-shaped structural belt in the Boxing sag of the Dongying Depression. The reservoir is buried at a depth of 3,000 meters, and the reservoir lithology is dense. It is a low-porosity and ultra-low-permeability reservoir with an average porosity of 13.9%, a permeability of 0.43mD to 7.2mD, and a formation crude oil viscosity of 1.89mPa·s. Based on field monitoring data from the Gao 89-11 well block in the Zhenglizhuang Oilfield, the corresponding oil and gas wells in this block utilize an intermittent injection-production coupled production method. Gas wells are opened while oil wells are shut down, and vice versa. The production cycle for production wells is 20 days, and the injection cycle for gas wells is 10 days. After two cycles, production in the Gao 89-11 well block began to slowly recover, rising from 1.3 tons before the shutdown to 2.4 tons after the shutdown, indicating the restoration of formation energy. A too low CO2 injection rate makes it difficult to restore formation pressure; a too high rate exacerbates gas channeling, impacting oil recovery efficiency. Numerical simulations show that the optimal gas injection rate for the Gao 89-11 well block is 8,000 m3 / d. The coupled injection-production development method of long-injection, short-production, and the dynamic control of the target reservoir using a reasonable injection rate, as provided by the present invention, has been shown to effectively delay gas channeling, significantly increasing CO2 underground storage before gas is observed, and increasing oil production by an average of 0.8 tons per well, a significant effect.

[0080] Example 2

[0081] In order to execute the method corresponding to the above embodiment 1 and achieve the corresponding functions and technical effects, the following provides an injection and production system based on the carbon dioxide storage volume in the oil recovery process, such as Figure 7 As shown, the system includes:

[0082] Numerical model building module 1 is used to establish a numerical model of five-point well network injection and production coupling and a numerical model of five-point well network continuous injection and production based on actual data of the oil field; the actual data of the oil field includes permeability, porosity, mid-depth of the oil layer, formation pressure, crude oil viscosity, rock compressibility and reservoir temperature.

[0083] The target injection and production mode determination module 2 is used to determine the target injection and production mode based on the injection and production process parameters obtained by simulation experiments under the same carbon dioxide injection volume within a set period based on the numerical model of the five-point well network injection and production coupling and the numerical model of the five-point well network continuous injection and production; the injection and production process parameters include the gasless oil production time, the gasless production degree, the carbon dioxide injection volume and the carbon dioxide sweep coefficient.

[0084] The target injection-production cycle determination module 3 is used to determine the target injection-production half-cycle ratio and the target injection-production cycle according to the injection-production process parameters obtained by simulation experiments under different injection-production half-cycles within the set cycle using the numerical model corresponding to the target injection-production method.

[0085] The injection rate determination module 4 is used to determine the carbon dioxide injection rate when the carbon dioxide storage capacity is maximum based on the injection and production process parameters obtained by simulation experiments under the target injection and production half-cycle ratio and the target injection and production cycle according to the numerical model corresponding to the target injection and production method.

[0086] Example 3

[0087] An embodiment of the present invention provides an electronic device including a memory and a processor, wherein the memory is used to store a computer program, and the processor runs the computer program to enable the electronic device to execute the injection and production method based on the carbon dioxide storage amount in the oil recovery process of embodiment 1.

[0088] Optionally, the above-mentioned electronic device may be a server.

[0089] In addition, an embodiment of the present invention further provides a computer-readable storage medium storing a computer program. When the computer program is executed by a processor, the injection and production method based on the carbon dioxide storage volume in the oil recovery process of embodiment 1 is implemented.

[0090] The various embodiments in this specification are described in a progressive manner, with each embodiment focusing on the differences from other embodiments. Reference can be made to the common and similar parts between the various embodiments. For the systems disclosed in the embodiments, since they correspond to the methods disclosed in the embodiments, the description is relatively simple, and the relevant parts can be referred to the method description.

[0091] This document uses specific examples to illustrate the principles and implementation methods of the present invention. The above examples are only intended to help understand the method and core concept of the present invention. At the same time, those skilled in the art will find that the specific implementation methods and application scopes may vary based on the concept of the present invention. In summary, the contents of this specification should not be construed as limiting the present invention.

Claims

1. A method for injection and production of carbon dioxide based on the amount of carbon dioxide stored in the oil recovery process, characterized in that: The method comprises: Based on actual data from oil fields and mines, numerical models for coupled injection and production using a five-point well pattern and a numerical model for continuous injection and production using a five-point well pattern were established; the actual data from the oil fields and mines included permeability, porosity, mid-layer depth, formation pressure, crude oil viscosity, rock compressibility, and reservoir temperature; Determining a target injection-production method based on injection-production process parameters obtained by simulation tests of the numerical model of the five-point well network injection-production coupling and the numerical model of the five-point well network continuous injection-production under the same carbon dioxide injection volume within a set period, specifically comprising: comparing the injection-production process parameters obtained by simulation tests of the numerical model of the five-point well network injection-production coupling and the numerical model of the five-point well network continuous injection-production under the same carbon dioxide injection volume within a set period to obtain a comparison result; determining, based on the comparison result, an injection-production method with a long airless production time, a large airless production degree, and a large carbon dioxide injection volume as the target injection-production method; the injection-production process parameters include the airless production time, the airless production degree, the carbon dioxide injection volume, and the carbon dioxide sweep coefficient; Determining a target injection-production half-cycle ratio and a target injection-production cycle according to injection-production process parameters obtained by simulation tests at different injection-production half-cycles within the set cycle using a numerical model corresponding to the target injection-production method, specifically comprising: determining the target injection-production half-cycle ratio according to injection-production process parameters obtained by simulation tests at different injection-production half-cycles within the set cycle using a numerical model corresponding to the target injection-production method; determining the target injection-production cycle according to injection-production process parameters obtained by simulation tests at the same carbon dioxide injection volume within different injection-production cycles based on the target injection-production half-cycle ratio using the numerical model corresponding to the target injection-production method; The carbon dioxide injection rate when the carbon dioxide storage capacity is maximum is determined based on the injection and production process parameters obtained by simulation experiments under the target injection and production half-cycle ratio and the target injection and production cycle according to the numerical model corresponding to the target injection and production mode.

2. The injection-production method based on the carbon dioxide storage amount in the oil displacement process according to claim 1, characterized in that: The different injection-production half-cycles within the set period are injection cycles and production cycles within the set period obtained according to different injection-production half-cycle ratios.

3. The injection-production method based on the amount of carbon dioxide stored in the oil displacement process according to claim 2, characterized in that: The injection-production half-cycle ratio is 1:1, 1:2 or 2:

1.

4. An injection and production system based on the amount of carbon dioxide stored in the oil recovery process, characterized in that: The system comprises: A numerical model building module is used to build a numerical model of five-point well network injection-production coupling and a numerical model of five-point well network continuous injection-production based on actual data from the oil field; the actual data from the oil field includes permeability, porosity, mid-oil layer depth, formation pressure, crude oil viscosity, rock compressibility and reservoir temperature; a target injection and production mode determination module, configured to determine a target injection and production mode based on injection and production process parameters obtained by simulation tests of the numerical model of the five-point well network injection and production coupling and the numerical model of the five-point well network continuous injection and production under the same carbon dioxide injection volume within a set period, specifically comprising: comparing the injection and production process parameters obtained by simulation tests of the numerical model of the five-point well network injection and production coupling and the numerical model of the five-point well network continuous injection and production under the same carbon dioxide injection volume within a set period to obtain a comparison result; determining, based on the comparison result, an injection and production mode with a long airless production time, a large airless production degree, and a large carbon dioxide injection volume as the target injection and production mode; the injection and production process parameters include the airless production time, the airless production degree, the carbon dioxide injection volume, and the carbon dioxide sweep coefficient; a target injection-production cycle determination module, configured to determine a target injection-production half-cycle ratio and a target injection-production cycle based on injection-production process parameters obtained by simulation tests at different injection-production half-cycles within the set cycle using a numerical model corresponding to the target injection-production method, specifically comprising: determining the target injection-production half-cycle ratio based on injection-production process parameters obtained by simulation tests at different injection-production half-cycles within the set cycle using the numerical model corresponding to the target injection-production method; and determining the target injection-production cycle based on injection-production process parameters obtained by simulation tests at the same carbon dioxide injection volume within different injection-production cycles based on the target injection-production half-cycle ratio using the numerical model corresponding to the target injection-production method; The injection rate determination module is used to determine the carbon dioxide injection rate when the carbon dioxide storage capacity is maximum based on the injection and production process parameters obtained by simulation experiments under the target injection and production half-cycle ratio and the target injection and production cycle using a numerical model corresponding to the target injection and production method.

5. An electronic device, characterized in that: The electronic device comprises a memory and a processor, wherein the memory is used to store a computer program, and the processor runs the computer program to enable the electronic device to perform the injection and production method based on the carbon dioxide storage amount in the oil recovery process according to any one of claims 1 to 3.

6. A computer-readable storage medium, characterized in that It stores a computer program, which, when executed by a processor, implements the injection and production method based on the carbon dioxide storage amount in the oil recovery process as described in any one of claims 1 to 3.

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