Efficient development method for gas well

Abstract

The application provides a gas well efficient development method, which comprises the following steps: collecting and analyzing reservoir data, establishing a three-dimensional geological model according to the reservoir data and analysis results, wherein the three-dimensional geological model is used to show the spatial distribution of the reservoir; performing fracturing simulation and fracture propagation analysis by using the three-dimensional geological model to obtain fracture simulation data; performing carbon dioxide injection and displacement simulation by using the three-dimensional geological model and the fracture simulation data to obtain displacement simulation data; and determining a well pattern layout according to the fracture simulation data and the displacement simulation data. By using the application, the well pattern layout can be optimized, the recovery rate can be improved, the gas well production stability can be improved, and the gas well production cycle can be prolonged.

Description

Technical Field

[0001] This invention relates to the field of natural gas development technology, and specifically to a method for efficient gas well development. Background Technology

[0002] Natural gas is a widely distributed natural gas resource, with tight gas and shale gas being particularly prevalent and considered important alternative energy sources with enormous reserve potential. However, due to the unique characteristics of tight gas and shale gas reservoirs—low permeability and low porosity resulting in poor gas flowability—development is challenging. Currently, the primary development method employs horizontal well staged fracturing technology. This involves performing staged hydraulic fracturing in the horizontal wellbore to force fractures into the reservoir rock, creating an artificial fracture network to improve reservoir permeability and gas flowability.

[0003] However, traditional fracturing technology has the following limitations in practice:

[0004] (1) Low recovery rate: Some gases in the reservoir exist in the form of adsorbed gases, especially shale gas, which can account for up to 80%. Traditional fracturing technology is difficult to effectively utilize these adsorbed gases and mainly recovers free gas in the reservoir. This leads to a waste of reservoir resources, especially in low-permeability and deep reservoirs, where the amount of unused adsorbed gas is considerable, affecting the overall recovery rate.

[0005] (2) Uneven reservoir utilization: During fracturing, the extent of fracture expansion is limited, especially in low-permeability reservoirs, where fractures cannot effectively cover the entire reservoir. This uneven utilization results in low overall efficiency of the gas well, and after fracturing, gas in some areas is not effectively utilized, leading to fluctuations in production.

[0006] (3) Short production cycle: Although the initial production of a fracturing gas well is high, the fractures will gradually close over time, and the reservoir pressure will also decrease. Ultimately, the production will drop sharply, the production cycle of the gas well will be shortened, and the economic benefits will be poor. In addition, the closure of the fractures and the decrease in reservoir pressure will make gas flow more difficult in the later stages. Summary of the Invention

[0007] This invention provides a method for efficient gas well development to address some limitations of existing technologies in gas well production, particularly in terms of recovery rate, production cycle, and reservoir utilization efficiency.

[0008] Therefore, the present invention provides the following technical solution:

[0009] A method for efficient development of gas wells, the method comprising:

[0010] Collect and analyze reservoir data, and establish a three-dimensional geological model based on the reservoir data and analysis results. The three-dimensional geological model is used to show the spatial distribution of the reservoir.

[0011] The three-dimensional geological model was used to perform hydraulic fracturing simulation and fracture propagation analysis to obtain fracture simulation data.

[0012] Using the three-dimensional geological model and the fracture simulation data, carbon dioxide injection and displacement simulations were performed to obtain displacement simulation data;

[0013] The well pattern layout is determined based on the fracture simulation data and the displacement simulation data.

[0014] Optionally, the reservoir data includes any one or more of the following: seismic wave data, core analysis data, gas composition data, and pressure and temperature data;

[0015] Collecting reservoir data includes:

[0016] Seismic wave data of reservoirs are obtained through seismic exploration;

[0017] Core analysis can be used to obtain reservoir porosity, permeability, and lithological characteristics, or nuclear magnetic resonance analysis and CT scanning techniques can be used to obtain pore structure, pore distribution, and fracture network characteristics.

[0018] The composition information of various gases in the reservoir is obtained through gas composition testing;

[0019] Reservoir pressure and temperature gradients are obtained through engineering techniques.

[0020] Optionally, the analyzed reservoir data includes:

[0021] Based on the reservoir data, reservoir heterogeneity analysis is performed;

[0022] Based on the analysis results, a preliminary reservoir profile is constructed to show the characteristic parameters of each layer. The characteristic parameters include any one or more of the following: thickness, permeability, and porosity.

[0023] Optionally, the method further includes: calibrating the three-dimensional geological model by comparing actual production data from different regions.

[0024] Optionally, the step of using the three-dimensional geological model to perform fracturing simulation and fracture propagation analysis to obtain fracture simulation data includes: based on the well data in the three-dimensional geological model, using fracturing simulation software, inputting reservoir physical property data and fracturing parameters, simulating the fracture propagation process, and obtaining fracture simulation data.

[0025] Optionally, the step of using the three-dimensional geological model to perform hydraulic fracturing simulation and fracture propagation analysis to obtain fracture simulation data further includes:

[0026] A finite element model was established, and the finite element analysis method was used to perform hydraulic fracturing simulation and fracture propagation analysis to obtain auxiliary simulation data.

[0027] The crack simulation data is corrected using the auxiliary simulation data.

[0028] Optionally, the method further includes: evaluating the carbon dioxide displacement effect based on simulation results of carbon dioxide injection and displacement with different injection parameters; the injection parameters include: injection rate, injection pressure, and injection time.

[0029] Optionally, the evaluation of carbon dioxide displacement effect includes any one or more of the following:

[0030] The extent to which carbon dioxide can substitute for natural gas is assessed by simulating the flow path of carbon dioxide in the reservoir.

[0031] Calculate the substitution efficiency of carbon dioxide and natural gas, and evaluate the displacement effect of injected carbon dioxide under different reservoir conditions;

[0032] Assess the trend of reservoir pressure changes after simulated carbon dioxide injection.

[0033] Optionally, the method further includes: using numerical simulation tools to verify different well network layout schemes in multiple scenarios during the well network layout optimization process.

[0034] Optionally, the method further includes: during on-site implementation, real-time monitoring and adjustment of on-site operating parameters, and dynamic adjustment of key parameters; the on-site operating parameters include any one or more of the following: gas flow rate, gas composition, reservoir pressure, and carbon dioxide concentration; the key parameters include any one or more of the following: gas injection rate, gas production rate, and well network layout parameters.

[0035] A computer-readable storage medium having a computer program stored thereon, the computer program being executed by a processor to perform the steps of the gas well efficient development method.

[0036] The efficient gas well development method provided by this invention has the following beneficial effects:

[0037] (1) Improve gas well recovery rate: By rationally designing the multi-layer well network layout, the carbon dioxide displacement technology is combined with the horizontal well segmented fracturing technology. While improving reservoir permeability, the adsorbed gas in the gas well is effectively utilized by the carbon dioxide displacement effect, thereby significantly improving the gas well recovery rate and reducing the waste of reservoir resources.

[0038] (2) Extending the production cycle: By rationally designing well spacing, gas injection rate, and gas production strategy, and combining carbon dioxide displacement and fracturing technology, the rate of gas well production decline can be effectively reduced. Carbon dioxide injection can not only increase reservoir pressure and prevent premature fracture closure, but also promote the release of more adsorbed gas, thereby extending the production cycle of gas wells and improving the long-term production and economic benefits of gas wells.

[0039] (3) Optimize gas displacement effect: Utilize the high density characteristics of carbon dioxide to improve gas displacement efficiency and reduce gas migration and fracture sealing problems in the reservoir.

[0040] (4) Enhancing reservoir pressure balance: Optimizing the fracture propagation range through multi-layer well network layout allows fractures to more evenly cover the entire reservoir, improving reservoir utilization efficiency. Injecting carbon dioxide increases reservoir pressure, promoting a more even flow of gas to production wells and optimizing the gas well extraction process. Attached Figure Description

[0041] To more clearly illustrate the technical solutions in the embodiments of the present invention or the prior art, the drawings used in the embodiments will be briefly described below. Obviously, the drawings described below are merely some embodiments of the present invention, and those skilled in the art can obtain other drawings based on these drawings without creative effort.

[0042] Figure 1 This is a flowchart of a gas well efficient development method provided in an embodiment of the present invention. Detailed Implementation

[0043] 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.

[0044] To enable those skilled in the art to better understand the present invention, the technical solutions of the present invention will be clearly and completely described below with reference to the accompanying drawings of the embodiments of the present invention. Obviously, the described embodiments are only some embodiments of the present invention, and not all embodiments. Based on the embodiments of the present invention, all other embodiments obtained by those skilled in the art without creative effort should fall within the scope of protection of the present invention.

[0045] To address the shortcomings in existing gas well development, this invention provides a method for efficient gas well development. This method combines multi-layer well network layout with carbon dioxide displacement and fracturing technologies, collects and analyzes reservoir data, establishes a three-dimensional geological model based on the reservoir data and analysis results, uses the three-dimensional geological model to perform fracturing and carbon dioxide injection simulations, and determines the well network layout based on the simulation data.

[0046] like Figure 1 The diagram shown is a flowchart of a gas well efficient development method provided by an embodiment of the present invention, including the following steps:

[0047] Step 101: Collect and analyze reservoir data, and establish a three-dimensional geological model based on the reservoir data and analysis results. The three-dimensional geological model is used to display the spatial distribution of the reservoir.

[0048] The reservoir data may include, but is not limited to, any one or more of the following: seismic wave data, core analysis data, gas composition data, pressure and temperature data, etc. The seismic wave data is used to analyze geological structure, interlayer distribution, and fracture information.

[0049] The specific methods for obtaining the above data are as follows:

[0050] (1) Seismic wave data: can be obtained through seismic exploration, such as using three-dimensional seismic exploration technology to obtain structural information of reservoirs; determine the location of layer interfaces by seismic reflection intensity; convert seismic time profiles into depth profiles to provide information on reservoir burial depth and layer thickness; determine reservoir burial depth (e.g., in the range of 1000 to 3000 meters), fault location and dip angle.

[0051] (2) Core analysis data: Porosity, permeability and lithological characteristics of the reservoir are obtained through core analysis (e.g., using full-diameter core testing method); or the pore structure and pore distribution are analyzed by nuclear magnetic resonance to clarify the characteristics of reservoir flow channels, and the fracture network characteristics, including fracture width (e.g., 1-3 mm) and fracture extension length are analyzed by CT scanning technology.

[0052] (3) Gas composition data: Obtain information on the composition of various gases in the reservoir through gas composition testing (such as gas chromatography), such as detecting the content of gas components such as methane, ethane, and propane.

[0053] (4) Pressure and temperature data: Use existing engineering techniques to obtain reservoir pressure gradient and temperature gradient, such as pressure logging and temperature logging to obtain pressure and temperature distribution.

[0054] Based on the reservoir data, reservoir heterogeneity analysis is performed, mainly including but not limited to: analyzing the spatial differences in reservoir permeability and porosity to provide a basis for subsequent stratified fracturing and well pattern layout; measuring the permeability of different layers, analyzing the pore size distribution, calculating the effective porosity of the reservoir, analyzing the distribution and connectivity of natural fractures in the reservoir, and determining whether natural fractures penetrate the main gas-producing areas of the reservoir. Based on the analysis results, a preliminary reservoir profile is constructed, displaying the characteristic parameters of each layer, which include, but are not limited to, any one or more of the following: thickness, permeability, porosity, etc.

[0055] For example, the following is an example of a preliminary reservoir profile, including upper, middle, and lower layers:

[0056] Upper layer: 30m thick, permeability 0.03mD, porosity 8%, mainly composed of adsorbed gas.

[0057] Middle layer: 50m thick, 0.05mD permeability, 12% porosity, with both free and adsorbed gases present.

[0058] Lower layer: 40m thick, permeability 0.01mD, porosity 10%, mainly composed of free gas.

[0059] Based on the collected reservoir data, existing geological modeling tools (such as Petrel and Jewelsuit) can be used to construct three-dimensional reservoir models, providing a foundation for subsequent fracturing simulation and optimization design. Input parameters during modeling can include information such as reservoir thickness, fault location, permeability, porosity, and gas content. Using the three-dimensional reservoir model, sequence stratigraphy can be completed; specifically, different reservoir segments can be divided according to reservoir characteristics, demonstrating the spatial distribution of the reservoir.

[0060] In some embodiments, the three-dimensional reservoir model may display a reservoir profile, including distribution maps of parameters such as reservoir thickness, permeability, porosity, and gas content.

[0061] After the model is established, the three-dimensional reservoir model can be further corrected using actual production data during subsequent production processes in the region to improve the model's accuracy.

[0062] Step 102: Use the three-dimensional geological model to simulate hydraulic fracturing and fracture propagation to obtain fracture simulation data.

[0063] Fracturing and fracture propagation simulation is mainly used to simulate the propagation process of fractures under different fracturing conditions.

[0064] Specifically, data from wells in a three-dimensional geological model, such as well trajectory, porosity, permeability, overlying strata pressure, and rock fracture pressure, can be used to simulate the fracture propagation process by using commercial fracturing simulation software (such as MFrac, FracPro, etc.), inputting reservoir physical property data (such as permeability, porosity, etc.) and fracturing parameters (such as injection volume, construction pressure, construction displacement, propagation volume, etc.). This includes simulating and predicting the formation, propagation, and spatial distribution of fractures in the reservoir.

[0065] In some embodiments, a finite element model can be established based on the reservoir data and analysis results obtained in step 101. The finite element analysis method is then used to perform fracturing simulation and fracture propagation analysis to obtain auxiliary simulation results. These auxiliary simulation results are then used to correct the fracture simulation results. Specifically, reservoir parameters (including porosity, permeability, rock mechanics, etc.), well trajectory, and fracturing parameters (including injection volume, construction pressure, construction displacement, etc.) are input into the finite element model to simulate the fracture morphology, including fracture length, fracture width, and fracture spatial distribution.

[0066] Finite element simulation can be combined with stress field to improve the accuracy of crack orientation simulation. It can also determine the degree of interference from artificial cracks and determine the parameters of hydraulic fracturing.

[0067] Step 103: Using the three-dimensional geological model and the fracture simulation data, perform carbon dioxide injection and displacement simulation to obtain displacement simulation data.

[0068] Carbon dioxide injection and displacement simulations are mainly used to predict the distribution of carbon dioxide in fracturing fractures and reservoirs.

[0069] Specifically, the injection process of carbon dioxide in a reservoir can be simulated using multiphase flow simulation tools (such as the Buckley-Leverett equation or other commercial simulation software). First, the physical properties of the reservoir (such as porosity, permeability, gas saturation, etc.) and injection parameters (such as injection rate, injection pressure, etc.) are input. Through numerical simulation, the distribution of carbon dioxide in the fracturing fractures and the reservoir can be predicted.

[0070] During the simulation, carbon dioxide, acting as a displacement gas, primarily flows through the fracture network, driving natural gas from the reservoir towards the production well. The injection process is simulated dynamically, adjusted based on reservoir pressure changes, carbon dioxide flow characteristics, and gas interactions.

[0071] Furthermore, in some non-limiting embodiments, the carbon dioxide displacement effect can be evaluated based on simulation results of carbon dioxide injection and displacement with different injection parameters.

[0072] In practical implementation, the evaluation of the carbon dioxide displacement effect can be analyzed from the following aspects:

[0073] (1) Displacement range: The displacement range of carbon dioxide is assessed by simulating the flow path of carbon dioxide in the reservoir. The simulation results can help optimize the injection location of carbon dioxide to ensure that it can cover a large area of ​​the reservoir.

[0074] (2) Substitution efficiency: The substitution efficiency between carbon dioxide and natural gas is calculated, and the displacement effect of injected carbon dioxide under different reservoir conditions is evaluated. By calculating the substitution efficiency, the gas injection strategy can be further optimized.

[0075] (3) Reservoir pressure change: Evaluate the trend of reservoir pressure change after simulated carbon dioxide injection to ensure that sufficient reservoir pressure is maintained by gas injection to prevent fracture closure and gas flow restriction.

[0076] Step 104: Determine the well pattern layout based on the fracture simulation data and the displacement simulation data.

[0077] A well network layout can improve reservoir gas utilization efficiency and reduce inter-well interference. Therefore, in some embodiments, the well network layout can be based on the following principles:

[0078] (1) Ensure that artificial fractures can effectively cover most of the reservoir;

[0079] (2) Artificial fractures do not interfere with each other, that is, artificial fractures will not penetrate into the wellbore of adjacent wells;

[0080] (3) Carbon dioxide covers most areas.

[0081] Specifically, the location and spacing of wells can be determined based on the length and height of artificial fracture propagation, as well as the length and height of carbon dioxide propagation. This ensures the well network effectively covers the fracture propagation area, and determines the location and number of injection and production wells.

[0082] In some embodiments, numerical simulation tools can be used to verify different well network layout schemes in multiple scenarios during the well network layout optimization process. Specifically, by simulating gas flow paths, reservoir pressure distribution, and carbon dioxide injection and expansion effects under different configurations, it can be verified whether the well network layout can achieve the expected goals. For example, one or more of the following simulations and analyses can be performed: simulating gas flow paths under different well network layouts to ensure that gas can flow efficiently to the gas production wells; simulating the changing trends of reservoir pressure under different well network layouts to ensure that the well network layout can maintain stable reservoir pressure and prevent premature exhaustion of gas wells; analyzing the expansion range and morphology of fractures after fracturing to verify whether the fractures cover all gas production areas and ensure the effectiveness of the fractures.

[0083] In some embodiments, on-site operation parameters can be monitored and adjusted in real time during on-site implementation, and key parameters can be dynamically adjusted.

[0084] The field operation parameters include, but are not limited to, any one or more of the following: gas flow rate, gas composition, reservoir pressure, and carbon dioxide concentration. For example, by deploying sensors and online monitoring equipment, parameters such as gas production, gas composition, reservoir pressure, and carbon dioxide concentration at the wellhead can be continuously tracked. Monitoring the gas production of each well ensures production efficiency. Monitoring the gas composition ensures that the target gas (such as methane) is collected and allows monitoring of carbon dioxide flow in the reservoir. Real-time monitoring of reservoir pressure ensures stable reservoir pressure, which is beneficial for efficient carbon dioxide displacement and gas recovery. Monitoring the concentration of carbon dioxide in the reservoir ensures that the displacement effect achieves the expected results.

[0085] Based on real-time monitoring data and on-site feedback, the key parameters include one or more of the following: gas injection rate, gas production rate, and well layout parameters. These key parameters, such as the gas injection rate, gas production rate, and well layout, are dynamically adjusted. By optimizing these parameters in real time, the continuous stability of the gas production process is ensured, and economic benefits are maximized.

[0086] In some embodiments, to accelerate the simulation and improve its accuracy, artificial intelligence methods can be used to obtain the optimal well network layout, gas injection parameters and gas production parameters at different time periods by using input reservoir parameters, fracturing parameters, carbon dioxide injection pressure, injection rate and actual production data (gas production rate, gas wellhead pressure, etc.).

[0087] It should be noted that the solutions of this invention can be applied to the development of various types of gas wells, such as shale gas, coal gas, or other tight gas wells.

[0088] The following examples further illustrate the process and effects of using the efficient gas well development method provided by this invention for gas well development.

[0089] Example 1: Calculate the dimensions of a gas field block that is 2 kilometers long from north to south and 2 kilometers wide from east to west.

[0090] 1) Reservoir geological conditions

[0091] The exploitable reservoirs are distributed across three main layers, from top to bottom: Layer 1, Layer 2, and Layer 3. The specific geological parameters of the reservoirs are as follows:

[0092] 1st layer: 23m thick, permeability 0.23mD, porosity 10%, gas content 100m³ 3 / t, the vertical distance from the second floor is 1250m.

[0093] Two sublayers: 40m thick, 0.03mD permeability, 12% porosity, 120m³ gas content. 3 / t, the vertical distance from the 3rd floor is 20m.

[0094] 3 sublayers: 17m thick, 0.05mD permeability, 8% porosity, 90m gas content 3 / t.

[0095] 2) Well pattern optimization and injection-production rate

[0096] Based on the reservoir characteristics and well pattern optimization, the following well pattern layout was designed:

[0097] Layer 1: Three wells are arranged with a spacing of 800 meters. The middle well is a gas injection well, and the two adjacent wells are gas production wells. The gas injection rate is 5 kg / s, the injection pressure is controlled at 15 MPa, and the gas production rate is controlled at 8000 m / s. 3 / d, and dynamically adjust the gas extraction rate according to pressure changes.

[0098] Two sub-layers: Five wells are arranged with a spacing of 400 meters between them. The middle well is a gas injection well, and the four adjacent wells are gas production wells. The gas injection rate is 20 kg / s, the injection pressure is controlled at 20 MPa, and the gas production rate is controlled at 6000 m³ / s. 3 / d, and dynamically adjust the gas extraction rate according to pressure changes.

[0099] Three sub-layers: Four wells are arranged, spaced 500 meters apart, all of which are gas production wells. Gas production rate is 6000 m / s². 3 / d, dynamically adjust the gas extraction rate according to pressure changes.

[0100] 3) Implementation Results

[0101] Through the above optimizations, the overall gas extraction rate of the block increased by 20,000 m³ / h. 3 / d, the wellhead pressure remained unchanged, maintaining pressure stability.

[0102] Example 2: Calculate the dimensions of a gas field in a certain block, which is 2 kilometers long from north to south and 2 kilometers wide from east to west.

[0103] 1) Reservoir geological conditions

[0104] The developable reservoirs are distributed in two main sections, which are sub-layers 1 and 2 from top to bottom. The specific geological parameters of the reservoirs are as follows:

[0105] 1st layer: 43m thick, permeability 0.23mD, porosity 10%, gas content 100m³ 3 / t, the vertical distance from the second floor is 150m.

[0106] Two sublayers: 27m thick, 0.28mD permeability, 12% porosity, 120m³ gas content. 3 / t.

[0107] 2) Well pattern optimization and injection-production rate

[0108] Based on the reservoir characteristics and well pattern optimization, the following well pattern layout was designed:

[0109] Layer 1: Five wells are arranged, spaced 400 meters apart. The middle well is a gas injection well, and the four adjacent wells are gas production wells. The gas injection rate is 10 kg / s, and the injection pressure is controlled at 15 MPa. The gas production rate is controlled at 10,000 m³ / s. 3 / d, and dynamically adjust the gas extraction rate according to pressure changes.

[0110] Two sub-layers: Three wells are arranged with a spacing of 800 meters. The middle well is a gas injection well, and the two adjacent wells are gas production wells. The gas injection rate is 18 kg / s, and the gas injection pressure is controlled at 20 MPa. The gas production rate is controlled at 6600 m / s. 3 / d, and dynamically adjust the gas extraction rate according to pressure changes.

[0111] 3) Implementation Results

[0112] Through the above optimizations, the overall gas extraction rate of the block increased by 15,000 m³ / h. 3 / d, the wellhead pressure remained unchanged, maintaining pressure stability.

[0113] The efficient gas well development method provided by this invention combines carbon dioxide displacement and horizontal well staged fracturing technology. By collecting and analyzing reservoir data, a three-dimensional geological model is established. This model is then used for fracturing simulation and fracture propagation analysis, as well as carbon dioxide injection and displacement simulation. The simulation data is then used to determine the well network layout. The above examples fully demonstrate the following technical effects of this invention:

[0114] (1) Significantly improves recovery rate: Carbon dioxide displacement can release adsorbed gas in the reservoir and free gas in low-permeability areas, improving the recovery rate by 15%-25% compared with traditional technology.

[0115] (2) Extending the production cycle of gas wells: After carbon dioxide injection, by maintaining reservoir pressure and avoiding fracture closure, the production cycle of gas wells is extended by 1.5-2 times, which improves the long-term economic benefits of gas wells.

[0116] (3) Improve the stability of gas well production: By controlling the formation of fractures and the carbon dioxide injection path, excessive concentration of reservoir gas flow is avoided, making the production process more balanced and stable.

[0117] (4) Significant environmental benefits: Through the injection and storage of carbon dioxide, a large amount of carbon dioxide emissions can be reduced every year.

[0118] (5) Reduced development costs: Due to the extended production cycle and increased recovery rate of gas wells, the frequency of re-fracture and well repair is reduced, thus lowering the maintenance costs for long-term development.

[0119] It should be noted that, for the sake of simplicity, the foregoing method embodiments are all described as a series of actions. However, those skilled in the art should understand that the present invention is not limited to the described order of actions, because according to the present invention, some steps can be performed in other orders or simultaneously. Furthermore, those skilled in the art should also understand that the embodiments described in the specification are preferred embodiments, and the actions and modules involved are not necessarily essential to the present invention.

[0120] In the above embodiments, the descriptions of each embodiment have different focuses. For parts not described in detail in a certain embodiment, please refer to the relevant descriptions in other embodiments.

[0121] In the several embodiments provided by the present invention, it should be understood that the disclosed apparatus can be implemented in other ways.

[0122] The present invention also provides a storage medium, which is a computer-readable storage medium storing a computer program thereon, the computer program being executable when it runs. Figure 1 The method shown may include some or all of the steps. The storage medium may include read-only memory (ROM), random access memory (RAM), magnetic disk, or optical disk, etc. The storage medium may also include non-volatile memory or non-transitory memory, etc.

[0123] The above embodiments can be implemented, in whole or in part, by software, hardware, firmware, or any other combination thereof. When implemented using software, the above embodiments can be implemented, in whole or in part, as a computer program product. The computer program product includes one or more computer instructions or computer programs. When the computer instructions or computer program are loaded or executed on a computer, all or part of the processes or functions described in the embodiments of this application are generated. The computer can be a general-purpose computer, a special-purpose computer, a computer network, or other programmable device. The computer instructions can be stored in a computer-readable storage medium or transmitted from one computer-readable storage medium to another. For example, the computer instructions can be transmitted from one website, computer, server, or data center to another website, computer, server, or data center via wired or wireless means.

[0124] The embodiments of the present invention have been described in detail above. Specific implementation methods have been used to illustrate the present invention. The descriptions of the embodiments above are only for the purpose of helping to understand the methods and systems of the present invention, and are merely some, not all, embodiments of the present invention. Based on the embodiments of the present invention, all other embodiments obtained by those skilled in the art without creative effort should fall within the scope of protection of the present invention, and the content of this specification should not be construed as a limitation of the present invention. Therefore, any modifications, equivalent substitutions, improvements, etc., made within the spirit and principles of the present invention should be included within the scope of protection of the present invention.

Claims

1. A method for efficient development of gas wells, characterized in that, The method includes: Collect and analyze reservoir data, and establish a three-dimensional geological model based on the reservoir data and analysis results. The three-dimensional geological model is used to show the spatial distribution of the reservoir. The three-dimensional geological model was used to perform hydraulic fracturing simulation and fracture propagation analysis to obtain fracture simulation data. Using the three-dimensional geological model and the fracture simulation data, carbon dioxide injection and displacement simulations were performed to obtain displacement simulation data; The well pattern layout is determined based on the fracture simulation data and the displacement simulation data.

2. The efficient gas well development method according to claim 1, characterized in that, The reservoir data includes any one or more of the following: seismic wave data, core analysis data, gas composition data, and pressure and temperature data; Collecting reservoir data includes: Seismic wave data of reservoirs are obtained through seismic exploration; Core analysis can be used to obtain reservoir porosity, permeability, and lithological characteristics, or nuclear magnetic resonance analysis and CT scanning techniques can be used to obtain pore structure, pore distribution, and fracture network characteristics. The composition information of various gases in the reservoir is obtained through gas composition testing; Reservoir pressure and temperature gradients are obtained through engineering techniques.

3. The efficient gas well development method according to claim 2, characterized in that, The analyzed reservoir data includes: Based on the reservoir data, reservoir heterogeneity analysis is performed; Based on the analysis results, a preliminary reservoir profile is constructed to show the characteristic parameters of each layer. The characteristic parameters include any one or more of the following: thickness, permeability, and porosity.

4. The efficient gas well development method according to claim 1, characterized in that, The method further includes: The three-dimensional geological model is corrected by comparing actual production data from different regions.

5. The efficient gas well development method according to claim 1, characterized in that, The fracturing simulation and fracture propagation analysis performed using the three-dimensional geological model yielded the following fracture simulation data: Based on the well data in the three-dimensional geological model, fracturing simulation software is used to input reservoir physical property data and fracturing parameters to simulate the fracture propagation process and obtain fracture simulation data.

6. The efficient gas well development method according to claim 5, characterized in that, The process of using the three-dimensional geological model to perform hydraulic fracturing simulation and fracture propagation analysis to obtain fracture simulation data also includes: A finite element model was established, and the finite element analysis method was used to perform hydraulic fracturing simulation and fracture propagation analysis to obtain auxiliary simulation data. The crack simulation data is corrected using the auxiliary simulation data.

7. The efficient gas well development method according to claim 1, characterized in that, The method further includes: The carbon dioxide displacement effect is evaluated based on the simulation results of carbon dioxide injection and displacement with different injection parameters; the injection parameters include: injection rate, injection pressure, and injection time.

8. The efficient gas well development method according to claim 7, characterized in that, The evaluation of carbon dioxide displacement effect includes any one or more of the following: The extent to which carbon dioxide can substitute for natural gas is assessed by simulating the flow path of carbon dioxide in the reservoir. Calculate the substitution efficiency of carbon dioxide and natural gas, and evaluate the displacement effect of injected carbon dioxide under different reservoir conditions; Assess the trend of reservoir pressure changes after simulated carbon dioxide injection.

9. The method for efficient gas well development according to any one of claims 1 to 8, characterized in that, The method further includes: During the well network layout optimization process, numerical simulation tools are used to verify different well network layout schemes in multiple scenarios.

10. The efficient gas well development method according to claim 9, characterized in that, The method further includes: During on-site implementation, on-site operation parameters are monitored and adjusted in real time, and key parameters are dynamically adjusted. The on-site operation parameters include any one or more of the following: gas flow rate, gas composition, reservoir pressure, and carbon dioxide concentration. The key parameters include any one or more of the following: gas injection rate, gas production rate, and well network layout parameters.

11. A computer-readable storage medium having a computer program stored thereon, characterized in that, The computer program, when executed by a processor, performs the steps of the efficient gas well development method according to any one of claims 1 to 10.

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