Method, device and medium for determining optimal chokes for shale gas wells based on dynamic monitoring

Abstract

The application discloses a kind of based on dynamic monitoring determination shale gas well optimum choke, equipment and medium, wherein method includes: using inclination data, establish well trajectory model;Based on the size of inclination angle in drilling process, in combination with the build-up of inclination, inclination in horizontal section drilling process, establish a variety of well trajectory change model;Using distributed optical fiber monitoring means, record the gas production and water production of each perforation cluster in horizontal section;Calculate the gas production ratio and water production ratio of each cluster;According to the cluster efficiency of each cluster gas production, water production condition determines;Combining a variety of well trajectory change model, get cluster efficiency change condition when different choke size;Calculate the artificial fracture conductivity in the process of different choke up-regulation;Establish the relationship curve between choke size and artificial fracture conductivity change, the relationship curve between choke size and cluster efficiency change, the intersection of two curves is the optimum choke size considering artificial fracture conductivity and cluster efficiency.The application can realize production optimization.

Description

TECHNICAL FIELD

[0001] The present application relates to the technical field of oil and gas field development, and particularly relates to a method, device and medium for determining a best choke of a shale gas well based on dynamic monitoring. BACKGROUND

[0002] In order to realize scale benefit development, cluster wells and horizontal wells are mainly used in shale gas well distribution modes. Artificial fracture conductivity is an effective means for timely evaluation of shale gas well production effect. Artificial fracture conductivity decreases with the extension of production time, but the decrease amplitude of artificial fracture conductivity is different under different production system conditions. Under high production pressure difference conditions, the decrease amplitude of artificial fracture conductivity is large, and under low production pressure difference conditions, the decrease amplitude of artificial fracture conductivity is small. At the same time, in order to ensure that the gas well obtains a high capacity contribution, the horizontal section track needs to pass through the optimal reservoir to the greatest extent, and in the micro-structure development area, the horizontal section inclination angle changes greatly. In the production process, different production systems have different effects on the cluster efficiency of different inclination sections of the horizontal section. Therefore, under different production system conditions, how to balance the cluster efficiency of different inclination sections of the horizontal section and the artificial fracture conductivity is an important factor affecting the final gas production of the shale gas well.

[0003] At present, the mainstream method for formulating shale gas well production system is to select production indexes in stages and use the comparison method to determine the reasonable production system. The production data of the put-into-production well are analyzed in stages. In stage 1, after the gas well is opened, before the peak pressure is reached, six indexes such as gas breakthrough time, gas breakthrough flowback rate, peak production flowback rate, 30-day flowback rate, peak pressure and peak pressure corresponding gas production are used for evaluation, and the six flowback indexes and the production system of the high-yield well are determined. One month after the peak pressure, the artificial fracture conductivity, unit pressure drop gas production, test production and flowback stage EUR are used for evaluation of the production capacity of the gas well, and the production system of the high-yield well in this stage is determined. Two to four months after the peak pressure, the artificial fracture conductivity is diagnosed and the EUR is corrected to determine the production capacity of the gas well, and the production system of the high-yield well is summarized, so as to determine the reasonable production system in each stage. This method needs to analyze many indexes, and the best production system can be determined only after the gas well reaches stable production, and the time cycle is long, which cannot achieve rapid response and rapid adjustment. SUMMARY

[0004] In order to solve the above problems, the present application provides a method, device and medium for determining a best choke of a shale gas well based on dynamic monitoring, which can realize optimization of production effect.

[0005] The technical scheme adopted by the present application is as follows:

[0006] A method for determining a best choke of a shale gas well based on dynamic monitoring, comprising:

[0007] The well trajectory model is established by using the inclination data;

[0008] Based on the inclination angle during drilling, combined with the build-up and drop-off during horizontal drilling, a plurality of well trajectory change models are established.

[0009] The gas production and water production of each perforation cluster in the horizontal section are recorded by using the distributed optical fiber monitoring method.

[0010] The gas production and water production of each perforation cluster in the horizontal section are recorded by using the distributed optical fiber monitoring method.

[0011] The cluster efficiency is determined according to the gas production and water production of each cluster.

[0012] The cluster efficiency change under different choke sizes is obtained by combining the plurality of well trajectory change models.

[0013] The artificial fracture conductivity during the adjustment process of different chokes is calculated, and the change characteristics of the artificial fracture conductivity are analyzed.

[0014] The relationship curves of the choke size and the artificial fracture conductivity change, and the relationship curves of the choke size and the cluster efficiency change are established, and the intersection of the two curves is the optimal choke size considering the artificial fracture conductivity and the cluster efficiency.

[0015] Further, the well trajectory model established by using the inclination data includes: a three-dimensional well trajectory model is established based on the measured parameters of the well trajectory and a pre-design calculation method, the measured parameters of the well trajectory include the drilling depth or logging depth, the azimuth angle and the inclination angle, and the pre-design calculation method includes the cylindrical spiral method.

[0016] Further, the plurality of well trajectory change models are established by: according to the build-up and drop-off during horizontal drilling, the drilling process is divided into three cases of upward drilling, downward drilling and horizontal drilling; based on the inclination angle during drilling, combined with the build-up and drop-off during horizontal drilling, a plurality of well trajectory change models are established, including upward large inclination and small inclination drilling sections, downward large inclination and small inclination drilling sections, and flat drilling sections.

[0017] Further, the distributed optical fiber monitoring method is used to record the gas production and water production of each perforation cluster in the horizontal section, including: keeping the choke size unchanged, recording two sets of data of temperature, pressure and rotor speed at different depths during the process of lowering the production logging instrument to the bottom of the well and lifting it from the bottom of the well to the wellhead, respectively, correcting the temperature, pressure and rotor speed curves during the lowering and lifting processes after data recording, determining the temperature, pressure and rotor speed curves under the current conditions by the weighted average method, and then calculating the gas production and water production of each perforation cluster in the horizontal section by using the related temperature-pressure-rotor speed model; the gas production and water production of each perforation cluster in the horizontal section under a plurality of choke sizes are recorded.

[0018] Furthermore, determining the cluster efficiency based on the gas and water production of each cluster includes: defining pure gas-producing clusters, pure water-producing clusters, and clusters that produce both gas and water as effective clusters, and defining clusters that produce neither gas nor water as invalid clusters, based on the gas and water production of each cluster. The cluster efficiency is the proportion of effective clusters to the total number of clusters.

[0019] Furthermore, the process of combining multiple well trajectory variation models to obtain the cluster efficiency variation under different nozzle sizes includes: plotting the cluster efficiency variation relationship curves of multiple well trajectory variation models under different nozzle sizes, and establishing an equivalent curve by using a weighted average method for multiple curves. The equivalent curve is the cluster efficiency variation relationship curve for the horizontal segment.

[0020] Furthermore, the analysis of the variation characteristics of the artificial fracture conductivity includes: using the comprehensive parameter analysis method of artificial fracture conductivity in the gas well volumetric fracturing model to establish a trend line diagram of artificial fracture conductivity under different nozzle sizes.

[0021] Furthermore, the establishment of the relationship curves between nozzle size and artificial fracture flow capacity, and between nozzle size and cluster efficiency includes: using nozzle size as the abscissa and artificial fracture flow capacity and cluster efficiency as the ordinate, establishing the relationship curves between nozzle size and artificial fracture flow capacity, and between nozzle size and cluster efficiency, respectively. The intersection of the two curves is the optimal nozzle size that balances fracture flow capacity and cluster efficiency.

[0022] A computer device includes a memory and a processor, the memory storing a computer program, and the processor executing the computer program to implement the above-described method for determining the optimal nozzle for a shale gas well based on dynamic monitoring.

[0023] A computer-readable storage medium storing a computer program that, when executed by a processor, implements the above-described method for determining the optimal nozzle for a shale gas well based on dynamic monitoring.

[0024] The beneficial effects of this invention are as follows:

[0025] This invention utilizes dynamic and static data from production horizontal wells, combined with the results of artificial fracture conductivity, to analyze the differences in cluster efficiency and artificial fracture conductivity of different dip angle sections in horizontal sections under different production regimes. Furthermore, considering the cluster efficiency and artificial fracture conductivity of different dip angle sections in horizontal sections, a scientifically sound nozzle control regime for shale gas wells is established to optimize production performance. Attached Figure Description

[0026] Figure 1 This is a flowchart of the method for determining the optimal nozzle for a shale gas well based on dynamic monitoring, according to Embodiment 1 of the present invention.

[0027] Figure 2This refers to the measured parameters of the well trajectory and the three-dimensional model of the well trajectory in Embodiment 2 of the present invention.

[0028] Figure 3 This is a three-dimensional model of the well trajectory in Embodiment 2 of the present invention.

[0029] Figure 4 These are the percentages of gas production and water production for each perforation cluster in the horizontal section under different production regimes in Embodiment 2 of the present invention.

[0030] Figure 5 This is a graph showing the relationship between the efficiency changes of five well trajectory variation model clusters in Embodiment 2 of the present invention.

[0031] Figure 6 This is a trend line diagram of the flow conduction capacity of artificial cracks under different production system conditions, as shown in Embodiment 2 of the present invention.

[0032] Figure 7 This is the relationship curve of nozzle-artificial crack flow guiding capacity-cluster efficiency in Embodiment 2 of the present invention. Detailed Implementation

[0033] To provide a clearer understanding of the technical features, objectives, and effects of the present invention, specific embodiments are now described. It should be understood that the specific embodiments described herein are merely illustrative of the invention and are not intended to limit the invention; that is, the described embodiments are only a part of the embodiments of the invention, not all of them. All other embodiments obtained by those skilled in the art based on the embodiments of the present invention without inventive effort are within the scope of protection of the present invention.

[0034] Example 1

[0035] like Figure 1 As shown, this embodiment provides a method for determining the optimal nozzle for a shale gas well based on dynamic monitoring, including the following steps:

[0036] A well trajectory model is established using well deviation data;

[0037] Based on the magnitude of the inclination angle during drilling, and combined with the increase and decrease in inclination during horizontal drilling, various well trajectory change models are established.

[0038] Using distributed optical fiber monitoring, the gas production and water production of each perforation cluster in the horizontal segment were recorded;

[0039] Calculate the gas production and water production percentages for each cluster;

[0040] Cluster efficiency is determined based on the gas and water production of each cluster.

[0041] By combining various well trajectory variation models, the cluster efficiency variation at different nozzle sizes was obtained;

[0042] Calculate the artificial crack guiding capacity (AK) during the adjustment process of different nozzles. 1 / 2 ), and analyze the changing characteristics of the conductivity of artificial fractures;

[0043] Establish curves showing the relationship between nozzle size and the flow conduction capacity of artificial fractures, and curves showing the relationship between nozzle size and cluster efficiency. The intersection of the two curves represents the optimal nozzle size that balances the flow conduction capacity of artificial fractures and cluster efficiency.

[0044] Preferably, establishing a well trajectory model using well inclination data includes: establishing a three-dimensional well trajectory model based on measured well trajectory parameters and a preset calculation method. The measured well trajectory parameters include drilling depth or logging depth, azimuth angle, and well inclination angle. The preset calculation method includes the cylindrical helix method.

[0045] Preferably, establishing multiple well trajectory variation models includes: classifying drilling into three scenarios—upward tilt drilling, downward tilt drilling, and horizontal drilling—based on the increase and decrease in inclination during horizontal drilling; and establishing multiple well trajectory variation models, including drilling sections with large and small upward tilt angles, drilling sections with large and small downward tilt angles, and gentle drilling sections, based on the magnitude of the inclination angle during drilling and combined with the increase and decrease in inclination during horizontal drilling.

[0046] Preferably, using distributed optical fiber monitoring, the gas and water production of each perforation cluster in the horizontal section is recorded as follows: keeping the nozzle size constant, during the process of the production logging instrument being lowered into the well and raised from the well to the wellhead, two sets of data for temperature, pressure, and rotor speed at different depths are recorded respectively. After the data is recorded, the temperature, pressure, and rotor speed curves during the lowering and raising processes are corrected respectively. The temperature, pressure, and rotor speed curves under the current conditions are determined by weighted averaging. Then, the gas and water production of each perforation cluster in the horizontal section are calculated using a relevant temperature-pressure-rotor speed model. The gas and water production of each perforation cluster in the horizontal section are recorded under multiple nozzle sizes.

[0047] Preferably, determining the cluster efficiency based on the gas production and water production of each cluster includes: defining pure gas-producing clusters, pure water-producing clusters, and clusters that produce both gas and water as effective clusters, and defining clusters that produce neither gas nor water as ineffective clusters, with the cluster efficiency being the proportion of effective clusters to the total number of clusters.

[0048] Preferably, combining multiple well trajectory variation models to obtain the cluster efficiency variation under different nozzle sizes includes: plotting the cluster efficiency variation relationship curves of multiple well trajectory variation models under different nozzle sizes, and establishing an equivalent curve by using a weighted average method for multiple curves. The equivalent curve is the cluster efficiency variation relationship curve of the horizontal segment.

[0049] Preferably, the analysis of the variation characteristics of the conductivity of artificial fractures includes: using the comprehensive parameter analysis method of the conductivity of artificial fractures in the gas well volumetric fracturing model to establish a trend line diagram of the conductivity of artificial fractures under different nozzle sizes.

[0050] Preferably, establishing the relationship curves between nozzle size and artificial fracture flow capacity, and between nozzle size and cluster efficiency includes: using nozzle size as the abscissa and artificial fracture flow capacity and cluster efficiency as the ordinate, respectively establishing the relationship curves between nozzle size and artificial fracture flow capacity, and between nozzle size and cluster efficiency. The intersection of the two curves is the optimal nozzle size that balances fracture flow capacity and cluster efficiency.

[0051] Example 2

[0052] This embodiment is based on embodiment 1:

[0053] This embodiment provides a method for determining the optimal nozzle for a shale gas well based on dynamic monitoring, including the following steps:

[0054] (1) Based on the measured parameters of the well trajectory (drilling depth or logging depth, azimuth angle, and inclination angle), a three-dimensional model of the well trajectory is established using calculation methods such as the cylindrical spiral method. The actual measured parameters of the well trajectory include drilling data and electrical logging data. Because the electrical logging data has been calibrated, its accuracy is higher than that of the drilling data (e.g., ...). Figure 2 (As shown).

[0055] (2) Based on the increase and decrease in inclination during the horizontal drilling process, three scenarios are classified: up-dip drilling (up-dip horizontal section), down-dip drilling (down-dip horizontal section), or horizontal drilling. Based on the magnitude of the inclination angle during drilling, and combined with the increase and decrease in inclination during the horizontal drilling process, various well trajectory change models are established, including up-dip large and small inclination angle drilling sections, down-dip large and small inclination angle drilling sections, and gentle drilling sections. Actual well trajectory models show that the inclination angle range of the gentle drilling section is between 0 and 1°, with an average of 0.13°; the inclination angle range of the up-dip small inclination angle drilling section is between 1 and 3°, with an average of 1.24°; the inclination angle range of the up-dip large inclination angle drilling section is greater than 3°, with an average of 3.25°; the inclination angle range of the down-dip small inclination angle drilling section is between 1 and 3°, with an average of 1.18°; and the inclination angle range of the down-dip large inclination angle drilling section is greater than 3°, with an average of 5.63° (e.g., ...). Figure 3 (As shown).

[0056] (3) Under the same production regime (with the nozzle size unchanged), during the process of the production logging instrument being lowered into the well and raised from the well to the wellhead, two sets of data on temperature, pressure, and rotor speed at different depths are recorded. After the data is recorded, the temperature, pressure, and rotor speed curves during the lowering and raising processes are corrected. The temperature, pressure, and rotor speed curves under the production regime are determined by weighted averaging. Then, the gas production and water production of each perforation cluster in the horizontal section are calculated using the relevant temperature-pressure-rotor speed model. This method is used to record the gas production and water production of each perforation cluster in the horizontal section under multiple production regimes. For example, a well has 18 fractured sections and 117 clusters. Two production regimes are used for production logging. In regime one (daily gas production of 46,000 cubic meters and daily water production of 55 cubic meters), the gas production of each cluster is between 0 and 1,430 cubic meters / day, and the water production is between 0 and 2.2 cubic meters / day. System Two (daily gas production 73,000 cubic meters, daily water production 70 cubic meters), with each cluster producing between 0 and 1,510 cubic meters of gas per day and between 0 and 1.9 cubic meters of water per day (e.g.) Figure 4 (As shown).

[0057] (4) Based on the gas production and water production of each cluster, pure gas-producing clusters, pure water-producing clusters, and gas-water co-producing clusters are defined as effective clusters, while clusters with no gas production and no water production are defined as invalid clusters. The cluster efficiency is the proportion of effective clusters to the total number of clusters.

[0058] (5) Plot the cluster efficiency variation curves of five well trajectory change models under different production system conditions (different nozzle sizes). Establish an equivalent curve using the weighted average method of the five curves. This equivalent curve is the cluster efficiency variation curve of the horizontal section. Under the condition of changing from low production pressure differential to high production pressure differential (adjusting the nozzle size to increase production), for example, the cluster efficiency of the gently sloping drilling section of the well increases from 85.6% to 94.6%, the cluster efficiency of the slightly inclined drilling section increases from 89.2% to 96.4%, the cluster efficiency of the heavily inclined drilling section increases from 95.3% to 99.3%, the cluster efficiency of the slightly inclined drilling section increases from 87.3% to 91.2%, the cluster efficiency of the heavily inclined drilling section increases from 98.5% to 100%, and the overall cluster efficiency increases from 93.4% to 98.5% (e.g., Figure 5 (As shown).

[0059] (6) Using the AK model in the gas well volumetric fracturing model 1 / 2 Using comprehensive parameter analysis methods, trend lines of the conductivity of artificial fractures under different production systems (dynamic monitoring data acquisition phase) were established. For example, the conductivity of the artificial fracture mesh varies under different nozzle conditions in an example well; when the nozzle is 6mm, the conductivity of the artificial fracture mesh is 5200m. 2 ·mD 1 / 2 At 8mm, the flow-guiding capacity of the artificially sewn mesh is 2500m. 2 ·mD 1 / 2The flow-guiding capacity of artificially sewn mesh is showing a downward trend (e.g. Figure 6 (As shown).

[0060] (7) After increasing gas well production (changing the production system, opening the nozzle), the bottom hole production pressure differential increases, the reservoir stress sensitivity damage increases, and the conductivity of artificial fractures (AK) increases. 1 / 2 The efficiency of the cluster shows a gradual downward trend. Simultaneously, after increasing gas well production, the cluster efficiency shows an upward trend, especially in the easily liquid-accumulating section (the horizontal section between the downdip and updip sections). Therefore, a curve relating "nozzle-artificial fracture conductivity-cluster efficiency" is plotted, with the nozzle as the abscissa and artificial fracture conductivity and cluster efficiency as the ordinates. Curves relating the nozzle to artificial fracture conductivity and the nozzle to cluster efficiency are established. The intersection of these two curves is defined as the optimal nozzle, representing the best production system that balances fracture conductivity and cluster efficiency. Under different nozzle conditions, for example, the intersection of cluster efficiency and artificial fracture conductivity in a well is 6.8 mm (e.g., ...). Figure 7 (As shown).

[0061] Example 3

[0062] This embodiment is based on embodiment 1:

[0063] This embodiment provides a computer device, including a memory and a processor. The memory stores a computer program, and the processor executes the computer program to implement the method of determining the optimal nozzle for a shale gas well based on dynamic monitoring, as described in Embodiment 1. The computer program can be in the form of source code, object code, executable file, or some intermediate form.

[0064] Example 4

[0065] This embodiment is based on embodiment 1:

[0066] This embodiment provides a computer-readable storage medium storing a computer program that, when executed by a processor, implements the method for determining the optimal nozzle for a shale gas well based on dynamic monitoring, as described in Embodiment 1. The computer program can be in the form of source code, object code, executable file, or some intermediate form. The storage medium includes any entity or device capable of carrying computer program code, a recording medium, a computer memory, a read-only memory (ROM), a random access memory (RAM), an electrical carrier signal, a telecommunication signal, and a software distribution medium, etc.

[0067] It should be noted that, for the sake of simplicity, the foregoing method embodiments are described as a series of actions. However, those skilled in the art should understand that this application is not limited to the described order of actions, as some steps may be performed in other orders or simultaneously according to this application. 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 this application.

Claims

1. A method for determining the optimal nozzle for a shale gas well based on dynamic monitoring, characterized in that, include: A well trajectory model is established using well deviation data; Based on the magnitude of the inclination angle during drilling, and combined with the increase and decrease in inclination during horizontal drilling, various well trajectory change models are established. Using distributed optical fiber monitoring, the gas production and water production of each perforation cluster in the horizontal segment were recorded; Calculate the gas production and water production percentages for each cluster; Cluster efficiency is determined based on the gas and water production of each cluster. By combining various well trajectory variation models, the cluster efficiency variation at different nozzle sizes was obtained; Calculate the flow-guiding capacity of artificial cracks during the adjustment process of different nozzles, and analyze the variation characteristics of the flow-guiding capacity of artificial cracks. Establish curves showing the relationship between nozzle size and the flow conduction capacity of artificial fractures, and curves showing the relationship between nozzle size and cluster efficiency. The intersection of the two curves represents the optimal nozzle size that balances the flow conduction capacity of artificial fractures and cluster efficiency. The establishment of multiple well trajectory change models includes: classifying drilling into three scenarios based on the increase and decrease in inclination during horizontal drilling: upward tilting drilling, downward tilting drilling, and horizontal drilling. Based on the magnitude of the inclination angle during drilling, and combined with the increase and decrease in inclination during horizontal drilling, various well trajectory change models are established, including drilling sections with large and small inclination angles, large and small inclination angles, and gentle drilling sections.

2. The method for determining the optimal nozzle for a shale gas well based on dynamic monitoring according to claim 1, characterized in that, The process of establishing a well trajectory model using well deviation data includes: establishing a three-dimensional well trajectory model based on measured well trajectory parameters and a preset calculation method. The measured well trajectory parameters include drilling depth or logging depth, azimuth angle, and well deviation angle. The preset calculation method includes the cylindrical helix method.

3. The method for determining the optimal nozzle for a shale gas well based on dynamic monitoring according to claim 1, characterized in that, The method of using distributed optical fiber monitoring to record the gas and water production of each perforation cluster in the horizontal section includes: keeping the nozzle size constant, recording two sets of data for temperature, pressure, and rotor speed at different depths during the process of the production logging instrument being lowered into the well and raised from the well to the wellhead. After the data is recorded, the temperature, pressure, and rotor speed curves during the lowering and raising processes are corrected respectively. The temperature, pressure, and rotor speed curves under the current conditions are determined by weighted averaging. Then, the gas and water production of each perforation cluster in the horizontal section are calculated using a relevant temperature-pressure-rotor speed model. The gas and water production of each perforation cluster in the horizontal section are recorded under multiple nozzle sizes.

4. The method for determining the optimal nozzle for a shale gas well based on dynamic monitoring according to claim 1, characterized in that, The determination of cluster efficiency based on the gas and water production of each cluster includes: defining pure gas-producing clusters, pure water-producing clusters, and clusters that produce both gas and water as effective clusters, and defining clusters that produce neither gas nor water as invalid clusters. The cluster efficiency is the proportion of effective clusters to the total number of clusters.

5. The method for determining the optimal nozzle for a shale gas well based on dynamic monitoring according to claim 1, characterized in that, The method of combining multiple well trajectory variation models to obtain the cluster efficiency variation under different nozzle sizes includes: drawing cluster efficiency variation relationship curves of multiple well trajectory variation models under different nozzle sizes, and establishing an equivalent curve by using a weighted average method for multiple curves. The equivalent curve is the cluster efficiency variation relationship curve of the horizontal segment.

6. The method for determining the optimal nozzle for a shale gas well based on dynamic monitoring according to claim 1, characterized in that, The analysis of the variation characteristics of artificial fracture conductivity includes: using the comprehensive parameter analysis method of artificial fracture conductivity in the gas well volumetric fracturing model to establish a trend line diagram of artificial fracture conductivity under different nozzle sizes.

7. The method for determining the optimal nozzle for a shale gas well based on dynamic monitoring according to claim 1, characterized in that, The establishment of the relationship curves between nozzle size and artificial fracture flow capacity, and between nozzle size and cluster efficiency includes: using nozzle size as the abscissa and artificial fracture flow capacity and cluster efficiency as the ordinate, respectively establishing the relationship curves between nozzle size and artificial fracture flow capacity, and between nozzle size and cluster efficiency. The intersection of the two curves is the optimal nozzle size that balances fracture flow capacity and cluster efficiency.

8. A computer device comprising a memory and a processor, wherein the memory stores a computer program, characterized in that, When the processor executes the computer program, it implements the method for determining the optimal nozzle for a shale gas well based on dynamic monitoring, as described in any one of claims 1-7.

9. A computer-readable storage medium storing a computer program, characterized in that, When the computer program is executed by the processor, it implements the method for determining the optimal nozzle for a shale gas well based on dynamic monitoring, as described in any one of claims 1-7.

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