Method, equipment and medium for determining optimal oil nozzle of shale gas well based on dynamic monitoring

Abstract

The invention discloses a method, equipment and medium for determining an optimal oil nozzle of a shale gas well based on dynamic monitoring, and the method comprises the steps: building a well trajectory model through well deviation data; on the basis of the inclination angle in the drilling process, various well trajectory change models are established in combination with the inclination increasing and decreasing conditions in the horizontal section drilling process; recording the gas production rate and the water production rate of each perforation cluster of the horizontal section by using a distributed optical fiber monitoring means; calculating a gas production ratio and a water production ratio of each cluster; cluster efficiency is determined according to the gas production rate and the water production rate of each cluster; in combination with various well trajectory change models, cluster efficiency change conditions of different oil nozzle sizes are obtained; the artificial fracture flow conductivity in the up-regulation process of different oil nozzles is calculated; and establishing a change relation curve of the oil nozzle size and the artificial fracture flow conductivity and a change relation curve of the oil nozzle size and the cluster efficiency, wherein the intersection point of the two curves is the optimal oil nozzle size considering the artificial fracture flow conductivity and the cluster efficiency. According to the method, the production effect can be optimized.

Description

Technical Field

[0001] The present invention relates to the technical field of oil and gas field development, and in particular to a method, a device and a medium for determining an optimal oil nozzle of a shale gas well based on dynamic monitoring. Background Art

[0002] In order to achieve scale benefits in shale gas development, cluster wells and horizontal wells are the main well layout patterns. The conductivity of artificial fractures is an effective means to timely evaluate the production effect of shale gas wells. The conductivity of artificial fractures tends to decrease with the extension of production time, but there are differences in the degree of decrease in the conductivity of artificial fractures under different production system conditions. Under high production pressure difference conditions, the conductivity of artificial fractures decreases more significantly, while under low production pressure difference conditions, the conductivity of artificial fractures decreases less significantly. At the same time, in order to ensure that the gas well obtains a higher production capacity contribution, the horizontal well trajectory needs to travel through the optimal reservoir to the greatest extent. In the micro-structure development area, the inclination angle of the horizontal section varies greatly. During the production process, affected by different production systems, the cluster efficiency of different inclination sections of the horizontal section is different. Therefore, under different production system conditions, how to balance the cluster efficiency of different inclination sections of the horizontal section and the conductivity of artificial fractures is an important factor affecting the final gas production of shale gas wells.

[0003] At present, the mainstream method of formulating shale gas well production system is to select production indicators in stages and use the comparison method to clarify the reasonable production system. The production data of the wells that have been put into production are used to carry out analysis in stages. In stage ①, after the gas well is opened, before reaching the peak pressure, six indicators such as gas time, gas flowback rate, peak production flowback rate, 30-day flowback rate, peak pressure and peak pressure corresponding gas production are used to carry out evaluation, and six flowback indicators and production systems of high-yield wells are clarified; one month after the peak pressure, the production capacity of the gas well is evaluated by artificial fracture conductivity, unit pressure drop gas production, test production and flowback stage EUR prediction, and the production system of high-yield wells in this stage is clarified; 2-4 months after the peak pressure, the production capacity of the gas well is determined by artificial fracture conductivity diagnosis and EUR correction, and the production system of high-yield wells is summarized, so as to determine the reasonable production system of each stage. This method requires the analysis of many indicators and the optimal production system can only be determined after the gas well reaches stable production. The time period is long and it is impossible to achieve rapid response and rapid adjustment. Summary of the invention

[0004] In order to solve the above problems, the present invention proposes a method, a device and a medium for determining the best nozzle of a shale gas well based on dynamic monitoring, which can optimize the production effect.

[0005] The technical solution adopted by the present invention is as follows:

[0006] A method for determining an optimal nozzle for a shale gas well based on dynamic monitoring, comprising:

[0007] Use well deviation data to build a well trajectory model;

[0008] Based on the inclination angle during drilling, and combined with the increase and decrease in inclination during horizontal drilling, multiple well trajectory change models are established;

[0009] Distributed optical fiber monitoring is used to record the gas and water production of each perforation cluster in the horizontal section;

[0010] Calculate the gas production ratio and water production ratio of each cluster;

[0011] The cluster efficiency is determined based on the gas and water production of each cluster;

[0012] Combining various well trajectory change models, the change of cluster efficiency at different nozzle sizes is obtained;

[0013] Calculate the conductivity of artificial fractures during different nozzle adjustment processes and analyze the changing characteristics of the conductivity of artificial fractures;

[0014] The relationship curves between nozzle size and artificial fracture conductivity and between nozzle size and cluster efficiency were established. The intersection of the two curves is the optimal nozzle size that takes into account both artificial fracture conductivity and cluster efficiency.

[0015] Furthermore, the use of well inclination data to establish a well trajectory model includes: establishing a three-dimensional well trajectory model based on measured well trajectory parameters and a preset calculation method, the well trajectory measured parameters include drilling depth or logging depth, azimuth and well inclination, and the preset calculation method includes a cylindrical spiral method.

[0016] Furthermore, the establishment of multiple well trajectory change models includes: dividing the well trajectory change models into three situations, namely, up-tilt drilling, down-tilt drilling and horizontal drilling, according to the increase and decrease in inclination during the horizontal section drilling process; based on the size of the inclination angle during the drilling process, combined with the increase and decrease in inclination during the horizontal section drilling process, multiple well trajectory change models are established, including up-tilt large-angle and small-angle drilling sections, down-tilt large-angle and small-angle drilling sections and gentle drilling sections.

[0017] Furthermore, the use of distributed optical fiber monitoring means to record the gas production and water production of each perforation cluster in the horizontal section includes: keeping the nozzle size unchanged, and recording two sets of temperature, pressure and rotor speed data at different depths during the process of lowering the production logging instrument into 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 the data are recorded, determining the temperature, pressure and rotor speed curves under current conditions by a weighted average method, and then calculating the gas production and water production of each perforation cluster in the horizontal section using a related temperature-pressure-rotor speed model; recording the gas production and water production of each perforation cluster in the horizontal section under multiple nozzle sizes.

[0018] Furthermore, determining the cluster efficiency according to the gas production and water production of each cluster includes: defining pure gas production clusters, pure water production clusters and gas and water production clusters as effective clusters, and defining no gas production and water production clusters as invalid clusters, according to the gas production and water production of each cluster; the cluster efficiency is the ratio of effective clusters to the total number of clusters.

[0019] Furthermore, the combination of multiple well trajectory change models to obtain cluster efficiency changes at different nozzle sizes includes: drawing cluster efficiency change relationship curves of multiple well trajectory change models under different nozzle sizes, and using a weighted average method to establish an equivalent curve for multiple curves, wherein the equivalent curve is the horizontal segment cluster efficiency change relationship curve.

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

[0021] Furthermore, the establishing of the relationship curve between the nozzle size and the change in conductivity of the artificial fracture, and the relationship curve between the nozzle size and the change in cluster efficiency includes: taking the nozzle size as the horizontal coordinate, and the artificial fracture conductivity and the cluster efficiency as the vertical coordinates, respectively establishing the relationship curve between the nozzle size and the change in conductivity of the artificial fracture, and the relationship curve between the nozzle size and the change in cluster efficiency, and the intersection of the two curves is the optimal nozzle size that takes into account both the fracture conductivity and the cluster efficiency.

[0022] A computer device includes a memory and a processor, wherein the memory stores a computer program, and when the processor executes the computer program, the method for determining the optimal nozzle of a shale gas well based on dynamic monitoring is implemented.

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

[0024] The beneficial effects of the present invention are:

[0025] The present invention utilizes the dynamic and static data of the put into production horizontal wells, combined with the results of artificial fracture conductivity, to analyze the differences in cluster efficiency of different inclination sections of the horizontal section and the conductivity of artificial fractures under different production system conditions. At the same time, considering the cluster efficiency of different inclination sections of the horizontal section and the conductivity of artificial fractures, a scientific and reasonable choke control system for shale gas wells is established to achieve the optimization of production effect. BRIEF DESCRIPTION OF THE DRAWINGS

[0026] Figure 1 This is a flow chart of a method for determining the best nozzle for a shale gas well based on dynamic monitoring according to Example 1 of the present invention.

[0027] Figure 2These are the measured parameters of the well trajectory and the three-dimensional model of the well trajectory of Example 2 of the present invention.

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

[0029] Figure 4 It is the gas production percentage and water production percentage of each perforation cluster in the horizontal section under different production system conditions of Example 2 of the present invention.

[0030] Figure 5 It is a curve diagram of the cluster efficiency change relationship of the five well trajectory change models of Example 2 of the present invention.

[0031] Figure 6 It is a trend line diagram of the conductivity of artificial fractures under different production system conditions established in Example 2 of the present invention.

[0032] Figure 7 This is the relationship curve between the nozzle-artificial fracture conductivity and the cluster efficiency in Example 2 of the present invention. DETAILED DESCRIPTION

[0033] In order to have a clearer understanding of the technical features, purposes and effects of the present invention, the specific implementation methods of the present invention are now described. It should be understood that the specific embodiments described herein are only used to explain the present invention and are not used to limit the present invention, that is, the embodiments described are only part of the embodiments of the present invention, rather than all the embodiments. Based on the embodiments of the present invention, all other embodiments obtained by those skilled in the art without making creative work 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 of a shale gas well based on dynamic monitoring, comprising the following steps:

[0036] Use well deviation data to build a well trajectory model;

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

[0038] Distributed optical fiber monitoring is used to record the gas and water production of each perforation cluster in the horizontal section;

[0039] Calculate the gas production ratio and water production ratio of each cluster;

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

[0041] Combining various well trajectory change models, the change of cluster efficiency at different nozzle sizes is obtained;

[0042] Calculation of the conductivity of artificial fractures during different nozzle adjustment processes (AK 1 / 2 ), analyzing the changing characteristics of the conductivity of artificial fractures;

[0043] The relationship curves between nozzle size and artificial fracture conductivity and between nozzle size and cluster efficiency were established. The intersection of the two curves is the optimal nozzle size that takes into account both artificial fracture conductivity and cluster efficiency.

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

[0045] Preferably, establishing multiple well trajectory change models includes: dividing the well trajectory change models into three situations, namely, up-tilt drilling, down-tilt drilling and horizontal drilling, according to the increase and decrease in inclination during the horizontal section drilling process; based on the size of the inclination angle during the drilling process, combined with the increase and decrease in inclination during the horizontal section drilling process, establishing multiple well trajectory change models including up-tilt large-angle and small-angle drilling sections, down-tilt large-angle and small-angle drilling sections and gentle drilling sections.

[0046] Preferably, using distributed optical fiber monitoring means, recording the gas production and water production of each perforation cluster in the horizontal section includes: keeping the nozzle size unchanged, recording two sets of temperature, pressure and rotor speed data at different depths during the process of lowering the production logging instrument into 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 process after the data are recorded, determining the temperature, pressure and rotor speed curves under current conditions by a weighted average method, and then calculating the gas production and water production of each perforation cluster in the horizontal section using a related temperature-pressure-rotor speed model; recording the gas production and water production of each perforation cluster in the horizontal section under multiple nozzle sizes.

[0047] Preferably, determining the cluster efficiency according to the gas production and water production of each cluster includes: defining pure gas production clusters, pure water production clusters and gas and water production clusters as effective clusters, and defining no gas and water production clusters as invalid clusters, and the cluster efficiency is the ratio of effective clusters to the total number of clusters.

[0048] Preferably, combining multiple well trajectory change models to obtain cluster efficiency changes at different nozzle sizes includes: drawing cluster efficiency change relationship curves of multiple well trajectory change models under different nozzle sizes, and using a weighted average method to establish an equivalent curve for multiple curves, where the equivalent curve is the horizontal segment cluster efficiency change relationship curve.

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

[0050] Preferably, establishing a curve of relationship between nozzle size and change in artificial fracture conductivity, and a curve of relationship between nozzle size and change in cluster efficiency comprises: taking nozzle size as the abscissa, and artificial fracture conductivity and cluster efficiency as the ordinates, respectively establishing a curve of relationship between nozzle size and change in artificial fracture conductivity, and a curve of relationship between nozzle size and change in cluster efficiency, wherein the intersection of the two curves is the optimal nozzle size that takes both fracture conductivity and cluster efficiency into consideration.

[0051] Example 2

[0052] This embodiment is based on embodiment 1:

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

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

[0055] (2) According to the increase or decrease in inclination during the horizontal section drilling process, it is divided into three situations: up-tilt drilling (up-tilt horizontal section), down-tilt drilling (down-tilt horizontal section) or horizontal drilling. Based on the size of the inclination angle during the drilling process and combined with the increase or decrease in inclination during the horizontal section drilling process, multiple well trajectory change models are established, including up-tilt large-angle and small-angle drilling sections, down-tilt large-angle and small-angle drilling sections, and gentle drilling sections. The actual well trajectory model shows that the inclination range of the gentle drilling section is between 0 and 1°, with an average of 0.13°; the inclination range of the up-tilt small-angle drilling section is between 1 and 3°, with an average of 1.24°; the inclination range of the up-tilt large-angle drilling section is greater than 3°, with an average of 3.25°; the inclination range of the down-tilt small-angle drilling section is between 1 and 3°, with an average of 1.18°; the inclination range of the down-tilt large-angle drilling section is greater than 3°, with an average of 5.63° (e.g. Figure 3 shown).

[0056] (3) Under the same production system conditions (the nozzle size remains unchanged), during the process of lowering the production logging instrument into the bottom of the well and lifting it from the bottom of the well to the wellhead, two sets of temperature, pressure and rotor speed data at different depths are recorded. After the data are recorded, the temperature, pressure and rotor speed curves during the lowering and lifting processes are corrected respectively. The temperature, pressure and rotor speed curves under the production system conditions are determined by the weighted average method, and 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 system conditions. For example, a well was fractured in 18 sections and 117 clusters. Two production system production loggings were carried out. System 1 (daily gas production of 46,000 cubic meters and daily water production of 55 cubic meters). The gas production of each cluster ranged from 0 to 14,300 cubic meters / day, and the water production ranged from 0 to 2.2 cubic meters / day. System 2 (daily gas production of 73,000 cubic meters and daily water production of 70 cubic meters), the gas production of each cluster is between 0 and 15,100 cubic meters / day, and the water production is between 0 and 1.9 cubic meters / day (such as Figure 4 shown).

[0057] (4) According to the gas and water production of each cluster, pure gas production clusters, pure water production clusters and gas and water production clusters are defined as effective clusters, and no gas production and water production clusters are defined as invalid clusters. The cluster efficiency is the ratio of effective clusters to the total number of clusters.

[0058] (5) Draw the cluster efficiency change relationship curves of the five well trajectory change models under different production system conditions (different nozzle sizes), and use the weighted average method to establish an equivalent curve for the five curves. The equivalent curve is the horizontal segment cluster efficiency change relationship curve. From low production pressure difference to high production pressure difference (adjusting the nozzle to increase production), the cluster efficiency of the gentle drilling section of the example well increased from 85.6% to 94.6%, the cluster efficiency of the upward low-angle drilling section increased from 89.2% to 96.4%, the cluster efficiency of the upward high-angle drilling section increased from 95.3% to 99.3%, the cluster efficiency of the downward low-angle drilling section increased from 87.3% to 91.2%, the cluster efficiency of the downward high-angle drilling section increased from 98.5% to 100%, and the comprehensive cluster efficiency increased from 93.4 to 98.5% (such as Figure 5 shown).

[0059] (6) Using the AK in the gas well volume fracturing model 1 / 2 By means of comprehensive parameter analysis, a trend line diagram of artificial fracture conductivity under different production systems (dynamic monitoring data collection stage) is established. For example, the conductivity of artificial fracture network under different oil nozzle conditions in the well is different. When the oil nozzle is 6mm, the conductivity of artificial fracture network is 5200m 2 ·mD 1 / 2 When the thickness is 8mm, the flow conductivity of the artificial seam net is 2500m 2 ·mD 1 / 2, the conductivity of the artificial seam network showed a downward trend (e.g. Figure 6 shown).

[0060] (7) After increasing the gas well production (changing the production system and opening a larger nozzle), the bottom hole production pressure difference increases, the stress sensitivity damage degree of the reservoir increases, and the conductivity of the artificial fracture (AK 1 / 2 ) shows a gradual downward trend. At the same time, after the gas well production is improved, the cluster efficiency shows an upward trend, especially for the liquid-prone section (the horizontal section between the downward steep-angle section and the upward steep-angle section). Therefore, a "nozzle-artificial fracture conductivity-cluster efficiency" relationship curve is drawn, with the nozzle as the horizontal coordinate, and the artificial fracture conductivity and cluster efficiency as the vertical coordinates. The nozzle and artificial fracture conductivity curves, and the nozzle and cluster efficiency relationship curves are established respectively. The intersection of the two curves is defined as a reasonable nozzle, which is the optimal production system that takes into account both fracture conductivity and cluster efficiency. Under different nozzle conditions, the intersection point of the cluster efficiency and artificial fracture network conductivity of the example well is 6.8mm (such as Figure 7 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, wherein the memory stores a computer program, and when the processor executes the computer program, the method for determining the optimal nozzle of a shale gas well based on dynamic monitoring in embodiment 1 is implemented. The computer program may be in source code form, object code form, 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, which, when executed by a processor, implements the method for determining the optimal nozzle of a shale gas well based on dynamic monitoring in Embodiment 1. The computer program may be in source code form, object code form, executable file, or some intermediate form, etc. The storage medium includes: any entity or device capable of carrying computer program code, recording medium, computer memory, read-only memory (ROM), random access memory (RAM), electric carrier signal, telecommunication signal, and software distribution medium, etc. It should be noted that the content contained in the storage medium may be appropriately increased or decreased according to the requirements of legislation and patent practice in the jurisdiction. For example, in some jurisdictions, according to legislation and patent practice, the storage medium does not include electric carrier signals and telecommunication signals.

[0067] It should be noted that, for the aforementioned method embodiments, for the sake of simplicity of description, they are expressed as a series of action combinations, but those skilled in the art should be aware that the present application is not limited by the order of the actions described, because according to the present application, certain steps can be performed in other orders or simultaneously. Secondly, those skilled in the art should also be aware that the embodiments described in the specification are all preferred embodiments, and the actions and modules involved are not necessarily required by the present application.

Claims

1. A method for determining the best nozzle for a shale gas well based on dynamic monitoring, characterized in that: include: Use well deviation data to build a well trajectory model; Based on the inclination angle during drilling, and combined with the increase and decrease in inclination during horizontal drilling, multiple well trajectory change models are established; Distributed optical fiber monitoring is used to record the gas and water production of each perforation cluster in the horizontal section; Calculate the gas production ratio and water production ratio of each cluster; The cluster efficiency is determined based on the gas and water production of each cluster; Combining various well trajectory change models, the change of cluster efficiency at different nozzle sizes is obtained; Calculate the conductivity of artificial fractures during different nozzle adjustment processes and analyze the changing characteristics of the conductivity of artificial fractures; The relationship curves between nozzle size and artificial fracture conductivity and between nozzle size and cluster efficiency were established. The intersection of the two curves is the optimal nozzle size that takes into account both artificial fracture conductivity and cluster efficiency.

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

3. The method for determining the optimal shale gas well nozzle based on dynamic monitoring according to claim 1 is characterized in that: The establishment of multiple well trajectory change models includes: dividing the well trajectory change models into three situations: up-tilt drilling, down-tilt drilling and horizontal drilling according to the increase and decrease in inclination during the horizontal section drilling process; based on the size of the inclination angle during the drilling process, combined with the increase and decrease in inclination during the horizontal section drilling process, establishing multiple well trajectory change models including up-tilt large-angle and small-angle drilling sections, down-tilt large-angle and small-angle drilling sections and gentle drilling sections.

4. The method for determining the optimal shale gas well nozzle based on dynamic monitoring according to claim 1 is characterized in that: The method of using distributed optical fiber monitoring means to record the gas production and water production of each perforation cluster in the horizontal section includes: keeping the nozzle size unchanged, recording two sets of temperature, pressure and rotor speed data at different depths during the process of lowering the production logging instrument into 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 the data are recorded, determining the temperature, pressure and rotor speed curves under current conditions by a weighted average method, and then calculating the gas production and water production of each perforation cluster in the horizontal section by using a related temperature-pressure-rotor speed model; recording the gas production and water production of each perforation cluster in the horizontal section under multiple nozzle sizes.

5. The method for determining the optimal shale gas well nozzle based on dynamic monitoring according to claim 1, characterized in that: Determining the cluster efficiency according to the gas and water production of each cluster includes: defining pure gas production clusters, pure water production clusters and gas and water production clusters as effective clusters, and defining no gas and water production clusters as invalid clusters, and the cluster efficiency is the ratio of effective clusters to the total number of clusters.

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

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

8. The method for determining the best shale gas well nozzle based on dynamic monitoring according to claim 1, characterized in that: The establishing of the relationship curve between the nozzle size and the artificial fracture conductivity, and the relationship curve between the nozzle size and the cluster efficiency includes: taking the nozzle size as the horizontal coordinate, and the artificial fracture conductivity and the cluster efficiency as the vertical coordinates, respectively establishing the relationship curve between the nozzle size and the artificial fracture conductivity, and the relationship curve between the nozzle size and the cluster efficiency, and the intersection of the two curves is the optimal nozzle size that takes both the fracture conductivity and the cluster efficiency into consideration.

9. A computer device comprising a memory and a processor, wherein the memory stores a computer program, wherein: When the processor executes the computer program, the method for determining the optimal nozzle of a shale gas well based on dynamic monitoring as described in any one of claims 1 to 8 is implemented.

10. A computer-readable storage medium storing a computer program, characterized in that: When the computer program is executed by a processor, the method for determining the optimal nozzle of a shale gas well based on dynamic monitoring as described in any one of claims 1 to 8 is implemented.

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