A deep high-pressure gas well reservoir reconstruction effect evaluation system and method

Abstract

This invention relates to the field of gas field development technology and discloses a system and method for evaluating the effect of deep high-pressure gas well reservoir stimulation. The system includes a data acquisition module, a data analysis module, and a comprehensive evaluation module. The data acquisition module collects various data parameters and sends them to the data analysis module. The data analysis module calculates the actual production capacity and ideal production capacity based on the multiple data collected by the acquisition module, and calculates the production capacity release rate based on the actual and ideal production capacities, sending it to the comprehensive evaluation module. The comprehensive evaluation module performs quantitative and qualitative classification based on the production capacity release rate. By using the percentage of the "actual production capacity" after stimulation to the "ideal production capacity," the system quantifies and classifies the reservoir stimulation effect, clarifies the applicability of the stimulation process, and evaluates the potential for further improvement in gas well production capacity.

Description

Technical Field

[0001] This invention relates to the field of gas field development technology, specifically to a system and method for evaluating the effect of deep high-pressure gas well reservoir stimulation. Background Technology

[0002] The Kuqa foreland area of ​​the Tarim Basin is rich in natural gas resources, but its geological conditions are extremely complex. The gas reservoirs are characterized by high pressure (105-136 MPa), high temperature (150-186℃), and ultra-deep depth (average 6800m, maximum 8038m), with thick salt-gypsum layers and low porosity and permeability of the reservoir matrix. The natural productivity of single wells is low, and reservoir stimulation is needed to increase the production of single wells. The stimulation technology for fractured tight sandstone reservoirs includes fracture network fracturing and fracture network acid fracturing. The core technology is to fully activate and utilize natural fractures to form a high-conductivity fracture network. The high-temperature, high-pressure, ultra-deep tight sandstone reservoirs in the Kuqa foreland area of ​​the Tarim Basin are unique in China and rare in the world. There is no mature development experience to draw on at home and abroad. Reservoir stimulation is an important means to improve productivity, but at present, there are problems such as unclear stimulation concepts and uncertain stimulation effects. Currently, the increase in unobstructed flow rate before and after reservoir stimulation is commonly used as the evaluation standard for reservoir stimulation effect. However, this method cannot objectively and reasonably evaluate the stimulation effect of "relieving reservoir damage and improving single-well productivity". For example, for wells with low natural productivity before stimulation, even if the unobstructed flow rate increases by 100% after stimulation, the post-stimulation productivity may still be classified as a low-yield and inefficient well. The evaluation of "100% increase in unobstructed flow rate" overestimates the effect of the stimulation process. Conversely, for wells with high natural productivity before stimulation, the increase in unobstructed flow rate after stimulation is often small due to the high baseline, thus underestimating the stimulation effect. This invention defines the production capacity of a gas well as the maximum production capacity of the well under conditions where there is no reservoir contamination and the high-speed non-Darcy flow is not affected, i.e., the "ideal production capacity". The effect of the modification is evaluated by the percentage of the "actual production capacity" after modification to the "ideal production capacity". Based on the evaluation results, the potential for repeated modification of the gas well is further judged. Summary of the Invention

[0003] (a) Technical problems to be solved To address the shortcomings of existing technologies, this invention provides a deep high-pressure gas well reservoir stimulation effect evaluation system. This system quantifies and grades the reservoir stimulation effect based on the percentage of "actual production capacity" to "ideal production capacity" after stimulation, clarifies the practicality of the stimulation process, assesses the potential for further production capacity enhancement in gas wells, and objectively evaluates the production-increasing effect of the stimulation process through the quantitative grading of "production release rate." This makes the effect evaluation of wells with significant differences in inherent geological conditions comparable. On the one hand, it objectively evaluates the practicality of the stimulation process; on the other hand, it accurately identifies wells with the potential for repeated stimulation to increase production capacity.

[0004] (II) Technical Solution To achieve the above objectives, the present invention provides the following technical solution: a system and method for evaluating the effect of deep high-pressure gas well reservoir stimulation, comprising a data acquisition module, a data analysis module, and a comprehensive evaluation module; The data acquisition module is used to collect various data parameters and send them to the data analysis module; The data analysis module calculates the actual production capacity based on multiple data points collected by the acquisition module. With ideal production capacity And based on actual production capacity With ideal production capacity Calculate the capacity release rate Send to the comprehensive evaluation module; The comprehensive evaluation module performs quantitative and qualitative assessments based on the capacity release rate.

[0005] Preferably, the data acquisition module forms an experimental measurement data set from the collected experimental measurement data. The experimental measurement data set includes: formation thickness, outer boundary pressure, bottom hole pressure, formation temperature, gas viscosity, gas deviation factor, inner zone permeability, outer zone permeability, and skin factor. The above data are obtained through experiments and field measurement and analysis.

[0006] Preferably, the data acquisition module forms a drilling data set from the collected drilling data, which includes: wellbore radius, inner zone radius, and outer zone radius, all of which are obtained from drilling records.

[0007] Preferably, the experimental measurement data set is labeled as: formation thickness. outer boundary pressure Bottom hole pressure Formation temperature Gas viscosity Gas deviation factor Inner Zone Penetration Rate Penetration rate in other areas Epidermal factors ; The drilling data set is labeled as follows: wellbore radius Inner radius Outer radius .

[0008] Preferably, the actual production capacity The calculation formula is:

[0009] In the above formula, It is a constant. Non-Darcy coefficient, This is a non-Darcy effect correction term. This represents the pressure difference between the two ends of the gas well. This indicates the additional flow resistance caused by drilling contamination, imperfect perforations, and the effect of high-velocity non-Darcy flow. This indicates the contribution of external permeability to external flow resistance.

[0010] Preferably, the non-Darcy coefficient The calculation formula is:

[0011] In the above formula, This represents an empirical constant used in calculations of non-Darcy flows. Represents the proportion of natural gas. 0.47 represents the reservoir permeability index. Represents porosity. An index representing porosity. This represents the thickness of the reservoir.

[0012] Preferably, the ideal production capacity The calculation method is as follows:

[0013] In the above formula, This represents the additional flow resistance caused by the permeability of the inner zone.

[0014] Preferably, the capacity release rate The calculation formula is: .

[0015] Preferably, when the capacity release rate If the result is greater than 60%, the quantitative grading and qualitative evaluation result is excellent, and the evaluation grade is Level 1. When the capacity release rate In 50% to 60% of cases, the quantitative grading and qualitative evaluation results were rated as "good," and the evaluation grade was Level II.

[0016] Preferably, when the capacity release rate In 40% to 50% of cases, the quantitative grading and qualitative assessment results were rated as medium, and the assessment grading was level three. When the capacity release rate When the result is less than 40%, the quantitative grading and qualitative evaluation result is poor, and the evaluation grade is level four.

[0017] A method for evaluating the effect of deep high-pressure gas well reservoir stimulation includes the following steps: Multiple experimental measurement data were collected from the modified deep high-pressure gas well reservoir; The actual production capacity and ideal production capacity are calculated based on the collected data, and the capacity release rate is calculated based on the actual production capacity and ideal production capacity. The capacity release rate is used for quantitative grading and qualitative analysis.

[0018] Compared with existing technologies, this invention provides a system for evaluating the effect of deep high-pressure gas well reservoir stimulation, which has the following beneficial effects: This invention discloses a deep high-pressure gas well reservoir stimulation effect evaluation system. A data acquisition module collects multiple experimental measurement data of the stimulated deep high-pressure gas well reservoir and sends them to a data analysis module. The data analysis module calculates the actual production capacity and ideal production capacity based on the data collected by the acquisition module, and calculates the production capacity release rate based on the actual and ideal production capacities, sending this rate to a comprehensive evaluation module. By using the percentage of the stimulated "actual production capacity" to the "ideal production capacity," the system quantifies and grades the reservoir stimulation effect, clarifies the practicality of the stimulation process, and assesses the potential for further improvement in gas well production capacity.

[0019] This invention objectively evaluates the production-enhancing effect of the modification process by quantifying and classifying the "production release rate," making the effect assessment of wells with large differences in inherent geological conditions comparable. On the one hand, it objectively evaluates the practicality of the modification process, and on the other hand, it accurately identifies wells with the potential to be repeatedly modified to increase production.

[0020] This invention, in its deep high-pressure gas well reservoir stimulation effect evaluation system, calculates actual and ideal production capacity by comprehensively considering parameters such as formation thickness, outer boundary pressure, bottom hole pressure, gas viscosity, gas deviation factor, formation temperature, inner zone permeability, outer zone permeability, skin factor, wellbore radius, inner zone radius, outer zone radius, non-Darcy coefficient, and non-Darcy effect correction term. These parameters work together to accurately assess the production capacity of the gas well and calculate the production release rate. This not only improves the accuracy of reservoir stimulation effect evaluation but also provides crucial technical support for oil and gas field development. By calculating actual and ideal production capacity, the effectiveness of reservoir stimulation can be accurately understood, guiding subsequent production optimization and decision-making. This refined management approach helps improve production efficiency, reduce production costs, and ultimately achieve efficient utilization of oil and gas resources, providing strong technical support for oil and gas field development and ensuring the efficient development and sustainable utilization of oil and gas resources. Attached image description; Figure 1 This is a schematic diagram of the deep high-pressure gas well reservoir stimulation effect evaluation system in an embodiment of the present invention; Figure 2 This is a schematic cross-sectional view of the "radial composite" reservoir model of the modified production well in an embodiment of the present invention.

[0022] Figure 3 This is a schematic diagram of the double logarithmic curve interpretation of well A in an embodiment of the present invention.

[0023] Figure 4 This is a schematic diagram of the double logarithmic curve interpretation of well B in an embodiment of the present invention. Detailed Implementation

[0024] The technical solutions of the embodiments of the present invention will be clearly and completely described below with reference to the accompanying drawings. 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 are within the scope of protection of the present invention.

[0025] Please see Figure 1-2 A deep high-pressure gas well reservoir stimulation effect evaluation system includes a data acquisition module, a data analysis module and a comprehensive evaluation module; The data acquisition module is used to collect various data parameters and send them to the data analysis module; The data acquisition module will collect multiple experimental measurement data to form an experimental measurement data set, which includes: formation thickness, outer boundary pressure, bottom hole pressure, formation temperature, gas viscosity, gas deviation factor, inner zone permeability, outer zone permeability, and skin factor. The above data are obtained through experiments and field measurement and analysis. The data acquisition module combines multiple collected drilling data into a drilling data set, which includes: wellbore radius, inner zone radius, and outer zone radius. The above data is obtained from the drilling records. The experimental measurement data set is labeled as: formation thickness. outer boundary pressure Bottom hole pressure Formation temperature Gas viscosity Gas deviation factor Inner Zone Penetration Rate Penetration rate in other areas Epidermal factors ; The drilling dataset is labeled as: wellbore radius Inner radius Outer radius ; The data analysis module calculates the actual production capacity based on multiple data points collected by the acquisition module. With ideal production capacity And based on actual production capacity With ideal production capacity Calculate the capacity release rate Send to the comprehensive evaluation module; Actual production capacity The calculation formula is:

[0026] In the above formula, It is a constant. Non-Darcy coefficient, This is a non-Darcy effect correction term. This represents the pressure difference between the two ends of the gas well. This indicates the additional flow resistance caused by drilling contamination, imperfect perforations, and the effect of high-velocity non-Darcy flow. This indicates the contribution of external penetration rate to external flow resistance; Formation thickness directly affects the reservoir's reserves and is one of the fundamental parameters for assessing gas well productivity. Understanding formation thickness helps to more accurately estimate the recoverable resources in the reservoir. Outer boundary pressure refers to the pressure at the far end of the reservoir, reflecting the overall pressure state. By monitoring and calculating outer boundary pressure, the energy state of the reservoir can be determined, providing a basis for formulating reasonable extraction strategies. Bottomhole pressure is the actual pressure downhole during gas well production, directly affecting gas flow characteristics and productivity. Accurate measurement of bottomhole pressure is crucial for optimizing gas well production parameters. Formation temperature affects the physical properties of gases, such as density and viscosity, thus influencing their flowability in the reservoir. Understanding formation temperature helps to more accurately predict changes in gas well productivity. Gas viscosity is a physical quantity describing the magnitude of gas flow resistance; it is closely related to formation temperature and pressure. Understanding gas viscosity helps to assess gas flowability in the reservoir, providing a basis for selecting appropriate production enhancement measures. The gas deviation factor reflects the degree of deviation between actual and ideal gas and is a necessary consideration when calculating gas well productivity. One of the factors to consider is the gas deviation factor, which can improve the accuracy of gas well productivity calculation. Inner zone permeability refers to the permeability of the high-permeability zone (such as fracture zone) formed after fracturing. It directly affects the gas flow velocity and productivity contribution in the inner zone. Improving the inner zone permeability is one of the effective ways to increase gas well productivity. Outer zone permeability refers to the original formation permeability far from the wellbore. Although the outer zone permeability contributes less to the initial productivity of the gas well, it affects the long-term stable production capacity and final recovery rate of the gas well. Skin factor is a parameter that comprehensively reflects the degree of formation damage near the wellbore. Reducing the skin factor can reduce the flow resistance of gas near the wellbore, thereby improving the productivity and economic benefits of the gas well. These factors play a crucial role in the evaluation system of deep high-pressure gas well reservoir stimulation effect. They not only help to more accurately assess the actual productivity of the gas well, but also provide a scientific basis for formulating reasonable production enhancement measures and optimizing the exploitation strategy. By comprehensively considering these factors, we can have a more comprehensive understanding of the characteristics and potential of the reservoir, providing strong support for the efficient development of gas wells. Wellbore radius is one of the fundamental parameters in gas well design, directly impacting well productivity and economic efficiency. A larger wellbore radius typically means a larger gas production channel, which helps increase gas flow velocity and production. Optimizing the wellbore radius can reduce gas flow resistance within the wellbore, thereby increasing well productivity. Furthermore, a wellbore radius design can reduce drilling costs and operational difficulty, improving the overall economic efficiency of the gas well. The inner zone radius refers to the radius of the high-permeability zone (such as the fracture zone) formed after fracturing. It directly affects the gas flow characteristics and productivity contribution within the inner zone. A larger inner zone radius typically means higher permeability and better fluidity, helping to improve the initial productivity of the gas well. Increasing the inner zone radius can improve gas flow velocity and recovery rate within the inner zone, thus increasing well productivity. Additionally, a larger inner zone radius can reduce gas flow resistance in the near-wellbore zone, improving the long-term productivity of the gas well. Stable production capacity is determined by the outer zone radius, which refers to the original formation radius far from the wellbore area. Although the outer zone permeability contributes little to the initial production capacity of a gas well, it affects the long-term stable production capacity and ultimate recovery rate. A larger outer zone radius means more recoverable resources and a longer stable production period. By considering the influence of the outer zone radius, the long-term production capacity and economic benefits of a gas well can be assessed more accurately. At the same time, a reasonable outer zone radius design can also provide a scientific basis for formulating reasonable exploitation strategies, ensuring the long-term stable production and efficient development of gas wells. The wellbore radius, inner zone radius, and outer zone radius play a crucial role in the evaluation system of reservoir stimulation effects in deep high-pressure gas wells. They not only help to more accurately assess the actual production capacity of gas wells, but also provide a scientific basis for formulating reasonable production enhancement measures and optimizing exploitation strategies. By comprehensively considering these factors, the characteristics and potential of the reservoir can be understood more comprehensively, providing strong support for the efficient development of gas wells. Due to the influence of reservoir stimulation technology, the reservoir properties within the well control range of the gas well to be evaluated generally have radial composite characteristics. Based on this reservoir characteristic, this technology uses a radial composite reservoir gas well productivity formula that takes into account the effects of skin and high-speed non-Darcy flow caused by drilling contamination and imperfect perforation to evaluate the actual productivity of the gas well. Non-Darcy coefficient The calculation formula is:

[0027] In the above formula, This represents an empirical constant used in calculations of non-Darcy flows. Represents the proportion of natural gas. 0.47 represents the reservoir permeability index. Represents porosity. An index representing porosity. Represents the thickness of the reservoir; Ideal production capacity The calculation method is as follows:

[0028] In the above formula, The additional flow resistance resulting from the penetration rate in the inner zone, ideal capacity. The production capacity of the well-controlled reservoir of the gas well to be evaluated is assumed to be the maximum production capacity of the gas well under the condition that there is no reservoir contamination and the influence of high-speed non-Darcy flow. This patented technology obtains reservoir properties of production wells through methods such as pressure recovery testing, modern production decline analysis chart fitting, well logging, and experiments. Taking pressure recovery testing as an example, after the flowback rate of the gas well to be evaluated exceeds 100%, a pressure recovery test is conducted on the well according to industry standards. The test data is interpreted using existing well test interpretation software platforms such as Saphir. In the interpretation model, the reservoir model is selected as "radial composite" to obtain the inner zone radius, a parameter required for effect evaluation. Outer radius Inner zone penetration rate Penetration rate in other areas Epidermal factors : Capacity Utilization Rate The calculation formula is:

[0029] The comprehensive evaluation module performs quantitative and qualitative classifications based on capacity release rates, specifically as follows: When the capacity release rate If the result is greater than 60%, the quantitative grading and qualitative evaluation results are excellent, and the evaluation grade is Level 1. When the capacity release rate In 50% to 60% of cases, the quantitative grading and qualitative assessment results were good, and the assessment grade was level two. When the capacity release rate In 40% to 50% of cases, the quantitative grading and qualitative assessment results were medium, and the assessment grading was level three. When the capacity release rate When the result is less than 40%, the quantitative grading and qualitative assessment results are poor, and the assessment grading is level four. Among them, Class I wells have a significant effect on improving production capacity and the modification process is highly applicable and can be promoted and applied in the same region; Class II and Class III wells have the potential for optimization of modification process based on clear geological understanding; Class IV wells with poor modification effect can be regarded as potential wells and the feasibility analysis of repeated modification to improve gas well production capacity can be carried out. Reservoir Stimulation Effect Evaluation Grading Table

[0030] In the "radial composite" reservoir model, the reservoir properties in the inner zone have a significant impact on gas well productivity. Based on the assessment and classification, reservoirs with poor inner zone properties have greater potential for production improvement. On the one hand, increasing the perforation thickness can improve the inner zone permeability and thus reduce the impact of non-Darcy flow, thereby increasing productivity. On the other hand, repeated stimulation processes such as acidizing to reduce inner zone reservoir contamination and fracturing to improve inner zone permeability can be used to increase the gas well productivity release rate. By quantifying and classifying the "production release rate", the production improvement effect of the modification process can be objectively evaluated, making the effect assessment of wells with large differences in inherent geological conditions comparable. On the one hand, the practicality of the modification process can be objectively evaluated, and on the other hand, wells with the potential to be repeatedly modified to improve production can be accurately identified.

[0031] In another embodiment of the present invention, such as Figure 3 As shown, a method for evaluating the effect of deep high-pressure gas well reservoir stimulation is provided, including the following steps: Multiple experimental measurement data were collected from the modified deep high-pressure gas well reservoir; The actual production capacity and ideal production capacity are calculated based on the collected data, and the capacity release rate is calculated based on the actual production capacity and ideal production capacity. The capacity release rate is used for quantitative grading and qualitative analysis.

[0032] Example: A deep, high-pressure gas reservoir has a formation pressure of 115.73 MPa, a reservoir temperature of 401.65 K, a relative gas density of 0.65, a gas viscosity of 0.0495 cP, and a gas deviation factor of 1.9235. Two new wells were deployed in the same development formation. Based on drilling and logging data, combined with fracture and geomechanical characteristic analysis, different reservoir stimulation techniques were selected for the two wells to improve gas well productivity. Well A has a wellbore radius of 0.075 m, a reservoir perforation thickness of 30 m in the production section, and an average porosity of 6.87%, and was completed using acid fracturing. Well B has a wellbore radius of 0.075 m, a reservoir perforation thickness of 50 m in the production section, and an average porosity of 6.52%, and was stimulated using proppant fracturing. Both wells yielded industrial oil and gas flows during testing. Three months after production began, pressure recovery testing and monitoring were conducted on both wells under full gas reservoir shut-in conditions, and qualified pressure and temperature data were recorded. This technology was used to evaluate the reservoir stimulation effect, process practicality, and potential for repeated stimulation to increase production in wells A and B.

[0033] (1) The test data of Well A were interpreted using existing well test interpretation software platforms such as Saphir. The reservoir model in the interpretation model was selected as "radial composite". The relevant parameters for effect evaluation were obtained as follows:

[0034] (2) Using the same technical means, the test data of Well B were interpreted. The reservoir model in the interpretation model was set to "radial composite". The relevant parameters for effect evaluation were obtained as follows:

[0035] (3) Substitute the relevant parameters of the well test interpretation obtained in step (1) into formula (2) to calculate the "ideal production capacity" of 8.7725 million cubic meters per day without considering reservoir contamination and the influence of high-speed non-Darcy flow.

[0036] (4) Substitute the relevant parameters into the non-Darcy coefficients. In the calculation formula, the non-Darcy coefficients of well A are obtained as follows: .

[0037] (5) Substitute the relevant parameters obtained in steps (1) and (4) into the ideal production capacity. In calculation formula ①, the actual production capacity of well A under the influence of reservoir contamination and high-speed non-Darcy flow is 3.32 million cubic meters per day.

[0038] (6) Based on the calculation results of steps (3) and (5), the production release rate of well A is calculated to be 37.85%, which is less than 40%. The reservoir stimulation effect assessment is grade IV, indicating that the gas well has a low production release rate and poor stimulation and production improvement effect.

[0039] (7) Repeat steps (3) to (5) to obtain the "ideal production capacity" of well B as 9,759,800 cubic meters / day and the actual production capacity as 6,729,200 cubic meters / day. The production capacity release rate of well B is calculated to be 68.95%. The reservoir stimulation effect assessment is classified as Level II. The stimulation and production improvement effect is good and the design target of the scheme has been achieved.

[0040] (8) Comparing the production effects of wells A and B, under the same structural background and similar reservoir characteristics, the production release rate of well A is significantly lower. Based on the interpretation of relevant parameters from well tests in steps (1) and (2), it is recommended that well A consider two aspects to further improve its natural gas production capacity: first, increase the degree of reservoir opening and reduce the impact of non-Darcy flow in the inner zone; second, learn from the pressurized fracturing technology of well B to improve the permeability of the inner zone.

[0041] Although embodiments of the invention have been shown and described, it will be understood by those skilled in the art that various changes, modifications, substitutions and alterations can be made to these embodiments without departing from the principles and spirit of the invention, the scope of which is defined by the appended claims and their equivalents.

Claims

1. A system for evaluating the effect of deep high-pressure gas well reservoir stimulation, characterized in that: It includes a data acquisition module, a data analysis module, and a comprehensive evaluation module; The data acquisition module is used to collect multiple experimental measurement data of the modified deep high-pressure gas well reservoir and send them to the data analysis module. The data analysis module calculates the actual production capacity based on multiple data points collected by the acquisition module. With ideal production capacity And based on actual production capacity With ideal production capacity Calculate the capacity release rate Send to the comprehensive evaluation module; The comprehensive evaluation module performs quantitative and qualitative assessments based on the capacity release rate.

2. The deep high-pressure gas well reservoir stimulation effect evaluation system according to claim 1, characterized in that: The data acquisition module will collect multiple experimental measurement data to form an experimental measurement data set, which includes: formation thickness, outer boundary pressure, bottom hole pressure, formation temperature, gas viscosity, gas deviation factor, inner zone permeability, outer zone permeability, and skin factor. The above data are obtained through experiments and field measurement and analysis.

3. The deep high-pressure gas well reservoir stimulation effect evaluation system according to claim 1, characterized in that: The data acquisition module forms a drilling data set from multiple collected drilling data. The drilling data set includes: wellbore radius, inner zone radius, and outer zone radius. The above data are obtained from drilling records.

4. The deep high-pressure gas well reservoir stimulation effect evaluation system according to claim 3, characterized in that: The experimental measurement data set is labeled as: formation thickness. outer boundary pressure Bottom hole pressure Formation temperature Gas viscosity Gas deviation factor Inner Zone Penetration Rate Penetration rate in other areas Epidermal factors ; The drilling data set is labeled as follows: wellbore radius Inner radius Outer radius .

5. The deep high-pressure gas well reservoir stimulation effect evaluation system according to claim 4, characterized in that: The actual production capacity The calculation formula is: In the above formula, It is a constant. Non-Darcy coefficient, This is a non-Darcy effect correction term. This represents the pressure difference between the two ends of the gas well. This indicates the additional flow resistance caused by drilling contamination, imperfect perforations, and the effect of high-velocity non-Darcy flow. This indicates the contribution of external permeability to external flow resistance.

6. The deep high-pressure gas well reservoir stimulation effect evaluation system according to claim 5, characterized in that: The non-Darcy coefficient The calculation formula is: In the above formula, This represents an empirical constant used in calculations of non-Darcy flows. Represents the proportion of natural gas. 0.47 represents the reservoir permeability index. Represents porosity. An index representing porosity. This represents the thickness of the reservoir.

7. The deep high-pressure gas well reservoir stimulation effect evaluation system according to claim 4, characterized in that: The ideal production capacity The calculation method is as follows: In the above formula, This represents the additional flow resistance caused by the permeability of the inner zone.

8. The deep high-pressure gas well reservoir stimulation effect evaluation system according to claim 7, characterized in that: The capacity release rate The calculation formula is: 。 9. The deep high-pressure gas well reservoir stimulation effect evaluation system according to claim 8, characterized in that: When the capacity release rate If the result is greater than 60%, the quantitative grading and qualitative evaluation result is excellent, and the evaluation grade is Level 1. When the capacity release rate In 50% to 60% of cases, the quantitative grading and qualitative evaluation results were rated as "good," and the evaluation grade was Level II.

10. The deep high-pressure gas well reservoir stimulation effect evaluation system according to claim 8, characterized in that: When the capacity release rate In 40% to 50% of cases, the quantitative grading and qualitative assessment results were rated as medium, and the assessment grading was level three. When the capacity release rate When the result is less than 40%, the quantitative grading and qualitative evaluation result is poor, and the evaluation grade is level four.

11. A method for evaluating the effect of deep high-pressure gas well reservoir stimulation, characterized in that: Includes the following steps: Multiple experimental measurement data were collected from the modified deep high-pressure gas well reservoir; The actual production capacity and ideal production capacity are calculated based on the collected data, and the capacity release rate is calculated based on the actual production capacity and ideal production capacity. The capacity release rate is used for quantitative grading and qualitative analysis.

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