A method for establishing a reasonable production allocation chart for gas wells in early development of a strong heterogeneous gas reservoir

Abstract

The application discloses a method for establishing a rational production allocation chart for gas wells in the early development stage of a strong heterogeneous gas reservoir, which comprises the following steps: step 1, calculating the development scale of high-quality reservoirs of multiple gas wells respectively; step 2, determining the production allocation system of the multiple gas wells with different stable production life by using a three-factor coupling method; and step 3, establishing the rational production allocation chart for the gas wells in the early development stage of the strong heterogeneous carbonate rock gas reservoir according to the results of step 1 and step 2. The development scale of high-quality reservoirs is calculated by using the seismic data body and the logging interpretation results to determine the planar distribution radius and the vertical thickness of the high-quality reservoirs, and the corresponding chart is established. The rational production scale of the gas wells with stable production for 5-10 years can be determined before the gas wells are put into production, which is not only convenient, efficient and fast, but also improves the accuracy of the evaluation of the production allocation scale of the gas wells.

Description

Technical Field

[0001] This invention belongs to the field of oil and gas exploration and development technology, and in particular relates to a method for establishing a reasonable production allocation chart for gas wells in the early stage of development of strongly heterogeneous gas reservoirs. Background Technology

[0002] Currently, in the early stages of production construction, production allocation for gas wells mainly relies on empirical methods. Production is allocated based on the unobstructed flow rate obtained from production capacity testing data, with a reasonable gas production rate uniformly set at 1 / 4 to 1 / 5 of the unobstructed flow rate. This method is suitable for gas wells in homogeneous gas reservoirs, but for strongly heterogeneous carbonate gas reservoirs, due to significant differences in reservoir characteristics and seepage models, the above-mentioned traditional empirical production allocation method cannot accurately obtain production allocation results. Other conventional production allocation methods include node analysis, gas production index method, and RTA instability analysis method. Among these, node analysis requires many parameters, has a complex calculation process, and cannot predict the stable production time. The gas production index method is heavily influenced by human factors and is prone to errors, also unable to predict the stable production time. The RTA instability analysis method obtains the reasonable production allocation and stable production years for gas wells by comparing prediction results, but this method ignores the pressure differences in various parts of the gas reservoir caused by uneven production, and therefore is only suitable for predicting the dynamics of gas reservoirs under balanced production methods.

[0003] In addition, document CN111911115A discloses a dynamic production allocation method for shale gas wells. The steps include: Step 1, constructing a single-well material balance equation for the shale gas well; Step 2, based on the actual reservoir properties of the shale gas well and combined with Step 1, establishing the actual single-well material balance equation and establishing a relationship function between cumulative gas production and formation pressure; Step 3, calculating the cumulative gas production based on the current formation pressure; Step 4, establishing a binomial production capacity equation through production capacity testing and allocating production based on unobstructed flow rate; Step 5, drawing a chart of cumulative gas production versus formation pressure and single-well production allocation based on the production allocation results obtained in Step 4; Step 6, using the chart to allocate production based on the cumulative gas production of different reservoirs in the shale gas well. This technology enables rapid production allocation. During the gas well production process, a reasonable production allocation can be quickly determined by looking up the chart based on the current cumulative gas production of the well. Furthermore, the production allocation process does not require consideration of time factors, making it very convenient, efficient, and practical. In practice, because shale gas reservoirs are generally dense and relatively heterogeneous, this technology can obtain a reasonable production allocation model for gas wells based solely on production data. However, for strongly heterogeneous carbonate gas reservoirs, due to drastic changes in reservoir properties and diverse seepage characteristics, this technology still cannot yield accurate and reasonable production allocation results. Summary of the Invention

[0004] The purpose of this invention is to overcome the aforementioned problems in the prior art and provide a method for establishing a reasonable production allocation chart for gas wells in the early stage of development of strongly heterogeneous gas reservoirs. This invention uses seismic data and well logging interpretation results to clarify the planar distribution radius and vertical thickness of high-quality reservoirs, calculates the development scale of high-quality reservoirs, and establishes a corresponding chart. Before the gas well is put into production, the reasonable production scale for 5 to 10 years of stable production can be determined. This method is not only convenient, efficient, and fast, but also improves the accuracy of gas well production allocation scale evaluation.

[0005] To achieve the above objectives, the technical solution adopted by the present invention is as follows:

[0006] A method for establishing a reasonable production allocation chart for gas wells in the early stage of development of a strongly heterogeneous gas reservoir, comprising the following steps:

[0007] Step 1: Calculate the scale of high-quality reservoir development for each of the multiple gas wells;

[0008] Step 2: Use the three-factor coupling method to determine the production allocation system for multiple gas wells with different stable production years;

[0009] Step 3: Based on the results of Step 1 and Step 2, establish a reasonable production allocation chart for early-stage gas wells in the development of strongly heterogeneous carbonate gas reservoirs.

[0010] In step 1, the development scale of the high-quality reservoir is calculated based on the planar distribution radius and vertical thickness of the high-quality reservoir in the gas well. The calculation method is as follows:

[0011] V =π×r 2 ×h(1)

[0012] In equation (1), h is the vertical thickness of the high-quality reservoir, m; r is the radius of the planar distribution of the high-quality reservoir, m; V For high-quality reservoir development scale, m 3 .

[0013] In step 1, a high-quality reservoir refers to a fractured-vuggy reservoir or a porous reservoir with a porosity greater than 3%.

[0014] In step 1, the number of gas wells must be at least 7.

[0015] In step 1, the method for obtaining the planar distribution radius of high-quality reservoirs is as follows:

[0016] First, by conducting earthquake prediction with different attributes, multi-attribute overlay analysis, and combining gas well imaging logging for detailed characterization, the planar distribution characteristics of fractured-vuggy and porous high-quality reservoirs are clarified.

[0017] Then, by extracting various seismic attributes using the facies method, and combining the distribution characteristics of sedimentary microfacies and karst dominant facies, the distribution morphology of different types of high-quality reservoirs is finely depicted, and the area of ​​different types of high-quality reservoirs is measured using mapping software.

[0018] Finally, the measured area of ​​the high-quality reservoir is represented as a circle, and the equivalent radius of the high-quality reservoir planar distribution can be obtained by inverse solving.

[0019] In step 1, the method for obtaining the vertical thickness of high-quality reservoirs is as follows:

[0020] Based on stratigraphic division, sedimentary facies research, and reservoir research, we comprehensively analyze the core, outcrop, and rock electrical characteristics, conduct classification and evaluation of different types of high-quality reservoirs, summarize the conventional logging response characteristics, imaging logging characteristics, seismic response models, sedimentary microfacies models, and karst models of each high-quality reservoir, and establish seismic-geological response models for different types of reservoirs.

[0021] Based on understanding the seismic-geological response patterns of different types of reservoirs, the vertical thickness of high-quality reservoirs for each type of fractured-vuggy and porous reservoir is determined through fine calibration using conventional logging and imaging logging.

[0022] In step 2, the method for determining the production allocation system for different stable production years of gas wells using the three-factor coupling method is as follows:

[0023] S1: A mathematical model of gas well production capacity and its variation law is established based on the coupling of three factors: gas well production capacity equation, wellbore flow equation, and well-controlled reserves equation. The established mathematical model is as follows:

[0024] (2)

[0025] (3)

[0026] (4)

[0027] In equations (2)-(4), Formation pressure during production, MPa; Wellhead oil pressure, MPa; P wf The bottom hole flowing pressure is in MPa. This represents the natural gas deviation coefficient under the original formation pressure conditions. This is the natural gas deviation coefficient under formation pressure conditions during the production period, and it is dimensionless. To accumulate gas production from the gas well, 10 8 m 3 ; For well-controlled reserves, 10 8 m 3 ; The relative density of the gas is dimensionless. The vertical depth of the middle of the producing layer is m; The inner diameter of the oil pipe is in cm; The coefficient of friction; Here, K represents the wellbore temperature. For the established production allocation system, 10 4 m 3 / d; A and B are the coefficients of the binomial equation for the production capacity equation; It is the original formation pressure, in MPa; Standard atmospheric pressure, MPa;

[0028] S2: According to the established production allocation system The wellhead oil pressure is obtained by solving the mathematical model to determine the required stable production years. Pressurize the wellhead oil Compared to the gas well's transmission pressure, if the wellhead oil pressure... If the pressure is less than the transmission pressure, then the gas well's production allocation system for that set time period. If the requirement of a stable production period is not met, the production allocation system should be redesigned. And recalculate the wellhead oil pressure until the wellhead oil pressure Until the pressure is equal to the transmission pressure; if the wellhead oil pressure If the pressure exceeds the transmission pressure, the set production allocation system will be increased. And recalculate the wellhead oil pressure until the wellhead oil pressure Until the pressure is equal to the input pressure.

[0029] In step 3, the method for establishing the reasonable production allocation chart for gas wells is as follows: a plane coordinate system is formed with the development scale of high-quality reservoirs and the production allocation system as the horizontal and vertical axes, respectively. The development scale of high-quality reservoirs of multiple gas wells obtained in step 1 and the production allocation system of multiple gas wells with different stable production years obtained in step 2 are added to the plane coordinate system to obtain a scatter plot. A binomial curve is obtained by regression from the scatter plot. Then, a production allocation model is obtained from the binomial curve. Finally, a reasonable production allocation chart for gas wells in the early stage of development of strongly heterogeneous carbonate gas reservoirs is drawn based on the production allocation model.

[0030] In step 3, if the stable production life of the gas wells is set to 5 years and 10 years respectively, then:

[0031] 5-Year Stable Production Allocation Model for Gas Wells:

[0032] =0.0004 V 2 +0.0987 V +4.8855 (5)

[0033] 10-Year Stable Production Allocation Model for Gas Wells:

[0034] =0.0005 V 2 +0.012 V +4.2716 (6)

[0035] In equations (5) and (6), To determine the appropriate production scale for gas wells with different stable production years; V For high-quality reservoir development scale, 10 6 m 3 .

[0036] The advantages of using this invention are:

[0037] 1. This invention primarily establishes a reasonable production allocation chart for early-stage gas well development in strongly heterogeneous carbonate gas reservoirs based on the development scale of high-quality reservoirs and the production allocation system for multiple gas wells with different stable production years. Research indicates that the reasonable production allocation system for gas wells in strongly heterogeneous gas reservoirs is determined by the development scale of high-quality reservoirs. Therefore, for a specific gas reservoir, a chart can be established using the development scale of high-quality reservoirs and the production allocation system for multiple gas wells with different stable production years. This allows for the determination of a reasonable production scale for 5-10 years before the gas wells are put into production. This method is not only convenient and efficient but also improves the accuracy of evaluating the production scale of gas wells in strongly heterogeneous carbonate gas reservoirs.

[0038] 2. Step 1 of this invention utilizes seismic data and well logging interpretation results to determine the planar distribution radius and vertical thickness of high-quality reservoirs, and calculates the development scale of high-quality reservoirs in gas wells. This method extends the characterization of high-quality reservoirs from a two-dimensional feature of "surface" to a three-dimensional feature of "volume," making it clearer and more vivid.

[0039] The three-factor coupling method used in step 2, constrained by the production capacity equation, wellbore flow equation, and well-controlled reserves equation, can predict the oil pressure decline of a gas well under a certain production level. By comparing the results, the reasonable production allocation and stable production years of the gas well can be obtained with higher accuracy.

[0040] 3. This invention establishes a mathematical model of gas well production capacity and its variation based on the coupling of three factors: the gas well's production capacity equation, the wellbore flow equation, and the well-controlled reserves equation. The model is then used to solve for the production allocation system and determine a reasonable production allocation system based on the transmission pressure. This method integrates factors related to gas well production capacity, wellbore flow, and reserves, providing a more comprehensive and accurate reflection of the reasonable production system for gas wells under different stable production years.

[0041] 4. This invention can directly determine a reasonable production scale for 5-10 years of stable production based on the development scale of high-quality gas well reservoirs, eliminating cumbersome calculation steps and significantly improving calculation accuracy and work efficiency. Simultaneously, it avoids the decline in stable gas well production capacity caused by unreasonable production systems implemented in the early stages of gas reservoir development due to objective factors such as lack of data and insufficient understanding, effectively supporting the rational and efficient development of gas reservoirs. Attached Figure Description

[0042] Figure 1 This is a flowchart of the present invention.

[0043] Figure 2 This is a diagram illustrating the rational production allocation of gas wells under different stable production years in this invention. Detailed Implementation

[0044] Example 1

[0045] This invention discloses a method for establishing a reasonable production allocation chart for gas wells in the early stages of development of strongly heterogeneous gas reservoirs. Once established, this chart allows for the determination of a reasonable production scale for a gas well to maintain stable production for 5-10 years before the well is put into production. It is not only convenient and efficient to use, but also improves the accuracy of gas well production scale evaluation. Specifically, as... Figure 1 As shown, it includes the following steps:

[0046] Step 1: Calculate the development scale of high-quality reservoirs for each of the multiple gas wells. High-quality reservoirs refer to fractured-vuggy or porous reservoirs with a porosity greater than 3%. Multiple gas wells refer to at least 7 wells, with 10-25 wells being preferred. The development scale of high-quality reservoirs for each well can be calculated based on the planar radius and vertical thickness of the high-quality reservoir. The methods for obtaining the planar radius and vertical thickness of the high-quality reservoir are as follows:

[0047] The method for obtaining the planar distribution radius of high-quality reservoirs is as follows:

[0048] First, by conducting earthquake prediction with different attributes, multi-attribute overlay analysis, and combining gas well imaging logging for detailed characterization, the planar distribution characteristics of fractured-vuggy and porous high-quality reservoirs are clarified.

[0049] Then, by extracting various seismic attributes using the facies method, and combining the distribution characteristics of sedimentary microfacies and karst dominant facies, the distribution morphology of different types of high-quality reservoirs is finely depicted, and the area of ​​different types of high-quality reservoirs is measured using mapping software.

[0050] Finally, the measured area of ​​the high-quality reservoir is represented as a circle, and the equivalent radius of the high-quality reservoir planar distribution can be obtained by inverse solving.

[0051] The method for obtaining the vertical thickness of high-quality reservoirs is as follows:

[0052] Based on stratigraphic division, sedimentary facies research, and reservoir research, we comprehensively analyze the core, outcrop, and rock electrical characteristics, conduct classification and evaluation of different types of high-quality reservoirs, summarize the conventional logging response characteristics, imaging logging characteristics, seismic response models, sedimentary microfacies models, and karst models of each high-quality reservoir, and establish seismic-geological response models for different types of reservoirs.

[0053] Based on understanding the seismic-geological response patterns of different types of reservoirs, the vertical thickness of high-quality reservoirs for each type of fractured-vuggy and porous reservoir is determined through fine calibration using conventional logging and imaging logging.

[0054] After obtaining the planar distribution radius and vertical thickness of the high-quality reservoir, the development scale of the high-quality reservoir in the gas well can be calculated based on these parameters. The calculation method is as follows:

[0055] V =π×r 2 ×h(1)

[0056] In equation (1), h is the vertical thickness of the high-quality reservoir, m; r is the radius of the planar distribution of the high-quality reservoir, m; V For high-quality reservoir development scale, m 3 .

[0057] Step 2: Use the three-factor coupling method to determine the production allocation system for multiple gas wells with different stable production years.

[0058] Specifically, the method for determining the production allocation system for gas wells with different stable production years using the three-factor coupling method is as follows:

[0059] S1: A mathematical model of gas well production capacity and its variation law is established based on the coupling of three factors: gas well production capacity equation, wellbore flow equation, and well-controlled reserves equation. The established mathematical model is as follows:

[0060] (2)

[0061] (3)

[0062] (4)

[0063] In equations (2)-(4), Formation pressure during production, MPa; Wellhead oil pressure, MPa; P wf The bottom hole flowing pressure is in MPa. This represents the natural gas deviation coefficient under the original formation pressure conditions. This is the natural gas deviation coefficient under formation pressure conditions during the production period, and it is dimensionless. To accumulate gas production from the gas well, 10 8 m 3 ; For well-controlled reserves, 10 8 m 3 ; The relative density of the gas is dimensionless. The vertical depth of the middle of the producing layer is m; The inner diameter of the oil pipe is in cm; The coefficient of friction; Here, K represents the wellbore temperature. For the established production allocation system, 10 4 m 3 / d; A and B are the coefficients of the binomial equation for the production capacity equation; It is the original formation pressure, in MPa; Standard atmospheric pressure, MPa.

[0064] S2: According to the established production allocation system The wellhead oil pressure is obtained by solving the mathematical model to determine the required stable production years. Pressurize the wellhead oil Compared to the gas well's transmission pressure, if the wellhead oil pressure... If the pressure is less than the transmission pressure, then the gas well's production allocation system for that set time period. If the requirement of a stable production period is not met, the production allocation system should be redesigned. And recalculate the wellhead oil pressure until the wellhead oil pressure Until the pressure is equal to the transmission pressure; if the wellhead oil pressure If the output pressure is greater than the transmission pressure, it indicates that the production allocation system q is in effect at this time. 配产 There is room for increasing production, which could allow for improvements to the established production allocation system. And recalculate the wellhead oil pressure until the wellhead oil pressure Until the pressure is equal to the input pressure.

[0065] This step requires clarification regarding the cumulative gas production of the gas well. Production allocation system can be set The well-controlled reserves are calculated based on the number of years of stable production. Given this, the current formation pressure during the production period can be calculated using equation (4). Similarly, since the production capacity equation of a gas well is determined, the production allocation system is established. From equation (2), the bottom hole flowing pressure P under this production allocation condition can be obtained. wf The bottom flow pressure P is... wf Substituting into equation (3), due to the relative density of the gas... Vertical depth in the middle of the producing layer Inner diameter of oil pipe Natural gas deviation coefficient under formation pressure conditions during production period , wellbore temperature Since the friction coefficient ƒ is known, the wellhead oil pressure can be solved by inverse problem. .

[0066] Step 3: Based on the results of Step 1 and Step 2, establish a reasonable production allocation chart for early-stage gas wells in the development of strongly heterogeneous carbonate gas reservoirs.

[0067] Specifically, the method for establishing a reasonable production allocation chart for gas wells is as follows: A plane coordinate system is formed with the development scale of high-quality reservoirs and the production allocation system as the x and y axes, respectively. The development scale of high-quality reservoirs for multiple gas wells obtained in step 1 and the production allocation systems for multiple gas wells with different stable production years obtained in step 2 are added to the plane coordinate system to obtain a scatter plot. A binomial curve is then derived from the scatter plot, and the production allocation model is obtained from the binomial curve. Wherein, the stable production years for gas wells are set to be 5 years and 10 years, then:

[0068] 5-Year Stable Production Allocation Model for Gas Wells:

[0069] =0.0004 V 2 +0.0987 V +4.8855 (5)

[0070] 10-Year Stable Production Allocation Model for Gas Wells:

[0071] =0.0005 V 2 +0.012 V +4.2716 (6)

[0072] In equations (5) and (6), To determine the appropriate production scale for gas wells with different stable production years; V For high-quality reservoir development scale, 10 6 m 3 .

[0073] Finally, based on the production allocation model, a reasonable production allocation chart for early-stage gas wells in highly heterogeneous carbonate gas reservoirs was drawn. The reasonable production allocation chart is as follows: Figure 2 As shown.

[0074] Step 2 of the present invention Defined as the established production allocation system, in step 3 The established production allocation system is defined as the reasonable production scale for gas wells in different stable production years. It should be noted that...

[0075] Step 2 The wellhead oil pressure under the corresponding production allocation system can be calculated using equations (2)-(4). The value is determined by comparing the wellhead oil pressure with the gas well's transmission pressure to determine whether the set production allocation system meets the requirements for stable production. Multiple values ​​can be set for this production allocation, and the maximum value that satisfies the stable production period is selected as the reasonable production allocation system. This refers to the reasonable production scale for gas wells with different stable production years in step 3. .

[0076] Example 2

[0077] This embodiment verifies the method described in Embodiment 1, as follows:

[0078] Taking well XX in block XX of the Southwest Oil and Gas Field as an example, this well was put into production on October 31, 2018. The initial oil pressure was 38.05 MPa, and the pressure was 20 × 10⁻⁶ MPa. 4 m 3 At a production scale of / d, the oil pressure cannot be maintained stably, decreasing by 2.03 MPa per month. The well's transmission pressure is 8.02 MPa. The monthly oil pressure decrease rate indicates that this gas well cannot operate at a rate of 20 × 10 4 m 3 The scale of production will remain stable for 5 to 10 years.

[0079] To address the above situation, the inventors employed the method described in this invention, utilizing seismic data and well logging interpretation results to characterize the high-quality reservoir in the well as having an equivalent radius of 500m and a vertical thickness of 13m, calculating the high-quality reservoir development scale to be 78.06 × 10⁻⁶ m. 6 m 3 Using the aforementioned reasonable production allocation chart, the reasonable production scale for this well to maintain stable production for 5-10 years can be determined to be 8-15 × 10⁻⁶. 4 m 3 / d.

[0080] In summary, this invention, through the commissioning of this production allocation system, enables gas wells to maintain reasonable production. It can determine the reasonable production scale for a gas well to maintain stable production for 5 to 10 years before the gas well is put into production. It is not only convenient, efficient and quick to use, but also improves the accuracy of gas well production allocation scale evaluation in highly heterogeneous carbonate gas reservoirs.

[0081] The above description is merely a specific embodiment of the present invention. Any feature disclosed in this specification may be replaced by other equivalent or similar features unless otherwise specified. All features or steps in the disclosed methods or processes may be combined in any way, except for mutually exclusive features and / or steps.

Claims

1. A method for establishing a reasonable production allocation chart for gas wells in the early stage of development of a strongly heterogeneous gas reservoir, characterized in that: Includes the following steps: Step 1: Calculate the scale of high-quality reservoir development for each of the multiple gas wells; Step 2: Use the three-factor coupling method to determine the production allocation system for multiple gas wells with different stable production years; Step 3: Based on the results of Step 1 and Step 2, establish a reasonable production allocation chart for early-stage gas wells in the development of strongly heterogeneous carbonate gas reservoirs; In step 1, the development scale of the high-quality reservoir is calculated based on the planar distribution radius and vertical thickness of the high-quality reservoir in the gas well. The calculation method is as follows: V =π×r 2 ×h（1） In equation (1), h is the vertical thickness of the high-quality reservoir, m; r is the radius of the planar distribution of the high-quality reservoir, m; V For high-quality reservoir development scale, m 3 ; In step 2, the method for determining the production allocation system for different stable production years of gas wells using the three-factor coupling method is as follows: S1: A mathematical model of gas well production capacity and its variation law is established based on the coupling of three factors: gas well production capacity equation, wellbore flow equation, and well-controlled reserves equation. The established mathematical model is as follows: （2） （3） （4） In equations (2)-(4), Formation pressure during production, MPa; Wellhead oil pressure, MPa; P wf The bottom hole flowing pressure is in MPa. This represents the natural gas deviation coefficient under the original formation pressure conditions. This is the natural gas deviation coefficient under formation pressure conditions during the production period, and it is dimensionless. To accumulate gas production from the gas well, 10 8 m 3 ; For well-controlled reserves, 10 8 m 3 ; The relative density of the gas is dimensionless. The vertical depth of the middle of the producing layer is m; The inner diameter of the oil pipe is in cm; The coefficient of friction; Here, K represents the wellbore temperature. For the established production allocation system, 10 4 m 3 / d; A and B are the coefficients of the binomial equation for the production capacity equation; It is the original formation pressure, in MPa; Standard atmospheric pressure, MPa; S2: According to the established production allocation system The wellhead oil pressure is obtained by solving the mathematical model to determine the required stable production years. Pressurize the wellhead oil Compared to the gas well's transmission pressure, if the wellhead oil pressure... If the pressure is less than the transmission pressure, then the gas well will implement a production allocation system within a set time period. If the requirement of a stable production period is not met, the production allocation system should be redesigned. And recalculate the wellhead oil pressure until the wellhead oil pressure Until the pressure is equal to the transmission pressure; if the wellhead oil pressure If the pressure exceeds the transmission pressure, the set production allocation system will be increased. And recalculate the wellhead oil pressure until the wellhead oil pressure Until the pressure is equal to the input pressure; In step 3, the method for establishing the reasonable production allocation chart for gas wells is as follows: a plane coordinate system is formed with the development scale of high-quality reservoirs and the production allocation system as the horizontal and vertical axes, respectively. The development scale of high-quality reservoirs of multiple gas wells obtained in step 1 and the production allocation system of multiple gas wells with different stable production years obtained in step 2 are added to the plane coordinate system to obtain a scatter plot. A binomial curve is obtained by regression from the scatter plot. Then, a production allocation model is obtained from the binomial curve. Finally, a reasonable production allocation chart for gas wells in the early stage of development of strongly heterogeneous carbonate gas reservoirs is drawn based on the production allocation model.

2. The method for establishing a reasonable production allocation chart for early-stage gas wells in the development of a strongly heterogeneous gas reservoir according to claim 1, characterized in that: In step 3, if the stable production life of the gas wells is set to 5 years and 10 years respectively, then: 5-Year Stable Production Allocation Model for Gas Wells: =0.0004 V 2 +0.0987 V +4.8855（5） 10-Year Stable Production Allocation Model for Gas Wells: =0.0005 V 2 +0.012 V +4.2716（6） In equations (5) and (6), To determine the appropriate production scale for gas wells with different stable production years; V For high-quality reservoir development scale, 10 6 m 3 .

3. The method for establishing a reasonable production allocation chart for early-stage gas wells in the development of a strongly heterogeneous gas reservoir according to claim 1, characterized in that: In step 1, a high-quality reservoir refers to a fractured-vuggy reservoir or a porous reservoir with a porosity greater than 3%.

4. The method for establishing a reasonable production allocation chart for early-stage gas wells in the development of a strongly heterogeneous gas reservoir according to claim 1, characterized in that: In step 1, the number of gas wells must be at least 7.

5. The method for establishing a reasonable production allocation chart for early-stage gas wells in the development of a strongly heterogeneous gas reservoir according to claim 1, characterized in that: In step 1, the method for obtaining the planar distribution radius of high-quality reservoirs is as follows: First, by conducting earthquake prediction with different attributes, multi-attribute overlay analysis, and combining gas well imaging logging for detailed characterization, the planar distribution characteristics of fractured-vuggy and porous high-quality reservoirs are clarified. Then, by extracting various seismic attributes using the facies method, and combining the distribution characteristics of sedimentary microfacies and karst dominant facies, the distribution morphology of different types of high-quality reservoirs is finely depicted, and the area of ​​different types of high-quality reservoirs is measured using mapping software. Finally, the measured area of ​​the high-quality reservoir is represented as a circle, and the equivalent radius of the high-quality reservoir planar distribution can be obtained by inverse solving.

6. The method for establishing a reasonable production allocation chart for early-stage gas wells in the development of a strongly heterogeneous gas reservoir according to claim 1, characterized in that: In step 1, the method for obtaining the vertical thickness of high-quality reservoirs is as follows: Based on stratigraphic division, sedimentary facies research and reservoir research, we comprehensively analyze the core, outcrop and rock electrical characteristics, carry out classification and evaluation of different types of high-quality reservoirs, summarize the conventional logging response characteristics, imaging logging characteristics, seismic response models, sedimentary microfacies models and karst models of each high-quality reservoir, and establish seismic-geological response models for different types of reservoirs. Based on understanding the seismic-geological response patterns of different types of reservoirs, the vertical thickness of high-quality reservoirs for each type of fractured-vuggy and porous reservoir is determined through fine calibration using conventional logging and imaging logging.

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