Gas well reasonable production allocation method and device, electronic equipment, storage medium and computer program product

Abstract

The embodiment of the invention discloses a gas well reasonable production allocation method and device, electronic equipment, a storage medium and a computer program product. The method comprises the steps that target reservoir physical property data of a gas well to be subjected to production allocation located in a target block and a target production allocation chart of the target block are obtained, and the target production allocation chart represents the corresponding relation between at least one alternative combination and at least one alternative production allocation parameter; the at least one alternative combination is obtained by permutation and combination of at least one alternative water invasion risk level, at least one alternative reservoir space type and at least one alternative reservoir type; determining a target combination from the at least one alternative combination according to the target reservoir physical property parameters; and according to the target combination and the target production allocation chart, determining a target production allocation parameter from the at least one alternative production allocation parameter, and according to the target production allocation parameter, determining a reasonable production allocation result of the gas well to be subjected to production allocation. According to the technical scheme, reasonable production allocation of the gas well can be rapidly and accurately achieved.

Description

Technical Field

[0001] The embodiments of the present invention relate to the field of gas reservoir development technology, and in particular to a method, apparatus, electronic equipment, storage medium and computer program product for rational production allocation of gas wells. Background Technology

[0002] my country has abundant marine carbonate oil and gas resources, which are an important source of future growth in the country's oil and gas reserves and production. Marine carbonate rocks in my country are mainly composed of natural gas, accounting for 74% of the country's natural gas resources and 86% of its proven reserves.

[0003] Marine carbonate matrix is ​​characterized by low porosity, low permeability, and well-developed dissolution cavities, along with extensive edge and bottom water features. Therefore, carbonate gas reservoir development faces high risks of water intrusion, severe water channeling, and a sharp decline in production after water intrusion, significantly hindering the economic viability of the reservoir. Proper well allocation in carbonate gas reservoirs is crucial for controlling water levels, stabilizing production, and maintaining a high recovery rate.

[0004] However, the current gas well production allocation method suffers from low allocation efficiency and poor accuracy, which urgently need to be addressed. Summary of the Invention

[0005] This invention provides a method, apparatus, electronic device, storage medium, and computer program product for rational production allocation of gas wells, which can quickly and accurately achieve rational production allocation of gas wells.

[0006] According to one aspect of the present invention, a method for rational production allocation of gas wells is provided, which may include: acquiring target reservoir physical property data of gas wells to be allocated in a target block and a target production allocation map of the target block, wherein the target production allocation map represents the correspondence between at least one alternative combination and at least one alternative production allocation parameter, the at least one alternative combination being obtained by arranging and combining at least one alternative water invasion risk level, at least one alternative reservoir space type and at least one alternative reservoir type; determining a target combination from at least one alternative combination based on the target reservoir physical property parameters; determining a target production allocation parameter from at least one alternative production allocation parameter based on the target combination and the target production allocation map, and determining the rational production allocation result of the gas wells to be allocated based on the target production allocation parameter.

[0007] According to another aspect of the present invention, a gas well rational production allocation device is provided, which may include: a target production allocation map acquisition module, used to acquire target reservoir physical property data of the gas well to be allocated in the target block and a target production allocation map of the target block, wherein the target production allocation map represents the correspondence between at least one alternative combination and at least one alternative production allocation parameter, and the at least one alternative combination is obtained by arranging and combining at least one alternative water invasion risk level, at least one alternative reservoir space type and at least one alternative reservoir type; a target combination determination module, used to determine a target combination from at least one alternative combination according to the target reservoir physical property parameters; and a rational production allocation result determination module, used to determine the target production parameter from at least one alternative production parameter according to the target combination and the target production allocation map, and determine the rational production allocation result of the gas well to be allocated according to the target production parameter.

[0008] According to another aspect of the present invention, an electronic device is provided, which may include: at least one processor; and a memory communicatively connected to the at least one processor; wherein the memory stores a computer program executable by the at least one processor, the computer program being executed by the at least one processor to implement the gas well rational production allocation method provided in any embodiment of the present invention when executed by the at least one processor.

[0009] According to another aspect of the present invention, a computer-readable storage medium is provided having computer instructions stored thereon, which are used to cause a processor to execute and implement the gas well rational production allocation method provided in any embodiment of the present invention.

[0010] According to another aspect of the present invention, a computer program product is provided, comprising a computer program that, when executed by a processor, implements the gas well rational production allocation method provided in any embodiment of the present invention.

[0011] The technical solution of this invention involves acquiring target reservoir physical property data of the gas wells to be produced in the target block and a target production allocation map of the target block. The target production allocation map represents the correspondence between at least one alternative combination and at least one alternative production allocation parameter. The at least one alternative combination is obtained by arranging and combining at least one alternative water invasion risk level, at least one alternative reservoir space type, and at least one alternative reservoir type to obtain a target production allocation map from which a target combination can be determined. Based on the target reservoir physical property parameters, a target combination is determined from the at least one alternative combination to determine the alternative water invasion risk level, alternative reservoir space type, and alternative reservoir type corresponding to the target combination of the gas wells to be produced. Based on the target combination and the target production allocation map, target production parameters are determined from the at least one alternative production allocation parameter, and based on the target production allocation parameters, a reasonable production allocation result for the gas wells to be produced is determined, thus achieving the determination of a reasonable production allocation result. The above technical solution, by systematically considering the target production allocation chart of alternative water invasion risk level, alternative reservoir space type and alternative reservoir type, can improve the accuracy and reliability of rational production allocation of gas wells. Based on the target combination and target production allocation chart, the target production allocation parameter can be determined from at least one alternative production allocation parameter, so as to achieve rational production allocation of gas wells quickly and accurately without complicated calculations.

[0012] It should be understood that the description in this section is not intended to identify key or important features of the embodiments of the present invention, nor is it intended to limit the scope of the invention. Other features of the invention will become readily apparent from the following description. Attached Figure Description

[0013] To more clearly illustrate the technical solutions in the embodiments of the present invention, the accompanying drawings used in the description of the embodiments will be briefly introduced below. Obviously, the accompanying drawings described below are only some embodiments of the present invention. For those skilled in the art, other drawings can be obtained based on these drawings without creative effort.

[0014] Figure 1 This is a flowchart of a method for rational production allocation of gas wells according to an embodiment of the present invention;

[0015] Figure 2 This is a flowchart of another method for rational gas well production allocation provided by an embodiment of the present invention;

[0016] Figure 3 This is a flowchart of another method for rational production allocation of gas wells provided according to an embodiment of the present invention;

[0017] Figure 4 This is an example diagram of a first three-dimensional layout in another gas well rational production allocation method provided by an embodiment of the present invention;

[0018] Figure 5 This is an example diagram of a second three-dimensional layout in another gas well rational production allocation method provided by an embodiment of the present invention;

[0019] Figure 6 This is a flowchart of an optional example of another gas well rational production allocation method provided by an embodiment of the present invention;

[0020] Figure 7 This is a structural block diagram of a gas well rational production allocation device provided according to an embodiment of the present invention;

[0021] Figure 8 This is a schematic diagram of the structure of an electronic device for implementing the gas well rational production allocation method of the present invention. Detailed Implementation

[0022] To enable those skilled in the art to better understand the present invention, the technical solutions of the present invention will be clearly and completely described below with reference to the accompanying drawings of the embodiments of the present invention. Obviously, the described embodiments are only some embodiments of the present invention, and not all embodiments. Based on the embodiments of the present invention, all other embodiments obtained by those skilled in the art without creative effort should fall within the scope of protection of the present invention.

[0023] It should be noted that the terms "first," "second," etc., in the specification, claims, and accompanying drawings of this invention are used to distinguish similar objects and are not necessarily used to describe a specific order or sequence. It should be understood that such data can be interchanged where appropriate so that embodiments of the invention described herein can be implemented in orders other than those illustrated or described herein. The same applies to "target," "original," etc., and will not be repeated here. Furthermore, the terms "comprising" and "having," and any variations thereof, are intended to cover non-exclusive inclusion; for example, a process, method, system, product, or apparatus that comprises a series of steps or units is not necessarily limited to those steps or units explicitly listed, but may include other steps or units not explicitly listed or inherent to such processes, methods, products, or apparatus.

[0024] Before introducing the embodiments of the present invention, the implementation process of the current reasonable gas well production allocation scheme and the reasons for its problems such as low production allocation efficiency and low accuracy will be explained by way of example, so as to better understand why the scheme proposed in the embodiments of the present invention can quickly and accurately achieve reasonable gas well production allocation.

[0025] For example, in the production and development of gas wells in carbonate rocks, if the production allocation of the gas well is too low, the gas flow rate is slow and it is impossible to carry the liquid in the wellbore to the surface, resulting in liquid accumulation at the bottom of the well. At the same time, low production allocation will also lead to problems such as long gas well production cycle and poor economic benefits. If the production allocation of the gas well is too high, it is easy to lead to problems such as large production pressure difference at the bottom of the well, rapid decline in production capacity, and short stable production period. Therefore, by studying the reasonable production allocation of gas wells, it is possible to effectively avoid the gas-liquid slippage effect in the reservoir caused by excessive production pressure difference while ensuring economic benefits. However, current traditional production allocation methods mainly employ empirical determination methods, production capacity equation calculations based on reservoir engineering theory, and coupled optimization methods based on node analysis. For example, a dynamic production allocation method for tight sandstone gas reservoirs establishes a model of the relationship between single-well production allocation and water breakthrough time by determining the water intrusion rate and single-well production allocation relationship model, thereby determining the dynamic production output of gas wells at different structural locations. Another example is a gas well optimization production allocation method that uses the critical liquid-carrying flow rate, the critical flow rate of gas wells with edge and bottom water, the unobstructed flow rate of gas wells, the lower limit of the annual effective production days, the upper limit of the annual effective production days, the formation pressure of gas wells, the average formation pressure of gas wells, and the annual planned gas production of the reservoir as constraints to determine the optimal solution for the annual production time and daily production output of gas wells. Yet another example is a dynamic production allocation method for shale gas wells that constructs a single-well material balance equation for shale gas wells and establishes a relationship function between cumulative gas production and formation pressure based on the relevant reservoir properties of actual shale gas wells, ultimately forming a chart of cumulative gas production, formation pressure, and single-well production allocation. However, the above methods are all based on theoretical or empirical methods and do not take into account the heterogeneity of actual reservoirs and reservoir geological characteristics (including water energy and interlayers, etc.). They have drawbacks such as large calculation errors and low reliability. At the same time, the above methods lack the systematic formation of production allocation charts for carbonate edge-bottom water gas reservoirs and lack the universality of gas reservoir production allocation charts, making it difficult to guide field production work. Therefore, the current gas well production allocation methods have low efficiency and low accuracy.

[0026] To address this, the embodiments of the present invention, by systematically considering the target production allocation charts of alternative water intrusion risk levels, alternative reservoir space types, and alternative reservoir types, can improve the accuracy and reliability of rational gas well production allocation. Based on the target combination and the target production allocation chart, the target production allocation parameter is determined from at least one alternative production allocation parameter, achieving rational gas well production allocation quickly and accurately without complex calculations. This will be described in detail below.

[0027] Figure 1 This is a flowchart of a gas well rational production allocation method provided in an embodiment of the present invention. This embodiment is applicable to the rational production allocation of gas wells. The method can be executed by the gas well rational production allocation device provided in this embodiment of the present invention. This device can be implemented by software and / or hardware, and can be integrated into an electronic device, which can be various user terminals or servers.

[0028] See Figure 1 The method of this invention specifically includes the following steps:

[0029] S110. Obtain the target reservoir physical property data of the gas wells to be allocated to production in the target block and the target production allocation map of the target block. The target production allocation map represents the correspondence between at least one alternative combination and at least one alternative production allocation parameter. The at least one alternative combination is obtained by arranging and combining at least one alternative water invasion risk level, at least one alternative reservoir space type and at least one alternative reservoir type.

[0030] The target block is the area where the gas wells to be allocated production are located. The gas wells to be allocated production are the gas wells for which reasonable production allocation is to be carried out. Target reservoir physical property data are the physical property parameters of the reservoir in the gas wells to be allocated production; these parameters may include, for example, at least one of the following: porosity, permeability, displacement pressure, median pressure, maximum pore throat radius, median pore throat radius, fracture development type, vulcanization development type, fracture development degree, water layer thickness, gas-water contact relationship, reservoir thickness, and initial unobstructed flow rate. The target production allocation chart is a tool used to assess, predict, and allocate production performance of gas wells in the target block. The alternative combination includes a set of alternative water invasion risk levels, alternative reservoir space types, and alternative reservoir types. Alternative production allocation parameters are production parameters that are chosen as target production allocation parameters; alternative production allocation parameters may include, for example, alternative production allocation coefficients. Target production allocation parameters are parameters used to rationally allocate production from gas wells to be produced; target production allocation parameters may be, for example, target production allocation coefficients or rational production output of gas wells.

[0031] It should be noted that the alternative water intrusion risk level is the water intrusion risk level that is selected as the target water intrusion risk level in the target combination; the alternative water intrusion risk level can be, for example, a low-risk area, a medium-risk area, or a high-risk area, etc.; the water intrusion risk level mentioned in the embodiments of this invention is a level obtained by quantitatively assessing the degree of risk of water intrusion that may occur during the development of oil and gas fields. The alternative reservoir space type is the reservoir space type that is selected as the target reservoir space type in the target combination; the alternative reservoir space type can be, for example, a fracture-void type, a fracture-pore type, a void type, or a porous type, etc.; the reservoir space type mentioned in the embodiments of this invention is the spatial form in which fluids can be stored and flow in oil and gas reservoirs. The alternative reservoir type is the reservoir type that is selected as the target reservoir type in the target combination; the alternative reservoir type can be, for example, a Class I reservoir, a Class II reservoir, or a Class III reservoir, etc.; the reservoir type mentioned in the embodiments of this invention is a type obtained by classifying underground oil and gas reservoirs according to geological characteristics and physical properties.

[0032] In embodiments of the present invention, for example, at least one candidate water intrusion risk level, at least one candidate reservoir space type, and at least one candidate reservoir type can be predetermined. These candidate water intrusion risk levels, reservoir space types, and reservoir types can be arranged and combined to obtain at least one non-repeating candidate combination comprising one candidate water intrusion risk level, one candidate reservoir space type, and one candidate reservoir type. In embodiments of the present invention, the source and determination method of the at least one candidate combination are not specifically limited.

[0033] In this embodiment of the invention, the target production allocation diagram represents the correspondence between at least one alternative combination and at least one alternative production allocation parameter. For each alternative combination, the alternative combination may correspond to one alternative production allocation parameter. In this embodiment of the invention, the target production allocation diagram may be obtained experimentally for a target block or pre-set according to requirements; no specific limitations are imposed here.

[0034] S120. Based on the target reservoir physical property parameters, determine the target combination from at least one alternative combination.

[0035] The target combination is the alternative combination corresponding to the gas producing well to be matched; the target combination may include, for example, the target water invasion risk level, the target reservoir space type, and the target reservoir type corresponding to the gas producing well to be matched.

[0036] In this embodiment of the invention, for example, the target water invasion risk level of the well to be paired with can be determined from at least one candidate water invasion risk level, the target reservoir space type of the well to be paired with can be determined from at least one candidate reservoir space type, and the target reservoir type of the well to be paired with can be determined from at least one candidate reservoir type. The candidate combination consisting of the target water invasion risk level, the target reservoir space type, and the target reservoir type from at least one candidate combination is then taken as the target combination. In this embodiment of the invention, the method of determining the target combination from at least one candidate combination based on the target reservoir property parameters is not specifically limited.

[0037] S130. Based on the target combination and the target production allocation chart, determine the target production allocation parameter from at least one alternative production allocation parameter, and determine the reasonable production allocation result of the gas well to be allocated based on the target production allocation parameter.

[0038] Among them, the result of reasonable production allocation is the result of reasonable production allocation of gas wells with production allocation requirements; the result of reasonable production allocation may be, for example, the target production allocation coefficient or the reasonable production output of gas wells.

[0039] In this embodiment of the invention, the target production parameter can be determined from at least one candidate production parameter in the target production drawing based on the correspondence between at least one candidate combination and at least one candidate production parameter. In this embodiment of the invention, the method for determining the target production parameter from at least one candidate production parameter based on the target combination and the target production drawing is not specifically limited.

[0040] In this embodiment of the invention, for example, when the target production allocation parameter can be the target production allocation coefficient, the reasonable production allocation result of the gas well to be allocated is determined according to the target production allocation coefficient; when the target production allocation parameter is the reasonable production allocation amount of the gas well, the reasonable production allocation amount of the gas well is taken as the reasonable production allocation result of the gas well to be allocated. In this embodiment of the invention, there is no specific limitation on the method of determining the reasonable production allocation result of the gas well to be allocated according to the target production allocation parameter.

[0041] The technical solution of this invention involves acquiring target reservoir physical property data of the gas wells to be produced in the target block and a target production allocation map of the target block. The target production allocation map represents the correspondence between at least one alternative combination and at least one alternative production allocation parameter. The at least one alternative combination is obtained by arranging and combining at least one alternative water invasion risk level, at least one alternative reservoir space type, and at least one alternative reservoir type to obtain a target production allocation map from which a target combination can be determined. Based on the target reservoir physical property parameters, a target combination is determined from the at least one alternative combination to determine the alternative water invasion risk level, alternative reservoir space type, and alternative reservoir type corresponding to the target combination of the gas wells to be produced. Based on the target combination and the target production allocation map, target production parameters are determined from the at least one alternative production allocation parameter, and based on the target production allocation parameters, a reasonable production allocation result for the gas wells to be produced is determined, thus achieving the determination of a reasonable production allocation result. The above technical solution, by systematically considering the target production allocation chart of alternative water invasion risk level, alternative reservoir space type and alternative reservoir type, can improve the accuracy and reliability of rational production allocation of gas wells. Based on the target combination and target production allocation chart, the target production allocation parameter can be determined from at least one alternative production allocation parameter, so as to achieve rational production allocation of gas wells quickly and accurately without complicated calculations.

[0042] An optional technical solution is that the target production allocation parameter is the target production allocation coefficient; based on the target production allocation parameter, the reasonable production allocation result of the gas well to be allocated is determined, including: obtaining the unobstructed flow rate of the gas well to be allocated, and determining the reasonable production output of the gas well to be allocated based on the target production allocation coefficient and the unobstructed flow rate of the gas well; and taking the reasonable production output of the gas well as the reasonable production allocation result of the gas well to be allocated.

[0043] The target production allocation coefficient is the coefficient for the production output of the gas well to be allocated. The unobstructed flow rate of a gas well is the maximum natural gas production that a gas well can achieve under ideal conditions without any surface or downhole throttling devices. The reasonable production allocation for a gas well is the reasonable production target or production limit set for the gas well to be allocated during the oil and gas field development process.

[0044] For example, it can be based on formula Q s =Q / Q AoF Determine the reasonable production rate of the gas wells to be allocated to production, where Q s The target production coefficient is represented as a dimensionless parameter; Q is the reasonable production output of the gas well, with units of 10. 4 m 3 / d;Q AoF This refers to the unobstructed flow rate of the gas well, measured in units of 10. 4 m 3 / d. In this embodiment of the invention, the method for determining the reasonable production output of the gas well to be allocated based on the target production allocation coefficient and the unobstructed flow rate of the gas well is not specifically limited. It should be noted that in this embodiment of the invention, calculations related to the production allocation coefficient can be performed using formula Q. s =Q / Q AoF conduct.

[0045] In this embodiment of the invention, by using the target production allocation coefficient as the target production allocation parameter, and determining the reasonable production rate of the gas well to be allocated based on the target production allocation coefficient and the gas well unobstructed flow rate, and using the reasonable production rate of the gas well as the reasonable production allocation result of the gas well to be allocated, the problem of weak universality of reasonable production allocation of gas wells caused by the target production allocation parameter being the reasonable production rate of the gas well cannot be applied to gas wells to be allocated with different gas well unobstructed flow rates can be avoided, thereby improving the universality of reasonable production allocation of gas wells.

[0046] Figure 2 This is a flowchart of another method for rational gas well production allocation provided in this embodiment of the invention. This embodiment is based on and optimized from the above-described technical solutions. Optionally, in this embodiment, before obtaining the reservoir properties of the gas wells to be allocated in the target block and the target production allocation chart for the target block, the rational gas well production allocation method further includes: obtaining fracture and vulcanization development data, water intrusion data, and reservoir properties data of typical wells located in the target block; and determining the target production allocation chart based on the fracture and vulcanization development data, water intrusion data, and reservoir properties data of typical wells. The explanations of terms that are the same as or corresponding to those in the above embodiments are not repeated here.

[0047] See Figure 2 The method in this embodiment may specifically include the following steps:

[0048] S210. Obtain fracture and pore development data, water intrusion data, and reservoir property data of typical wells located in the target block.

[0049] Among them, a typical well is a representative gas well in the target block, and can also be considered a key well; there can be at least one typical well. Fracture and pore development data are measurement and analysis data related to the degree of fracture and pore development in the reservoir of the typical well; such data may include at least one of the following: reservoir porosity, permeability, displacement pressure, median pressure, maximum pore throat radius, median pore throat radius, fracture development type, and pore development type. Water intrusion data are data related to determining the extent of groundwater intrusion into oil and gas reservoirs; such data may include at least one of the following: degree of fracture development, water layer thickness, gas-water contact relationship, and geological characteristics. Typical well reservoir physical property data refers to the data on the physical property parameters of the reservoir in a typical well. Typical well reservoir physical property data may include at least one of the following: porosity, permeability, displacement pressure, median pressure, maximum pore throat radius, median pore throat radius, fracture development type, pore development type, fracture development degree, water layer thickness, gas-water contact relationship, gas-bearing layer thickness, initial formation pressure, gas-bearing height of the reservoir, gas-bearing area, original formation pressure characteristics, reservoir thickness, and initial unobstructed flow rate, etc.

[0050] In this embodiment of the invention, relatively complete wells can be identified as typical wells based on dynamic and static data such as well logging data, seismic data, and core sampling data in the target block. In this invention, the method for determining typical wells is not specifically limited.

[0051] In embodiments of the present invention, for example, exploration, measurement, or analysis can be performed on typical wells and target blocks to obtain fracture and vulcanization development data, water intrusion data, and reservoir property data of typical wells located in the target block. In embodiments of the present invention, no specific limitations are placed on the method of obtaining fracture and vulcanization development data, water intrusion data, and reservoir property data of typical wells located in the target block.

[0052] S220. Based on fracture and pore development data, water intrusion data, and typical well reservoir physical property data, determine the target production chart.

[0053] In this embodiment of the invention, for example, a target production chart can be determined using methods such as analysis and modeling based on fracture and porosity development data, water intrusion data, and typical well reservoir property data. In this embodiment of the invention, no specific limitations are placed on the method used to determine the target production chart based on fracture and porosity development data, water intrusion data, and typical well reservoir property data.

[0054] S230. Obtain the target reservoir physical property data of the gas wells to be allocated to production in the target block and the target production allocation map of the target block. The target production allocation map represents the correspondence between at least one alternative combination and at least one alternative production allocation parameter. The at least one alternative combination is obtained by arranging and combining at least one alternative water invasion risk level, at least one alternative reservoir space type and at least one alternative reservoir type.

[0055] S240. Based on the target reservoir physical property parameters, determine the target combination from at least one alternative combination.

[0056] S250. Based on the target combination and the target production allocation chart, determine the target production allocation parameter from at least one alternative production allocation parameter, and determine the reasonable production allocation result of the gas well to be allocated based on the target production allocation parameter.

[0057] The technical solution of this invention acquires fracture and vulcanization development data, water intrusion data, and reservoir property data of typical wells located in the target block. This allows the subsequent determination of the target production allocation chart to take into account the actual reservoir heterogeneity and reservoir geological characteristics. Based on the fracture and vulcanization development data, water intrusion data, and reservoir property data of typical wells, the target production allocation chart is determined. This technical solution enables the determination of the target chart to take into account the actual reservoir heterogeneity and reservoir geological characteristics, such as fracture and vulcanization development data, water intrusion data, and reservoir property data of typical wells, thereby achieving more rapid and accurate rational production allocation for gas wells.

[0058] An optional technical solution, before obtaining fracture and void development data of typical wells located in the target block, the method for rational production allocation of gas wells further includes: obtaining logging characteristics and thin-section test results of typical wells, and determining at least one fracture and void development type based on the thin-section test results, wherein the thin-section test results are obtained by conducting experiments on core thin sections, and the core thin sections are collected from typical wells; and using at least one fracture and void development type and logging characteristics as fracture and void development data.

[0059] Well logging characteristics refer to characteristic data obtained from measurements of typical wells. These characteristics may include at least one of the following: reservoir porosity, permeability, displacement pressure, median pressure, maximum pore throat radius, median pore throat radius, fracture development type, pore development type, fracture development degree, water layer thickness, gas-water contact relationship, reservoir thickness, and initial unobstructed flow rate. Thin section experimental results are obtained from experiments on core thin sections. Fracture and pore development type refers to the development type of fractures and pores in the reservoir of a typical well; at least one fracture and pore development type may include at least one of the following: vug, dissolution pore, intergranular pore, intragranular pore, interlayer fracture, dissolution fracture, tectonic fracture, associated dissolution pore, dissolution pore, pinhole, and residual intergranular pore. Core thin sections are thin sections obtained from typical wells.

[0060] In this embodiment of the invention, core samples from selected typical wells can be ground into thin core sections and solidified with resin or liquid adhesive under certain temperature and pressure. The porosity, throats, and fracture development of the thin core sections are then observed under a polarizing microscope to achieve thin core section experiments and obtain the experimental results. In this embodiment of the invention, no specific limitations are placed on the method for obtaining the logging characteristics and thin core experimental results of typical wells.

[0061] In this embodiment of the invention, for example, the porosity, throat, and fracture development degree and logging characteristics of the core thin section from the thin section experiment results can be summarized and integrated to obtain at least one fracture and pore development type. In this embodiment of the invention, no specific limitation is made on the method for determining at least one fracture and pore development type based on the thin section experiment results.

[0062] In this embodiment of the invention, based on the thin section experiment results, the type characteristics of at least one fracture and cavity development type, fracture and cavity size, and fracture and cavity pairing relationship can be determined. The thin section experiment results, at least one fracture and cavity development type, well logging characteristics, type characteristics of at least one fracture and cavity development type, fracture and cavity size, and fracture and cavity pairing relationship are used as fracture and cavity development data.

[0063] In this embodiment of the invention, by using at least one fracture and cavity development type and logging characteristics as fracture and cavity development data, the comprehensiveness of fracture and cavity development data can be improved, thereby making the target production chart determined subsequently based on the fracture and cavity development data more accurate.

[0064] Another optional technical solution, the rational production allocation method for gas wells, also includes: obtaining the geological characteristics of typical wells and static and dynamic data of the target block; determining the geological numerical simulation model of typical wells based on the geological characteristics, static and dynamic data; and determining the target production allocation chart based on fracture and vulcanization development data, water intrusion data, and reservoir property data of typical wells, including: determining the target production allocation chart based on the geological numerical simulation model, fracture and vulcanization development data, water intrusion data, and reservoir property data of typical wells.

[0065] Geological data refers to geological information about the area where typical wells are located; this data may include, for example, information on the structural characteristics of the strata corresponding to the typical wells. Static data refers to data obtained from the target block through exploration and surveying; static data may include, for example, at least one of the following: drilling data, well logging data, core data, seismic data such as 3D seismic fine structural interpretation results, drilling geological stratification data, and fault data. Dynamic data refers to data related to the dynamic changes in the target block; dynamic data may include, for example, at least one of the following: historical production data and core sampling data.

[0066] In this embodiment of the invention, for example, a geological numerical simulation model of a typical well can be determined based on geological characteristics, static data, and dynamic data using numerical simulation software. This embodiment of the invention does not impose specific limitations on the method used to determine the geological numerical simulation model of a typical well based on geological characteristics, static data, and dynamic data.

[0067] In this embodiment of the invention, no specific limitation is made on the method of determining the target production chart based on geological numerical simulation model, fracture and pore development data, water intrusion data, and typical well reservoir physical property data.

[0068] In this embodiment of the invention, a target production allocation chart is determined based on geological numerical simulation models, fracture and pore development data, water intrusion data, and typical well reservoir physical property data. This makes the target production allocation chart more consistent with the target block, thereby improving the accuracy of the reasonable production allocation results of the gas wells to be allocated in the determined target block.

[0069] Based on the above scheme, another optional technical solution is to determine the geological numerical simulation model of a typical well based on geological characteristics, static data, and dynamic data. This includes: determining the initial numerical simulation model of a typical well based on geological characteristics and static data; and updating the model permeability, gas-water interface, and energy magnitude of the second water body in the initial numerical simulation model based on dynamic data to obtain the geological numerical simulation model of the typical well.

[0070] The initial numerical simulation model is a pre-determined model where permeability, gas-water interface, and the energy magnitude of the second water body may not be entirely accurate. Model permeability is a quantified value representing the reservoir's ability to allow fluid passage, corresponding to a typical well in the geological numerical simulation model. The gas-water interface is the boundary between natural gas and groundwater as represented by the geological numerical simulation model. The energy magnitude of the second water body represents the pressure and driving capacity of the reservoir's water as represented by the geological numerical simulation model.

[0071] In this embodiment of the invention, for example, a comprehensive reservoir geology study can be conducted based on geological features and static data. Based on the study results, numerical simulation software is used to determine the initial numerical simulation models for each typical well, corresponding to detailed bedding planes and fault fractures. These initial numerical simulation models can characterize the three-dimensional spatial distribution and variation patterns of each stratum or reservoir in the target formation, as well as the combination and configuration relationships of faults. Based on dynamic data, the initial numerical simulation models are initialized and historically fitted using methods such as constant gas production fitting. Factors such as the height of the gas-water interface, the distribution pattern of interlayers, model permeability, the energy level of the second water body, and the water body type in the initial numerical simulation model at the single-well scale are fitted to update these parameters, ensuring that the geological numerical simulation model can reflect the production dynamics of the gas reservoir in the target block. In this embodiment of the invention, there are no specific limitations on the method of determining the initial numerical simulation model of a typical well based on geological characteristics and static data, or on the method of updating the model permeability, gas-water interface and energy magnitude of the second water body in the initial numerical simulation model based on dynamic data to obtain the geological numerical simulation model of a typical well.

[0072] It should be noted that the digital simulation software mentioned in the embodiments of this invention may include, but is not limited to, Schlumberger's Petrel geological modeling and interpretation software (Petrel Reservoir Exploration, Petrel RE), the Computer Modeling Group (CMG) reservoir numerical simulation software, the open-source reservoir numerical simulation software based on the MATrix LABoratory (MATLAB) program (MATLABReservoir Simulation Toolbox, MRST), and the high-performance simulator (Hi-Sim) reservoir numerical simulation software independently developed by China National Petroleum Corporation (CNPC). Commercial numerical simulation software is widely used in major oilfields in China and has advantages such as low learning cost, simple modeling method, fast simulation process and intuitive results.

[0073] In this embodiment of the invention, an initial numerical simulation model of a typical well is determined based on geological characteristics and static data. Then, based on dynamic data, the model permeability, gas-water interface, and energy magnitude of the second water body in the initial numerical simulation model are updated to obtain a geological numerical simulation model of the typical well. This allows the geological numerical simulation model to reflect the production dynamics of the gas reservoir in the target block, thereby making the target production allocation map more consistent with the target block. This further improves the accuracy of the reasonable production allocation results of the gas wells to be allocated in the determined target block.

[0074] Figure 3 This is a flowchart of another method for rational production allocation of gas wells provided in this embodiment of the invention. This embodiment is an optimization based on the above-mentioned technical solutions. In this embodiment, optionally, the target production allocation chart is determined according to fracture and void development data, water invasion data, and typical well reservoir property data, including: determining at least one candidate reservoir space type and a first classification standard corresponding to at least one candidate reservoir space type based on fracture and void development data; determining at least one candidate water invasion risk level and a second classification standard corresponding to at least one candidate water invasion risk level based on water invasion data; determining at least one candidate reservoir type and a third classification standard corresponding to at least one candidate reservoir type based on typical well reservoir property data; and determining the target production allocation chart based on at least one candidate reservoir space type, the first classification standard, at least one candidate water invasion risk level, the second classification standard, at least one candidate reservoir type, and the third classification standard. The explanations of terms that are the same as or corresponding to those in the above embodiments are not repeated here.

[0075] See Figure 3The method in this embodiment may specifically include the following steps:

[0076] S310. Obtain fracture and vulcanization development data, water intrusion data, and reservoir property data of typical wells located in the target block.

[0077] S320. Based on the fracture and void development data, determine at least one alternative reservoir space type and the first classification criteria corresponding to each alternative reservoir space type.

[0078] The first classification criterion is the criterion for classifying at least one alternative storage space type.

[0079] For example, the core thin section observation characteristics, at least one fracture-void development type, logging characteristics, type characteristics of at least one fracture-void development type, fracture-void size, and fracture-void combination relationship in the thin section experimental results of fracture-void development data can be summarized and integrated to determine at least one candidate reservoir space type as fracture-void type, fracture-void type, void type, and void type. The first classification criteria are shown in Table 1 below. In this embodiment of the invention, the method of determining at least one candidate reservoir space type and the corresponding first classification criteria based on fracture-void development data is not specifically limited.

[0080] Table 1 First Classification Criteria

[0081]

[0082]

[0083] S330. Based on the water intrusion data, determine at least one alternative water intrusion risk level and the second classification standard corresponding to each alternative water intrusion risk level.

[0084] The second classification criterion is the standard for classifying at least one alternative water intrusion risk level.

[0085] In this embodiment of the invention, no specific limitation is made on the method of determining at least one alternative water intrusion risk level and the second classification standard corresponding to each alternative water intrusion risk level based on water intrusion data.

[0086] S340. Based on typical well reservoir physical property data, determine at least one candidate reservoir type and the corresponding third classification criteria for each candidate reservoir type.

[0087] The third classification criterion is the standard for classifying at least one candidate reservoir type.

[0088] In embodiments of the present invention, for example, the gas-bearing layer thickness, initial unobstructed flow rate, and initial formation pressure in typical well reservoir physical property data can be analyzed to determine at least one candidate reservoir type and a third classification standard corresponding to each candidate reservoir type. Alternatively, the typical well reservoir physical property data can be quantitatively processed, and K-means clustering analysis can be used to classify the various factors in the typical well reservoir physical property data. At least two cluster centers are selected for each factor, and the boundary ranges of different factors are determined. Based on the distance between each parameter in the typical well reservoir physical property data and the cluster centers of its corresponding factors, at least one candidate reservoir type and a third classification standard corresponding to each candidate reservoir type are determined. Human experience is then used to adjust at least one candidate reservoir type and the third classification standard to make them more reasonable. In embodiments of the present invention, the method for determining at least one candidate reservoir type and a third classification standard corresponding to each candidate reservoir type based on typical well reservoir physical property data is not specifically limited.

[0089] For example, referring to Table 2, at least one candidate reservoir type can be determined based on typical well reservoir property data, and a third classification standard for each candidate reservoir type in terms of reservoir thickness and initial unobstructed flow rate.

[0090] Table 2 Third Classification Criteria

[0091]

[0092] S350. Determine the target production allocation chart based on at least one alternative reservoir space type, a first classification standard, at least one alternative water intrusion risk level, a second classification standard, at least one alternative reservoir type, and a third classification standard.

[0093] In this embodiment of the invention, for example, at least one alternative reservoir space type, a first classification standard, at least one alternative water intrusion risk level, a second classification standard, at least one alternative reservoir type, and a third classification standard can be summarized, integrated, and tested to obtain a target production allocation chart. In this embodiment of the invention, the method for determining the target production allocation chart based on at least one alternative reservoir space type, the first classification standard, at least one alternative water intrusion risk level, the second classification standard, at least one alternative reservoir type, and the third classification standard is not specifically limited.

[0094] S360. Obtain the target reservoir physical property data of the gas wells to be allocated to production in the target block and the target production allocation map of the target block. The target production allocation map represents the correspondence between at least one alternative combination and at least one alternative production allocation parameter. The at least one alternative combination is obtained by arranging and combining at least one alternative water invasion risk level, at least one alternative reservoir space type and at least one alternative reservoir type.

[0095] S370. Based on the target reservoir physical property parameters, determine the target combination from at least one alternative combination.

[0096] S380. Based on the target combination and the target production allocation chart, determine the target production allocation parameter from at least one alternative production allocation parameter, and determine the reasonable production allocation result of the gas well to be allocated based on the target production allocation parameter.

[0097] The technical solution of this invention standardizes the target production chart by determining at least one candidate reservoir space type and a first classification standard corresponding to each candidate reservoir space type based on fracture and porosity development data; standardizes the target production chart by determining at least one candidate reservoir space type and a first classification standard corresponding to each candidate reservoir space type based on water intrusion data; standardizes the target production chart by determining at least one candidate reservoir space type and a third classification standard corresponding to each candidate reservoir space type based on typical well reservoir property data; and standardizes the target production chart by determining the target production chart by determining at least one candidate reservoir space type, a first classification standard, a first candidate water intrusion risk level, a second classification standard, a first candidate reservoir type, and a third classification standard.

[0098] An optional technical solution involves determining a target production allocation map based on at least one alternative reservoir space type, a first classification standard, at least one alternative water intrusion risk level, a second classification standard, at least one alternative reservoir type, and a third classification standard. This includes: determining a first three-dimensional map corresponding to each of the at least one alternative reservoir space type, based on the first classification standard, at least one alternative water intrusion risk level, and the second classification standard. The first three-dimensional map represents the at least one alternative water intrusion risk level and... The correspondence between the candidate production allocation parameters and the gas reservoir recovery rate is defined, including at least one alternative production allocation parameter. Based on at least one alternative reservoir space type, a first classification standard, at least one alternative reservoir type, and a third classification standard, a second three-dimensional map corresponding to each of the at least one alternative reservoir space type is determined. The second three-dimensional map represents the correspondence between at least one alternative reservoir type, the candidate production allocation parameter, and the gas reservoir recovery rate under the alternative reservoir space type corresponding to the second three-dimensional map. A target production allocation map is determined based on the first three-dimensional map and the second three-dimensional map.

[0099] Among them, the production parameters to be selected are the production parameters to be considered as alternative production parameters. Gas reservoir recovery rate is the proportion of natural gas that can actually be extracted from a gas well in a target block relative to the original geological reserves of that gas reservoir.

[0100] In embodiments of the present invention, for example, at least one single-well-scale numerical simulation model can be constructed, which may be, for example, a geological numerical simulation model. For at least one numerical simulation model, orthogonal experimental design criteria are used to conduct corresponding numerical simulation studies. At least one alternative reservoir space type and at least one alternative water intrusion risk level are combined to establish a first three-dimensional chart showing the corresponding production parameters and gas reservoir recovery rate of gas wells corresponding to different numerical simulation models under different alternative water intrusion risk levels, for example, see [reference needed]. Figure 4 Using at least one numerical simulation model as a simulation sample, and through numerical simulation studies of at least one numerical simulation model, the different alternative water intrusion risk levels corresponding to each alternative reservoir space type are determined. Figure 4 (Types of water intrusion risk) and different candidate production parameters representing different levels of design production ( Figure 4 The gas recovery rate corresponding to each combination of gas reservoir optimization production coefficients (in the context of gas reservoir optimization production coefficients) is ( ). Figure 4The first three-dimensional map is obtained by combining different alternative water intrusion risk levels and different candidate production parameters to ensure the accuracy and repeatability of the simulation results in numerical simulation studies, while also ensuring the accuracy of the calculated gas reservoir recovery rate. In this embodiment of the invention, there is no specific limitation on the method of determining the first three-dimensional map corresponding to at least one alternative reservoir space type based on at least one alternative reservoir space type, a first classification standard, at least one alternative water intrusion risk level, and a second classification standard.

[0101] In this embodiment of the invention, at least one single-well-scale numerical simulation model can be constructed, such as a geological numerical simulation model. For each of the at least one numerical simulation model, orthogonal experimental design criteria are used to conduct corresponding numerical simulation studies. At least one candidate reservoir space type and at least one candidate reservoir type are combined to establish a second three-dimensional chart showing the corresponding production parameters and gas recovery rates of gas wells corresponding to different numerical simulation models under different candidate reservoir space types and different candidate reservoir types representing different levels of designed production. See, for example, [reference needed]. Figure 5 Using at least one numerical simulation model as a simulation sample, and through numerical simulation studies of at least one numerical simulation model, the different candidate reservoir types corresponding to each candidate reservoir space type are determined. Figure 5 (gas reservoir type) and different candidate production parameters ( Figure 5 The gas recovery rate corresponding to each combination of gas reservoir optimization production coefficients (in the context of gas reservoir optimization production coefficients) is ( ). Figure 5 The second three-dimensional map is obtained by combining different candidate reservoir types and different production parameters to ensure the accuracy and repeatability of the simulation results in numerical simulation studies, while also ensuring the accuracy of the calculated gas reservoir recovery rate. In this embodiment of the invention, there is no specific limitation on the method of determining the second three-dimensional map corresponding to at least one candidate reservoir space type based on at least one candidate reservoir space type, a first classification standard, at least one candidate reservoir type, and a third classification standard.

[0102] In this embodiment of the invention, since the first three-dimensional map represents the correspondence between at least one alternative water invasion risk level and the selected production allocation parameter and the gas reservoir recovery rate under the alternative reservoir space type corresponding to the first three-dimensional map, and the second three-dimensional map represents the correspondence between at least one alternative reservoir type and the selected production allocation parameter and the gas reservoir recovery rate under the alternative reservoir space type corresponding to the second three-dimensional map, the first three-dimensional map and the second three-dimensional map can be summarized to obtain at least one alternative combination. For each alternative combination, the highest gas reservoir recovery rate or the interval corresponding to the gas reservoir recovery rate of the alternative combination is determined. The production allocation coefficient or the interval corresponding to the highest gas reservoir recovery rate or the interval corresponding to the gas reservoir recovery rate of the alternative combination is used as the alternative production allocation parameter of the alternative combination layer, so that the target production allocation parameter determined from at least one alternative production allocation parameter can maximize the gas reservoir recovery rate, thereby finally determining the reasonable production allocation result of the recommended reasonable production allocation index range of the gas well to be allocated. In this embodiment of the invention, no specific limitation is made on the method of determining the target production pattern based on the first three-dimensional pattern and the second three-dimensional pattern.

[0103] In this embodiment of the invention, a target production allocation map is determined based on the first three-dimensional map and the second three-dimensional map, so that the target production allocation map can be combined with multiple indicators such as the alternative water invasion risk level, the alternative reservoir space type and the alternative reservoir type, so as to quickly and accurately achieve reasonable production allocation of gas wells without complicated calculations.

[0104] Another optional technical solution involves using water intrusion data that includes at least one of the following: the energy level of the first water body, the understanding of the gas-water relationship of the water body type, and the distribution pattern of interlayers. Based on the water intrusion data, at least one alternative water intrusion risk level and a second classification standard corresponding to each alternative water intrusion risk level are determined. This includes: conducting water intrusion risk analysis on typical wells based on at least one of the following: the energy level of the first water body, the understanding of the gas-water relationship of the water body type, and the distribution pattern of interlayers; and determining at least one alternative water intrusion risk level and a second classification standard corresponding to each alternative water intrusion risk level based on the obtained risk analysis results.

[0105] Among these, the energy magnitude of the first water body refers to the pressure and driving capacity of the reservoir water body as characterized by the geological numerical simulation model. The understanding of water body type and gas-water relationship refers to the understanding of the water body type and gas-water relationship in typical wells. The distribution pattern of interlayers refers to the distribution pattern of non-producing layers located between or within oil and gas layers. The risk analysis results are obtained by conducting risk analysis on at least one of the following: the energy magnitude of the first water body, the understanding of the water body type and gas-water relationship, and the distribution pattern of interlayers.

[0106] In this embodiment of the invention, for example, the three factors of energy magnitude of the first water body, understanding of the gas-water relationship of the water body type, and distribution morphology of interlayers can be quantitatively processed. K-means clustering analysis is then used to divide each factor, selecting at least two cluster centers for each factor and determining the boundary ranges for different factors. The risk analysis results are determined based on the distance between each parameter in the water intrusion data and the cluster centers of its corresponding factors. Based on the risk analysis results, at least one alternative water intrusion risk level and a second classification standard corresponding to each alternative water intrusion risk level are determined. The at least one alternative water intrusion risk level and the second classification standard are then adjusted manually based on experience to make them more reasonable. In this embodiment of the invention, the method of performing water intrusion risk analysis on typical wells based on at least one of the following factors—energy magnitude of the first water body, understanding of the gas-water relationship of the water body type, and distribution morphology of interlayers—and determining at least one alternative water intrusion risk level and a second classification standard corresponding to each alternative water intrusion risk level based on the obtained risk analysis results is not specifically limited.

[0107] For example, referring to Table 3, a water invasion risk analysis can be performed on a typical well based on at least one of the following: the energy level of the first water body, the water body type, the understanding of the gas-water relationship, and the distribution pattern of the interlayer. Based on the risk analysis results, at least one alternative water invasion risk level and a second classification standard corresponding to the alternative water invasion risk level in terms of fracture development degree, water layer thickness, gas-water contact relationship, and geological characteristics are determined.

[0108] Table 3 Second Classification Criteria

[0109]

[0110] In this embodiment of the invention, the risk analysis results obtained by performing water invasion risk analysis on a typical well based on at least one of the following: the energy level of the first water body, the understanding of the gas-water relationship of the water body type, and the distribution pattern of the interlayer, can determine at least one alternative water invasion risk level and a second classification standard corresponding to each alternative water invasion risk level. This can improve the accuracy of the determined at least one alternative water invasion risk level and the second classification standard in relation to the target block.

[0111] To better understand the technical solutions of the above embodiments of the present invention, an optional example is provided herein. For example, see... Figure 6Based on well logging characteristics, static data, dynamic data, and thin section test results, fracture and pore development data are determined, and based on this data, at least one candidate reservoir space type and a first classification standard are identified. Based on geological characteristics and static data, an initial numerical simulation model is determined, and based on dynamic data, the production parameters of typical wells are historically fitted to the initial numerical simulation model to obtain a geological numerical simulation model. Based on water invasion data such as the energy magnitude of the first water body, the understanding of water body type and gas-water relationship, and the distribution morphology of interlayers, at least one candidate water invasion risk level and a second classification standard are identified. Based on reservoir thickness, initial unobstructed flow rate, and formation pressure, typical well reservoir properties such as reservoir thickness, initial unobstructed flow rate, and formation pressure are identified, at least one candidate reservoir type and a third classification standard are identified. Based on at least one candidate reservoir space type, the first classification standard, and at least one candidate water body type, at least one candidate reservoir type and a third classification standard are identified. Based on the water intrusion risk level and the second classification standard, determine the first three-dimensional map corresponding to at least one candidate reservoir space type; based on at least one candidate reservoir space type, the first classification standard, at least one candidate reservoir type, and the third classification standard, determine the second three-dimensional map corresponding to at least one candidate reservoir space type; based on the first and second three-dimensional maps, determine the target production allocation map; based on the target reservoir physical properties, the water energy of the gas wells to be allocated, and the gas reservoir characteristics of the target block, determine the target water intrusion risk level, the target reservoir space type, and the target reservoir target production allocation map type; based on the target water intrusion risk level, the target reservoir space type, and the target reservoir type, find the target production allocation map to obtain the target production allocation parameters; and based on the target production allocation parameters, determine the reasonable production allocation range of the gas wells to be allocated as the reasonable production allocation result. The above-mentioned technical solution can quickly determine the reasonable production allocation of gas wells in carbonate gas reservoirs. Whether it is a new well or an old well, the reasonable production allocation can be quickly determined through the target reservoir physical property data. At the same time, it can eliminate the need to consider factors such as production time and incomplete gas well data in the process of finding reasonable production allocation. It has the advantages of high efficiency, accuracy and convenience, thereby enabling rapid optimization of single-well production allocation in carbonate gas reservoirs with different geological characteristics, and providing guidance for the efficient development of carbonate bottom water gas reservoirs.

[0112] Figure 7 This is a structural block diagram of a gas well rational production allocation device provided in an embodiment of the present invention. This device is used to execute the gas well rational production allocation method provided in any of the above embodiments. This device and the gas well rational production allocation method of the above embodiments belong to the same inventive concept. Details not described in detail in the embodiments of the gas well rational production allocation device can be found in the embodiments of the gas well rational production allocation method. See also... Figure 7 The device may specifically include: a target production pattern acquisition module 410, a target combination determination module 420, and a reasonable production result determination module 430.

[0113] The target production allocation map acquisition module 410 is used to acquire the target reservoir physical property data of the gas wells to be allocated to production in the target block and the target production allocation map of the target block. The target production allocation map represents the correspondence between at least one alternative combination and at least one alternative production allocation parameter. The at least one alternative combination is obtained by arranging and combining at least one alternative water invasion risk level, at least one alternative reservoir space type and at least one alternative reservoir type.

[0114] The target combination determination module 420 is used to determine a target combination from at least one alternative combination based on the target reservoir physical property parameters.

[0115] The module 430 for determining reasonable production allocation results is used to determine the target production allocation parameter from at least one alternative production allocation parameter based on the target combination and the target production allocation chart, and to determine the reasonable production allocation result of the gas well to be allocated based on the target production allocation parameter.

[0116] Optionally, the device may also include:

[0117] The typical well reservoir property data acquisition module is used to acquire fracture and vulcanization development data, water invasion data, and typical well reservoir property data of typical wells in the target block before acquiring the reservoir property parameters of the gas production wells to be matched and the target production chart of the target block.

[0118] The target production chart determination module is used to determine the target production chart based on fracture and porosity development data, water intrusion data, and typical well reservoir physical property data.

[0119] Optionally, based on the above-mentioned device, the target production pattern determination module includes:

[0120] The first classification standard determination submodule is used to determine at least one candidate reservoir space type and the first classification standard corresponding to each candidate reservoir space type based on fracture and void development data.

[0121] The second classification standard determination submodule is used to determine at least one alternative water intrusion risk level and the second classification standard corresponding to each alternative water intrusion risk level based on water intrusion data.

[0122] The third classification standard determination submodule is used to determine at least one candidate reservoir type and the third classification standard corresponding to each candidate reservoir type based on typical well reservoir physical property data.

[0123] The first target production allocation chart determination submodule is used to determine the target production allocation chart based on at least one alternative reservoir space type, a first classification standard, at least one alternative water intrusion risk level, a second classification standard, at least one alternative reservoir type, and a third classification standard.

[0124] Optionally, based on the above-mentioned device, the first target production drawing determination submodule includes:

[0125] The first three-dimensional map determination unit is used to determine the first three-dimensional map corresponding to at least one candidate reservoir space type based on at least one candidate reservoir space type, a first classification standard, at least one candidate water intrusion risk level, and a second classification standard. The first three-dimensional map represents the correspondence between at least one candidate water intrusion risk level and candidate production parameters and gas reservoir recovery rate under the candidate reservoir space type corresponding to the first three-dimensional map. The candidate production parameters include at least one candidate production parameter.

[0126] The second three-dimensional map determination unit is used to determine the second three-dimensional map corresponding to at least one candidate reservoir space type based on at least one candidate reservoir space type, a first division standard, at least one candidate reservoir type and a third division standard. The second three-dimensional map represents the correspondence between at least one candidate reservoir type and the selected production allocation parameter and the gas reservoir recovery rate under the candidate reservoir space type corresponding to the second three-dimensional map.

[0127] The target production layout determination unit is used to determine the target production layout based on the first three-dimensional layout and the second three-dimensional layout.

[0128] Optionally, based on the above-mentioned device, the water intrusion data includes at least one of the following: the energy level of the first water body, the water body type and the understanding of the gas-water relationship, and the distribution pattern of the interlayer.

[0129] The second division criterion determines the sub-modules, including:

[0130] The water invasion risk analysis unit is used to conduct water invasion risk analysis on typical wells based on at least one of the following: the energy size of the first water body, the water body type, the understanding of the gas-water relationship, and the distribution pattern of the interlayer.

[0131] The second classification standard determination unit is used to determine at least one alternative water intrusion risk level and the second classification standard corresponding to each alternative water intrusion risk level based on the obtained risk analysis results.

[0132] Optionally, based on the above-described apparatus, the apparatus may further include:

[0133] The type feature determination module is used to acquire the logging features and thin section test results of typical wells before acquiring fracture and void development data of typical wells located in the target block, and to determine at least one fracture and void development type based on the thin section test results. The thin section test results are obtained by conducting experiments on core thin sections, which are collected from typical wells.

[0134] Fracture and cavity development data is used as a module to include at least one fracture and cavity development type and logging characteristics as fracture and cavity development data.

[0135] Optionally, based on the above-described apparatus, the apparatus may further include:

[0136] The dynamic data acquisition module is used to acquire the geological characteristics of typical wells as well as static and dynamic data of the target block;

[0137] The geological numerical simulation model determination module is used to determine the geological numerical simulation model of a typical well based on geological characteristics, static data, and dynamic data.

[0138] The target production plan determination module includes:

[0139] The second target production chart determination submodule is used to determine the target production chart based on geological numerical simulation models, fracture and pore development data, water intrusion data, and typical well reservoir physical property data.

[0140] Optionally, based on the above-mentioned device, the geological numerical simulation model determination module includes:

[0141] The initial numerical simulation model determination submodule is used to determine the initial numerical simulation model for typical wells based on geological characteristics and static data.

[0142] The geological numerical simulation model obtains a sub-module, which is used to update the model permeability, gas-water interface and energy magnitude of the second water body in the initial numerical simulation model based on dynamic data, so as to obtain a geological numerical simulation model of a typical well.

[0143] Optionally, the target production allocation parameter is the target production allocation coefficient;

[0144] The module 430 for determining reasonable production allocation results includes:

[0145] The submodule for determining the reasonable production output of gas wells is used to obtain the unobstructed flow rate of the gas wells to be allocated production, and to determine the reasonable production output of the gas wells to be allocated production based on the target production allocation coefficient and the unobstructed flow rate of the gas wells.

[0146] The reasonable production allocation result is used as a submodule to use the reasonable production allocation result of the gas well as the reasonable production allocation result of the gas well to be allocated.

[0147] The gas well rational production allocation device provided in this embodiment of the invention acquires target reservoir physical property data and target production allocation map of the gas well to be allocated in the target block through a target production allocation map acquisition module. The target production allocation map represents the correspondence between at least one alternative combination and at least one alternative production allocation parameter. The at least one alternative combination is obtained by arranging and combining at least one alternative water invasion risk level, at least one alternative reservoir space type, and at least one alternative reservoir type to obtain a target production allocation map from which a target combination can be determined. A target combination determination module determines a target combination from the at least one alternative combination based on the target reservoir physical property parameters, thereby determining the alternative water invasion risk level, alternative reservoir space type, and alternative reservoir type corresponding to the target combination of the gas well to be allocated. A rational production allocation result determination module determines the target production parameter from the at least one alternative production parameter based on the target combination and the target production allocation map, and determines the rational production allocation result of the gas well to be allocated based on the target production parameter, thus realizing the determination of the rational production allocation result. The aforementioned device, by systematically considering the target production allocation chart of alternative water invasion risk levels, alternative reservoir space types, and alternative reservoir types, can improve the accuracy and reliability of rational production allocation for gas wells. Based on the target combination and the target production allocation chart, it can determine the target production allocation parameter from at least one alternative production allocation parameter, achieving rational production allocation for gas wells quickly and accurately without complex calculations.

[0148] The gas well rational production allocation device provided in the embodiments of the present invention can execute the gas well rational production allocation method provided in any embodiment of the present invention, and has the corresponding functional modules and beneficial effects of the method.

[0149] It is worth noting that in the embodiments of the above-mentioned gas well rational production allocation device, the various units and modules included are only divided according to functional logic, but are not limited to the above division, as long as the corresponding functions can be achieved; in addition, the specific names of each functional unit are only for easy differentiation and are not used to limit the scope of protection of the present invention.

[0150] Figure 8 A schematic diagram of an electronic device 10 that can be used to implement embodiments of the present invention is shown. The electronic device is intended to represent various forms of digital computers, such as laptop computers, desktop computers, workstations, personal digital assistants, servers, blade servers, mainframe computers, and other suitable computers. The electronic device can also represent various forms of mobile devices, such as personal digital processors, cellular phones, smartphones, wearable devices (e.g., helmets, glasses, watches, etc.), and other similar computing devices. The components shown herein, their connections and relationships, and their functions are merely illustrative and are not intended to limit the implementation of the invention described and / or claimed herein.

[0151] like Figure 8 As shown, the electronic device 10 includes at least one processor 11 and a memory, such as a read-only memory (ROM) 12 or a random access memory (RAM) 13, communicatively connected to the at least one processor 11. The memory stores computer programs executable by the at least one processor. The processor 11 can perform various appropriate actions and processes based on the computer program stored in the ROM 12 or loaded into the RAM 13 from storage unit 18. The RAM 13 can also store various programs and data required for the operation of the electronic device 10. The processor 11, ROM 12, and RAM 13 are interconnected via a bus 14. An input / output (I / O) interface 15 is also connected to the bus 14.

[0152] Multiple components in electronic device 10 are connected to I / O interface 15, including: input unit 16, such as keyboard, mouse, etc.; output unit 17, such as various types of displays, speakers, etc.; storage unit 18, such as disk, optical disk, etc.; and communication unit 19, such as network card, modem, wireless transceiver, etc. Communication unit 19 allows electronic device 10 to exchange information / data with other devices through computer networks such as the Internet and / or various telecommunications networks.

[0153] Processor 11 can be a variety of general-purpose and / or special-purpose processing components with processing and computing capabilities. Some examples of processor 11 include, but are not limited to, central processing unit (CPU), graphics processing unit (GPU), various special-purpose artificial intelligence (AI) computing chips, various processors running machine learning model algorithms, digital signal processors (DSPs), and any suitable processor, controller, microcontroller, etc. Processor 11 performs the various methods and processes described above, such as gas well rational production allocation methods.

[0154] In some embodiments, the gas well rational production allocation method may be implemented as a computer program tangibly contained in a computer-readable storage medium, such as storage unit 18. In some embodiments, part or all of the computer program may be loaded and / or installed on electronic device 10 via ROM 12 and / or communication unit 19. When the computer program is loaded into RAM 13 and executed by processor 11, one or more steps of the gas well rational production allocation method described above may be performed. Alternatively, in other embodiments, processor 11 may be configured to perform the gas well rational production allocation method by any other suitable means (e.g., by means of firmware).

[0155] Various embodiments of the systems and techniques described above herein can be implemented in digital electronic circuit systems, integrated circuit systems, field-programmable gate arrays (FPGAs), application-specific integrated circuits (ASICs), application-specific standard products (ASSPs), systems-on-a-chip (SoCs), payload-programmable logic devices (CPLDs), computer hardware, firmware, software, and / or combinations thereof. These various embodiments may include implementations in one or more computer programs that can be executed and / or interpreted on a programmable system including at least one programmable processor, which may be a dedicated or general-purpose programmable processor, capable of receiving data and instructions from a storage system, at least one input device, and at least one output device, and transmitting data and instructions to the storage system, the at least one input device, and the at least one output device.

[0156] Computer programs used to implement the methods of the present invention can be written in any combination of one or more programming languages. These computer programs can be provided to a processor of a general-purpose computer, a special-purpose computer, or other programmable data processing device, such that when executed by the processor, the computer programs cause the functions / operations specified in the flowcharts and / or block diagrams to be implemented. The computer programs can be executed entirely on a machine, partially on a machine, as a standalone software package partially on a machine and partially on a remote machine, or entirely on a remote machine or server.

[0157] In the context of this invention, a computer-readable storage medium can be a tangible medium that may contain or store a computer program for use by or in conjunction with an instruction execution system, apparatus, or device. A computer-readable storage medium may include, but is not limited to, electronic, magnetic, optical, electromagnetic, infrared, or semiconductor systems, apparatus, or devices, or any suitable combination thereof. Alternatively, a computer-readable storage medium may be a machine-readable signal medium. More specific examples of machine-readable storage media include electrical connections based on one or more wires, portable computer disks, hard disks, random access memory (RAM), read-only memory (ROM), erasable programmable read-only memory (EPROM or flash memory), optical fibers, portable compact disk read-only memory (CD-ROM), optical storage devices, magnetic storage devices, or any suitable combination thereof.

[0158] To provide interaction with a user, the systems and techniques described herein can be implemented on an electronic device having: a display device (e.g., a CRT (cathode ray tube) or LCD (liquid crystal display) monitor) for displaying information to the user; and a keyboard and pointing device (e.g., a mouse or trackball) through which the user provides input to the electronic device. Other types of devices can also be used to provide interaction with the user; for example, feedback provided to the user can be any form of sensory feedback (e.g., visual feedback, auditory feedback, or tactile feedback); and input from the user can be received in any form (including sound input, voice input, or tactile input).

[0159] The systems and technologies described herein can be implemented in computing systems that include backend components (e.g., as data servers), or computing systems that include middleware components (e.g., application servers), or computing systems that include frontend components (e.g., user computers with graphical user interfaces or web browsers through which users can interact with implementations of the systems and technologies described herein), or any combination of such backend, middleware, or frontend components. The components of the system can be interconnected via digital data communication of any form or medium (e.g., communication networks). Examples of communication networks include local area networks (LANs), wide area networks (WANs), blockchain networks, and the Internet.

[0160] A computing system can include clients and servers. Clients and servers are generally located far apart and typically interact through communication networks. The client-server relationship is created by computer programs running on the respective computers and having a client-server relationship with each other. The server can be a cloud server, also known as a cloud computing server or cloud host, which is a hosting product within the cloud computing service system to address the shortcomings of traditional physical hosts and VPS services, such as high management difficulty and weak business scalability.

[0161] It should be understood that the various forms of processes shown above can be used, with steps reordered, added, or deleted. For example, the steps described in this invention can be executed in parallel, sequentially, or in different orders, as long as the desired result of the technical solution of this invention can be achieved, and this is not limited herein.

[0162] The specific embodiments described above do not constitute a limitation on the scope of protection of this invention. Those skilled in the art should understand that various modifications, combinations, sub-combinations, and substitutions can be made according to design requirements and other factors. Any modifications, equivalent substitutions, and improvements made within the spirit and principles of this invention should be included within the scope of protection of this invention.

Claims

1. A method for rationally allocating gas well production, characterized in that, include: Acquire the target reservoir physical property data of the gas wells to be allocated to production in the target block and the target production allocation map of the target block, wherein the target production allocation map represents the correspondence between at least one alternative combination and at least one alternative production allocation parameter, and the at least one alternative combination is obtained by arranging and combining at least one alternative water invasion risk level, at least one alternative reservoir space type and at least one alternative reservoir type. Based on the target reservoir physical property parameters, a target combination is determined from the at least one alternative combination; Based on the target combination and the target production allocation chart, a target production allocation parameter is determined from the at least one alternative production allocation parameter, and based on the target production allocation parameter, a reasonable production allocation result for the gas well to be allocated is determined.

2. The method according to claim 1, characterized in that, Before obtaining the reservoir properties of the gas wells to be produced in the target block and the target production map of the target block, the method further includes: Acquire fracture and void development data, water intrusion data, and reservoir property data of typical wells located in the target block; The target production chart is determined based on the fracture and pore development data, the water intrusion data, and the typical well reservoir physical property data.

3. The method according to claim 2, characterized in that, The step of determining the target production chart based on the fracture and porosity development data, the water intrusion data, and the typical well reservoir property data includes: Based on the fracture and void development data, determine the at least one candidate storage space type and the first classification criteria corresponding to each of the at least one candidate storage space type; Based on the water intrusion data, determine the at least one alternative water intrusion risk level and the second classification criteria corresponding to the at least one alternative water intrusion risk level; Based on the typical well reservoir physical property data, determine the at least one candidate reservoir type and the third classification criteria corresponding to the at least one candidate reservoir type; The target production allocation chart is determined based on the at least one alternative reservoir space type, the first classification criterion, the at least one alternative water intrusion risk level, the second classification criterion, the at least one alternative reservoir type, and the third classification criterion.

4. The method according to claim 3, characterized in that, The step of determining the target production allocation chart based on the at least one alternative reservoir space type, the first classification criterion, the at least one alternative water intrusion risk level, the second classification criterion, the at least one alternative reservoir type, and the third classification criterion includes: Based on the at least one alternative reservoir space type, the first classification standard, the at least one alternative water intrusion risk level, and the second classification standard, a first three-dimensional map corresponding to each of the at least one alternative reservoir space type is determined. The first three-dimensional map represents the correspondence between the at least one alternative water intrusion risk level and the candidate production allocation parameter and the gas reservoir recovery rate under the alternative reservoir space type corresponding to the first three-dimensional map. The candidate production allocation parameter includes the at least one alternative production allocation parameter. Based on the at least one alternative reservoir space type, the first classification standard, the at least one alternative reservoir type, and the third classification standard, a second three-dimensional map corresponding to each of the at least one alternative reservoir space type is determined. The second three-dimensional map represents the correspondence between the at least one alternative reservoir type, the selected production parameters, and the gas reservoir recovery rate under the alternative reservoir space type corresponding to the second three-dimensional map. The target production layout is determined based on the first three-dimensional layout and the second three-dimensional layout.

5. The method according to claim 3, characterized in that, The water intrusion data includes at least one of the following: the energy level of the first water body, the water body type, the understanding of the gas-water relationship, and the distribution pattern of the interlayer. The step of determining the at least one alternative flood risk level and the second classification criteria corresponding to each of the at least one alternative flood risk level based on the flood data includes: Based on at least one of the following: the energy level of the first water body, the water body type, the understanding of the gas-water relationship, and the distribution pattern of the interlayer, a water intrusion risk analysis is performed on the typical well. Based on the obtained risk analysis results, the at least one alternative water intrusion risk level and the corresponding second classification criteria are determined.

6. The method according to claim 2, characterized in that, Before obtaining fracture and porosity development data of typical wells located in the target block, the method further includes: The logging characteristics and thin section test results of the typical well are obtained, and at least one fracture and cavity development type is determined based on the thin section test results. The thin section test results are obtained by conducting experiments on core thin sections, which are collected from the typical well. The at least one fracture and cavity development type and the well logging characteristics are used as the fracture and cavity development data.

7. The method according to claim 2, characterized in that, Also includes: Obtain the geological characteristics of the typical wells and the static and dynamic data of the target block; Based on the geological characteristics, the static data, and the dynamic data, a geological numerical simulation model for the typical well is determined; The step of determining the target production chart based on the fracture and porosity development data, the water intrusion data, and the typical well reservoir property data includes: Based on the geological numerical simulation model, the fracture and pore development data, the water intrusion data, and the typical well reservoir property data, the target production chart is determined.

8. The method according to claim 7, characterized in that, Based on the geological characteristics, the static data, and the dynamic data, a geological numerical simulation model for the typical well is determined, including: Based on the geological characteristics and the static data, the initial numerical simulation model of the typical well is determined; Based on the dynamic data, the model permeability, gas-water interface, and energy magnitude of the second water body in the initial numerical simulation model are updated to obtain the geological numerical simulation model of the typical well.

9. The method according to claim 1, characterized in that, The target production allocation parameter is the target production allocation coefficient; The step of determining the reasonable production allocation result of the gas well to be allocated based on the target production allocation parameters includes: Obtain the unobstructed flow rate of the gas well to be allocated production, and determine the reasonable production rate of the gas well to be allocated production based on the target production allocation coefficient and the unobstructed flow rate of the gas well. The reasonable production output of the gas well is taken as the reasonable production output result of the gas well to be produced.

10. A gas well rational production allocation device, characterized in that, include: The target production allocation map acquisition module is used to acquire the target reservoir physical property data of the gas wells to be allocated to production in the target block and the target production allocation map of the target block. The target production allocation map represents the correspondence between at least one alternative combination and at least one alternative production allocation parameter. The at least one alternative combination is obtained by arranging and combining at least one alternative water invasion risk level, at least one alternative reservoir space type and at least one alternative reservoir type. The target combination determination module is used to determine a target combination from the at least one alternative combination based on the target reservoir physical property parameters; The reasonable production allocation result determination module is used to determine the target production allocation parameter from the at least one alternative production allocation parameter according to the target combination and the target production allocation chart, and to determine the reasonable production allocation result of the gas well to be allocated according to the target production allocation parameter.

11. An electronic device, characterized in that, include: At least one processor; as well as A memory communicatively connected to the at least one processor; wherein, The memory stores a computer program that can be executed by the at least one processor to cause the at least one processor to perform the gas well rational production allocation method as described in any one of claims 1-9.

12. A computer-readable storage medium, characterized in that, The computer-readable storage medium stores computer instructions that cause a processor to execute the gas well rational production allocation method as described in any one of claims 1-9.

13. A computer program product comprising a computer program that, when executed by a processor, implements the gas well rational production allocation method according to any one of claims 1-9.

Images