Deployment method and system for three-dimensional injection-production well pattern of low-permeability sandstone gas storage and medium

Abstract

The invention discloses a low-permeability sandstone gas storage three-dimensional injection-production well pattern deployment method and system and a medium. The method comprises the steps that S1, gas-water space distribution is depicted, a single-well closed gas reservoir is determined, the current exploiting reserve and the maximum exploiting reserve are obtained, a closed gas reservoir material balance method is adopted, the current reserve exploiting condition and the pressure maintaining condition are obtained, and the maximum exploiting reserve is obtained; determining a reasonable working gas amount; s2, the conventional productivity of vertical well development is confirmed based on the dynamic monitoring data; s3, the reasonable length of the horizontal section of the horizontal well is determined; and S4, according to the fine description of the gas reservoir, multiple sets of oil groups developed by interlayers are selected, and an injection-production well pattern is deployed. According to the deployed injection-production well pattern, the injection-production capacity is greatly improved, the storage capacity is controlled, the problems that the working gas amount of a low-permeability gas reservoir rebuilt gas storage is high, and the injection-production capacity of a vertical well is insufficient are solved, and the method can also be popularized and applied to a conceptual design scheme for large-scale production in medium-high permeability gas reservoir development and design of a low-permeability and tight gas reservoir difficult-to-produce reserve development scheme. And the applicability is improved.

Description

Technical Field

[0001] The present invention relates to the technical field of oil and gas reservoir engineering, and in particular to a method, system and medium for deploying a three-dimensional injection and production well network in a low-permeability sandstone gas storage reservoir. Background Art

[0002] The detailed description technology of oil and gas reservoirs includes the characterization of geological body fracture systems, structural morphology, reservoir distribution, and spatial distribution of oil, gas and water, which can provide the geological body basic framework and material basis for the injection and production well network. The field of oil and gas reservoir engineering technology is to analyze the production capacity characteristics, influencing factors and distribution of single wells in low permeability gas reservoirs, evaluate the strength of natural water invasion, analyze the connectivity of low permeability gas reservoirs, analyze the current gas reservoir pressure distribution, and evaluate the control and utilization of gas reservoir reserves, which can provide a basis for the design parameters of the injection and production well network. The injection and production well network design technology includes the design reservoir capacity, working gas volume, cushion gas volume, upper and lower operating pressure limits, single well injection and production capacity, reasonable well spacing, and well type.

[0003] Conventional gas reservoir construction has abundant geological development data, solid geological bodies, and relatively clear understanding of geological and development characteristics. Development dynamic analysis technology can apply abundant basic data such as work system, output, pressure, and dynamic monitoring data such as standardized production capacity well test, and can easily analyze production capacity characteristics, pressure distribution, and reserve utilization status.

[0004] Since a single horizontal section cannot mobilize multiple oil groups, multiple horizontal wells and several vertical well networks are needed to increase production capacity. Therefore, there is an urgent need for a deployment method of a three-dimensional injection and production well network for multi-oil group low-permeability sandstone gas storage to meet the design storage capacity and reasonable working gas volume in multiple oil groups. Summary of the invention

[0005] In view of the above problems, the present invention is proposed to provide a method, system and medium for deploying a three-dimensional injection and production well network in a low permeability sandstone gas storage reservoir, which overcomes the above problems or at least partially solves the above problems.

[0006] In a first aspect, a method for deploying a three-dimensional injection and production well pattern in a low permeability sandstone gas storage is provided, wherein the method comprises the following steps:

[0007] S1. Describe the spatial distribution of gas and water, determine the closed gas reservoir of a single well, fit the relationship between the cumulative gas production and the number of production days for the closed gas reservoir of a single well, and predict the recovery factor to determine the recoverable reserves. According to the natural gas reserve management standards, determine the recovery factor, obtain the current producing reserves and the maximum producing reserves, and then use the closed gas reservoir material balance method to obtain the current reserve production status and pressure maintenance status to determine the reasonable working gas volume;

[0008] S2. Confirm the conventional production capacity of vertical well development based on dynamic monitoring data;

[0009] S3. Determine the reasonable length of the horizontal section of the horizontal well;

[0010] S4. Based on the detailed description of the gas reservoir, multiple oil groups with well-developed interlayers are selected to design and deploy the injection and production well network.

[0011] Optionally, in step S1, confirming the spatial distribution of gas and water includes:

[0012] According to the detailed description of the gas reservoir, the parameters affecting the geological reserves and reservoir physical properties are characterized, the gas components, the volume coefficient of the high-pressure physical parameters, the condensate content are tested and analyzed, and the geological reserves of natural gas and condensate are calculated to achieve the distribution characterization of the gas-water space. The geological reserve parameters include the fault space position of the oil-bearing area, the distribution of sand bodies, the distribution of gas layers, and the gas-water interface. The reservoir physical property parameters include porosity, permeability, and gas saturation.

[0013] Optionally, in step S1, determining a single well closed gas reservoir includes:

[0014] Based on the characteristics of pressure conductivity and inactive water bodies, the connectivity and pressure conductivity of low permeability reservoirs were analyzed to confirm the existence of pressure drop funnels between wells. At the same time, the flow units were divided according to the driving type and production situation of the gas reservoir. The overall evaluation was equivalent to isolated flow units and determined to be single-well closed gas reservoirs. The original storage capacity of each isolated flow unit is the single controlled reserves, and the corresponding pressure is the original pressure of the gas reservoir.

[0015] Optionally, in step S1, fitting the relationship between cumulative gas production and production days for a single well closed gas reservoir includes:

[0016] Applying the statistical method in the field of oil and gas reservoir engineering technology, for a single well closed gas reservoir that has entered the decline stage, the fitted relationship is a parabola with a negative quadratic coefficient and a downward opening, which has a maximum value;

[0017] For single-well closed gas reservoirs that have not entered the decline stage, the single-well dynamic reserves are determined by the relationship between the ratio of the current producing reserves to the maximum producing reserves determined by the geological regional statistical method and the production time, which is determined as a quadratic or cubic relationship of the cumulative production days based on the actual gas reservoirs in the specific region.

[0018] Optionally, in step S2, confirming the conventional production capacity of vertical well development based on dynamic monitoring data further includes:

[0019] When production, pressure gas test data and productivity well test dynamic test data are unavailable, refer to the geological productivity well test data in the same area and perform parameter correction.

[0020] Optionally, in step S3, determining a reasonable length of a horizontal section of a horizontal well includes:

[0021] When there is no horizontal well productivity test data, the horizontal well formula capacity replacement ratio is used to convert the vertical well capacity into the horizontal well capacity, and the reasonable length of a single horizontal section is determined based on the inflection point of the unobstructed flow and horizontal section relationship curve corresponding to the two cases with and without friction along the way.

[0022] Optionally, in step S4, the step of selecting multiple oil groups with well-developed interlayers according to the detailed description of the gas reservoir, and designing and deploying the injection-production well pattern specifically includes:

[0023] When drilling an oil formation, it is deployed as a single horizontal section. In areas with developed internal interlayers, a double-step, four-target horizontal well is used. In areas with undeveloped interlayers, a conventional horizontal well is designed.

[0024] When drilling multiple oil formations, they are deployed as one wellbore with multiple branches. When the internal interlayers of each oil formation are not developed, a single-step double-target horizontal section is used to form a multi-branch single-step well network. When the internal interlayers of each oil formation are developed, a multi-step horizontal section is used to form a multi-branch multi-step well network.

[0025] Optionally, in step S4, the method further includes: when the production capacity requirement cannot be met, deploying a large-size screen to complete the well and acidizing the reservoir before putting it into production.

[0026] In a second aspect, a three-dimensional injection and production well pattern deployment system for a low permeability sandstone gas storage reservoir is provided, which is applied to any of the three-dimensional injection and production well pattern deployment methods for a low permeability sandstone gas storage reservoir described above, comprising:

[0027] The working gas volume calculation module is used to characterize the spatial distribution of gas and water, determine the closed gas reservoir of a single well, fit the relationship between the cumulative gas production and the number of production days for the closed gas reservoir of a single well, and predict the recovery rate to determine the recoverable reserves. According to the natural gas reserve management standards, the recovery rate is determined to obtain the current producing reserves and the maximum producing reserves. Then, the closed gas reservoir material balance method is used to obtain the current reserve production status and pressure maintenance status to determine the reasonable working gas volume;

[0028] Conventional production capacity calculation module, used to confirm the conventional production capacity of vertical well development based on dynamic monitoring data;

[0029] Horizontal section calculation module, used to determine the reasonable length of the horizontal section of the horizontal well;

[0030] The injection-production well network deployment module is used to design and deploy the injection-production well network based on the detailed description of the gas reservoir and multiple oil groups with well-developed interlayers.

[0031] In a third aspect, a medium is provided, wherein the medium stores computer executable instructions, and the computer executable instructions are used to implement any of the above-mentioned methods for deploying a three-dimensional injection and production well network for a low-permeability sandstone gas storage.

[0032] The technical solution provided in the embodiments of the present invention has at least the following technical effects or advantages:

[0033] A method for deploying a three-dimensional injection and production well network for a low-permeability sandstone gas storage reservoir is provided in an embodiment of the present invention. Its injection and production well network design technology can easily design storage capacity parameters such as bottom gas with the support of clear and definite pressure change data at each stage; after applying sufficient test data, the injection and production capacity of vertical wells and horizontal wells can be reasonably designed; in a set of oil groups, well areas with superior geological conditions and higher production capacity are selected to design the injection and production well network, and a single horizontal section can meet the designed working gas volume; the injection and production well network deployed by the present invention greatly improves the injection and production capacity and controls the storage capacity. Under superior geological conditions, a double-branch double-step horizontal well can increase the injection and production capacity by 8 times, solving the problem of high working gas volume and insufficient injection and production capacity of vertical wells in the reconstruction of gas storage reservoirs from low-permeability gas reservoirs, and can also be promoted and applied to conceptual design schemes for significantly increasing production in the development of medium- and high-permeability gas reservoirs, and development schemes for difficult-to-use reserves in low-permeability and tight gas reservoirs, thereby improving applicability.

[0034] The above description is only an overview of the technical solution of the present invention. In order to more clearly understand the technical means of the present invention, it can be implemented according to the contents of the specification. In order to make the above and other purposes, features and advantages of the present invention more obvious and easy to understand, the specific implementation methods of the present invention are listed below. BRIEF DESCRIPTION OF THE DRAWINGS

[0035] By reading the detailed description of the preferred embodiment below, various other advantages and benefits will become clear to those of ordinary skill in the art. The accompanying drawings are only used for the purpose of illustrating the preferred embodiment and are not considered to be limitations of the present invention. In addition, the same reference symbols are used to represent the same components throughout the accompanying drawings.

[0036] In the attached picture:

[0037] Figure 1 It is a schematic flow chart of a method for deploying a three-dimensional injection and production well pattern for a low-permeability sandstone gas storage provided by an embodiment of the present invention;

[0038] Figure 2 This is a reference diagram for the deployment of the injection-production well network;

[0039] Figure 3 A principle block diagram of a three-dimensional injection and production well pattern deployment system for a low-permeability sandstone gas storage reservoir provided in an embodiment of the present invention. DETAILED DESCRIPTION

[0040] Exemplary embodiments of the present disclosure will be described in more detail below with reference to the accompanying drawings.

[0041] Various structural schematic diagrams according to embodiments of the present disclosure are shown in the accompanying drawings. These figures are not drawn to scale, and some details are magnified and some details may be omitted for the purpose of clear expression. The shapes of various regions and layers shown in the figures and the relative sizes and positional relationships therebetween are only exemplary, and may deviate in practice due to manufacturing tolerances or technical limitations, and those skilled in the art may further design regions / layers with different shapes, sizes, and relative positions according to actual needs.

[0042] In the context of the present disclosure, when a layer / element is referred to as being "on" another layer / element, the layer / element may be directly on the other layer / element, or there may be an intervening layer / element therebetween. Additionally, if a layer / element is "on" another layer / element in one orientation, the layer / element may be "below" the other layer / element when the orientation is reversed. In the context of the present disclosure, similar or identical components may be denoted by the same or similar reference numerals.

[0043] In order to better understand the above-mentioned technical scheme, the above-mentioned technical scheme will be described in detail below in combination with specific implementation methods. It should be understood that the embodiments of the present disclosure and the specific features in the embodiments are detailed descriptions of the technical scheme of the present application, rather than limitations on the technical scheme of the present application. In the absence of conflict, the embodiments of the present application and the technical features in the embodiments can be combined with each other.

[0044] Figure 1 Schematic diagram of a method for deploying a three-dimensional injection and production well pattern for a low permeability sandstone gas storage provided by an embodiment of the present invention. Figure 1 As shown, the method for deploying a three-dimensional injection and production well pattern in a low permeability sandstone gas storage reservoir includes the following steps:

[0045] S1. Describe the spatial distribution of gas and water, determine the closed gas reservoir of a single well, fit the relationship between the cumulative gas production and the number of production days for the closed gas reservoir of a single well, and predict the recovery factor to determine the recoverable reserves. According to the natural gas reserve management standards, determine the recovery factor, obtain the current producing reserves and the maximum producing reserves, and then use the closed gas reservoir material balance method to obtain the current reserve production status and pressure maintenance status to determine the reasonable working gas volume;

[0046] S2. Confirm the conventional production capacity of vertical well development based on dynamic monitoring data;

[0047] S3. Determine the reasonable length of the horizontal section of the horizontal well;

[0048] S4. Based on the detailed description of the gas reservoir, multiple oil groups with well-developed interlayers are selected to design and deploy the injection and production well network.

[0049] In the embodiment of the present invention, the first step is to evaluate the reserve production and pressure maintenance conditions and design a reasonable working gas volume. Optionally, in step S1, the confirmation of the gas-water spatial distribution includes:

[0050] According to the detailed description of the gas reservoir, the parameters affecting the geological reserves and reservoir physical properties are characterized, the gas components, the volume coefficient of the high-pressure physical parameters, the condensate content are tested and analyzed, and the geological reserves of natural gas and condensate are calculated to achieve the distribution characterization of the gas-water space. The geological reserve parameters include the fault space position of the oil-bearing area, the distribution of sand bodies, the distribution of gas layers, and the gas-water interface. The reservoir physical property parameters include porosity, permeability, and gas saturation.

[0051] Dynamic analysis and evaluation of water body energy, well-to-well connectivity, drive type, and dynamic reserves. The general development characteristics are characterized by inactive water bodies, poor pressure conductivity, limited single well utilization range, and small inter-well interference. They can be equivalent to isolated flow units, similar to the "fracture-cave units" of carbonate rocks, which are not connected to each other. In step S1, based on the characteristics of pressure conductivity and inactive water bodies, the connectivity and reservoir pressure conductivity of low-permeability reservoirs are analyzed to confirm the existence of pressure drop funnels between wells. At the same time, the flow units are divided according to the drive type and utilization of the gas reservoir, and the overall evaluation is equivalent to isolated flow units, which are determined as single-well closed gas reservoirs, where the original storage capacity of each isolated flow unit is the single controlled reserve, and the corresponding pressure is the original pressure of the gas reservoir. Optionally, based on the overall social gas supply demand, the medium- and long-term planning of the gas storage, the actual gas reservoir production capacity, etc., a certain proportion of the original storage capacity is taken to determine the working gas volume. The ratio is generally less than 1, but can also be slightly larger than 1.

[0052] Optionally, in step S1, the fitting of the relationship between the cumulative gas production and the production days for a single-well closed gas reservoir includes: applying statistical methods in the field of oil and gas reservoir engineering technology, for a single-well closed gas reservoir that has entered a declining stage, the fitted relationship is a parabola with a negative quadratic coefficient and a downward opening, and there is a maximum value, for example, "Qp = -0.01t^2+t+10" (Qp is the cumulative gas production, and t is the cumulative production days); it should be noted that actual development is controlled by the technical level and economic cost, and the maximum value is not necessarily the recoverable reserves in some embodiments; for a single-well closed gas reservoir that has not entered a declining stage, the single-well dynamic reserves are determined by using the relationship between the ratio of the current producing reserves to the maximum producing reserves determined by the geological regional statistics method and the production time, for example, a quadratic relationship or a cubic relationship of the cumulative production days is actually determined according to the specific regional gas reservoir.

[0053] Specifically, the relationship between cumulative gas production and production days is fitted for single-well closed gas reservoirs, and the recovery rate is predicted to determine the recoverable reserves. Based on isolated flow units, a scatter plot of cumulative gas production and cumulative production time is made, and a suitable fitting relationship is selected. The fitting curve can be selected from exponential, logarithmic, and quadratic polynomials. It should be noted that in the case of condensate gas reservoirs, the cumulative gas production is the sum of the cumulative gas production at the wellhead and the condensate equivalent production; for production time, the smaller the level, the better, and generally the number of production days is selected. The correlation coefficient of the fitting relationship can generally reach above 0.96. Derivate the fitting relationship, and select a relationship with a high correlation coefficient. The derivation is the daily gas production. Using the technical abandoned production and economic abandoned production, the final recoverable reserves can be calculated. The reserves produced at this time point are the maximum natural producing reserves. At this point, the current reserves can be easily obtained: according to the regression relationship of high-development and low-permeability gas fields in the same layer - the degree of production at different cumulative production times (the ratio of current reserves to maximum reserves), it can be obtained using the production characteristic relationship of the overall geological area.

[0054] The embodiment of the present invention determines the recovery factor according to the natural gas reserve management standard, and obtains the current producing reserves and the maximum producing reserves. Finally, the closed gas reservoir material balance method is used to obtain the current reserve production status and pressure maintenance status.

[0055] In an embodiment of the present invention, the second step is to confirm the conventional production capacity of vertical well development based on dynamic monitoring data. Optionally, in step S2, the conventional production capacity of vertical well development based on dynamic monitoring data also includes: when it is impossible to obtain production, pressure gas test data and production capacity test dynamic test data, refer to the geological production capacity test data in the same area and perform parameter correction. Specifically, low-permeability gas reservoirs generally cannot be put into production naturally, and often require reservoir transformation. If there is no production, pressure gas test data and production capacity test dynamic test data, the geological conditions of similar gas reservoirs can be compared to correct the formation pressure and gas layer thickness to obtain the binomial equation A and B coefficients. In an embodiment of the present invention, it can be conveniently implemented using reliable dynamic monitoring data. Generally, 3 working system test points are selected for testing, and 4 working system test points can also be selected. However, the testing time of low permeability gas reservoirs is short and it is difficult to reach a stable state, so corresponding processing methods are needed. For example, when the current formation pressure is unclear, the variable difference method between working systems is used for processing; when the quadratic coefficient is a negative number or the constant term is a coefficient, it is necessary to consider a fixed starting pressure gradient or a variable starting pressure gradient. For those without test data, it is still necessary to refer to the geological production capacity test data in the same area and perform corrections on parameters such as pressure and effective thickness.

[0056] Optionally, in an embodiment of the present invention, the third step is based on step S3, and the determination of the reasonable length of the horizontal section of the horizontal well includes: when there is no horizontal well productivity test data, using the Borisov, Joshi, and Giger horizontal well formula productivity replacement ratio to convert the vertical well productivity into the horizontal well productivity, and according to the inflection point of the unobstructed flow and horizontal section relationship curve corresponding to the two cases with and without friction along the way, clarify the reasonable length of a single horizontal section.

[0057] In the embodiment of the present invention, for the appearance of the inflection point of the relationship considering the friction along the way, the research results of Dikken's capacity error rate are adopted: the inflection point is when the ratio of the capacity difference of the relationship considering the friction along the way and not considering the friction along the way to the capacity difference of the relationship considering the friction along the way is 20%, and the corresponding horizontal section length is a reasonable length.

[0058] Optional, see Figure 2 As shown, Figure 2 The fourth step is a reference diagram for the deployment of the injection-production well network. The fourth step is based on the step S4, which selects multiple sets of oil groups with developed interlayers according to the detailed description of the gas reservoir, and designs and deploys the injection-production well network, which specifically includes:

[0059] When drilling an oil formation, it is deployed as a single horizontal section. In areas with developed internal interlayers, a double-step, four-target horizontal well is used. In areas with undeveloped interlayers, a conventional horizontal well is designed.

[0060] When drilling into two oil formations, the wells are deployed as one wellbore with two branches. When the internal interlayers of each oil formation are not well developed, a single-step double-target horizontal section is used to form a multi-branch single-step well network. When the internal interlayers of each oil formation are well developed, a double-step horizontal section is used to form a multi-branch double-step well network.

[0061] For multiple oil groups, similarly, they are deployed as one wellbore with multiple branches. When the internal interlayers of each oil group are not developed, a single-step double-target horizontal section is used to form a multi-branch single-step well network. When the internal interlayers of each oil group are developed, a multi-step horizontal section is used to form a multi-branch multi-step well network.

[0062] Optionally, when the production capacity requirement cannot be met, a large-size screen is deployed to complete the well and put it into production after the reservoir is acidified. The embodiment of the present invention tries to improve the reservoir capacity control degree and injection and production capacity. In areas with low reservoir capacity control degree, vertical wells are designed to form a multi-branch mixed step injection and production well network.

[0063] The method for deploying a three-dimensional injection and production well network for a low-permeability sandstone gas storage reservoir described in an embodiment of the present invention and its injection and production well network design technology can easily design storage capacity parameters such as bottom gas with the support of clear and definite pressure change data at each stage; after applying sufficient test data, the injection and production capacity of vertical wells and horizontal wells can be reasonably designed; in a set of oil groups, well areas with superior geological conditions and higher production capacity are selected to design the injection and production well network, and a single horizontal section can meet the designed working gas volume; the injection and production well network deployed by the present invention greatly improves the injection and production capacity and controls the storage capacity. Under superior geological conditions, a double-branch double-step horizontal well can increase the injection and production capacity by 8 times, solving the problems of high working gas volume and insufficient injection and production capacity of vertical wells in the reconstruction of gas storage reservoirs from low-permeability gas reservoirs, and can also be promoted and applied to conceptual design schemes for significantly increasing production in the development of medium- and high-permeability gas reservoirs, and development schemes for difficult-to-use reserves in low-permeability and tight gas reservoirs, thereby improving applicability.

[0064] On the basis of the above embodiments, based on the same inventive concept, the embodiments of the present invention further provide a three-dimensional injection and production well network deployment system for a low permeability sandstone gas storage reservoir, and the three-dimensional injection and production well network deployment system for a low permeability sandstone gas storage reservoir is applied to the three-dimensional injection and production well network deployment method for a low permeability sandstone gas storage reservoir described in any of the above embodiments, see Figure 3 As shown, Figure 3 A principle block diagram of a three-dimensional injection and production well network deployment system for a low permeability sandstone gas storage provided by an embodiment of the present invention, wherein the three-dimensional injection and production well network deployment system for a low permeability sandstone gas storage comprises:

[0065] The working gas volume calculation module 100 is used to characterize the spatial distribution of gas and water, determine the closed gas reservoir of a single well, fit the relationship between the cumulative gas production and the production days for the closed gas reservoir of a single well, and predict the recovery factor, determine the recoverable reserves, and determine the recovery factor according to the natural gas reserve management standard, obtain the current producing reserves and the maximum producing reserves, and then use the closed gas reservoir material balance method to obtain the current reserve production status and pressure maintenance status to determine the reasonable working gas volume;

[0066] Conventional production capacity calculation module 200, used to confirm the conventional production capacity of vertical well development based on dynamic monitoring data;

[0067] A horizontal section calculation module 300 is used to determine a reasonable length of a horizontal section of a horizontal well;

[0068] The injection-production well pattern deployment module 400 is used to design and deploy the injection-production well pattern according to the detailed description of the gas reservoir and select multiple oil groups with well-developed interlayers.

[0069] The three-dimensional injection and production well network deployment system for a low permeability sandstone gas storage reservoir described in the embodiment of the present invention can execute the three-dimensional injection and production well network deployment method for a low permeability sandstone gas storage reservoir provided in the above embodiment. The three-dimensional injection and production well network deployment system for a low permeability sandstone gas storage reservoir has the corresponding functional steps and beneficial effects of the three-dimensional injection and production well network deployment method for a low permeability sandstone gas storage reservoir described in the above embodiment. For details, please refer to the embodiment of the above-mentioned three-dimensional injection and production well network deployment method for a low permeability sandstone gas storage reservoir. The embodiment of the present invention will not be repeated here.

[0070] The embodiment of the present invention also provides an electronic device, which may include a processor and a memory, wherein the processor and the memory may be connected via a bus or other means. The processor may be a central processing unit (CPU). The processor may also be other general-purpose processors, digital signal processors (DSP), application-specific integrated circuits (ASIC), field-programmable gate arrays (FPGA) or other programmable logic devices, discrete gates or transistor logic devices, discrete hardware components and other chips, or a combination of the above-mentioned various types of chips. The memory, as a non-transient computer-readable storage medium, can be used to store non-transient software programs, non-transient computer executable programs and modules, such as the program instructions / modules corresponding to the three-dimensional injection and production well network deployment method for low permeability sandstone gas storage in the embodiment of the present invention. The processor executes various functional applications and data processing of the processor by running the non-transient software programs, instructions and modules stored in the memory, that is, the three-dimensional injection and production well network deployment method for low permeability sandstone gas storage in the above method embodiment is realized.

[0071] The memory may include a program storage area and a data storage area, wherein the program storage area may store an operating system and an application required by at least one function; the data storage area may store data created by the processor, etc. In addition, the memory may include a high-speed random access memory, and may also include a non-volatile memory, such as at least one disk storage device, a flash memory device, or other non-volatile solid-state storage device. The one or more modules are stored in the memory, and when executed by the processor, the execution is as follows: Figure 1 The three-dimensional injection and production well network deployment method of the low permeability sandstone gas storage in the embodiment shown. Figure 1The corresponding related descriptions and effects in the embodiments shown are understood and will not be repeated here. Those skilled in the art will understand that all or part of the processes in the above-mentioned embodiment methods can be implemented by instructing the relevant hardware through a computer program, and the program can be stored in a computer-readable storage medium. When the program is executed, it may include the processes of the embodiments of the above-mentioned methods. Among them, the storage medium may be a read-only memory (ROM), a random access memory (RAM), a flash memory (Flash Memory), a hard disk (Hard Disk Drive, abbreviated as: HDD) or a solid-state drive (Solid-State Drive, SSD), etc.; the storage medium may also include a combination of the above-mentioned types of memory.

[0072] In the description provided herein, a large number of specific details are described. However, it is understood that embodiments of the present invention can be practiced without these specific details. In some instances, well-known methods, structures and techniques are not shown in detail so as not to obscure the understanding of this description.

[0073] Similarly, it should be understood that in order to streamline the present disclosure and aid in understanding one or more of the various inventive aspects, in the above description of exemplary embodiments of the present invention, various features of the present invention are sometimes grouped together into a single embodiment, figure, or description thereof. However, this disclosed method should not be interpreted as reflecting the intention that the claimed invention requires more features than those explicitly recited in each claim. More specifically, as reflected in the claims below, inventive aspects lie in less than all the features of the individual embodiments disclosed above. Therefore, the claims that follow the specific embodiment are hereby expressly incorporated into the specific embodiment, with each claim itself serving as a separate embodiment of the present invention.

[0074] It should be noted that the above-mentioned embodiments illustrate rather than limit the invention and that those skilled in the art will be able to design alternative embodiments without departing from the scope of the appended claims.

Claims

1. A method for deploying a three-dimensional injection and production well pattern in a low-permeability sandstone gas storage reservoir. It is characterized in that The method for deploying a three-dimensional injection and production well pattern in a low permeability sandstone gas storage reservoir comprises: S1. Describe the spatial distribution of gas and water, determine the closed gas reservoir of a single well, fit the relationship between the cumulative gas production and the number of production days for the closed gas reservoir of a single well, and predict the recovery factor to determine the recoverable reserves. According to the natural gas reserve management standards, determine the recovery factor, obtain the current producing reserves and the maximum producing reserves, and then use the closed gas reservoir material balance method to obtain the current reserve production status and pressure maintenance status to determine the reasonable working gas volume; S2. Confirm the conventional production capacity of vertical well development based on dynamic monitoring data; S3. Determine the reasonable length of the horizontal section of the horizontal well; S4. Based on the detailed description of the gas reservoir, multiple oil groups with well-developed interlayers are selected to design and deploy the injection and production well network.

2. The method for deploying a three-dimensional injection and production well pattern for a low permeability sandstone gas storage according to claim 1, It is characterized in that In step S1, the confirming of the gas-water spatial distribution includes: According to the detailed description of the gas reservoir, the parameters affecting the geological reserves and reservoir physical properties are characterized, the gas components, the volume coefficient of the high-pressure physical parameters, the condensate content are tested and analyzed, and the geological reserves of natural gas and condensate are calculated to achieve the distribution characterization of the gas-water space. The geological reserve parameters include the fault space position of the oil-bearing area, the distribution of sand bodies, the distribution of gas layers, and the gas-water interface. The reservoir physical property parameters include porosity, permeability, and gas saturation.

3. The method for deploying a three-dimensional injection and production well pattern for a low permeability sandstone gas storage according to claim 1, It is characterized in that In step S1, determining a single well closed gas reservoir includes: Based on the characteristics of pressure conductivity and inactive water bodies, the connectivity and pressure conductivity of low permeability reservoirs were analyzed to confirm the existence of pressure drop funnels between wells. At the same time, the flow units were divided according to the driving type and production situation of the gas reservoir. The overall evaluation was equivalent to isolated flow units and determined to be single-well closed gas reservoirs. The original storage capacity of each isolated flow unit is the single controlled reserves, and the corresponding pressure is the original pressure of the gas reservoir.

4. The method for deploying a three-dimensional injection and production well pattern for a low permeability sandstone gas storage according to claim 1, It is characterized in that In step S1, fitting the relationship between cumulative gas production and production days for a single well closed gas reservoir includes: Applying the statistical method in the field of oil and gas reservoir engineering technology, for a single well closed gas reservoir entering the decline stage, the fitted relationship is a parabola with a negative quadratic coefficient and a downward opening, which has a maximum value; For single-well closed gas reservoirs that have not entered the decline stage, the single-well dynamic reserves are determined by the relationship between the ratio of the current producing reserves to the maximum producing reserves determined by the geological regional statistical method and the production time, which is determined as a quadratic or cubic relationship of the cumulative production days based on the actual gas reservoirs in the specific region.

5. The method for deploying a three-dimensional injection and production well pattern for a low permeability sandstone gas storage according to claim 1, It is characterized in that In step S2, the conventional production capacity of vertical well development based on dynamic monitoring data further includes: When production, pressure gas test data and productivity well test dynamic test data are unavailable, refer to the geological productivity well test data in the same area and perform parameter correction.

6. The method for deploying a three-dimensional injection and production well pattern for a low permeability sandstone gas storage according to claim 1, It is characterized in that In step S3, determining the reasonable length of the horizontal section of the horizontal well includes: When there is no horizontal well productivity test data, the horizontal well formula capacity replacement ratio is used to convert the vertical well capacity into the horizontal well capacity, and the reasonable length of a single horizontal section is determined based on the inflection point of the unobstructed flow and horizontal section relationship curve corresponding to the two cases with and without friction along the way.

7. The method for deploying a three-dimensional injection and production well pattern for a low permeability sandstone gas storage according to claim 1, It is characterized in that In step S4, the method of selecting multiple oil groups with well-developed interlayers according to the detailed description of the gas reservoir, and designing and deploying the injection-production well pattern specifically includes: When drilling an oil formation, it is deployed as a single horizontal section. In areas with developed internal interlayers, a double-step, four-target horizontal well is used. In areas with undeveloped interlayers, a conventional horizontal well is designed. When drilling multiple oil formations, they are deployed as one wellbore with multiple branches. When the internal interlayers of each oil formation are not developed, a single-step double-target horizontal section is used to form a multi-branch single-step well network. When the internal interlayers of each oil formation are developed, a multi-step horizontal section is used to form a multi-branch multi-step well network.

8. The method for deploying a three-dimensional injection and production well pattern for a low permeability sandstone gas storage according to claim 7, It is characterized in that In step S4, the method further includes: when the production capacity requirement cannot be met, deploying a large-size screen to complete the well and acidizing the reservoir before putting it into production.

9. A three-dimensional injection and production well network deployment system for a low permeability sandstone gas storage reservoir, applied to the three-dimensional injection and production well network deployment method for a low permeability sandstone gas storage reservoir as claimed in any one of claims 1 to 8, It is characterized in that include: The working gas volume calculation module is used to characterize the spatial distribution of gas and water, determine the closed gas reservoir of a single well, fit the relationship between the cumulative gas production and the number of production days for the closed gas reservoir of a single well, and predict the recovery rate to determine the recoverable reserves. According to the natural gas reserve management standards, the recovery rate is determined to obtain the current producing reserves and the maximum producing reserves. Then, the closed gas reservoir material balance method is used to obtain the current reserve production status and pressure maintenance status to determine the reasonable working gas volume; Conventional production capacity calculation module, used to confirm the conventional production capacity of vertical well development based on dynamic monitoring data; Horizontal section calculation module, used to determine the reasonable length of the horizontal section of the horizontal well; The injection-production well network deployment module is used to design and deploy the injection-production well network based on the detailed description of the gas reservoir and multiple oil groups with well-developed interlayers.

10. A medium, It is characterized in that The medium stores computer executable instructions, and the computer executable instructions are used to implement the three-dimensional injection and production well network deployment method for a low permeability sandstone gas storage reservoir as described in any one of claims 1-8.

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