Well pattern density determination method and device, storage medium and equipment

Abstract

The invention discloses a well pattern density determination method and device, a storage medium and equipment. The method comprises the steps that initial productivity data of a preset regular well pattern is obtained, a first relational graph of first well pattern density and the initial productivity data is constructed, and the first well pattern density is the well pattern density of the preset regular well pattern; arranging an infilled well in a preset regular well pattern, and determining an infilled well pattern and a second well pattern density corresponding to the infilled well pattern; obtaining encrypted productivity data of the encrypted well pattern, and constructing a second relational graph between the second well pattern density and the encrypted productivity data; and performing optimization processing on the second well pattern density based on the first relational graph and the second relational graph, and determining the target well pattern density. The method solves the technical problems that the dynamic change in the tight gas reservoir development process is not considered in the existing well pattern density optimization, and the determination result of the well pattern density is inaccurate.

Description

Technical Field

[0001] The present invention relates to the technical field of tight gas reservoir well pattern optimization, and in particular to a method, device, storage medium and equipment for determining well pattern density. Background Art

[0002] For tight gas reservoirs, increasing the well density is the main means to improve the recovery rate of gas reservoirs. However, as the well density increases, interference will occur between wells, the final cumulative gas production of a single well will gradually decrease, the growth of gas reservoir recovery rate will gradually slow down, and the economic benefits of gas reservoir development will gradually decrease. At present, the optimization of well density for tight gas reservoirs at home and abroad mainly considers two parameters: the recovery rate representing the development effect and the internal rate of return representing the economic benefit. When the internal rate of return meets certain conditions and the gas reservoir recovery rate is relatively high, it is considered that the well density under the corresponding conditions is the reasonable well density for the tight gas reservoir.

[0003] However, the existing well network density optimization mainly considers the recovery rate and yield rate, but does not take into account the dynamic changes in the development process of tight gas reservoirs. It is a static evaluation method, and the evaluated reasonable well network density is only applicable to specific parameter conditions in a certain period.

[0004] To address the above-mentioned problems, no effective solution has been proposed yet. Summary of the invention

[0005] The embodiments of the present invention provide a method, device, storage medium and equipment for determining well pattern density, so as to at least solve the technical problem that the existing well pattern density optimization does not consider the dynamic changes in the tight gas reservoir development process, and the well pattern density determination results are inaccurate.

[0006] According to one aspect of an embodiment of the present invention, a method for determining a well network density is provided, comprising: obtaining initial production capacity data of a preset regular well network, and constructing a first relationship diagram between a first well network density and the initial production capacity data, wherein the first well network density is the well network density of the preset regular well network, and the first relationship diagram comprises: a first gas production relationship diagram, a first yield relationship diagram and a first formation pressure data relationship diagram; setting encrypted wells in the preset regular well network, determining an encrypted well network and a second well network density corresponding to the encrypted well network; obtaining encrypted production capacity data of the encrypted well network, and constructing a second relationship diagram between the second well network density and the encrypted production capacity data, wherein the second relationship diagram comprises: a second gas production relationship diagram, a second yield relationship diagram and a second formation pressure data relationship diagram; optimizing the second well network density based on the first relationship diagram and the second relationship diagram to determine the target well network density.

[0007] Optionally, the above-mentioned obtaining of the initial production capacity data of the preset regular well network and constructing a first relationship diagram between the first well network density and the above-mentioned initial production capacity data include: obtaining the initial production capacity data of the above-mentioned preset regular well network, wherein the above-mentioned initial production capacity data include: a first gas production, a first rate of return and a first formation pressure data; constructing a first gas production relationship diagram between the first well network density and the above-mentioned first gas production based on the above-mentioned first gas production, constructing a first rate of return relationship diagram between the above-mentioned first well network density and the above-mentioned first rate of return based on the above-mentioned first rate of return, and constructing a first formation pressure data relationship diagram between the above-mentioned first well network density and the above-mentioned first formation pressure data based on the above-mentioned first formation pressure data; determining the above-mentioned first gas production relationship diagram, the above-mentioned first rate of return relationship diagram and the above-mentioned first formation pressure data relationship diagram as the above-mentioned first relationship diagram.

[0008] Optionally, the above-mentioned setting of encrypted wells in the above-mentioned preset regular well network, determining the encrypted well network and the second well network density corresponding to the above-mentioned encrypted well network, includes: determining the positions of vertical wells in the above-mentioned preset regular well network; determining the positions of encrypted wells based on the above-mentioned vertical well positions and preset interval distances; setting the above-mentioned encrypted wells based on the above-mentioned encrypted well positions, and determining the above-mentioned second well network density.

[0009] Optionally, the above-mentioned obtaining of the encrypted production capacity data of the above-mentioned encrypted well network and constructing a second relationship graph between the above-mentioned second well network density and the above-mentioned encrypted production capacity data include: obtaining the encrypted production capacity data of the above-mentioned encrypted well network, wherein the above-mentioned encrypted production capacity data include: second gas production, second rate of return and second formation pressure data; constructing a second gas production relationship graph between the second well network density and the above-mentioned second gas production based on the above-mentioned second gas production, constructing a second rate of return relationship graph between the above-mentioned second well network density and the above-mentioned second rate of return based on the above-mentioned second rate of return, and constructing a second formation pressure data relationship graph between the above-mentioned second well network density and the above-mentioned second formation pressure data based on the above-mentioned second formation pressure data; determining the above-mentioned second gas production relationship graph, the above-mentioned second rate of return relationship graph and the above-mentioned second formation pressure data relationship graph as the above-mentioned second relationship graph.

[0010] Optionally, the above-mentioned second well network density is optimized based on the above-mentioned first relationship diagram and the above-mentioned second relationship diagram to determine the target well network density, including: comparing the above-mentioned first relationship diagram and the above-mentioned second relationship diagram to determine the comparison result; determining the internal rate of return based on the above-mentioned comparison result; when the above-mentioned internal rate of return reaches a preset rate of return threshold, determining that the well network density corresponding to the above-mentioned internal rate of return is the above-mentioned target well network density.

[0011] According to another aspect of an embodiment of the present invention, a well network density determination device is also provided, including: a first acquisition module, used to acquire the initial production capacity data of a preset regular well network, and construct a first relationship diagram between the first well network density and the above-mentioned initial production capacity data, wherein the above-mentioned first well network density is the well network density of the above-mentioned preset regular well network, and the above-mentioned first relationship diagram includes: a first gas production relationship diagram, a first yield relationship diagram and a first formation pressure data relationship diagram; a first determination module, used to set encrypted wells in the above-mentioned preset regular well network, determine the encrypted well network and a second well network density corresponding to the above-mentioned encrypted well network; a second acquisition module, used to acquire the encrypted production capacity data of the above-mentioned encrypted well network, and construct a second relationship diagram between the above-mentioned second well network density and the above-mentioned encrypted production capacity data, wherein the above-mentioned second relationship diagram includes: a second gas production relationship diagram, a second yield relationship diagram and a second formation pressure data relationship diagram; a second determination module, used to optimize the above-mentioned second well network density based on the above-mentioned first relationship diagram and the above-mentioned second relationship diagram to determine the target well network density.

[0012] According to another aspect of an embodiment of the present invention, a non-volatile storage medium is provided. The non-volatile storage medium stores a plurality of instructions. The instructions are suitable for being loaded by a processor and executing any one of the well pattern density determination methods.

[0013] According to another aspect of an embodiment of the present invention, a processor is further provided, and the processor is used to run a program, wherein the program is configured to execute any one of the above-mentioned well pattern density determination methods when running.

[0014] According to another aspect of an embodiment of the present invention, there is also provided an electronic device, including a memory and a processor, wherein the memory stores a computer program, and the processor is configured to run the computer program to execute any one of the above-mentioned well pattern density determination methods.

[0015] In an embodiment of the present invention, initial production capacity data of a preset regular well network is obtained, and a first relationship diagram between a first well network density and the initial production capacity data is constructed, wherein the first well network density is the well network density of the preset regular well network, and the first relationship diagram includes: a first gas production relationship diagram, a first yield relationship diagram, and a first formation pressure data relationship diagram; infill wells are set in the preset regular well network, and an infill well network and a second well network density corresponding to the infill well network are determined; the infill production capacity data of the infill well network are obtained, and a second relationship diagram between the second well network density and the infill production capacity data is constructed, wherein the second relationship The figures include: a second gas production relationship diagram, a second rate of return relationship diagram and a second formation pressure data relationship diagram; based on the above first relationship diagram and the above second relationship diagram, the above second well network density is optimized to determine the target well network density, thereby achieving the purpose of clarifying the cumulative gas production of the infill wells when the gas reservoir is infilled to different well network densities as the production time of the old wells changes, thereby achieving the technical effect of calculating the critical benefit cumulative gas production of the gas wells in combination with factors such as the internal rate of return, and then determining the density of the infill wells, thereby solving the technical problem that the existing well network density optimization does not take into account the dynamic changes in the development process of the tight gas reservoir and the well network density determination results are inaccurate. BRIEF DESCRIPTION OF THE DRAWINGS

[0016] The drawings described herein are used to provide a further understanding of the present invention and constitute a part of this application. The exemplary embodiments of the present invention and their descriptions are used to explain the present invention and do not constitute an improper limitation of the present invention. In the drawings:

[0017] Figure 1 is a flow chart of a method for determining well pattern density according to an embodiment of the present invention;

[0018] Figure 2 It is a schematic diagram of average single-well cumulative gas production of different well pattern densities in an optional overall deployment according to an embodiment of the present invention;

[0019] Figure 3 It is a schematic diagram of cumulative gas production of critical benefits of a gas well under different optional natural gas prices and different internal rate of return conditions according to an embodiment of the present invention;

[0020] Figure 4 It is an optional schematic diagram of formation pressure at different distances and different production times of old wells according to an embodiment of the present invention;

[0021] Figure 5 This is a schematic diagram of an optional control range and mutual interference of old wells and infill wells according to an embodiment of the present invention;

[0022] Figure 6 It is a schematic diagram of cumulative gas production of infilled wells under different optional infilling timings and different well pattern densities according to an embodiment of the present invention;

[0023] Figure 7 It is an optional cumulative gas production of infill wells EUR2 and the cumulative gas production of single well critical benefit EUR according to an embodiment of the present invention. 临界 Schematic diagram for comparison;

[0024] Figure 8 It is a schematic diagram of different optional natural gas prices, different infill timings and economic limit well pattern densities according to an embodiment of the present invention;

[0025] Fig. 9 It is a structural schematic diagram of a well pattern density determination device according to an embodiment of the present invention. DETAILED DESCRIPTION

[0026] In order to enable those skilled in the art to better understand the scheme of the present invention, the technical scheme in the embodiments of the present invention will be clearly and completely described below in conjunction with the drawings in the embodiments of the present invention. Obviously, the described embodiments are only part of the embodiments of the present invention, not all of the embodiments. Based on the embodiments of the present invention, all other embodiments obtained by ordinary technicians in this field without creative work should fall within the scope of protection of the present invention.

[0027] It should be noted that the terms "first", "second", etc. in the specification and claims of the present invention and the above-mentioned drawings are used to distinguish similar objects, and are not necessarily used to describe a specific order or sequence. It should be understood that the data used in this way can be interchanged where appropriate, so that the embodiments of the present invention described herein can be implemented in an order other than those illustrated or described herein. In addition, the terms "including" and "having" and any variations thereof are intended to cover non-exclusive inclusions, for example, a process, method, system, product or device that includes a series of steps or units is not necessarily limited to those steps or units that are clearly listed, but may include other steps or units that are not clearly listed or inherent to these processes, methods, products or devices.

[0028] Example 1

[0029] According to an embodiment of the present invention, an embodiment of a method for determining a well network density is provided. It should be noted that the steps shown in the flowchart of the accompanying drawings can be executed in a computer system such as a set of computer executable instructions, and although a logical order is shown in the flowchart, in some cases, the steps shown or described can be executed in an order different from that shown here.

[0030] Figure 1 FIG. 1 is a flow chart of a method for determining well pattern density according to an embodiment of the present invention. Figure 1 As shown, the method comprises the following steps:

[0031] Step S102, obtaining initial productivity data of a preset regular well pattern, and constructing a first relationship diagram between a first well pattern density and the initial productivity data, wherein the first well pattern density is the well pattern density of the preset regular well pattern, and the first relationship diagram includes: a first gas production relationship diagram, a first yield relationship diagram, and a first formation pressure data relationship diagram;

[0032] Step S104, setting up infill wells in the above-mentioned preset regular well pattern, determining the infill well pattern and a second well pattern density corresponding to the infill well pattern;

[0033] Step S106, obtaining the encrypted production capacity data of the encrypted well pattern, and constructing a second relationship diagram between the second well pattern density and the encrypted production capacity data, wherein the second relationship diagram includes: a second gas production relationship diagram, a second yield relationship diagram, and a second formation pressure data relationship diagram;

[0034] Step S108, optimizing the second well pattern density based on the first relationship diagram and the second relationship diagram to determine a target well pattern density.

[0035] In an embodiment of the present invention, the execution body of the well network density determination method provided in the above steps S102 to S108 is a well network density determination system, and the above system is used to obtain the initial production capacity data of the preset regular well network, and construct a first relationship diagram between the first well network density and the above initial production capacity data, wherein the above first well network density is the well network density of the above preset regular well network, and the above first relationship diagram includes: a first gas production relationship diagram, a first yield relationship diagram and a first formation pressure data relationship diagram; infill wells are set in the above preset regular well network, and the infill wells and the second well network density corresponding to the above infill well network are determined; the infill production capacity data of the above infill well network is obtained, and a second relationship diagram between the above second well network density and the above infill production capacity data is constructed, wherein the above second relationship diagram includes: a second gas production relationship diagram, a second yield relationship diagram and a second formation pressure data relationship diagram; the above second well network density is optimized based on the above first relationship diagram and the above second relationship diagram to determine the target well network density.

[0036] As an optional embodiment, as the gas reservoir is developed, conditions such as natural gas prices and expected internal rate of return change, and the original well network needs to be adjusted for densification multiple times. Therefore, the well network density is dynamically optimized by considering the natural gas price, expected internal rate of return and the timing of densification.

[0037] Through the embodiment of the present invention, the cumulative gas production of gas wells with different well pattern densities and the pressure distribution characteristics within the control range of different production times of old wells under the condition of the overall deployment of the well pattern are analyzed, and the cumulative gas production of the infilled wells when the gas reservoir is infilled to different well pattern densities as the production time of the old wells changes is clarified. At the same time, the critical benefit cumulative gas production of the gas wells is calculated by combining factors such as natural gas prices and internal rate of return, and finally a method for determining the economic limit well pattern density at different infill times of tight gas reservoirs is formed.

[0038] In an optional embodiment, the above-mentioned obtaining of the initial production capacity data of the preset regular well network and constructing a first relationship diagram between the first well network density and the above-mentioned initial production capacity data include: obtaining the initial production capacity data of the above-mentioned preset regular well network, wherein the above-mentioned initial production capacity data include: a first gas production, a first rate of return and a first formation pressure data; constructing a first gas production relationship diagram between the first well network density and the above-mentioned first gas production based on the above-mentioned first gas production, constructing a first rate of return relationship diagram between the above-mentioned first well network density and the above-mentioned first rate of return based on the above-mentioned first rate of return, and constructing a first formation pressure data relationship diagram between the above-mentioned first well network density and the above-mentioned first formation pressure data based on the above-mentioned first formation pressure data; determining the above-mentioned first gas production relationship diagram, the above-mentioned first rate of return relationship diagram and the above-mentioned first formation pressure data relationship diagram as the above-mentioned first relationship diagram.

[0039] As an optional embodiment, Figure 2 The figure shows the average cumulative gas production of a single well with different well network densities deployed as a whole. Based on the three-dimensional geological model of the study area, a regular well network with different well network densities is deployed in the study area with vertical wells as the well type. The gas reservoir numerical simulation technology is used to predict the average cumulative gas production of a single well EUR1 under the corresponding well network density conditions.

[0040] It should be noted that EUR1 is the average single well cumulative gas production based on the overall deployment of vertical wells and the corresponding well pattern density. 4 m 3 .

[0041] As an optional embodiment, Figure 3 The cumulative gas production of the critical benefit of the gas well under different natural gas prices and different internal rates of return is shown. On the basis of the clear decline law of the gas well, the cumulative gas production of the critical benefit of the gas well under different natural gas prices and different internal rates of return is evaluated. 临界 .

[0042] As an optional embodiment, Figure 4 The formation pressure diagram at different distances and different production times of old wells shown is established by analyzing the formation pressure test data of the gas wells that have been put into production, and the formation pressure diagram at different well spacings and different production times of old wells is established to clarify the distribution law of formation pressure within the control range of old wells with different production years.

[0043] Optionally, for a certain study area, vertical wells are used to deploy a well pattern density of 1.5 wells / km. 2 Up to 6.5 ports / km 2 The regular well pattern is used to predict the average cumulative gas production of a single well under different well pattern densities by numerical simulation. As the well pattern density increases, the average cumulative gas production of a single well decreases. When the well pattern density is 4.0 wells / km 2 When the average single well cumulative gas production EUR1 = 2073 × 10 4 m 3 Based on the clear decline law in the study area, the critical benefit cumulative gas production EUR of gas wells under different natural gas prices and different internal rates of return was evaluated. 临界 . With the same internal rate of return, as the natural gas price rises, the cumulative gas production of the critical benefit of a single well decreases; with the same natural gas price, the lower the internal rate of return, the lower the cumulative gas production of the critical benefit of a single well. When the natural gas price is 1.119 yuan / cubic meter and the internal rate of return is 8%, the cumulative gas production of the critical benefit of a gas well EUR 临界 =1530×10 4 m 3 By analyzing the formation pressure test data of the gas wells that have been put into production in the study area, a formation pressure chart was established at different distances and different production times of old wells in the area. That is, the formation pressure at 500m away from the old well that has been in production for 3 years is 18.2MPa. If the well network is deployed with a well spacing of 500m, the corresponding well network density is 4 wells / km 2 .

[0044] In an optional embodiment, the above-mentioned setting of encrypted wells in the above-mentioned preset regular well network, determining the encrypted well network and the second well network density corresponding to the above-mentioned encrypted well network, includes: determining the positions of vertical wells in the above-mentioned preset regular well network; determining the positions of encrypted wells based on the above-mentioned vertical well positions and preset interval distances; setting the above-mentioned encrypted wells based on the above-mentioned encrypted well positions, and determining the above-mentioned second well network density.

[0045] In an optional embodiment, the above-mentioned obtaining of the encrypted production capacity data of the above-mentioned encrypted well network and constructing a second relationship graph between the above-mentioned second well network density and the above-mentioned encrypted production capacity data include: obtaining the encrypted production capacity data of the above-mentioned encrypted well network, wherein the above-mentioned encrypted production capacity data include: second gas production, second rate of return and second formation pressure data; constructing a second gas production relationship graph between the second well network density and the above-mentioned second gas production based on the above-mentioned second gas production, constructing a second rate of return relationship graph between the above-mentioned second well network density and the above-mentioned second rate of return based on the above-mentioned second rate of return, and constructing a second formation pressure data relationship graph between the above-mentioned second well network density and the above-mentioned second formation pressure data based on the above-mentioned second formation pressure data; determining the above-mentioned second gas production relationship graph, the above-mentioned second rate of return relationship graph and the above-mentioned second formation pressure data relationship graph as the above-mentioned second relationship graph.

[0046] As an optional embodiment, Figure 5 The schematic diagram of the control range and mutual interference of old wells and infill wells is shown. The integral method is used to calculate the average formation pressure within the control range of infill wells at different production years and well spacings of old wells.

[0047]

[0048] Where: P 加密井 , average formation pressure within the control range of the infill wells, MPa; P i , original reservoir formation pressure, MPa; S1, overlapping area of ​​old well and infill well control range, m 2 ; S2, the area of ​​the infill well control range excluding the overlapping area between the old well and the infill well control range, m 2 ; ds, differential element of the overlapping area S1 of the old well and the infill well control range, m 2 ;P s , the average formation pressure when infilling wells within the range of ds, MPa, can be obtained from the distribution law of formation pressure within the control range of old wells with different production years.

[0049] As an optional embodiment, Figure 6 The cumulative gas production chart of the infilled wells at different infilling times and under different well network density conditions is shown. The corresponding cumulative gas production EUR2 of the infilled wells when the well network is infilled to different well network densities under different production years of old wells is obtained, and a chart of the cumulative gas production EUR2 of the infilled wells at different infilling times and under different well network density conditions is produced.

[0050]

[0051] Where: EUR2, the cumulative gas production of a single infill well when infilling to the corresponding well pattern density at different infilling times, 10 4 m 3 .

[0052] In an optional embodiment, the above-mentioned second well network density is optimized based on the above-mentioned first relationship diagram and the above-mentioned second relationship diagram to determine the target well network density, including: comparing the above-mentioned first relationship diagram and the above-mentioned second relationship diagram to determine the comparison result; determining the internal rate of return based on the above-mentioned comparison result; when the above-mentioned internal rate of return reaches a preset rate of return threshold, determining that the well network density corresponding to the above-mentioned internal rate of return is the above-mentioned target well network density.

[0053] As an optional embodiment, under different well density conditions, the cumulative gas production EUR2 of the infilled wells and the cumulative gas production EUR of the critical benefit of the gas wells 临界The cumulative gas production EUR of the corresponding gas well critical benefit under different natural gas prices and corresponding internal rate of return conditions 临界 , when EUR2 is equal to or slightly higher than EUR 临界 When, it is the economic limit well network density that can be intensified under the corresponding natural gas price and internal rate of return requirements for different old well production years (such as Figure 7 The cumulative gas production of the infill wells EUR2 and the cumulative gas production of the critical benefit of a single well EUR 临界 Comparison chart), and make Figure 8 The chart shows different natural gas prices, different infill opportunities and economic limit well density.

[0054] Optionally, the original formation pressure P in the above study area i =30Mpa, when a well is added next to an old well that has been in production for 3 years, and the distance between the wells is 500m (i.e. the well density is 4 wells / km 2 ), and use the integral method to calculate the average formation pressure P within the control range of the infill well 加密井 =22.27MPa. Well density increased to 4 wells / km 2 When the cumulative gas production of the infill well is EUR2=1539×10 4 m 3 The well density is increased to 4 wells / km. 2 When the cumulative gas production of the infill well is EUR2=1539×10 4 m 3 Slightly higher than the cumulative gas production of the gas well EUR when the natural gas price is 1.119 yuan / m3 and the internal rate of return is 8% in step 2 临界 =1530×10 4 m 3 Therefore, it can be considered that the well network density in the study area should be increased when the old wells have been in production for 3 years, the natural gas price is 1.119 yuan / m3, and the internal rate of return is 8%. The economic limit well network density after the increase is 4 wells / km 2 , that is, the density of well network after infill is less than 4 wells / km 2 All of them can achieve an internal rate of return of 8%. At the same time, you can check the chart. When the old wells have been in production for 6 years, the natural gas price is 1.119 yuan / m3, and the internal rate of return is 8%, the well network density is increased. The economic limit well network density after encryption is 3.5 wells / km 2 At the same time, a map of different natural gas prices, different infill opportunities and economic limit well density was produced for the study area.

[0055] Through the above steps, we can fully consider the influencing factors such as natural gas prices, well density, and old well production conditions, and determine the economic limit well density that can be encrypted under different encryption timing conditions. In addition, multiple sets of charts are formed, and corresponding relationship charts can be established for specific research areas. When parameters such as natural gas prices, old well production years, and internal rate of return change, the economic limit well density under specific conditions can be quickly determined by simply querying the charts.

[0056] Example 2

[0057] According to an embodiment of the present invention, there is also provided an embodiment of a device for implementing the above-mentioned method for determining well pattern density. Fig. 9 is a schematic diagram of the structure of a well pattern density determination device according to an embodiment of the present invention. Fig. 9 As shown, the above device includes: a first acquisition module 90, a first determination module 92, a second acquisition module 94 and a second determination module 96, wherein:

[0058] A first acquisition module 90 is used to acquire initial productivity data of a preset regular well pattern, and construct a first relationship diagram between a first well pattern density and the initial productivity data, wherein the first well pattern density is the well pattern density of the preset regular well pattern, and the first relationship diagram includes: a first gas production relationship diagram, a first yield relationship diagram, and a first formation pressure data relationship diagram;

[0059] A first determination module 92 is used to set up infill wells in the above-mentioned preset regular well pattern, determine the infill well pattern and a second well pattern density corresponding to the infill well pattern;

[0060] The second acquisition module 94 is used to obtain the encrypted production capacity data of the encrypted well pattern, and construct a second relationship diagram between the second well pattern density and the encrypted production capacity data, wherein the second relationship diagram includes: a second gas production relationship diagram, a second yield relationship diagram and a second formation pressure data relationship diagram;

[0061] The second determination module 96 is used to optimize the second well pattern density based on the first relationship diagram and the second relationship diagram to determine the target well pattern density.

[0062] It should be noted here that the above-mentioned first acquisition module 90, first determination module 92, second acquisition module 94 and second determination module 96 correspond to steps S102 to S108 in Example 1, and the four modules and the corresponding steps implement the same instances and application scenarios, but are not limited to the contents disclosed in the above-mentioned Example 1.

[0063] It should be noted that the preferred implementation of this embodiment can refer to the relevant description in Example 1, which will not be repeated here.

[0064] According to an embodiment of the present invention, an embodiment of a computer-readable storage medium is also provided. Optionally, in this embodiment, the computer-readable storage medium can be used to store the program code executed by the method for determining the well pattern density provided in the above embodiment 1.

[0065] Optionally, in this embodiment, the computer-readable storage medium may be located in any computer terminal in a computer terminal group in a computer network, or in any mobile terminal in a mobile terminal group.

[0066] Optionally, in this embodiment, the computer-readable storage medium is configured to store program codes for executing the following steps: obtaining initial production capacity data of a preset regular well network, and constructing a first relationship diagram between a first well network density and the above-mentioned initial production capacity data, wherein the above-mentioned first well network density is the well network density of the above-mentioned preset regular well network, and the above-mentioned first relationship diagram includes: a first gas production relationship diagram, a first yield relationship diagram and a first formation pressure data relationship diagram; setting encrypted wells in the above-mentioned preset regular well network, determining an encrypted well network and a second well network density corresponding to the above-mentioned encrypted well network; obtaining the encrypted production capacity data of the above-mentioned encrypted well network, and constructing a second relationship diagram between the above-mentioned second well network density and the above-mentioned encrypted production capacity data, wherein the above-mentioned second relationship diagram includes: a second gas production relationship diagram, a second yield relationship diagram and a second formation pressure data relationship diagram; optimizing the above-mentioned second well network density based on the above-mentioned first relationship diagram and the above-mentioned second relationship diagram to determine the target well network density.

[0067] Optionally, the computer-readable storage medium is configured to store program codes for executing the following steps: obtaining initial production capacity data of the preset regular well network, wherein the initial production capacity data includes: a first gas production, a first rate of return and a first formation pressure data; constructing a first gas production relationship diagram between the first well network density and the first gas production based on the first gas production, constructing a first rate of return relationship diagram between the first well network density and the first rate of return based on the first rate of return, and constructing a first formation pressure data relationship diagram between the first well network density and the first formation pressure data based on the first formation pressure data; determining the first gas production relationship diagram, the first rate of return relationship diagram and the first formation pressure data relationship diagram as the first relationship diagram.

[0068] Optionally, the computer-readable storage medium is configured to store program codes for executing the following steps: determining the positions of vertical wells in the preset regular well network; determining the positions of infill wells based on the vertical well positions and preset spacing distances; setting the infill wells based on the infill well positions, and determining the second well network density.

[0069] Optionally, the computer-readable storage medium is configured to store program code for executing the following steps: obtaining encrypted production capacity data of the encrypted well network, wherein the encrypted production capacity data includes: second gas production, second yield rate and second formation pressure data; constructing a second gas production relationship diagram between the second well network density and the second gas production based on the second gas production, constructing a second yield rate relationship diagram between the second well network density and the second yield rate based on the second yield rate, and constructing a second formation pressure data relationship diagram between the second well network density and the second formation pressure data based on the second formation pressure data; determining the second gas production relationship diagram, the second yield rate relationship diagram and the second formation pressure data relationship diagram as the second relationship diagram.

[0070] Optionally, the computer-readable storage medium is configured to store program codes for executing the following steps: comparing the first relationship diagram and the second relationship diagram to determine the comparison result; determining the internal rate of return based on the comparison result; when the internal rate of return reaches a preset rate of return threshold, determining that the well network density corresponding to the internal rate of return is the target well network density.

[0071] According to an embodiment of the present invention, an embodiment of a processor is also provided. Optionally, in this embodiment, the computer-readable storage medium may be used to store program codes executed by the method for determining the well pattern density provided in the first embodiment.

[0072] An embodiment of the present application provides an electronic device, which includes a processor, a memory, and a program stored in the memory and executable on the processor. When the processor executes the program, the following steps are implemented: obtaining initial production capacity data of a preset regular well network, and constructing a first relationship diagram between a first well network density and the initial production capacity data, wherein the first well network density is the well network density of the preset regular well network, and the first relationship diagram includes: a first gas production relationship diagram, a first yield relationship diagram, and a first formation pressure data relationship diagram; setting encrypted wells in the preset regular well network, determining an encrypted well network and a second well network density corresponding to the encrypted well network; obtaining encrypted production capacity data of the encrypted well network, and constructing a second relationship diagram between the second well network density and the encrypted production capacity data, wherein the second relationship diagram includes: a second gas production relationship diagram, a second yield relationship diagram, and a second formation pressure data relationship diagram; optimizing the second well network density based on the first relationship diagram and the second relationship diagram to determine the target well network density.

[0073] The present application also provides a computer program product, which, when executed on a data processing device, is suitable for executing an initialized program having the following method steps: obtaining initial production capacity data of a preset regular well network, and constructing a first relationship diagram between a first well network density and the above initial production capacity data, wherein the above first well network density is the well network density of the above preset regular well network, and the above first relationship diagram includes: a first gas production relationship diagram, a first yield relationship diagram and a first formation pressure data relationship diagram; setting encrypted wells in the above preset regular well network, determining an encrypted well network and a second well network density corresponding to the above encrypted well network; obtaining encrypted production capacity data of the above encrypted well network, and constructing a second relationship diagram between the above second well network density and the above encrypted production capacity data, wherein the above second relationship diagram includes: a second gas production relationship diagram, a second yield relationship diagram and a second formation pressure data relationship diagram; optimizing the above second well network density based on the above first relationship diagram and the above second relationship diagram to determine the target well network density.

[0074] The serial numbers of the above embodiments of the present invention are only for description and do not represent the advantages or disadvantages of the embodiments.

[0075] In the above embodiments of the present invention, the description of each embodiment has its own emphasis. For parts that are not described in detail in a certain embodiment, reference can be made to the relevant descriptions of other embodiments.

[0076] In the several embodiments provided in this application, it should be understood that the disclosed technical content can be implemented in other ways. Among them, the device embodiments described above are only schematic. For example, the division of the units can be a logical function division. There may be other division methods in actual implementation. For example, multiple units or components can be combined or integrated into another system, or some features can be ignored or not executed. Another point is that the mutual coupling or direct coupling or communication connection shown or discussed can be through some interfaces, indirect coupling or communication connection of units or modules, which can be electrical or other forms.

[0077] The units described as separate components may or may not be physically separated, and the components shown as units may or may not be physical units, that is, they may be located in one place or distributed on multiple units. Some or all of the units may be selected according to actual needs to achieve the purpose of the present embodiment.

[0078] In addition, each functional unit in each embodiment of the present invention may be integrated into one processing unit, or each unit may exist physically separately, or two or more units may be integrated into one unit. The above-mentioned integrated unit may be implemented in the form of hardware or in the form of software functional units.

[0079] If the integrated unit is implemented in the form of a software functional unit and sold or used as an independent product, it can be stored in a computer-readable storage medium. Based on this understanding, the technical solution of the present invention, in essence, or the part that contributes to the prior art, or all or part of the technical solution can be embodied in the form of a software product, and the computer software product is stored in a storage medium, including a number of instructions for a computer device (which can be a personal computer, a server or a network device, etc.) to perform all or part of the steps of the method described in each embodiment of the present invention. The aforementioned storage medium includes: U disk, read-only memory (ROM, Read-Only Memory), random access memory (RAM, Random Access Memory), mobile hard disk, magnetic disk or optical disk and other media that can store program codes.

[0080] The above is only a preferred embodiment of the present invention. It should be pointed out that for ordinary technicians in this technical field, several improvements and modifications can be made without departing from the principle of the present invention. These improvements and modifications should also be regarded as the scope of protection of the present invention.

Claims

1. A method for determining well pattern density, characterized in that: include: Acquire initial productivity data of a preset regular well pattern, and construct a first relationship diagram between a first well pattern density and the initial productivity data, wherein the first well pattern density is the well pattern density of the preset regular well pattern, and the first relationship diagram includes: a first gas production relationship diagram, a first yield relationship diagram, and a first formation pressure data relationship diagram; Setting up infill wells in the preset regular well pattern, determining the infill well pattern and a second well pattern density corresponding to the infill well pattern; Acquire the encrypted production capacity data of the encrypted well network, and construct a second relationship diagram between the second well network density and the encrypted production capacity data, wherein the second relationship diagram includes: a second gas production relationship diagram, a second yield relationship diagram, and a second formation pressure data relationship diagram; The second well pattern density is optimized based on the first relationship diagram and the second relationship diagram to determine a target well pattern density.

2. The method according to claim 1, characterized in that: The obtaining of the initial productivity data of the preset regular well pattern and constructing a first relationship diagram between the first well pattern density and the initial productivity data includes: Acquiring initial productivity data of the preset regular well pattern, wherein the initial productivity data includes: first gas production, first yield rate and first formation pressure data; constructing a first gas production relationship graph between a first well pattern density and the first gas production based on the first gas production, constructing a first yield relationship graph between the first well pattern density and the first yield based on the first yield, and constructing a first formation pressure data relationship graph between the first well pattern density and the first formation pressure data based on the first formation pressure data; The first gas production relationship graph, the first rate of return relationship graph and the first formation pressure data relationship graph are determined as the first relationship graph.

3. The method according to claim 1, characterized in that The step of setting up the encrypted wells in the preset regular well pattern and determining the encrypted well pattern and a second well pattern density corresponding to the encrypted well pattern includes: Determining the vertical well positions in the preset regular well pattern; Determine the location of the infill well based on the vertical well location and the preset spacing distance; The infill wells are set based on the infill well positions, and the second well network density is determined.

4. The method according to claim 1, characterized in that: The step of obtaining the encrypted production capacity data of the encrypted well pattern and constructing a second relationship diagram between the second well pattern density and the encrypted production capacity data includes: Acquire encrypted production capacity data of the encrypted well pattern, wherein the encrypted production capacity data includes: second gas production, second yield rate and second formation pressure data; constructing a second gas production relationship graph between the second well pattern density and the second gas production based on the second gas production, constructing a second yield relationship graph between the second well pattern density and the second yield based on the second yield, and constructing a second formation pressure data relationship graph between the second well pattern density and the second formation pressure data based on the second formation pressure data; The second gas production relationship graph, the second rate of return relationship graph and the second formation pressure data relationship graph are determined as the second relationship graph.

5. The method according to claim 1, characterized in that The optimizing the second well pattern density based on the first relationship graph and the second relationship graph to determine the target well pattern density includes: Comparing the first relationship graph and the second relationship graph to determine a comparison result; Determining an internal rate of return based on the comparison results; When the internal rate of return reaches a preset rate of return threshold, the well pattern density corresponding to the internal rate of return is determined as the target well pattern density.

6. A device for determining well pattern density, characterized in that: include: A first acquisition module is used to acquire initial productivity data of a preset regular well pattern, and construct a first relationship diagram between a first well pattern density and the initial productivity data, wherein the first well pattern density is the well pattern density of the preset regular well pattern, and the first relationship diagram includes: a first gas production relationship diagram, a first yield relationship diagram, and a first formation pressure data relationship diagram; A first determination module is used to set up infill wells in the preset regular well pattern, determine the infill well pattern and a second well pattern density corresponding to the infill well pattern; A second acquisition module is used to acquire the encrypted production capacity data of the encrypted well pattern, and construct a second relationship diagram between the second well pattern density and the encrypted production capacity data, wherein the second relationship diagram includes: a second gas production relationship diagram, a second yield relationship diagram, and a second formation pressure data relationship diagram; The second determination module is used to optimize the second well pattern density based on the first relationship diagram and the second relationship diagram to determine a target well pattern density.

7. A non-volatile storage medium, characterized in that: The non-volatile storage medium stores a plurality of instructions, and the instructions are suitable for being loaded by a processor and executing the method for determining the well pattern density according to any one of claims 1 to 5.

8. A processor, characterized in that: The processor is used to run a program, wherein the program is configured to execute the well pattern density determination method according to any one of claims 1 to 5 when running.

9. An electronic device, comprising a memory and a processor, characterized in that: A computer program is stored in the memory, and the processor is configured to run the computer program to execute the well pattern density determination method according to any one of claims 1 to 5.

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