Method, device and equipment for determining rock compression coefficient of gas storage geologic body and medium

Abstract

The invention discloses a gas storage geologic body rock compression coefficient determination method, device, equipment and medium, and the method comprises the steps: obtaining stratum data and historical production data corresponding to a target gas storage geologic body, the stratum data comprising original stratum pressure data and stratum temperature data; the historical production data comprises accumulated gas production rate; determining the geologic body water storage amount corresponding to the target gas storage geologic body according to the stratum data and the historical production data; and determining a compression coefficient corresponding to the target gas storage geologic body based on the geologic body water storage amount and the gas storage geologic body material balance equation. Based on the technical scheme, the geologic body water storage amount is determined according to the stratum data and the historical production data corresponding to the target gas storage geologic body, and the compression coefficient is rapidly determined according to the geologic body water storage amount and the gas storage geologic body material balance equation, so that the compression coefficient of the gas storage geologic body can be rapidly and accurately calculated; and the calculation efficiency of the compression coefficient is improved.

Description

Technical Field

[0001] This invention relates to the field of gas storage geological body parameter calculation technology, and in particular to a method, apparatus, equipment and medium for determining the rock compressibility coefficient of a gas storage geological body. Background Technology

[0002] The compressibility factor is a crucial parameter in well test analysis and the calculation of the mass balance equation for gas reservoirs. Currently, various methods for calculating the dynamic reserves of gas reservoirs are primarily based on the mass balance equation. Regardless of the method used, the compressibility factor remains critical, significantly impacting the estimation of gas reservoir reserves. Furthermore, the compressibility factor is also vital in oil and gas well testing, as the interpretation results of skin factor, detection radius, and fault distance are all affected by its accuracy.

[0003] However, there are two main existing methods for determining the compressibility coefficient: laboratory measurement and empirical formula methods. Laboratory measurement methods are accurate and highly specific, but complex and costly. Empirical formula methods are simple, easy to use, and easy to calculate, but have strict applicable conditions, specifying rock type, pressure, and porosity. Furthermore, both of these methods are too complex to provide a simplified calculation of the compressibility coefficient. Summary of the Invention

[0004] This invention provides a method, apparatus, equipment, and medium for determining the compressibility coefficient of rocks in gas-bearing geological bodies. The method for calculating the compressibility coefficient is derived based on the material balance equation of the gas-bearing geological body. Using only historical cumulative gas production and formation pressure data, the compressibility coefficient of the gas-bearing geological body can be calculated quickly and accurately, thereby improving the calculation efficiency of the compressibility coefficient.

[0005] According to one aspect of the present invention, a method for determining the rock compressibility coefficient of a gas-bearing geological body is provided, comprising:

[0006] Acquire formation data and historical production data corresponding to the target gas storage geological body, wherein the formation data includes raw formation pressure data and formation temperature data; and the historical production data includes cumulative gas production.

[0007] The water volume of the geological body corresponding to the target gas storage geological body is determined based on the stratigraphic data and the historical production data.

[0008] The compressibility coefficient corresponding to the target gas-storing geological body is determined based on the water content of the geological body and the material balance equation of the gas-storing geological body.

[0009] According to another aspect of the present invention, an apparatus for determining the rock compressibility coefficient of a gas-bearing geological body is provided, comprising:

[0010] The data acquisition module is used to acquire formation data and historical production data corresponding to the target gas storage geological body. The formation data includes raw formation pressure data and formation temperature data; the historical production data includes cumulative gas production.

[0011] The water storage calculation module is used to determine the water storage of the geological body corresponding to the target gas storage geological body based on the stratigraphic data and the historical production data.

[0012] The compressibility coefficient determination module is used to determine the compressibility coefficient corresponding to the target gas storage geological body based on the water content of the geological body and the material balance equation of the gas storage geological body.

[0013] According to another aspect of the present invention, an electronic device is provided, the electronic device comprising:

[0014] At least one processor; and

[0015] A memory communicatively connected to the at least one processor; wherein,

[0016] The memory stores a computer program that can be executed by the at least one processor, which enables the at least one processor to perform the method for determining the rock compressibility of a gas-bearing geological body according to any embodiment of the present invention.

[0017] According to another aspect of the present invention, a computer-readable storage medium is provided, the computer-readable storage medium storing computer instructions for causing a processor to execute and implement the method for determining the rock compressibility coefficient of a gas-storage geological body as described in any embodiment of the present invention.

[0018] The technical solution of this invention involves acquiring stratigraphic data and historical production data corresponding to a target gas-bearing geological body, then determining the water content of the geological body based on the stratigraphic data and historical production data, and finally determining the compressibility coefficient corresponding to the target gas-bearing geological body based on the water content and the mass balance equation of the gas-bearing geological body. Based on this technical solution, the water content of the geological body is determined according to the stratigraphic data and historical production data corresponding to the target gas-bearing geological body, and the compressibility coefficient is quickly determined based on the water content and the mass balance equation of the gas-bearing geological body. This allows for rapid and accurate calculation of the compressibility coefficient of the gas-bearing geological body, thereby improving the calculation efficiency of the compressibility coefficient.

[0019] It should be understood that the description in this section is not intended to identify key or essential features of the embodiments of the present invention, nor is it intended to limit the scope of the invention. Other features of the invention will become readily apparent from the following description. Attached Figure Description

[0020] To more clearly illustrate the technical solutions in the embodiments of the present invention, the accompanying drawings used in the description of the embodiments will be briefly introduced below. Obviously, the accompanying drawings described below are only some embodiments of the present invention. For those skilled in the art, other drawings can be obtained based on these drawings without creative effort.

[0021] Figure 1 This is a flowchart illustrating a method for determining the rock compressibility coefficient of a gas-bearing geological body according to an embodiment of the present invention.

[0022] Figure 2 This is a schematic diagram of the production indicator curve of the gas storage geological body provided in an embodiment of the present invention;

[0023] Figure 3 This is a schematic diagram of the material balance line diagram of the gas storage geological body provided in the embodiment of the present invention;

[0024] Figure 4 This is a structural block diagram of a device for determining the rock compressibility of a gas-storage geological body, provided in an embodiment of the present invention.

[0025] Figure 5 This is a schematic diagram of the structure of the electronic device provided in an embodiment of the present invention. Detailed Implementation

[0026] To enable those skilled in the art to better understand the present invention, the technical solutions of the present invention will be clearly and completely described below with reference to the accompanying drawings of the embodiments of the present invention. Obviously, the described embodiments are only some embodiments of the present invention, and not all embodiments. Based on the embodiments of the present invention, all other embodiments obtained by those skilled in the art without creative effort should fall within the scope of protection of the present invention.

[0027] It should be noted that the terms "first," "second," etc., in the specification, claims, and accompanying drawings of this invention are used to distinguish similar objects and are not necessarily used to describe a specific order or sequence. It should be understood that such data can be interchanged where appropriate so that the embodiments of the invention described herein can be implemented in orders other than those illustrated or described herein. Furthermore, the terms "comprising" and "having," and any variations thereof, are intended to cover a non-exclusive inclusion; for example, a process, method, system, product, or apparatus that comprises a series of steps or units is not necessarily limited to those steps or units explicitly listed, but may include other steps or units not explicitly listed or inherent to such processes, methods, products, or apparatus.

[0028] Example 1

[0029] Figure 1 This is a flowchart illustrating a method for determining the rock compressibility coefficient of a gas-bearing geological body according to an embodiment of the present invention. This embodiment is applicable to situations where the compressibility coefficient of a gas-bearing geological body is quickly determined based on the corresponding stratigraphic data and historical production data. This method can be executed by a device for determining the rock compressibility coefficient of a gas-bearing geological body. This device can be implemented in hardware and / or software and can be configured in an electronic device, such as a server or a personal terminal. Figure 1 As shown, the method includes:

[0030] S110. Obtain stratigraphic data and historical production data corresponding to the target gas storage geological body.

[0031] In this context, the target gas-bearing geological body can be understood as the geological body whose compressibility coefficient needs to be determined. It should be noted that in the technical solution of this embodiment, the gas-bearing geological body can be understood as a water-intruded gas reservoir, meaning the technical solution provided by this embodiment is to determine the compressibility coefficient of the gas-bearing geological body in a water-intruded gas reservoir. Formation data can be monitoring data corresponding to each stratum of the gas-bearing geological body collected during the extraction process. Formation data includes original formation pressure data and formation temperature data. Historical production data can be understood as the amount of gas extracted from the gas-bearing geological body during the extraction process, corresponding to each stratum. Historical production data includes the cumulative gas production corresponding to each stratum.

[0032] Specifically, drilling technology can be used to deploy and drill wells into the target gas-bearing geological formation. During drilling, well logging techniques are used for formation evaluation, including resistivity logging, sonic logging, and density logging, to obtain detailed formation information and production information generated by the gas-bearing geological body during development, such as cumulative gas production data corresponding to the formation. It is important to note that when acquiring data, attention must be paid to the source and quality of the data to ensure its accuracy and reliability. Exploration and drilling logging data require professional processing and interpretation; historical production data needs to be verified and calibrated. Furthermore, the acquired formation data and historical production data need to be integrated and analyzed to establish accurate reservoir models and production prediction models.

[0033] S120. Determine the water volume of the geological body corresponding to the target gas storage geological body based on the stratigraphic data and the historical production data.

[0034] The water volume in a geological body can refer to the total amount of water stored within a gas-bearing geological body. This can include bound water, condensate water, mobile water, edge water, and bottom water within the target gas-bearing geological body. The amount of water in a geological body is influenced by various factors, such as the geological structure, rock properties, fluid properties, and water intrusion phenomena during development. For example, in gas-bearing geological bodies with strong reservoir heterogeneity or microstructures, the distribution and flow of water may be more complex, thus affecting the water volume of the gas-bearing geological body.

[0035] Specifically, after obtaining the stratigraphic data and historical production data corresponding to the target gas-bearing geological body, the water volume of the corresponding geological body can be determined using methods such as the mass balance equation or numerical simulation. The mass balance equation is established based on the principle of mass conservation of the gas-bearing geological body. By considering factors such as gas production and water intrusion during the development process, the water volume of the gas-bearing geological body can be calculated. Numerical simulation methods utilize computers for simulation and calculation, establishing geological and mathematical models of the gas-bearing geological body to predict its water volume. For example, using the mass balance principle, a mass balance equation for the gas-bearing geological body is established. This equation considers factors such as gas production, water intrusion, and formation pressure changes during the extraction process, and thus, the water volume in the gas-bearing geological body can be estimated. When using numerical simulation methods, oil and gas storage geological body numerical simulation software can be used to establish geological and fluid models of the gas-bearing geological body. By simulating the production dynamics of the gas-bearing geological body under different development schemes, the impact of water intrusion on the water volume of the geological body can be analyzed.

[0036] Based on the above technical solution, the step of determining the geological water volume corresponding to the target gas storage geological body according to the stratigraphic data and the historical production data includes: determining the stratigraphic temperature value corresponding to each stratum of the target gas storage geological body, and the gas relative density value corresponding to the target gas storage geological body; and determining the geological water volume of the target gas storage geological body based on the stratigraphic temperature value corresponding to each stratum of the target gas storage geological body and the gas relative density value.

[0037] Among them, the formation temperature value can be the temperature measurement value corresponding to each formation of the gas storage geological body. The relative density of the gas can be understood as the ratio of the density of the gas to the density of the reference substance. In the development of oil and gas storage geological bodies, the relative density of the gas is usually used to describe the composition and properties of natural gas.

[0038] Specifically, by installing well temperature logging instruments during drilling, the formation temperature is directly measured. Using known gas composition and property parameters (such as mole fraction of hydrocarbon components, critical temperature and pressure, etc.), the relative density of the gas is calculated using empirical formulas. After determining the formation temperature and gas relative density values, these parameters can be used to estimate the water content in the geological body. This can be achieved by combining the material balance equation of the gas-bearing geological body with known production data (such as gas production, water production, etc.), considering the influence of formation temperature and gas relative density on fluid properties, and estimating the water content in the gas-bearing geological body.

[0039] Based on the above technical solution, determining the geological water volume of the target gas storage geological body based on the formation temperature values ​​and gas relative density values ​​corresponding to each stratum of the target gas storage geological body includes: determining the natural gas deviation factor corresponding to each stratum of the target gas storage geological body according to the formation temperature values ​​and gas relative density values; determining the pseudo-formation pressure values ​​corresponding to each stratum of the target gas storage geological body based on the natural gas deviation factors and the original formation pressure data; and determining the geological water volume of the target gas storage geological body based on the pseudo-formation pressure values ​​corresponding to each stratum and the cumulative gas production.

[0040] The natural gas deviation factor can be used to describe the deviation between the volume of natural gas under actual conditions and the ideal gas volume. The pseudo-formation pressure value can be understood as a parameter used to describe the fluid flow characteristics in the gas storage geological body.

[0041] Specifically, the deviation factor can be determined by measuring the compressibility of natural gas, or it can be calculated using known parameters such as gas composition, formation temperature, and pressure through equations of state (such as the Peng-Robinson equation, the Soave-Redlich-Kwong equation, etc.). It should be noted that the technical solution of this embodiment uses the Chen method to calculate the natural gas deviation factor. After obtaining the natural gas deviation factor corresponding to the formation, the pseudo-formation pressure values ​​corresponding to each stratum of the target gas storage geological body are determined based on the natural gas deviation factor and the original formation pressure data. The original formation pressure data and the natural gas deviation factor can be compared to obtain the pseudo-formation pressure values ​​corresponding to each stratum. Then, based on the pseudo-formation pressure values ​​corresponding to each stratum and the cumulative gas production, the geological water volume of the target gas storage geological body is determined.

[0042] Based on the above technical solution, determining the geological water volume of the target gas-bearing geological body based on the pseudo-formation pressure value corresponding to each stratum and the cumulative gas production includes: determining a dimensionless production indicator curve corresponding to the target gas-bearing geological body based on the pseudo-formation pressure value and the cumulative gas production; determining the water volume coefficient corresponding to the target gas-bearing geological body based on the dimensionless production indicator curve; and determining the geological water volume of the target gas-bearing geological body based on the water volume coefficient and the formation data.

[0043] The dimensionless production indicator curve can be used to describe the production dynamics of an oil and gas storage geological body. The water volume factor can be understood as a parameter describing the relative content of water and gas in a gas storage geological body. It can be understood that in an anhydrous gas storage geological body, this factor is usually zero; while in a gas storage geological body, due to the presence of water, this factor will be greater than zero.

[0044] Specifically, production data of the target gas-bearing geological body is collected, including simulated formation pressure values, cumulative gas production, and time, etc. The cumulative gas production is used as the X-axis, and the corresponding simulated formation pressure values ​​of each formation are used as the Y-axis, establishing a system as follows: Figure 2 The diagram shows a dimensionless production indicator curve. After determining the water volume factor, this factor, along with formation data, can be used to estimate the water volume of the target gas-bearing geological body. Based on the water volume factor and formation data (such as the volume and porosity of the gas-bearing geological body), the water volume is calculated using an appropriate formula. Water volume is typically expressed as the ratio of the volume or mass of water to the volume or mass of gas in the gas-bearing geological body. It should be noted that the production indicator curve for a gas-bearing geological body-type gas storage facility may initially exhibit an upward sloping, near-straight, or downward sloping characteristic; the larger the water body, the more pronounced the upward sloping of the production indicator curve. Furthermore, the water volume of the geological body is calculated using the production indicator curve of the gas-bearing geological body-type gas storage facility, and then calculated using the formula... The water storage volume coefficient is calculated, where ΔPp represents the deviation of the production indicator curve from the straight line segment, in MPa; ω represents the water storage volume coefficient, which is dimensionless. This indicates the simulated pressure of the gas storage geological body, in MPa.

[0045] Based on the above technical solution, the step of determining the geological water volume of the target gas storage geological body based on the water volume coefficient and the formation data includes: substituting the formation data into the gas volume coefficient calculation formula to determine the gas volume coefficient corresponding to the target gas storage geological body; and determining the geological water volume of the target gas storage geological body based on the gas volume coefficient, the water volume coefficient, and the cumulative gas production.

[0046] The gas volume factor calculation formula can be understood as a pre-established formula for calculating the gas volume factor. The water volume factor can be a parameter describing the relative content of water and gas in a gas-bearing geological body.

[0047] Specifically, it is necessary to collect formation data of the target gas-bearing geological body, including formation temperature, formation pressure, and gas composition. Then, based on the gas composition and conditions, a suitable equation of state is selected to calculate the gas volume factor. The collected formation data is then substituted into the selected equation of state to calculate the gas volume factor corresponding to the target gas-bearing geological body. For example, according to the definition of the gas volume factor, the formation data will be substituted into the gas volume factor calculation formula. Where Bg represents the gas volume factor at the end of the development stage of the gas-bearing geological body, dimensionless; Z represents the deviation factor at the pressure at the end of the development stage of the gas-bearing geological body, dimensionless; T represents the formation temperature, K; P represents the pressure at the end of the development stage of the gas-bearing geological body, MPa; Tsc represents the temperature under standard conditions, K; and Psc represents the pressure under standard conditions, MPa. The temperature Tsc under standard conditions is taken as 293.15 K, and the pressure Psc under standard conditions is taken as 0.0101325 MPa. After determining the gas volume factor, the water volume factor, and the cumulative gas production, according to W = GB... gi ·ω×10 4 Calculate the water volume of the target gas-bearing geological body, where W represents the water volume (10⁴ m³), ​​G represents the geological reserves of the gas-bearing geological body (10⁸ m³), ​​and Bgi represents the gas volume coefficient under the original strata conditions (dimensionless).

[0048] S130. Based on the water content of the geological body and the material balance equation of the gas-storing geological body, determine the compressibility coefficient corresponding to the target gas-storing geological body.

[0049] The compressibility coefficient can be understood as a parameter used to describe the volume change of rocks and fluids in oil and gas reservoirs under pressure changes.

[0050] Specifically, after determining the water content of the geological body and the material balance equation of the gas-bearing geological body, the compressibility coefficient can be calculated by solving the equation. The water content of the geological body can be substituted into the material balance equation as a known condition to obtain the compressibility coefficient corresponding to the target gas-bearing geological body. It should be noted that the value of the compressibility coefficient is not only related to the geological structure and fluid properties of the gas-bearing geological body, but also affected by various factors such as pressure and temperature changes during the extraction process. Therefore, when determining the compressibility coefficient, it is necessary to comprehensively consider the influence of these factors and make necessary corrections and adjustments.

[0051] Based on the above technical solution, the step of determining the compressibility coefficient corresponding to the target gas-storing geological body based on the water content of the geological body and the material balance equation of the gas-storing geological body includes: drawing a material balance line graph corresponding to the target gas-storing geological body based on the material balance equation of the gas-storing geological body; determining the slope value of the line graph relative to the material balance line graph; and determining the compressibility coefficient based on the slope value of the line and the water content of the geological body.

[0052] Specifically, based on the material balance equation of the gas storage geological body, a material balance line diagram corresponding to the target gas storage geological body is drawn, and the slope value of the line relative to the material balance line diagram is determined, such as... Figure 3 As shown, the compressibility coefficient is determined based on the slope of the straight line and the water volume of the geological body. For example, it is assumed that the water intrusion is entirely caused by the elastic changes in the formation due to the decrease in pressure. The GB... gi =B g (GG p )+W e and W e The mass balance equation of the gas storage geological body is obtained by deforming WcΔp. Where Gp represents the cumulative gas production during the development stage of the gas-bearing geological body, 10⁸ m³; G represents the geological reserves of the gas-bearing geological body, 10⁸ m³; Bgi represents the gas volume coefficient under the original conditions of the gas-bearing geological body, dimensionless; Bg represents the gas volume coefficient at the end of the development stage of the gas-bearing geological body, dimensionless; W represents the water volume of the geological body, 10⁴ m³; c represents the compressibility coefficient, MPa⁻¹; Δp represents the cumulative pressure drop from the original formation conditions to the end of the development stage of the gas-bearing geological body, MPa. Furthermore, given the cumulative gas production GP, ​​formation pressure P, and volume coefficient Bg, ... For the X-axis, Plotting the Y-axis yields a straight line with slope Wc, which determines the value of Wc. The compressibility coefficient c is then calculated based on the water volume W of the geological body.

[0053] The technical solution of this invention involves acquiring stratigraphic data and historical production data corresponding to a target gas-bearing geological body, then determining the water content of the geological body based on the stratigraphic data and historical production data, and finally determining the compressibility coefficient corresponding to the target gas-bearing geological body based on the water content and the mass balance equation of the gas-bearing geological body. Based on this technical solution, the water content of the geological body is determined according to the stratigraphic data and historical production data corresponding to the target gas-bearing geological body, and the compressibility coefficient is quickly determined based on the water content and the mass balance equation of the gas-bearing geological body. This allows for rapid and accurate calculation of the compressibility coefficient of the gas-bearing geological body, thereby improving the calculation efficiency of the compressibility coefficient.

[0054] Example 2

[0055] Figure 4 This is a structural block diagram of a device for determining the rock compressibility of a gas-bearing geological body, provided as an embodiment of the present invention. Figure 4 As shown, the device includes: a data acquisition module 410, a water storage calculation module 420, and a compression coefficient determination module 430.

[0056] The data acquisition module 410 is used to acquire formation data and historical production data corresponding to the target gas storage geological body, wherein the original formation data includes original formation pressure data and formation temperature data; and the historical production data includes cumulative gas production.

[0057] The water storage calculation module 420 is used to determine the water storage of the geological body corresponding to the target gas storage geological body based on the stratigraphic data and the historical production data.

[0058] The compressibility coefficient determination module 430 is used to determine the compressibility coefficient corresponding to the target gas storage geological body based on the water content of the geological body and the material balance equation of the gas storage geological body.

[0059] Based on the above technical solution, the water storage calculation module is used to determine the formation temperature value corresponding to each stratum of the target gas storage geological body, and the gas relative density value corresponding to the target gas storage geological body; and to determine the geological body water storage of the target gas storage geological body based on the formation temperature value corresponding to each stratum of the target gas storage geological body and the gas relative density value.

[0060] Based on the above technical solution, the water storage calculation module is used to determine the natural gas deviation factor corresponding to each stratum of the target gas storage geological body according to the formation temperature value and the gas relative density value; determine the pseudo-formation pressure value corresponding to each stratum of the target gas storage geological body based on the natural gas deviation factor and the original formation pressure data; and determine the geological body water storage of the target gas storage geological body based on the pseudo-formation pressure value corresponding to each stratum and the cumulative gas production.

[0061] Based on the above technical solution, the water storage calculation module is used to determine the dimensionless production indicator curve corresponding to the target gas storage geological body based on the simulated formation pressure value and the cumulative gas production; determine the water storage volume coefficient corresponding to the target gas storage geological body according to the dimensionless production indicator curve; and determine the geological body water storage of the target gas storage geological body based on the water storage volume coefficient and the formation data.

[0062] Based on the above technical solution, the water storage calculation module is used to substitute the formation data into the gas volume factor calculation formula to determine the gas volume factor corresponding to the target gas storage geological body; and to determine the geological body water storage of the target gas storage geological body based on the gas volume factor, the water storage volume factor and the cumulative gas production.

[0063] Based on the above technical solution, the water storage calculation module is used to establish a dimensionless production indicator curve by taking the cumulative gas production as the X-axis and the corresponding pseudo-formation pressure value of each stratum as the Y-axis.

[0064] Based on the above technical solution, the compression coefficient determination module is used to draw a material balance line diagram corresponding to the target gas storage geological body based on the material balance equation of the gas storage geological body; determine the slope value of the line relative to the material balance line diagram; and determine the compression coefficient based on the slope value of the line and the water content of the geological body.

[0065] The technical solution of this invention involves acquiring stratigraphic data and historical production data corresponding to the target gas-bearing geological body, then determining the water content of the geological body based on the stratigraphic data and historical production data, and finally determining the compressibility coefficient corresponding to the target gas-bearing geological body based on the water content and the material balance equation of the gas-bearing geological body. Based on this technical solution, by determining the water content of the geological body according to the stratigraphic data and historical production data corresponding to the target gas-bearing geological body, and quickly determining the compressibility coefficient based on the water content and the material balance equation of the gas-bearing geological body, the compressibility coefficient of the gas-bearing geological body type can be calculated quickly and accurately, thereby improving the calculation efficiency of the compressibility coefficient.

[0066] The device for determining the rock compressibility of a gas-bearing geological body provided in this embodiment of the invention can execute the method for determining the rock compressibility of a gas-bearing geological body provided in any embodiment of the invention, and has the corresponding functional modules and beneficial effects of the method.

[0067] Example 3

[0068] Figure 5A schematic diagram of an electronic device 10 that can be used to implement embodiments of the present invention is shown. The electronic device is intended to represent various forms of digital computers, such as laptop computers, desktop computers, workstations, personal digital assistants, servers, blade servers, mainframe computers, and other suitable computers. The electronic device can also represent various forms of mobile devices, such as personal digital processors, cellular phones, smartphones, wearable devices (e.g., helmets, glasses, watches, etc.), and other similar computing devices. The components shown herein, their connections and relationships, and their functions are merely illustrative and are not intended to limit the implementation of the invention described and / or claimed herein.

[0069] like Figure 5 As shown, the electronic device 10 includes at least one processor 11 and a memory, such as a read-only memory (ROM) 12 or a random access memory (RAM) 13, communicatively connected to the at least one processor 11. The memory stores computer programs executable by the at least one processor. The processor 11 can perform various appropriate actions and processes based on the computer program stored in the ROM 12 or loaded from storage unit 18 into the RAM 13. The RAM 13 may also store various programs and data required for the operation of the electronic device 10. The processor 11, ROM 12, and RAM 13 are interconnected via a bus 14. An input / output (I / O) interface 15 is also connected to the bus 14.

[0070] Multiple components in electronic device 10 are connected to I / O interface 15, including: input unit 16, such as keyboard, mouse, etc.; output unit 17, such as various types of displays, speakers, etc.; storage unit 18, such as disk, optical disk, etc.; and communication unit 19, such as network card, modem, wireless transceiver, etc. Communication unit 19 allows electronic device 10 to exchange information / data with other devices through computer networks such as the Internet and / or various telecommunications networks.

[0071] Processor 11 can be a variety of general-purpose and / or special-purpose processing components with processing and computing capabilities. Some examples of processor 11 include, but are not limited to, a central processing unit (CPU), a graphics processing unit (GPU), various special-purpose artificial intelligence (AI) computing chips, various processors running machine learning model algorithms, digital signal processors (DSPs), and any suitable processor, controller, microcontroller, etc. Processor 11 performs the various methods and processes described above, such as the method for determining the rock compressibility coefficient of a gas-bearing geological body.

[0072] In some embodiments, the method for determining the rock compressibility coefficient of a gas-bearing geological body can be implemented as a computer program tangibly contained in a computer-readable storage medium, such as storage unit 18. In some embodiments, part or all of the computer program can be loaded and / or installed on electronic device 10 via ROM 12 and / or communication unit 19. When the computer program is loaded into RAM 13 and executed by processor 11, one or more steps of the method for determining the rock compressibility coefficient of a gas-bearing geological body described above can be performed. Alternatively, in other embodiments, processor 11 can be configured to perform the method for determining the rock compressibility coefficient of a gas-bearing geological body by any other suitable means (e.g., by means of firmware).

[0073] Various embodiments of the systems and techniques described above herein can be implemented in digital electronic circuit systems, integrated circuit systems, field-programmable gate arrays (FPGAs), application-specific integrated circuits (ASICs), application-specific standard products (ASSPs), systems-on-a-chip (SoCs), payload-programmable logic devices (CPLDs), computer hardware, firmware, software, and / or combinations thereof. These various embodiments may include implementations in one or more computer programs that can be executed and / or interpreted on a programmable system including at least one programmable processor, which may be a dedicated or general-purpose programmable processor, capable of receiving data and instructions from a storage system, at least one input device, and at least one output device, and transmitting data and instructions to the storage system, the at least one input device, and the at least one output device.

[0074] Computer programs used to implement the methods of the present invention may be written in any combination of one or more programming languages. These computer programs may be provided to a processor of a general-purpose computer, a special-purpose computer, or other programmable data processing device, such that when executed by the processor, the computer programs cause the functions / operations specified in the flowcharts and / or block diagrams to be performed. The computer programs may be executed entirely on a machine, partially on a machine, or as a standalone software package, partially on a machine and partially on a remote machine, or entirely on a remote machine or server.

[0075] In the context of this invention, a computer-readable storage medium can be a tangible medium that may contain or store a computer program for use by or in conjunction with an instruction execution system, apparatus, or device. A computer-readable storage medium may include, but is not limited to, electronic, magnetic, optical, electromagnetic, infrared, or semiconductor systems, apparatus, or devices, or any suitable combination thereof. Alternatively, a computer-readable storage medium may be a machine-readable signal medium. More specific examples of machine-readable storage media include electrical connections based on one or more wires, portable computer disks, hard disks, random access memory (RAM), read-only memory (ROM), erasable programmable read-only memory (EPROM or flash memory), optical fibers, portable compact disk read-only memory (CD-ROM), optical storage devices, magnetic storage devices, or any suitable combination thereof.

[0076] To provide interaction with a user, the systems and techniques described herein can be implemented on an electronic device having: a display device (e.g., a CRT (cathode ray tube) or LCD (liquid crystal display) monitor) for displaying information to the user; and a keyboard and pointing device (e.g., a mouse or trackball) through which the user provides input to the electronic device. Other types of devices can also be used to provide interaction with the user; for example, feedback provided to the user can be any form of sensory feedback (e.g., visual feedback, auditory feedback, or tactile feedback); and input from the user can be received in any form (including sound input, voice input, or tactile input).

[0077] The systems and technologies described herein can be implemented in computing systems that include backend components (e.g., as data servers), or computing systems that include middleware components (e.g., application servers), or computing systems that include frontend components (e.g., user computers with graphical user interfaces or web browsers through which users can interact with implementations of the systems and technologies described herein), or any combination of such backend, middleware, or frontend components. The components of the system can be interconnected via digital data communication of any form or medium (e.g., communication networks). Examples of communication networks include local area networks (LANs), wide area networks (WANs), blockchain networks, and the Internet.

[0078] A computing system can include clients and servers. Clients and servers are generally located far apart and typically interact through communication networks. The client-server relationship is created by computer programs running on the respective computers and having a client-server relationship with each other. The server can be a cloud server, also known as a cloud computing server or cloud host, which is a hosting product within the cloud computing service system to address the shortcomings of traditional physical hosts and VPS services, such as high management difficulty and weak business scalability.

[0079] It should be understood that the various forms of processes shown above can be used, with steps reordered, added, or deleted. For example, the steps described in this invention can be executed in parallel, sequentially, or in different orders, as long as the desired result of the technical solution of this invention can be achieved, and no limitation is imposed herein.

[0080] The specific embodiments described above do not constitute a limitation on the scope of protection of this invention. Those skilled in the art should understand that various modifications, combinations, sub-combinations, and substitutions can be made according to design requirements and other factors. Any modifications, equivalent substitutions, and improvements made within the spirit and principles of this invention should be included within the scope of protection of this invention.

Claims

1. A method for determining the rock compressibility coefficient of a gas-bearing geological body, characterized in that, include: Acquire formation data and historical production data corresponding to the target gas storage geological body, wherein the formation data includes raw formation pressure data and formation temperature data; and the historical production data includes cumulative gas production. The water volume of the geological body corresponding to the target gas storage geological body is determined based on the stratigraphic data and the historical production data. The compressibility coefficient corresponding to the target gas-storing geological body is determined based on the water content of the geological body and the material balance equation of the gas-storing geological body.

2. The method according to claim 1, characterized in that, The step of determining the water volume of the geological body corresponding to the target gas storage geological body based on the stratigraphic data and the historical production data includes: Determine the formation temperature values ​​corresponding to each stratum of the target gas storage geological body, and the gas relative density values ​​corresponding to the target gas storage geological body; The water content of the target gas-storing geological body is determined based on the formation temperature values ​​corresponding to each stratum of the target gas-storing geological body and the relative density values ​​of the gas.

3. The method according to claim 2, characterized in that, The determination of the water content of the target gas-bearing geological body based on the formation temperature values ​​corresponding to each stratum of the target gas-bearing geological body and the relative density values ​​of the gas includes: Determine the natural gas deviation factor corresponding to each stratum of the target gas storage geological body based on the formation temperature value and the gas relative density value; Based on the natural gas deviation factor and the original formation pressure data, determine the pseudo-formation pressure values ​​corresponding to each stratum of the target gas storage geological body; The geological water volume of the target gas-bearing geological body is determined based on the corresponding pseudo-formation pressure values ​​of each stratum and the cumulative gas production.

4. The method according to claim 3, characterized in that, The determination of the geological water volume of the target gas-bearing geological body based on the corresponding pseudo-formation pressure values ​​of each stratum and the cumulative gas production includes: Based on the pseudo-formation pressure value and the cumulative gas production, a dimensionless production indication curve corresponding to the target gas storage geological body is determined. The water volume coefficient corresponding to the target gas storage geological body is determined based on the dimensionless production indication curve. The geological water volume of the target gas-bearing geological body is determined based on the water volume coefficient and the formation data.

5. The method according to claim 4, characterized in that, Determining the geological water volume of the target gas-bearing geological body based on the water volume coefficient and the formation data includes: Substitute the formation data into the gas volume factor calculation formula to determine the gas volume factor corresponding to the target gas storage geological body; The geological water volume of the target gas storage geological body is determined based on the gas volume coefficient, the water volume coefficient, and the cumulative gas production.

6. The method according to claim 4, characterized in that, The determination of the dimensionless production indication curve corresponding to the target gas storage geological body based on the pseudo-formation pressure value and the cumulative gas production includes: Using the cumulative gas production as the X-axis and the corresponding pseudo-formation pressure values ​​of each stratum as the Y-axis, a dimensionless production indicator curve is established.

7. The method according to claim 1, characterized in that, The determination of the compressibility coefficient corresponding to the target gas-bearing geological body based on the water content of the geological body and the material balance equation of the gas-bearing geological body includes: Based on the material balance equation of the gas storage geological body, a material balance line diagram corresponding to the target gas storage geological body is drawn. Determine the slope value of the line relative to the material balance line graph, and determine the compressibility coefficient based on the slope value and the water content of the geological body.

8. A device for determining the compressibility coefficient of rocks in a gas-storage geological body, characterized in that, include: The data acquisition module is used to acquire formation data and historical production data corresponding to the target gas storage geological body. The formation data includes raw formation pressure data and formation temperature data; the historical production data includes cumulative gas production. The water storage calculation module is used to determine the water storage of the geological body corresponding to the target gas storage geological body based on the stratigraphic data and the historical production data. The compressibility coefficient determination module is used to determine the compressibility coefficient corresponding to the target gas storage geological body based on the water content of the geological body and the material balance equation of the gas storage geological body.

9. An electronic device, characterized in that, The electronic device includes: At least one processor; and A memory communicatively connected to the at least one processor; wherein, The memory stores a computer program executable by the at least one processor, which enables the at least one processor to perform the method for determining the rock compressibility coefficient of the gas-bearing geological body according to any one of claims 1-7.

10. A computer-readable storage medium, characterized in that, The computer-readable storage medium stores computer instructions that, when executed by a processor, implement the method for determining the rock compressibility coefficient of the gas-bearing geological body as described in any one of claims 1-7.

Images