A method, device, equipment and medium for evaluating leakage of carbon dioxide geological storage

Abstract

The application discloses a carbon dioxide geological storage leakage evaluation method, device, equipment and medium, and relates to the field of oil and gas field development.The method comprises the following steps: a shale seepage mathematical model is established based on a pre-established partial permeation boundary shale gas reservoir multi-stage fracturing horizontal well physical model; the shale seepage mathematical model is subjected to dimensionless processing to obtain a processed mathematical model; the processed mathematical model is calculated to obtain an injection pressure response analytical solution; a pressure response theoretical chart is established; an injection well injection pressure dynamic curve is fitted with the pressure response theoretical chart to obtain a reservoir boundary leakage ratio; and a leakage rate change curve is drawn based on the reservoir boundary leakage ratio, and the carbon dioxide geological storage leakage risk is evaluated in real time according to the leakage rate change curve. Through the above technical scheme, the leakage risk of the target block can be effectively evaluated, and support is provided for efficient and safe promotion of the carbon dioxide geological storage project.

Description

TECHNICAL FIELD

[0001] The present application relates to the field of oil and gas field development, and particularly relates to a carbon dioxide geological storage leakage evaluation method, device, equipment and medium. BACKGROUND

[0002] Currently, scholars both domestically and internationally have conducted extensive research on methods for assessing the geological storage potential and risks of carbon dioxide. In 2014, Rinaldi et al. established a geomechanical model of fault response during carbon dioxide injection, analyzing the integrity of the caprock and the possibility of carbon dioxide leakage through activated faults during large-scale carbon dioxide injection. In 2015, Chen Zhiming et al. derived a semi-analytical mathematical model of a dual-medium system considering carbon dioxide adsorption and desorption at a closed boundary, and calculated the storage potential of carbon dioxide in abandoned shale gas reservoirs under different reservoir properties using dynamic inversion. The results showed that injection pressure, reservoir matrix adsorption coefficient, diffusion coefficient, and reservoir capacity ratio significantly affect the carbon dioxide storage potential. In 2016, Xiao Cong et al. established a method for calculating the abandonment pressure of shale gas reservoirs using instantaneous pressure analysis (PTA) and instantaneous production analysis (RTA), and established the mathematical relationship between abandonment pressure and dynamic parameters and geological storage potential. In 2017, Kim et al. used numerical simulation to study the mechanism of enhanced carbon dioxide recovery (ECR) and storage in shale gas reservoirs. The results revealed that carbon dioxide exists mainly in shale as free gas and free gas. The permeability of natural fractures, the half-length of hydraulically fractured fractures, and the adsorption coefficient of the reservoir matrix significantly affect the potential for ECR and storage. In 2018, Yang Sen et al. established a three-dimensional geological model to study the impact of faults on gas leakage under two development modes: depletion-type development and carbon dioxide injection development. They pointed out that excessively high injection rates will exacerbate carbon dioxide leakage, but at the same time, they can, to some extent, inhibit natural gas leakage into the overlying water layer through high-permeability areas such as faults and fractures in the caprock. In 2019, Mu Lingyu et al., based on well testing theory and combining Laplace transform, Fourier cosine transform, and Duhamel's principle, calculated the carbon dioxide leakage rate and the pressure response of the monitoring well during fault opening in a sealed reservoir for carbon dioxide geological storage without considering carbon dioxide adsorption and desorption. In 2020, Newell et al. established a numerical model coupling fluid flow and geomechanics, determining the impact of factors such as fracture activation, fault opening, injection rate, and wellbore direction on caprock integrity during carbon dioxide geological storage. Due to its large storage capacity and high safety, carbon dioxide geological storage is currently the most effective technical means to address the global greenhouse effect and climate change. Shale gas reservoirs, with their stable geological structures, strong reservoir matrix adsorption capacity, and well-developed gas storage and transportation facilities, are ideal locations for carbon dioxide geological storage. However, the hydraulic fracturing technology used during the development of shale gas reservoirs and the large-scale injections during geological storage can lead to microseismic events of varying degrees within the reservoir, potentially triggering fault activation and opening, thus providing pathways for carbon dioxide leakage and causing serious pollution to the underground and surface environments.

[0003] From the above, how to realize the effective evaluation of the leakage risk of the target block, thereby providing strong support for the efficient and safe promotion of the carbon dioxide geological storage project is a problem to be solved in the art. SUMMARY

[0004] Therefore, the purpose of the present application is to provide a carbon dioxide geological storage leakage evaluation method, device, equipment and medium, which can realize the effective evaluation of the leakage risk of the target block, thereby providing strong support for the efficient and safe promotion of the carbon dioxide geological storage project. The specific scheme is as follows:

[0005] In a first aspect, the present application discloses a carbon dioxide geological storage leakage evaluation method, comprising:

[0006] A multi-stage fractured horizontal well physical model of a partially permeable boundary shale gas reservoir is established, and a shale seepage mathematical model is established based on the multi-stage fractured horizontal well physical model of the partially permeable boundary shale gas reservoir;

[0007] The shale seepage mathematical model is dimensionless processed to obtain a processed mathematical model, and the processed mathematical model is calculated to obtain an injection pressure response analytical solution;

[0008] A pressure response theoretical chart is established based on the shale seepage mathematical model and the injection pressure response analytical solution, and an injection well injection pressure dynamic curve is fitted with the pressure response theoretical chart to obtain a reservoir boundary leakage ratio;

[0009] A leakage rate change curve is plotted based on the reservoir boundary leakage ratio, and a carbon dioxide geological storage leakage risk is evaluated in real time according to the leakage rate change curve.

[0010] Optionally, the multi-stage fractured horizontal well physical model of the partially permeable boundary shale gas reservoir is established, comprising:

[0011] A seepage area is determined; wherein the seepage area includes a hydraulic fracture area, a natural fracture area, and a shale matrix area;

[0012] A multi-stage fractured horizontal well physical model of a partially permeable boundary shale gas reservoir is established based on the seepage area.

[0013] Optionally, the shale seepage mathematical model is established based on the multi-stage fractured horizontal well physical model of the partially permeable boundary shale gas reservoir, comprising:

[0014] The shale seepage mathematical model containing a shale matrix seepage mathematical model and a natural fracture seepage mathematical model is constructed based on the multi-stage fractured horizontal well physical model of the partially permeable boundary shale gas reservoir.

[0015] Optionally, the dimensionless treatment is performed on the shale seepage mathematical model to obtain a processed mathematical model, including:

[0016] The dimensionless treatment is performed on the shale matrix seepage mathematical model and the natural fracture seepage mathematical model to obtain a processed mathematical model containing shale matrix seepage equations and natural fracture seepage equations.

[0017] Optionally, the processed mathematical model is calculated to obtain an injection pressure response analytical solution, including:

[0018] The processed mathematical model is solved and calculated by using a Laplace transform method, a point source function, and a potential superposition principle to obtain a pressure solution in a Laplace space;

[0019] Based on the pressure solution in the Laplace space, Stehfest numerical inversion calculation is performed to obtain an injection pressure response analytical solution of a multi-stage fractured horizontal well bottom in a real space.

[0020] Optionally, before the injection well injection pressure dynamic curve is fitted with the pressure response theoretical chart, it further includes:

[0021] Injection dynamic data of the injection well are obtained to draw an actual pressure-injection time curve;

[0022] Based on reservoir properties, fluid properties of a target shale gas reservoir, and the injection dynamic data, a pressure response theoretical chart of a multi-stage fractured horizontal well bottom with a partially permeable boundary is established;

[0023] The maximum injection pressure is dimensionless processed to obtain a maximum dimensionless injection pseudo-pressure, a dimensionless time corresponding to the maximum dimensionless injection pseudo-pressure is found in the pressure response theoretical chart of the multi-stage fractured horizontal well bottom with the partially permeable boundary, and an actual injection time is calculated, and the carbon dioxide storage amount is calculated in combination with an actual injection rate and the actual injection time.

[0024] Optionally, the injection well injection pressure dynamic curve is fitted with the pressure response theoretical chart to obtain a reservoir boundary leakage ratio, including:

[0025] The actual pressure-injection time curve is dimensionless processed to obtain a dimensionless pseudo-pressure-dimensionless time curve, and the dimensionless pseudo-pressure-dimensionless time curve is fitted with the pressure response theoretical chart by using a least square method to obtain a reservoir boundary leakage ratio;

[0026] According to a non-permeable boundary, the reservoir boundary leakage ratio, and the dimensionless pseudo-pressure-dimensionless time curve, a leakage rate change curve of the reservoir boundary leakage ratio is calculated.

[0027] In a second aspect, the application discloses a carbon dioxide geological storage leakage evaluation device, comprising:

[0028] A model establishing module is configured to establish a partial-permeability boundary shale gas reservoir multi-stage fractured horizontal well physical model, and establish a shale seepage mathematical model based on the partial-permeability boundary shale gas reservoir multi-stage fractured horizontal well physical model;

[0029] A model calculation module is configured to perform non-dimensional processing on the shale seepage mathematical model to obtain a processed mathematical model, and perform calculation on the processed mathematical model to obtain an injection pressure response analytical solution;

[0030] A reservoir boundary leakage ratio determining module is configured to establish a pressure response theoretical chart based on the shale seepage mathematical model and the injection pressure response analytical solution, and perform fitting on an injection well injection pressure dynamic curve and the pressure response theoretical chart to obtain a reservoir boundary leakage ratio;

[0031] A leakage risk real-time evaluation module is configured to draw a leakage rate change curve based on the reservoir boundary leakage ratio, and perform real-time evaluation on a carbon dioxide geological storage leakage risk according to the leakage rate change curve.

[0032] In a third aspect, the application discloses an electronic device, comprising:

[0033] A memory is configured to save a computer program;

[0034] A processor is configured to execute the computer program to realize the foregoing carbon dioxide geological storage leakage evaluation method.

[0035] In a fourth aspect, the application discloses a computer storage medium configured to save a computer program; wherein the computer program is executed by a processor to realize the steps of the foregoing disclosed carbon dioxide geological storage leakage evaluation method.

[0036] It can be seen that the application provides a carbon dioxide geological storage leakage evaluation method, which comprises the following steps: establishing a physical model of a multi-stage fractured horizontal well in a partially permeable boundary shale gas reservoir, and establishing a shale seepage mathematical model based on the physical model; performing dimensionless processing on the shale seepage mathematical model to obtain a processed mathematical model, and performing calculation on the processed mathematical model to obtain an injection pressure response analytical solution; establishing a pressure response theoretical chart based on the shale seepage mathematical model and the injection pressure response analytical solution, fitting the injection pressure dynamic curve of an injection well with the pressure response theoretical chart to obtain a reservoir boundary leakage ratio; and drawing a leakage rate change curve based on the reservoir boundary leakage ratio, and performing real-time evaluation on the leakage risk of carbon dioxide geological storage according to the leakage rate change curve. The application is based on seepage mechanics, modern well testing theory and numerical inversion method, and comprehensively considers complex seepage and mass transfer processes such as gas adsorption and desorption in a shale gas reservoir porous medium, Knudsen diffusion and the seepage characteristics of a permeable boundary outside the reservoir, to establish a physical model and a mathematical model of a multi-stage fractured horizontal well in a partially permeable boundary shale gas reservoir, and further establish an evaluation process of carbon dioxide geological storage potential and leakage risk of a shale gas reservoir. The application can combine the reservoir and fluid physical property parameters and injection dynamic parameters of a target block to dynamically invert the seepage characteristics of the outer boundary of the target block, and quickly evaluate the carbon dioxide geological storage potential and leakage risk, so as to effectively evaluate the leakage risk of the target block, thereby providing strong support for efficient and safe promotion of a carbon dioxide geological storage project. BRIEF DESCRIPTION OF DRAWINGS

[0037] In order to more clearly illustrate the technical solutions in the embodiments of the present application or the prior art, the following will briefly introduce the drawings needed to be used in the embodiments or prior art description. Obviously, the drawings in the following description are only embodiments of the present application, and for those skilled in the art, other drawings can be obtained without creative labor based on the provided drawings.

[0038] Figure 1 A flow chart of a carbon dioxide geological storage leakage evaluation method disclosed by the present application;

[0039] Figure 2 A physical model schematic diagram disclosed by the present application;

[0040] Figure 3 A flow chart of a carbon dioxide geological storage leakage evaluation method disclosed by the present application;

[0041] Figure 4 A pressure response curve example diagram disclosed by the present application;

[0042] Figure 5A pressure response theoretical chart example diagram disclosed by the application;

[0043] Figure 6 A time fitting result example diagram disclosed by the application;

[0044] Figure 7 An injection well dimensionless pseudo-pressure-dimensionless time curve fitting result example diagram disclosed by the application;

[0045] Figure 8 A leakage rate change curve example diagram disclosed by the application;

[0046] Figure 9 A carbon dioxide geological storage leakage evaluation device structure schematic diagram disclosed by the application;

[0047] Figure 10 An electronic device structure diagram provided by the application. DETAILED DESCRIPTION

[0048] The technical solutions in the embodiments of the application will be clearly and completely described below with reference to the drawings in the embodiments of the application. Obviously, the described embodiments are only part of the embodiments of the application, rather than all the embodiments of the application. Based on the embodiments in the application, all other embodiments obtained by those skilled in the art without creative work are within the protection scope of the application.

[0049] At present, domestic and foreign scholars have carried out a large number of research work on the evaluation method of carbon dioxide geological storage potential and risk. In 2014, Rinaldi and other scholars established a geomechanical model of fault response in the process of carbon dioxide injection, and analyzed the integrity of the cap rock in the process of large-scale carbon dioxide injection and the possibility of carbon dioxide leakage through activated faults. In 2015, Chen Zhiming and other scholars deduced a double medium semi-analytical mathematical model considering carbon dioxide adsorption and desorption in closed boundary, and calculated the carbon dioxide storage potential in abandoned shale gas reservoir under different reservoir properties by dynamic inversion method. The results show that injection pressure, reservoir matrix adsorption coefficient, diffusion coefficient and storage ratio have significant influence on carbon dioxide storage potential. In 2016, Xiao Cong and other scholars established a calculation method of abandoned pressure in shale gas reservoir by using transient pressure analysis (PTA) and transient production analysis (RTA), and established the mathematical relationship between abandoned pressure, dynamic parameters and geological storage potential. In 2017, Kim and other scholars used numerical simulation method to study the mechanism of carbon dioxide improving gas recovery and storage in shale gas reservoir. The results show that carbon dioxide mainly exists in the form of free gas and free gas in shale, and the permeability of natural fracture, hydraulic fracture half length and adsorption coefficient of reservoir matrix have significant influence on the potential of carbon dioxide improving gas recovery and storage. In 2018, Yang Sen and other scholars established a three-dimensional geological model to study the influence of fault on gas leakage under the two modes of depletion development and carbon dioxide injection development. The author points out that too high injection rate will aggravate the leakage of carbon dioxide, but at the same time, it can inhibit the leakage of natural gas through high permeability area such as fault and fracture in cap rock into overlying water layer. In 2019, Mu Lingyu and other scholars calculated the leakage rate of carbon dioxide and the pressure response of monitoring well when the fault is opened during the geological storage of carbon dioxide in closed reservoir based on well testing theory, combining with Laplace transform, Fourier cosine transform and Duhamel principle without considering carbon dioxide adsorption and desorption. In 2020, Newell and other scholars established a numerical model coupling fluid flow and geomechanics, and determined the influence of factors such as fracture activation, fault opening, injection rate and wellbore direction on the integrity of cap rock in the process of carbon dioxide geological storage. Carbon dioxide geological storage is the most effective technical means to cope with global greenhouse effect and climate change due to its large storage capacity and high safety. Shale gas reservoir is an ideal place for carbon dioxide geological storage because of its stable geological structure, strong adsorption capacity of reservoir matrix, perfect gas storage and transportation facilities and other supporting facilities. However, the use of hydraulic fracturing technology in the development period of shale gas reservoir and large-scale injection in the geological storage period will cause different degrees of microseismic in the reservoir, which may cause the activation and opening of faults, providing a channel for carbon dioxide leakage and causing serious pollution of underground and surface environment.From the above, how to realize the effective evaluation of the leakage risk of the target block, so as to provide strong support for the efficient and safe promotion of the carbon dioxide geological storage project is a problem to be solved in the art.

[0050] Referring to Figure 1 As shown in the figure, the embodiment of the application discloses a carbon dioxide geological storage leakage evaluation method, which can specifically include:

[0051] Step S11: establishing a partially permeable boundary shale gas reservoir multi-stage fractured horizontal well physical model, and establishing a shale seepage mathematical model based on the partially permeable boundary shale gas reservoir multi-stage fractured horizontal well physical model.

[0052] In this embodiment, the process of establishing a partially permeable boundary shale gas reservoir multi-stage fractured horizontal well physical model is to determine a seepage area; wherein the seepage area includes a hydraulic fracture area, a natural fracture area, and a shale matrix area; and a partially permeable boundary shale gas reservoir multi-stage fractured horizontal well physical model is established based on the seepage area. The process of establishing a shale seepage mathematical model is to construct the shale seepage mathematical model including a shale matrix seepage mathematical model and a natural fracture seepage mathematical model based on the partially permeable boundary shale gas reservoir multi-stage fractured horizontal well physical model.

[0053] In this embodiment, after the horizontal well is subjected to multi-stage fracturing construction, multiple hydraulic fractures penetrating the shale reservoir are generated along the horizontal well bore direction and are interconnected with the shale reservoir. During the carbon dioxide injection process, the fluid first enters the hydraulic fractures, then enters the natural fractures in the shale reservoir, and finally enters the reservoir matrix through Langmuir isothermal adsorption and Knudsen diffusion. Correspondingly, the seepage area in the physical model includes: a hydraulic fracture area, a natural fracture area, and a shale matrix area. A partially permeable boundary shale gas reservoir multi-stage fractured horizontal well physical model is shown in Figure 2 As shown in the figure, (a) is a top view of an abandoned shale gas reservoir, (b) is a microcosmic schematic diagram of carbon dioxide molecule adsorption and diffusion in a shale matrix, (c) is a schematic diagram of carbon dioxide molecule flow in a limited conductivity hydraulic fracture, and (d) is a schematic diagram of shale matrix particles. The establishment of the partially permeable boundary shale gas reservoir multi-stage fractured horizontal well mathematical model specifically introduces the following three parameters to describe the shale gas reservoir properties. The storage capacity ratio represents the relative size of the reservoir matrix and the natural fracture storage capacity:

[0054]

[0055]

[0056] wherein, φ represents the reservoir porosity; C g represents the gas compressibility factor; k nfrepresents natural fracture permeability; h represents reservoir thickness; q sc represents injection well injection rate; μ represents viscosity of carbon dioxide under reservoir conditions. Dimensionless Knudsen diffusion coefficient, representing diffusion rate of carbon dioxide in shale matrix:

[0057]

[0058] wherein, D K represents Knudsen diffusion coefficient of carbon dioxide in shale matrix; R m represents radius of shale matrix particle. Dimensionless adsorption coefficient, representing adsorption capacity of carbon dioxide molecules in shale matrix.

[0059]

[0060] wherein, p sc represents ground standard state pressure; T represents reservoir temperature; V L represents Langmuir volume; p L represents Langmuir pressure; Z represents carbon dioxide compression factor; T sc represents ground standard state temperature; p represents average pressure of reservoir; p i represents abandonment pressure of shale gas reservoir.

[0061] Step S12: performing dimensionless processing on the shale seepage mathematical model to obtain a processed mathematical model, and performing calculation on the processed mathematical model to obtain an injection pressure response analytical solution.

[0062] In the embodiment, the shale matrix seepage mathematical model and the natural fracture seepage mathematical model are processed dimensionlessly to obtain a processed mathematical model containing shale matrix seepage equation and natural fracture seepage equation, and then the processed mathematical model is calculated to obtain an injection pressure response analytical solution.

[0063] In the embodiment, for the multi-stage fractured horizontal well physical model of the partial permeable boundary shale gas reservoir, a mathematical model thereof is established: (1) shale seepage mathematical model:

[0064] The control equation is:

[0065] The inner boundary condition is:

[0066] The outer boundary condition is:

[0067] The initial condition is:

[0068] wherein, r mr represents the radial coordinate of any point in the shale matrix system; p represents the density of carbon dioxide at standard conditions; V represents the concentration of carbon dioxide in the matrix; t represents the injection time; r sc r represents the radial coordinate of any point in the shale matrix system; p represents the density of carbon dioxide at standard conditions; V represents the concentration of carbon dioxide in the matrix; t represents the injection time; r m r represents the radial coordinate of any point in the shale matrix system; p represents the density of carbon dioxide at standard conditions; V represents the concentration of carbon dioxide in the matrix; t represents the injection time; r E r represents the radial coordinate of any point in the shale matrix system; p represents the density of carbon dioxide at standard conditions; V represents the concentration of carbon dioxide in the matrix; t represents the injection time; r i r represents the radial coordinate of any point in the shale matrix system; p represents the density of carbon dioxide at standard conditions; V represents the concentration of carbon dioxide in the matrix; t represents the injection time; r

[0069] (2) Mathematical model of natural fracture seepage

[0070] The control equation is:

[0071] The inner boundary condition is:

[0072] The outer boundary condition is:

[0073] The initial condition is: t＝0 = p i

[0074] wherein r nf r represents the radial coordinate of any point in the natural fracture system; p represents the density of carbon dioxide under reservoir conditions; q represents the line source; q l represents the leakage rate.

[0075] In order to facilitate equation solving, dimensionless variables are used to make the above equation dimensionless:

[0076] (1) Dimensionless pseudo-pressure:

[0077]

[0078] (2) Dimensionless time:

[0079]

[0080] (3) Dimensionless carbon dioxide concentration:

[0081]

[0082] (4) Dimensionless distance:

[0083]

[0084] (5) Dimensionless hydraulic fracture conductivity:

[0085]

[0086] (6) Leakage rate:

[0087]

[0088] (7) Dimensionless flow rate of hydraulic fracture:

[0089]

[0090] wherein: m represents the average pseudo-pressure of the formation; m i represents the abandoned pseudo-pressure of the formation; r mD represents the dimensionless radial coordinate of any point in the shale matrix system; r nfD represents the dimensionless radial coordinate of any point in the natural fracture system; r 12D represents the dimensionless radial coordinate of the outer boundary of the shale reservoir; r 12 represents the radial coordinate of the outer boundary of the shale reservoir; h wD represents the dimensionless depth at which the multi-section pressure horizontal well is located; h w represents the reservoir depth at which the multi-section pressure horizontal well is located; y D represents the dimensionless y coordinate of any point in the hydraulic fracture system; y represents the y coordinate of any point in the hydraulic fracture system; L f represents the hydraulic fracture half-length; L fD represents the dimensionless hydraulic fracture half-length; k hf represents the hydraulic fracture permeability; w f represents the hydraulic fracture width.

[0091] After the model is dimensionless, the following can be obtained:

[0092] 1) Shale matrix seepage equation

[0093]

[0094] 2) Natural fracture seepage equation

[0095]

[0096] Step S13: based on the shale seepage mathematical model and the injection pressure response analytical solution, a pressure response theoretical chart is established, the injection pressure dynamic curve of the injection well is fitted with the pressure response theoretical chart, and the reservoir boundary leakage ratio is obtained.

[0097] Step S14: based on the reservoir boundary leakage ratio, a leakage rate change curve is drawn, and the leakage risk of carbon dioxide geological storage is evaluated in real time according to the leakage rate change curve.

[0098] The steps of the application are as follows: firstly, a physical model of a multi-fractured horizontal well in a partially permeable boundary shale gas reservoir is established. The basic assumptions of the physical model are as follows: 1. The shale gas reservoir is a homogeneous reservoir, and the pressure and temperature are the same everywhere in the reservoir under the initial condition; 2. The top and bottom of the reservoir are non-permeable boundaries; 3. The fluid in the reservoir is single-phase and single-component, and the effects of gravity and capillary force are ignored; 4. The shale gas reservoir is a dual medium composed of reservoir matrix and natural fractures, wherein: the flow mode of carbon dioxide in the reservoir matrix is Knudsen diffusion, and the adsorption process on the surface of the matrix satisfies the Langmuir isothermal adsorption law, while in the natural fractures, the flow process of carbon dioxide conforms to Darcy's law; 5. The lengths of the hydraulic fractures are the same and completely penetrate the reservoir, and the injection pressure of the injection well remains unchanged during the carbon dioxide storage process. Secondly, a mathematical model of a multi-fractured horizontal well in a partially permeable boundary shale gas reservoir is established. Then, a chart for evaluating carbon dioxide geological storage and leakage in a partially permeable boundary shale gas reservoir is established. Laplace transform, Stehfest numerical inversion and other methods are used to solve the mathematical model and establish the pressure response characteristic curve of the injection well for carbon dioxide geological storage in a partially permeable boundary shale gas reservoir and the calculation process of carbon dioxide leakage. Finally, an evaluation process for the potential and leakage risk of carbon dioxide geological storage in a shale gas reservoir is constructed. The entire analysis process is completed through four steps: data collection, model setting, fitting analysis and parameter evaluation and application. Based on percolation mechanics, modern well testing theory and numerical inversion method, considering the complex percolation characteristics of shale gas reservoirs and the pressure response characteristics of multi-fractured horizontal wells, the application establishes a pressure response analysis method for multi-fractured horizontal wells in shale gas reservoirs, proposes a calculation method for the potential of carbon dioxide geological storage in shale gas reservoirs, and proposes an evaluation method for the leakage risk of geological storage, ultimately forming a research system for the optimization and risk assessment of geological storage sites.

[0099] In the embodiment, a multi-stage fractured horizontal well physical model of a partially permeable boundary shale gas reservoir is established, and a shale seepage mathematical model is established based on the multi-stage fractured horizontal well physical model of the partially permeable boundary shale gas reservoir; the shale seepage mathematical model is dimensionless processed to obtain a processed mathematical model, and the processed mathematical model is calculated to obtain an injection pressure response analytical solution; a pressure response theoretical chart is established based on the shale seepage mathematical model and the injection pressure response analytical solution, and an injection well injection pressure dynamic curve is fitted with the pressure response theoretical chart to obtain a reservoir boundary leakage ratio; a leakage rate change curve is drawn based on the reservoir boundary leakage ratio, and a carbon dioxide geological storage leakage risk is evaluated in real time according to the leakage rate change curve. Based on seepage mechanics, modern well testing theory and numerical inversion method, the seepage and mass transfer processes such as gas adsorption and desorption, Knudsen diffusion in the shale gas reservoir porous medium and the seepage characteristics of the permeable boundary outside the reservoir are comprehensively considered, the multi-stage fractured horizontal well physical model and the mathematical model of the partially permeable boundary shale gas reservoir are established, and then the carbon dioxide geological storage potential and leakage risk evaluation process of the shale gas reservoir are established. The present application can dynamically invert the seepage characteristics of the outer boundary of the target block in combination with the reservoir and fluid physical parameters and injection dynamic parameters of the target block, and quickly evaluate the carbon dioxide geological storage potential and leakage risk, which can effectively evaluate the leakage risk of the target block, thereby providing strong support for efficient and safe promotion of the carbon dioxide geological storage project.

[0100] Referring to Figure 3 As shown in the drawings, the embodiment of the present application discloses a carbon dioxide geological storage leakage evaluation method, which can specifically include:

[0101] Step S21: a multi-stage fractured horizontal well physical model of a partially permeable boundary shale gas reservoir is established, and a shale seepage mathematical model is established based on the multi-stage fractured horizontal well physical model of the partially permeable boundary shale gas reservoir.

[0102] Step S22: the shale seepage mathematical model is dimensionless processed to obtain a processed mathematical model, the processed mathematical model is solved and calculated by using Laplace transform method, point source function and potential superposition principle to obtain a pressure solution in a Laplace space, and Stehfest numerical inversion calculation is performed based on the pressure solution in the Laplace space to obtain an injection pressure response analytical solution of a multi-stage fractured horizontal well bottom in a real space.

[0103] In the embodiment, the processed mathematical model is solved by using Laplace transform method, point source function and potential superposition principle, and the model can obtain a pressure solution in a line source form with a partially permeable boundary on the top and bottom and on the side:

[0104]

[0105]

[0106] where n represents the number of cumulative terms; s represents the Laplace variable; K0 represents the modified Bessel function (one class, zero order); I0 represents the modified Bessel function (two class, zero order); K1 represents the modified Bessel function (one class, first order); and I1 represents the modified Bessel function (two class, first order).

[0107] According to the above formula, integration is performed along the hydraulic fracture direction to obtain a pressure response of a single hydraulic fracture in a shale gas reservoir:

[0108]

[0109] where q fD represents a dimensionless flow density of the hydraulic fracture, and a represents a hydraulic fracture direction integral variable.

[0110] By using the potential superposition principle, a bottom hole pressure response of a multi-stage fracturing horizontal well considering finite conductivity of the hydraulic fracture is obtained:

[0111]

[0112]

[0113] where C fDj represents a dimensionless conductivity of the jth hydraulic fracture, and N represents the number of hydraulic fractures of the multi-stage fracturing horizontal well. Further, according to the Duhamel principle, a bottom hole pressure solution considering the wellbore storage effect and the skin effect is obtained

[0114]

[0115] where S represents a skin coefficient; and C D represents a dimensionless well storage coefficient.

[0116] Step S23: A pressure response theoretical chart is established based on the shale seepage mathematical model and the injection pressure response analytical solution, and an injection well injection pressure dynamic curve is fitted with the pressure response theoretical chart to obtain a reservoir boundary leakage ratio.

[0117] In this embodiment, the injection dynamic data of the injection well is obtained to draw an actual pressure-injection time curve; a pressure response theoretical chart of a bottom of a multi-fractured horizontal well with a partial permeable boundary is established based on reservoir properties, fluid properties of a target shale gas reservoir and the injection dynamic data; a dimensionless injection pseudo-pressure is obtained by dimensionless processing of a maximum injection pressure; a dimensionless time corresponding to the maximum dimensionless injection pseudo-pressure is found in the pressure response theoretical chart of the bottom of the multi-fractured horizontal well with the partial permeable boundary, and an actual injection time is calculated; and a carbon dioxide storage amount is calculated in combination of an actual injection rate and the actual injection time. The process of obtaining the leakage rate is as follows: the actual pressure-injection time curve is subjected to dimensionless processing to obtain a dimensionless pseudo-pressure-dimensionless time curve; the dimensionless pseudo-pressure-dimensionless time curve is fitted with the pressure response theoretical chart by using a least square method to obtain a reservoir boundary leakage ratio; and a leakage rate change curve of the reservoir boundary leakage ratio is calculated according to a non-permeable boundary, the reservoir boundary leakage ratio and the dimensionless pseudo-pressure-dimensionless time curve.

[0118] Step S24: a leakage rate change curve is drawn based on the reservoir boundary leakage ratio, and a carbon dioxide geological storage leakage risk is evaluated in real time according to the leakage rate change curve.

[0119] In this embodiment, a mathematical model is solved and a bottom pressure response theoretical chart of a carbon dioxide geological storage well of an abandoned shale gas reservoir is established, as shown in FIG. 1, in which the first row from left to right is a different Langmuir volume curve and a different Langmuir pressure curve, and the second row is a different dimensionless diffusion coefficient curve and a different leakage radius. Figure 4 Theoretical model basic parameter table is shown in Table 1:

[0120] Table 1

[0121]

[0122]

[0123] The carbon dioxide leakage amount calculation process of the depleted shale gas reservoir is established based on the bottom pressure response theoretical chart of the injection well, and the specific steps are as follows:

[0124] First, the injection pressure p inj of the injection well is set, and the corresponding dimensionless pseudo-pressure m Dinj is calculated;

[0125]

[0126] Then, according to the dimensionless pseudo-pressure m DinjThe non-dimensional time t corresponding to the non-permeable boundary model (L = 0) and the partial permeable boundary model (L ≠ 0) is obtained on the injection well bottom hole pressure response curve respectively D | L＝0 ,t D | L The real injection time t is calculated in combination with the injection rate of the injection well and the reservoir physical property parameters inj | L＝0 , t inj | L The corresponding cumulative injection quantity Q is calculated inj | L＝0 Q inj | L

[0127]

[0128]

[0129] Q inj | L＝0 = q inj t inj | L＝0

[0130] Q inj | L = q inj t inj | L

[0131] Then, the relative difference value is calculated according to the cumulative injection quantity of the non-permeable boundary model and the partial permeable boundary model, and the leakage rate L of the reservoir corresponding to the injection time and the injection pressure is obtained inj .

[0132]

[0133] In the embodiment, according to the reservoir physical property parameters of the carbon dioxide geological storage target block and the fluid physical property parameters under the corresponding temperature and pressure conditions, a shale gas reservoir carbon dioxide geological storage potential and leakage risk evaluation process based on the injection well injection pressure response is established, and the specific process is as follows: first, the reservoir physical property parameters, fluid parameters and fracturing construction parameters of the target block are collected, and a partial permeable boundary multi-stage fracturing horizontal well bottom hole pressure response theoretical chart under corresponding parameters is constructed, such as Figure 5Theoretical chart of bottom hole pressure response of partial penetration boundary multi-stage fractured horizontal well is shown in a double logarithmic form and a linear form from left to right, respectively; then, injection dynamic data of the injection well are collected, carbon dioxide storage capacity under the maximum injection pressure is calculated according to the above formula, and the actual pressure-injection time curve of the injection well is converted into a dimensionless pseudo-pressure-dimensionless time curve; then, the converted dimensionless pseudo-pressure-dimensionless time curve is fitted with the established theoretical chart of bottom hole pressure response of partial penetration boundary multi-stage fractured horizontal well by using the least square method, and the reservoir boundary leakage ratio L of the reservoir outer boundary is obtained by inversion, so that the preliminary evaluation of the leakage risk of the target block is realized; finally, based on the dimensionless pseudo-pressure leakage rate change curve of the injection well, in combination with the carbon dioxide leakage amount calculation process of the depleted shale gas reservoir, the reservoir leakage ratio L at each time point is calculated inj , and the leakage rate change curve of the reservoir leakage ratio with the injection time is drawn, so that the real-time evaluation of the carbon dioxide geological storage leakage risk of the shale gas reservoir is realized.

[0134] Taking the multi-stage fractured horizontal well of the Marcellus shale gas reservoir as an example, the carbon dioxide geological storage potential and leakage risk of the abandoned shale gas reservoir are evaluated. In combination with the rock mechanics parameters of the shale gas reservoir, the maximum injection pressure of the injection well is set to be 20 MPa, and the injection rate is set to be 10 5 m 3 / d. According to the established evaluation process of the carbon dioxide geological storage potential and leakage risk of the shale gas reservoir, the following steps are taken for calculation: first, the theoretical chart of bottom hole pressure response of the partial penetration boundary multi-stage fractured horizontal well is established in combination with the reservoir physical properties, fluid physical properties and dynamic parameters (in Table 1) of the injection well of the Marcellus shale gas reservoir; then, the carbon dioxide storage potential corresponding to the maximum injection pressure is calculated by using the above formula, and the dimensionless injection time fitting result under the maximum injection pressure is shown in Figure 6 ;

[0135]

[0136]

[0137] Then, the injection dynamic curve is dimensionless, the dimensionless pseudo-pressure-dimensionless time curve is calculated, and the least square method is used for fitting with the bottom hole pressure response theoretical chart, as shown in Figure 7 . It can be seen that: the curve is well fitted with the pressure response curve under the condition of L=0.1 in the theoretical chart, the peripheral fault of the target block is partially opened, and the reservoir leakage ratio is 0.1. Based on the dimensionless pseudo-pressure-dimensionless time curve and the bottom hole pressure response calculation leakage rate change curve of the non-permeable boundary model, as shown in Figure 8 .

[0138] In this embodiment, a multi-stage fractured horizontal well physical model of a partially permeable boundary shale gas reservoir is established, and a shale seepage mathematical model is established based on the multi-stage fractured horizontal well physical model of the partially permeable boundary shale gas reservoir; the shale seepage mathematical model is dimensionless processed to obtain a processed mathematical model, and the processed mathematical model is calculated to obtain an injection pressure response analytical solution; a pressure response theoretical chart is established based on the shale seepage mathematical model and the injection pressure response analytical solution, and an injection well injection pressure dynamic curve is fitted with the pressure response theoretical chart to obtain a reservoir boundary leakage ratio; a leakage rate change curve is plotted based on the reservoir boundary leakage ratio, and a carbon dioxide geological storage leakage risk is evaluated in real time according to the leakage rate change curve. Based on seepage mechanics, modern well testing theory and numerical inversion method, the present application comprehensively considers complex seepage and mass transfer processes such as gas adsorption and desorption in a shale gas reservoir porous medium, Knudsen diffusion and seepage characteristics of a permeable boundary outside the reservoir, establishes a multi-stage fractured horizontal well physical model and a mathematical model of a partially permeable boundary shale gas reservoir, and further establishes a carbon dioxide geological storage potential and leakage risk evaluation process. The present application can dynamically invert the seepage characteristics of the outer boundary of the target block in combination with the reservoir and fluid physical parameters and injection dynamic parameters of the target block, and quickly evaluates the carbon dioxide geological storage potential and leakage risk, and can effectively evaluate the leakage risk of the target block, thereby providing strong support for efficient and safe promotion of the carbon dioxide geological storage project.

[0139] Referring to Figure 9 The embodiment of the present application discloses a carbon dioxide geological storage leakage evaluation device, which can specifically include:

[0140] The model establishment module 11 is configured to establish a multi-stage fractured horizontal well physical model of a partially permeable boundary shale gas reservoir, and establish a shale seepage mathematical model based on the multi-stage fractured horizontal well physical model of the partially permeable boundary shale gas reservoir;

[0141] The model calculation module 12 is configured to dimensionless process the shale seepage mathematical model to obtain a processed mathematical model, and calculate the processed mathematical model to obtain an injection pressure response analytical solution;

[0142] The reservoir boundary leakage ratio determination module 13 is configured to establish a pressure response theoretical chart based on the shale seepage mathematical model and the injection pressure response analytical solution, and fit an injection well injection pressure dynamic curve with the pressure response theoretical chart to obtain a reservoir boundary leakage ratio;

[0143] The leakage risk real-time evaluation module 14 is configured to plot a leakage rate change curve based on the reservoir boundary leakage ratio, and evaluate a carbon dioxide geological storage leakage risk in real time according to the leakage rate change curve.

[0144] In the embodiment, a multi-stage fractured horizontal well physical model of a partially permeable boundary shale gas reservoir is established, and a shale seepage mathematical model is established based on the multi-stage fractured horizontal well physical model of the partially permeable boundary shale gas reservoir; the shale seepage mathematical model is subjected to dimensionless processing to obtain a processed mathematical model, and the processed mathematical model is calculated to obtain an injection pressure response analytical solution; a pressure response theoretical chart is established based on the shale seepage mathematical model and the injection pressure response analytical solution, and an injection well injection pressure dynamic curve is fitted with the pressure response theoretical chart to obtain a reservoir boundary leakage ratio; a leakage rate change curve is plotted based on the reservoir boundary leakage ratio, and a carbon dioxide geological storage leakage risk is evaluated in real time according to the leakage rate change curve. Based on seepage mechanics, modern well testing theory and numerical inversion method, the present application comprehensively considers complex seepage and mass transfer processes such as gas adsorption and desorption in a shale gas reservoir porous medium, Knudsen diffusion and seepage characteristics of a permeable boundary outside the reservoir, establishes a multi-stage fractured horizontal well physical model and a mathematical model of a partially permeable boundary shale gas reservoir, and further establishes a carbon dioxide geological storage potential and leakage risk evaluation process. The present application can dynamically invert the seepage characteristics of the outer boundary of a target block in combination with reservoir and fluid physical property parameters and injection dynamic parameters of the target block, and quickly evaluates the carbon dioxide geological storage potential and leakage risk, can effectively evaluate the leakage risk of the target block, and thus provides strong support for efficient and safe promotion of a carbon dioxide geological storage project.

[0145] In some specific embodiments, the model establishing module 11 can specifically include:

[0146] A seepage region determining module is configured to determine a seepage region; wherein the seepage region includes a hydraulic fracture region, a natural fracture region and a shale matrix region.

[0147] A physical model establishing module is configured to establish a multi-stage fractured horizontal well physical model of a partially permeable boundary shale gas reservoir based on the seepage region.

[0148] In some specific embodiments, the model establishing module 11 can specifically include:

[0149] A mathematical model establishing module is configured to establish the shale seepage mathematical model including a shale matrix seepage mathematical model and a natural fracture seepage mathematical model based on the multi-stage fractured horizontal well physical model of the partially permeable boundary shale gas reservoir.

[0150] In some specific embodiments, the model establishing module 11 can specifically include:

[0151] A dimensionless processing module is configured to perform dimensionless processing on the shale matrix seepage mathematical model and the natural fracture seepage mathematical model to obtain a processed mathematical model comprising shale matrix seepage equations and natural fracture seepage equations.

[0152] In some embodiments, the model calculation module 12 can specifically comprise:

[0153] A pressure solution determination module is configured to perform solution calculation on the processed mathematical model by using a Laplace transform method, a point source function, and a potential superposition principle to obtain a pressure solution in a Laplace space.

[0154] An injection pressure response analytical solution determination module is configured to perform Stehfest numerical inversion calculation based on the pressure solution in the Laplace space to obtain an injection pressure response analytical solution of a multi-stage fractured horizontal well bottom in a real space.

[0155] In some embodiments, the reservoir boundary leakage ratio determination module 13 can specifically comprise:

[0156] An injection dynamic data acquisition module is configured to acquire injection dynamic data of an injection well to draw an actual pressure-injection time curve.

[0157] A pressure response theoretical chart determination module is configured to establish a pressure response theoretical chart of a multi-stage fractured horizontal well bottom with a partially permeable boundary based on reservoir properties, fluid properties of a target shale gas reservoir, and the injection dynamic data.

[0158] A carbon dioxide storage amount calculation module is configured to perform dimensionless processing on a maximum injection pressure to obtain a maximum dimensionless injection pseudo-pressure, find a dimensionless time corresponding to the maximum dimensionless injection pseudo-pressure in the pressure response theoretical chart of the multi-stage fractured horizontal well bottom with the partially permeable boundary, and calculate an actual injection time. The carbon dioxide storage amount is calculated based on an actual injection rate and the actual injection time.

[0159] In some embodiments, the leakage risk real-time evaluation module 14 can specifically comprise:

[0160] A reservoir boundary leakage ratio determination module is configured to perform dimensionless processing on the actual pressure-injection time curve to obtain a dimensionless pseudo-pressure-dimensionless time curve, and perform fitting of the dimensionless pseudo-pressure-dimensionless time curve and the pressure response theoretical chart by using a least square method to obtain a reservoir boundary leakage ratio.

[0161] A leakage rate change curve determination module is configured to calculate a leakage rate change curve of the reservoir boundary leakage ratio based on a non-permeable boundary, the reservoir boundary leakage ratio, and a dimensionless pseudo-pressure-dimensionless time curve.

[0162] Figure 10 A structural schematic diagram of an electronic device is provided in the embodiments of the present application. The electronic device 20 can specifically include at least one processor 21, at least one memory 22, a power supply 23, a communication interface 24, an input / output interface 25, and a communication bus 26. The memory 22 is configured to store a computer program, and the processor 21 is configured to load and execute the computer program to implement the related steps in the method for evaluating leakage of carbon dioxide geological storage performed by the electronic device disclosed in any of the foregoing embodiments.

[0163] In the embodiments, the power supply 23 is configured to provide working voltage for each hardware device on the electronic device 20, the communication interface 24 is capable of creating a data transmission channel between the electronic device 20 and external devices, and the communication protocol followed by the communication interface 24 can be any communication protocol applicable to the technical solution of the present application, which is not limited specifically herein. The input / output interface 25 is configured to obtain external input data or output data to the outside, and the specific interface type can be selected according to the specific application needs, which is not limited specifically herein.

[0164] In addition, the memory 22 as a carrier for resource storage can be a read-only memory, a random access memory, a magnetic disk, or an optical disk, and the resources stored thereon include an operating system 221, a computer program 222, and data 223, etc., and the storage mode can be temporary storage or permanent storage.

[0165] The operating system 221 is configured to manage and control each hardware device on the electronic device 20 and the computer program 222, so as to implement the operation and processing of the processor 21 on the data 223 in the memory 22, and the operating system 221 can be Windows, Unix, Linux, etc. The computer program 222 can further include computer programs capable of completing other specific work in addition to the computer program capable of completing the method for evaluating leakage of carbon dioxide geological storage performed by the electronic device 20 disclosed in any of the foregoing embodiments. The data 223 can include data transmitted from external devices by the carbon dioxide geological storage leakage evaluation device, and can also include data collected by the input / output interface 25 itself, etc.

[0166] The steps of the methods or algorithms described in conjunction with the embodiments disclosed herein can be implemented directly by hardware, a software module executed by a processor, or a combination thereof. The software module can be placed in a random access memory (RAM), a memory, a read-only memory (ROM), an electrically programmable ROM, an electrically erasable programmable ROM, a register, a hard disk, a removable disk, a CD-ROM, or any other form of storage medium known in the technical field.

[0167] Furthermore, embodiments of this application also disclose a computer-readable storage medium storing a computer program. When the computer program is loaded and executed by a processor, it implements the steps of the carbon dioxide geological sequestration leakage assessment method disclosed in any of the foregoing embodiments.

[0168] Finally, it should be noted that in this document, relational terms such as "first" and "second" are used only to distinguish one entity or operation from another, and do not necessarily require or imply any such actual relationship or order between these entities or operations. Furthermore, the terms "comprising," "including," or any other variations thereof are intended to cover non-exclusive inclusion, such that a process, method, article, or apparatus that comprises a list of elements includes not only those elements but also other elements not expressly listed, or elements inherent to such a process, method, article, or apparatus. Without further limitations, an element defined by the phrase "comprising one..." does not exclude the presence of other identical elements in the process, method, article, or apparatus that includes said element.

[0169] The above provides a detailed description of the carbon dioxide geological storage leakage assessment method, apparatus, equipment, and storage medium provided by the present invention. Specific examples have been used to illustrate the principles and implementation methods of the present invention. The descriptions of the above embodiments are only for the purpose of helping to understand the method and core ideas of the present invention. At the same time, for those skilled in the art, there will be changes in the specific implementation methods and application scope based on the ideas of the present invention. Therefore, the content of this specification should not be construed as a limitation of the present invention.

Claims

1. A method of assessing leakage of carbon dioxide geological storage, characterised in that, The method comprises the following steps: a physical model of a multi-stage fractured horizontal well in a partially permeable boundary shale gas reservoir is established, and a shale seepage mathematical model is established based on the physical model; dimensionless processing is performed on the shale seepage mathematical model to obtain a processed mathematical model, and calculation is performed on the processed mathematical model to obtain an injection pressure response analytical solution; a pressure response theoretical chart is established based on the shale seepage mathematical model and the injection pressure response analytical solution, and injection well injection pressure dynamic curves are fitted with the pressure response theoretical chart to obtain a reservoir boundary leakage ratio; a leakage rate change curve is plotted based on the reservoir boundary leakage ratio, and real-time evaluation is performed on carbon dioxide geological storage leakage risk according to the leakage rate change curve; a physical model of a multi-stage fractured horizontal well in a partially permeable boundary shale gas reservoir is established, including: determining a seepage region; establishing a physical model of a multi-stage fractured horizontal well in a partially permeable boundary shale gas reservoir based on the seepage region; the seepage region includes a hydraulic fracture zone, a natural fracture zone, and a shale matrix zone; the injection well injection pressure dynamic curves are fitted with the pressure response theoretical chart to obtain a reservoir boundary leakage ratio, and a leakage rate change curve is plotted based on the reservoir boundary leakage ratio, including: obtaining injection dynamic data of the injection well to plot an actual pressure-injection time curve, performing dimensionless processing on the actual pressure-injection time curve to obtain a dimensionless pseudo-pressure-dimensionless time curve, fitting the dimensionless pseudo-pressure-dimensionless time curve with the pressure response theoretical chart by using a least square method to obtain the reservoir boundary leakage ratio, and calculating a leakage rate change curve of the reservoir boundary leakage ratio according to a non-permeable boundary, the reservoir boundary leakage ratio, and the dimensionless pseudo-pressure-dimensionless time curve; calculation is performed on the processed mathematical model to obtain an injection pressure response analytical solution, including: performing solution calculation on the processed mathematical model by using a Laplace transform method, a point source function, and a potential superposition principle to obtain a pressure solution in a Laplace space; and performing Stehfest numerical inversion calculation based on the pressure solution in the Laplace space to obtain an injection pressure response analytical solution of a multi-stage fractured horizontal well bottom in a real space; a shale seepage mathematical model is established based on the physical model of the multi-stage fractured horizontal well in the partially permeable boundary shale gas reservoir, including: the shale seepage mathematical model is constructed to include a shale matrix seepage mathematical model and a natural fracture seepage mathematical model based on the physical model of the multi-stage fractured horizontal well in the partially permeable boundary shale gas reservoir.

2. The carbon dioxide geologic sequestration leak assessment method of claim 1, wherein, The dimensionless processing on the shale seepage mathematical model to obtain the processed mathematical model comprises: dimensionless processing is performed on the shale matrix seepage mathematical model and the natural fracture seepage mathematical model to obtain the processed mathematical model including a shale matrix seepage equation and a natural fracture seepage equation.

3. A method of assessing leakage from geological storage of carbon dioxide according to any one of claims 1 to 2, characterised in that, Before the fitting of the injection well injection pressure dynamic curves with the pressure response theoretical chart, the following step is further included: a pressure response theoretical chart of a multi-stage fractured horizontal well bottom in a partially permeable boundary is established based on target shale gas reservoir physical properties, fluid physical properties, and the injection dynamic data; The maximum injection pressure is dimensionless, the maximum dimensionless injection pseudo-pressure is obtained, the corresponding dimensionless time of the maximum dimensionless injection pseudo-pressure is found in a pressure response theoretical chart of a bottom of the multi-section fractured horizontal well in the partially permeable boundary reservoir, and the actual injection time is calculated; and the carbon dioxide storage amount is calculated by combining the actual injection rate and the actual injection time.

4. A carbon dioxide geological storage leak assessment device, characterized by, The method comprises the following steps: The model establishing module is configured to establish a physical model of a multi-section fractured horizontal well in a partially permeable boundary shale gas reservoir, and establish a shale seepage mathematical model based on the physical model of the multi-section fractured horizontal well in the partially permeable boundary shale gas reservoir; The model calculating module is configured to perform dimensionless processing on the shale seepage mathematical model to obtain a processed mathematical model, and calculate the processed mathematical model to obtain an injection pressure response analytical solution; The reservoir boundary leakage ratio determining module is configured to establish a pressure response theoretical chart based on the shale seepage mathematical model and the injection pressure response analytical solution, and fit an injection pressure dynamic curve of an injection well with the pressure response theoretical chart to obtain a reservoir boundary leakage ratio; The leakage risk real-time evaluating module is configured to plot a leakage rate change curve based on the reservoir boundary leakage ratio, and evaluate a carbon dioxide geological storage leakage risk in real time according to the leakage rate change curve. The physical model of the multi-section fractured horizontal well in the partially permeable boundary shale gas reservoir is established, including: determining a seepage region; and establishing the physical model of the multi-section fractured horizontal well in the partially permeable boundary shale gas reservoir based on the seepage region; the seepage region includes a hydraulic fracture zone, a natural fracture zone, and a shale matrix zone; The injection pressure dynamic curve of the injection well is fitted with the pressure response theoretical chart to obtain the reservoir boundary leakage ratio, and the leakage rate change curve is plotted based on the reservoir boundary leakage ratio, including: obtaining injection dynamic data of the injection well to plot an actual pressure-injection time curve; performing dimensionless processing on the actual pressure-injection time curve to obtain a dimensionless pseudo-pressure-dimensionless time curve; fitting the dimensionless pseudo-pressure-dimensionless time curve with the pressure response theoretical chart by using a least square method to obtain the reservoir boundary leakage ratio; and calculating a leakage rate change curve of the reservoir boundary leakage ratio according to a non-permeable boundary, the reservoir boundary leakage ratio, and the dimensionless pseudo-pressure-dimensionless time curve; The processed mathematical model is calculated to obtain the injection pressure response analytical solution, including: performing solution calculation on the processed mathematical model by using a Laplace transform method, a point source function, and a potential superposition principle to obtain a pressure solution in a Laplace space; and performing Stehfest numerical inversion calculation based on the pressure solution in the Laplace space to obtain an injection pressure response analytical solution of a bottom of the multi-section fractured horizontal well in a real space; The shale seepage mathematical model is established based on the physical model of the multi-section fractured horizontal well in the partially permeable boundary shale gas reservoir, including: constructing the shale seepage mathematical model including a shale matrix seepage mathematical model and a natural fracture seepage mathematical model based on the physical model of the multi-section fractured horizontal well in the partially permeable boundary shale gas reservoir.

5. An electronic device, comprising: The method comprises the following steps: The memory is configured to save a computer program. A processor configured to execute the computer program to implement the method of any one of claims 1 to 3.

6. A computer-readable storage medium, characterized in that, A computer program product comprising a computer readable medium bearing computer program code embodied therewith, the computer program code, when executed by a processor, implementing the method of any one of claims 1 to 3. A computer program product comprising a computer readable medium bearing computer program code embodied therewith, the computer program code, when executed by a processor, implementing the method of any one of claims 1 to 3.

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