Method and device for determining dynamic loss of permeability, electronic device and storage medium

Abstract

The present disclosure relates to a method and device for determining dynamic loss of permeability, an electronic device and a storage medium, and relates to the technical field of oilfield development. The method for determining dynamic loss of permeability includes: obtaining the original reservoir pressure and reservoir permeability; determining the corresponding starting pressure gradient according to the reservoir permeability; determining the reservoir pressure change according to the starting pressure gradient and the original reservoir pressure; determining the static confining pressure at any point of the reservoir according to the reservoir pressure change, and determining the permeability loss rate at any point of the reservoir based on the static confining pressure. The embodiments of the present disclosure can determine the dynamic loss of reservoir permeability under different effective stresses during the production process of an oil well.

Description

Technical Field

[0001] The present disclosure relates to the technical field of oilfield development, and in particular to a method and device for dynamic loss of permeability, an electronic device and a storage medium. Background Art

[0002] The phenomenon that reservoir permeability decreases with the increase of effective stress is called stress sensitivity. There are generally two existing methods to determine stress sensitivity. One is to fit the experimental data through indoor experimental tests to obtain the relationship between effective stress and permeability; the other is to use fluid-solid coupling theory for calculation. When using numerical methods for oil well dynamic analysis and production capacity prediction, directly using the first method will result in large errors because the results do not take into account the dynamic changes of reservoir and fluid parameters, especially the impact of fracturing on formation pressure distribution. Even if the current commercial reservoir numerical simulation software has fluid-solid coupling function, there are many problems such as slow calculation and non-convergence when performing reservoir numerical simulation considering fluid-solid coupling to determine the dynamic loss of reservoir permeability during oil well production, making it difficult to apply in practice. Summary of the invention

[0003] The present disclosure proposes a method and device for determining dynamic loss of permeability, an electronic device, and a storage medium technical solution.

[0004] According to one aspect of the present disclosure, a method for determining dynamic permeability loss is provided, comprising:

[0005] Obtain original reservoir pressure and reservoir permeability;

[0006] Determining a corresponding starting pressure gradient according to the reservoir permeability;

[0007] Determining a reservoir pressure change according to the starting pressure gradient and the original reservoir pressure;

[0008] The static confining pressure at any point of the reservoir is determined according to the reservoir pressure change, and the permeability loss rate at any point of the reservoir is determined based on the static confining pressure.

[0009] Preferably, the method for determining the dynamic loss of permeability further comprises:

[0010] Step S1011: obtaining a preset determination time, an initial time and a set time step;

[0011] Step S1012: within the preset calculation time, determining the reservoir pressure change corresponding to the time point of the set time step according to the start pressure gradient corresponding to the initial time and the original reservoir pressure;

[0012] Step S1014: determining the static confining pressure at any point of the reservoir according to the reservoir pressure change, and determining the permeability loss rate at any point of the reservoir corresponding to the time point of the set time step based on the static confining pressure;

[0013] Step S1015: If the time point corresponding to the permeability loss rate is less than the preset determination time, update the reservoir permeability corresponding to the next set time step, and execute the method of steps S1012-S1014; until the time point is equal to the preset determination time, obtain the permeability loss rate at any point in the reservoir corresponding to the preset determination time.

[0014] Preferably, before obtaining the original reservoir pressure and the reservoir permeability, the original reservoir pressure and the reservoir permeability are determined. The method for determining the original reservoir pressure and the reservoir permeability includes:

[0015] Obtain the grid division diagram corresponding to the horizontal well physical model;

[0016] The original reservoir pressure and reservoir permeability in the grid are determined according to the grid division diagram.

[0017] Preferably, before obtaining the grid division diagram corresponding to the horizontal well physical model, the grid division diagram corresponding to the horizontal well physical model is determined, and the determination method includes:

[0018] Acquire a horizontal well physical model and parameters corresponding to the horizontal well physical model;

[0019] The horizontal well physical model is meshed to determine a mesh diagram corresponding to the horizontal well physical model and parameters within the mesh of the mesh diagram.

[0020] Preferably, before acquiring the horizontal well physical model, the horizontal well physical model is determined, and the determination method thereof includes:

[0021] Get a 2D plan view of the horizontal well;

[0022] If the complexity of the fractures in the two-dimensional plane diagram meets the preset conditions, the fracture simulation is performed on the fracturing section and the horizontal section of the two-dimensional plane diagram according to the set fracture parameters to obtain the horizontal well physical model;

[0023] and / or,

[0024] The method of meshing the horizontal well physical model to obtain a meshing diagram corresponding to the horizontal well physical model includes:

[0025] Get the shape unit of the mesh;

[0026] The horizontal well physical model is meshed according to the shape unit to obtain a meshed graph corresponding to the horizontal well physical model.

[0027] Preferably, the method of performing fracture simulation on the fracturing section and the horizontal section of the two-dimensional plane diagram according to the set fracture parameters comprises:

[0028] Acquire set fracture parameters; wherein the fracture parameters include at least: fracture half-length, angle between the fracture and the horizontal section, number of fracture clusters in the fracturing section, and fracture pressure at the horizontal wellbore;

[0029] According to the number of clusters of fractures in the fracturing section, the half length of the fractures, the angle between the fractures and the horizontal section, and the pressure of the fractures at the wellbore of the horizontal well, the fracture simulation is performed on the two-dimensional plane diagram to obtain the physical model of the horizontal well;

[0030] and / or,

[0031] The method of meshing the horizontal well physical model to obtain a meshing diagram corresponding to the horizontal well physical model further includes:

[0032] Get the line elements of the mesh;

[0033] The mesh division diagram corresponding to the horizontal well physical model is encrypted according to the line unit to obtain a final mesh division diagram and parameters within the mesh of the final mesh division diagram.

[0034] Preferably, the method for determining the reservoir pressure change according to the starting pressure gradient and the original reservoir pressure comprises:

[0035] Determining reservoir pressure distribution according to the starting pressure gradient;

[0036] Determining a reservoir pressure change according to the reservoir pressure distribution and the original reservoir pressure;

[0037] and / or,

[0038] The method for determining the corresponding starting pressure gradient according to the reservoir permeability includes:

[0039] Obtaining a first relationship between reservoir permeability and its corresponding starting pressure gradient;

[0040] Determine a corresponding starting pressure gradient based on the first relationship and the reservoir permeability or the updated reservoir permeability;

[0041] and / or,

[0042] The method of determining the static confining pressure at any point of the reservoir according to the reservoir pressure change, and determining the permeability loss rate at any point of the reservoir based on the static confining pressure, comprises:

[0043] Obtain the second relationship between static confining pressure and permeability loss rate,

[0044] Determine the permeability loss rate at any point in the reservoir based on the static confining pressure or the static confining pressure corresponding to the updated reservoir permeability

[0045] According to one aspect of the present disclosure, there is provided a device for determining dynamic loss of permeability, comprising:

[0046] An acquisition unit, used for acquiring original reservoir pressure and reservoir permeability;

[0047] A first determining unit, configured to determine a corresponding starting pressure gradient according to the reservoir permeability;

[0048] A second determining unit, configured to determine a reservoir pressure change according to the starting pressure gradient and the original reservoir pressure;

[0049] The third determination unit is used to determine the static confining pressure at any point of the reservoir according to the reservoir pressure change, and determine the permeability loss rate at any point of the reservoir based on the static confining pressure.

[0050] According to one aspect of the present disclosure, there is provided an electronic device, including:

[0051] processor;

[0052] a memory for storing processor-executable instructions;

[0053] Wherein, the processor is configured to: execute the above-mentioned method for determining the dynamic loss of permeability.

[0054] According to one aspect of the present disclosure, a computer-readable storage medium is provided, on which computer program instructions are stored. When the computer program instructions are executed by a processor, the above-mentioned method for determining the dynamic loss of permeability is implemented.

[0055] In the disclosed embodiments, the determination method and device of the dynamic loss of permeability, the electronic device and the storage medium technical solution can determine the dynamic loss of reservoir permeability under different effective stresses during the production of oil wells, and guide the dynamic adjustment of fracturing wells according to the permeability loss results, so as to solve the problem that the dynamic loss of reservoir permeability under different effective stresses during the production of oil wells cannot be determined. At the same time, by determining the current loss of reservoir permeability, the influence of stress sensitivity effect is clarified; and based on the dynamic permeability loss of reservoirs, the oil well production system is optimized to improve the effect of oil well development.

[0056] It is to be understood that both the foregoing general description and the following detailed description are exemplary and explanatory only and are not restrictive of the disclosure.

[0057] Further features and aspects of the present disclosure will become apparent from the following detailed description of exemplary embodiments with reference to the attached drawings. BRIEF DESCRIPTION OF THE DRAWINGS

[0058] The drawings herein are incorporated into the specification and constitute a part of the specification. These drawings illustrate embodiments consistent with the present disclosure and are used to illustrate the technical solutions of the present disclosure together with the specification.

[0059] Figure 1 A flowchart showing a method for determining a dynamic loss of permeability according to an embodiment of the present disclosure;

[0060] Figure 2 A graph showing the relationship between reservoir permeability and start-up pressure gradient according to an embodiment of the present disclosure;

[0061] Figure 3 A graph showing the relationship between the permeability loss rate and the static confining pressure of a reservoir according to an embodiment of the present disclosure;

[0062] Figure 4 A graph showing the relationship between the bottom flow pressure of a reservoir and time according to an embodiment of the present disclosure;

[0063] Figure 5 A physical model of a horizontal well according to an embodiment of the present disclosure is shown;

[0064] Figure 6 A grid partition diagram corresponding to a horizontal well physical model according to an embodiment of the present disclosure is shown;

[0065] Figure 7 A reservoir pressure distribution diagram is shown when the production time is 1 year according to an embodiment of the present disclosure;

[0066] Figure 8 A distribution diagram showing the reservoir permeability loss rate at 1 year of production according to an embodiment of the present disclosure;

[0067] Fig. 9 A reservoir pressure distribution diagram is shown when the production time is 3 years according to an embodiment of the present disclosure;

[0068] Fig.10 A distribution diagram showing the reservoir permeability loss rate at 3 years of production according to an embodiment of the present disclosure;

[0069] Fig.11 is a block diagram of an electronic device 800 according to an exemplary embodiment;

[0070] Fig.12is a block diagram of an electronic device 1900 according to an exemplary embodiment. DETAILED DESCRIPTION

[0071] Various exemplary embodiments, features and aspects of the present disclosure will be described in detail below with reference to the accompanying drawings. The same reference numerals in the accompanying drawings represent elements with the same or similar functions. Although various aspects of the embodiments are shown in the accompanying drawings, the drawings are not necessarily drawn to scale unless otherwise specified.

[0072] The word “exemplary” is used exclusively herein to mean “serving as an example, example, or illustration.” Any embodiment described herein as “exemplary” is not necessarily to be construed as preferred or advantageous over other embodiments.

[0073] The term "and / or" herein is only a description of the association relationship of the associated objects, indicating that there may be three relationships. For example, A and / or B can represent: A exists alone, A and B exist at the same time, and B exists alone. In addition, the term "at least one" herein represents any combination of at least two of any one or more of a plurality of. For example, including at least one of A, B, and C can represent including any one or more elements selected from the set consisting of A, B, and C.

[0074] In addition, in order to better illustrate the present disclosure, numerous specific details are given in the following specific embodiments. It should be understood by those skilled in the art that the present disclosure can also be implemented without certain specific details. In some examples, methods, means, components and circuits well known to those skilled in the art are not described in detail in order to highlight the subject matter of the present disclosure.

[0075] It can be understood that the above-mentioned various method embodiments mentioned in the present disclosure can be combined with each other to form a combined embodiment without violating the principle logic. Due to space limitations, the present disclosure will not go into details.

[0076] In addition, the present disclosure also provides a device for determining the dynamic loss of permeability, an electronic device, a computer-readable storage medium, and a program, all of which can be used to implement any method for determining the dynamic loss of permeability provided by the present disclosure. The corresponding technical solutions and descriptions are referred to the corresponding records in the method part and will not be repeated here.

[0077] Figure 1 A flow chart showing a method for determining dynamic permeability loss according to an embodiment of the present disclosure is shown in FIG. Figure 1As shown, the method for determining the dynamic loss of permeability includes: step S101: obtaining the original reservoir pressure and reservoir permeability; step S102: determining the corresponding starting pressure gradient according to the reservoir permeability; step S103: determining the reservoir pressure change according to the starting pressure gradient and the original reservoir pressure; step S104: determining the static confining pressure at any point of the reservoir according to the reservoir pressure change, and determining the permeability loss rate at any point of the reservoir based on the static confining pressure. The dynamic loss of reservoir permeability under different effective stresses during the production of the oil well can be determined, and the dynamic adjustment of the fracturing well can be guided according to the permeability loss results, so as to solve the problem that the dynamic loss of reservoir permeability under different effective stresses during the production of the oil well cannot be determined. At the same time, by determining the current reservoir permeability loss, the influence degree of the stress sensitivity effect is clarified; and based on the dynamic permeability loss of the reservoir, the oil well production system is optimized to improve the oil well development effect.

[0078] By adopting this embodiment, the dynamic loss rate of reservoir permeability caused by stress-sensitive effect during oil well production can be determined. The present disclosure is aimed at low-permeability and extra-low-permeability oil reservoirs with stress-sensitive effect. As the effective stress increases during oil well development, the loss of reservoir permeability is caused. The method for determining the dynamic loss of reservoir permeability during oil well development is considered after the reservoir permeability loss is started. Specifically, the present disclosure proposes a method for determining the dynamic permeability loss of the reservoir during oil well production for fracturing horizontal wells in low-permeability oil reservoirs with pressure-sensitive effect. At the same time, the present method is not limited to the horizontal well fracturing embodiment, and is also applicable to non-fractured wells and other fracturing methods.

[0079] Step S101: Obtaining original reservoir pressure and reservoir permeability.

[0080] In the embodiments of the present disclosure and other possible embodiments, those skilled in the art may obtain the original reservoir pressure and reservoir permeability from the well logging data, which will not be described in detail here.

[0081] Step S102: Determine the corresponding starting pressure gradient according to the reservoir permeability.

[0082] In the present disclosure, the method for determining the corresponding starting pressure gradient based on the reservoir permeability includes: obtaining a first relationship between the reservoir permeability and the corresponding starting pressure gradient; and determining the corresponding starting pressure gradient based on the first relationship and the reservoir permeability or the updated reservoir permeability.

[0083] Figure 2 FIG. 4 shows a relationship diagram between reservoir permeability and start-up pressure gradient according to an embodiment of the present disclosure. Figure 2As shown, before obtaining the first relationship between the reservoir permeability and the corresponding starting pressure gradient, the first relationship between the reservoir permeability and the corresponding starting pressure gradient is determined, and the determination method includes: obtaining multiple reservoir permeabilities and multiple corresponding starting pressure gradients, taking the multiple reservoir permeabilities as independent variables and the multiple corresponding starting pressure gradients as dependent variables, performing linear regression analysis or fitting operation to obtain the first relationship between the reservoir permeability and the corresponding starting pressure gradient.

[0084] Specifically, the corresponding starting pressure gradients of reservoir rocks at different permeabilities are not the same. The stress sensitivity effect causes the reservoir permeability to lose dynamically with the production of oil wells. Figure 2 By interpolating the data, the starting pressure gradient corresponding to the dynamic loss permeability can be obtained. The dynamic starting pressure gradient is used in the numerical calculation to realize the dynamic starting pressure gradient.

[0085] Step S103: Determine a reservoir pressure change according to the starting pressure gradient and the original reservoir pressure.

[0086] In the present disclosure, the method for determining reservoir pressure changes based on the starting pressure gradient and the original reservoir pressure includes: determining reservoir pressure distribution based on the starting pressure gradient; and determining reservoir pressure changes based on the reservoir pressure distribution and the original reservoir pressure.

[0087] In the embodiment of the present disclosure and other possible embodiments, the method for determining reservoir pressure distribution according to the starting pressure gradient includes: obtaining multiple distances from the wellbore of the horizontal well; and determining the reservoir pressure distribution based on the multiple distances and the starting pressure gradients corresponding to the multiple distances. Specifically, the multiple distances are multiplied by the multiple distances corresponding to them to obtain multiple pressures at multiple distances from the wellbore of the horizontal well, and the distribution of the multiple pressures is the reservoir pressure distribution.

[0088] Step S104: determining the static confining pressure at any point of the reservoir according to the reservoir pressure change, and determining the permeability loss rate at any point of the reservoir based on the static confining pressure.

[0089] In the present disclosure, the method of determining the static confining pressure at any point of the reservoir according to the reservoir pressure change, and determining the permeability loss rate at any point of the reservoir based on the static confining pressure, includes: obtaining a second relationship between the static confining pressure and the permeability loss rate, and determining the permeability loss rate at any point of the reservoir based on the static confining pressure or the static confining pressure corresponding to the updated reservoir permeability.

[0090] Figure 3 FIG. 4 shows a relationship between the permeability loss rate and the static confining pressure of a reservoir according to an embodiment of the present disclosure. Figure 3As shown, before obtaining the second relationship between the static confining pressure and the permeability loss rate, the second relationship between the static confining pressure and the permeability loss rate is determined, and the determination method includes: obtaining multiple static confining pressures and multiple permeability loss rates corresponding to them, taking multiple of the multiple as independent variables and the corresponding multiple permeability loss rates as dependent variables, performing linear regression analysis or fitting operation to obtain the second relationship between the static confining pressure and the permeability loss rate corresponding to it.

[0091] Specifically, the relationship between reservoir permeability and static confining pressure is given by indoor stress sensitivity effect experiments, such as Figure 1 When performing numerical calculations, the static confining pressure (original reservoir pressure - current reservoir pressure) at any point in the reservoir is calculated. Figure 3 Interpolate the data in the , calculate the permeability loss rate at any point in the reservoir, and then update the reservoir permeability data at each numerical calculation time step. With the increase of production time, the reservoir pressure gradually decreases, the static confining pressure gradually increases, and the reservoir permeability loss rate gradually increases.

[0092] In the present disclosure, before obtaining the original reservoir pressure and reservoir permeability, the original reservoir pressure and reservoir permeability are determined. The method for determining the original reservoir pressure and reservoir permeability includes: obtaining a grid division diagram corresponding to a horizontal well physical model; and determining the original reservoir pressure and reservoir permeability within a grid according to the grid division diagram.

[0093] In the present disclosure, before obtaining the grid division diagram corresponding to the horizontal well physical model, the grid division diagram corresponding to the horizontal well physical model is determined, and the determination method includes: obtaining the horizontal well physical model and parameters corresponding to the horizontal well physical model; gridding the horizontal well physical model to determine the grid division diagram corresponding to the horizontal well physical model and parameters within the grid of the grid division diagram.

[0094] In the embodiments of the present disclosure and other possible embodiments, the parameters corresponding to the horizontal well physical model may include: reservoir and fluid related parameters and fracture parameters, relative permeability curve (abscissa: saturation) and capillary pressure curve (abscissa: saturation) and / or bottom hole flow pressure. The reservoir and fluid related parameters and fracture parameters may include: original formation pressure (original reservoir pressure), saturation pressure, porosity, effective reservoir thickness, underground crude oil viscosity, reservoir permeability; fracture permeability, fracture porosity.

[0095] In the present disclosure, before obtaining the horizontal well physical model, the horizontal well physical model is determined, and its determination method includes: obtaining a two-dimensional plane diagram of the horizontal well; if the complexity of the fractures in the two-dimensional plane diagram meets the preset conditions, the fracturing section and the horizontal section of the two-dimensional plane diagram are subjected to fracture simulation according to the set fracture parameters to obtain the acquired horizontal well physical model.

[0096] In the embodiments of the present disclosure and other possible embodiments, the method for judging whether the complexity of cracks in the two-dimensional plane diagram meets the preset conditions includes: obtaining the preset conditions; wherein the preset conditions at least include: plane cracks and the preset number of intersections; determining the type of multiple cracks in the two-dimensional plane diagram; if the type is a plane crack, generating a first judgment condition; under the first judgment condition, calculating the number of intersections between the multiple cracks; if the number of intersections is less than or equal to the number of intersections, the complexity of cracks in the two-dimensional plane diagram meets the preset conditions. Among them, those skilled in the art can determine the number of intersections by themselves as needed, for example, the number of intersections can be configured to be 10.

[0097] In the present disclosure, the method for performing fracture simulation on the fracturing section and the horizontal section of the two-dimensional plane diagram according to the set fracture parameters includes:

[0098] Acquire set fracture parameters; wherein the fracture parameters include at least: fracture half-length, angle between the fracture and the horizontal section, number of fracture clusters in the fracturing section, and pressure of the fracture at the wellbore of the horizontal well; perform fracture simulation on the two-dimensional plane diagram according to the number of fracture clusters in the fracturing section, fracture half-length, angle between the fracture and the horizontal section, and pressure of the fracture at the wellbore of the horizontal well, and obtain the horizontal well physical model.

[0099] For example, the number of clusters of cracks in the fracturing section can be 2, that is, the number of cracks in the fracturing section is 2; 12 sections are fracturing, each section has 2 clusters, a total of 24 cracks, and the half-length of the cracks is 120m. The cracks are perpendicular to the horizontal section, and the half-lengths of the cracks on both sides of the horizontal section are the same. The friction resistance of the fracturing horizontal wellbore is not considered, that is, the pressure of all cracks in the fracturing horizontal wellbore is the same, which is equal to the bottom hole flow pressure.

[0100] Figure 4 FIG. 2 shows a graph showing the relationship between the bottom flow pressure of the reservoir and time according to an embodiment of the present disclosure. Figure 4As shown, before obtaining the pressure of the fracture at the horizontal wellbore, the pressure of the fracture at the horizontal wellbore is determined according to the bottom hole flow pressure, and the determination method includes: obtaining a third relationship of the bottom hole flow pressure changing with time; and determining the pressure of the fracture at the horizontal wellbore based on the third relationship and the time point where the fracture is located. Specifically, before obtaining the third relationship of the bottom hole flow pressure changing with time, the third relationship of the bottom hole flow pressure changing with time is determined, and the determination method includes: obtaining the bottom hole flow pressure corresponding to multiple time points, taking the multiple time points as independent variables and the bottom hole flow pressure corresponding to the multiple time points as dependent variables, performing linear regression or fitting operations, and determining the third relationship of the bottom hole flow pressure changing with time.

[0101] Specifically, the numerical calculation of horizontal wells or fractured horizontal wells adopts constant flow pressure production. In each calculation step, Figure 4 The data in the calculation are interpolated to determine the bottom hole flowing pressure value during the production process and perform numerical calculations.

[0102] Figure 5 FIG. 2 shows a physical model of a horizontal well according to an embodiment of the present disclosure. Figure 5 As shown in the figure, a multi-cluster fractured horizontal well is selected in the two-dimensional plane. The well is produced by natural energy. The fluid in the formation is oil and water. Low-speed non-Darcy flow is considered. It is assumed that no complex fracture network is formed during the fracturing process. The fracture is a simple plane fracture. The fracture is perpendicular to the horizontal segment, and the half-length of the fractures on both sides of the horizontal segment is the same, as shown in Figure 4 As shown. The specific parameters are: simulation area size 600m╳1200m, horizontal section length 1000m, 12 fracturing sections, 2 clusters in each section, 24 fractures in total, and the half-length of the fracture is 120m. Among them, one method of large-scale volume fracturing of horizontal wells is called: segmented multi-cluster volume fracturing. One section contains multiple fracturing clusters. Figure 4 There are 2 clusters in the figure. The complexity of the cracks in each cluster is different under different conditions. Here, it is assumed that the complexity of the cracks in each cluster is not high and they are treated as plane cracks, so each cluster contains one crack.

[0103] In the present disclosure, the method of meshing the horizontal well physical model to obtain a meshing diagram corresponding to the horizontal well physical model includes: obtaining a shape unit of meshing; meshing the horizontal well physical model according to the shape unit to obtain a meshing diagram corresponding to the horizontal well physical model. The shape unit can be any triangular unit.

[0104] In the present disclosure, the method of gridding the horizontal well physical model to obtain a grid division map corresponding to the horizontal well physical model also includes: obtaining grid division line units; encrypting the grid division map corresponding to the horizontal well physical model according to the line units to obtain a final grid division map and parameters within the grid of the final grid division map.

[0105] Figure 6 FIG. 2 shows a grid partition diagram corresponding to the horizontal well physical model according to an embodiment of the present disclosure. Figure 6 As shown, according to the horizontal physical model, the numerical simulation program based on finite element is used, and the numerical model of the simulation area is established by using GID pre- and post-processing software. The reservoir grid is divided into arbitrary triangle units, and the fractures are divided into line units and the grid is encrypted to obtain the grid division as shown in FIG. Figure 5 As shown, there are 11794 nodes and 23346 triangular elements in the model.

[0106] In the present disclosure, the method for determining the dynamic loss of permeability also includes: step S1011: obtaining a preset determination time, an initial time and a set time step; step S1012: within the preset calculation time, determining the reservoir pressure change corresponding to the time point of the set time step according to the starting pressure gradient corresponding to the initial time and the original reservoir pressure; step S1014: determining the static confining pressure at any point in the reservoir according to the reservoir pressure change, and determining the permeability loss rate at any point in the reservoir corresponding to the time point of the set time step based on the static confining pressure; step S1015: if the time point corresponding to the permeability loss rate is less than the preset determination time, updating the reservoir permeability corresponding to the next set time step, and executing the method of steps S1012-S1014; until the time point is equal to the preset determination time, the permeability loss rate at any point in the reservoir corresponding to the preset determination time is obtained.

[0107] For example, the preset determination time is the time when the permeability loss rate at any point in the reservoir needs to be determined, such as the 8th year. The initial time can be the time point when the horizontal well starts production or a certain time point during the production process of the horizontal well, and the set time step can be 1 year.

[0108] In the embodiment of the present disclosure and other possible embodiments, setting the time step may include: a calculation step and an output step. Within the preset calculation time, the reservoir pressure change corresponding to the time point of the set time step is determined according to the start-up pressure gradient and the original reservoir pressure corresponding to the initial time; for example, the preset calculation time is 8 years, the calculation step and the output step in the time step are set to 1 year, and the reservoir pressure change in the second year is determined according to the start-up pressure gradient and the original reservoir pressure at the time point when the horizontal well starts production. The static confining pressure at any point of the reservoir is determined according to the reservoir pressure change in the second year, and the permeability loss rate at any point of the reservoir corresponding to the second year is determined based on the static confining pressure; the permeability loss rate at this time is the permeability loss rate corresponding to the second year, which is less than the preset determination time of 8 years, and the reservoir permeability corresponding to the next time point of the set time step (the third year) is updated, and the method of step S1012-step S1014 is performed; until the time point is equal to the preset determination time of 8 years, the permeability loss rate at any point of the reservoir corresponding to the preset determination time of 8 years is obtained.

[0109] More specifically, in the embodiments of the present disclosure and other possible embodiments, the original reservoir formation pressure data and calculation time parameters (preset determination time, calculation step, output step) are read, and the static confining pressure is calculated from the current reservoir formation pressure (reservoir pressure) distribution to determine the current reservoir permeability loss rate. If the current time is less than the preset determination time, the reservoir permeability is updated because the permeability loss rates at different locations in the simulation area are different, and the reservoir permeability loss rate corresponding to the next set time step is calculated.

[0110] In the embodiments of the present disclosure and other possible embodiments, during the numerical calculation of the current time step (setting the time step), the starting pressure gradient at different positions of the current reservoir can be obtained by setting the reservoir permeability at the time point corresponding to the time step and the first relationship; the reservoir pressure can be obtained by setting the starting pressure gradient at the time point corresponding to the time step, and the reservoir pressure distribution can be obtained according to the reservoir pressure. Among them, the reservoir pressure distribution can clarify the change of reservoir pressure, which can be used to calculate the static confining pressure data of any point in the reservoir, and then analyze the reservoir permeability loss.

[0111] Figure 7 The reservoir pressure distribution diagram at the time of one year of production according to the embodiment of the present disclosure is shown. Figure 7 As shown in Figure 1, the current reservoir pressure distribution is based on a horizontal well production time of one year. Figure 7 From the reservoir pressure distribution, it can be seen that at the current time, most areas of the reservoir have the original reservoir pressure of 64MPa, and only the pressure in the area near the fracture is lower than the original formation pressure.

[0112] Figure 8 The distribution diagram of the reservoir permeability loss rate at the time of one year of production according to the embodiment of the present disclosure is shown. Figure 8 As shown in the figure, according to the current reservoir pressure distribution data, the static confining pressure data is calculated, and then the relationship between reservoir permeability and static confining pressure is used to interpolate and obtain the reservoir permeability loss rate data. Figure 8 It can be seen that when the current horizontal well is produced for one year, the reservoir permeability loss is only in the area where the reservoir pressure is lower than the original formation pressure. Most of the simulation area (within the grid division diagram) has no permeability loss. The maximum permeability loss occurs at the location of the artificial fracture, which is 12.513%.

[0113] After each set time step, the pressure distribution of the storage layer and the permeability loss rate of the reservoir are preserved. It is determined whether the current calculation time has reached the maximum simulation calculation time (preset calculation time). If "yes", the calculation ends. If "no", the current permeability loss rate corresponding to the next set time step is obtained again, the startup pressure gradient data is updated, and the calculation of the next time step is completed, thereby realizing the calculation of the permeability loss rate of the reservoir under the dynamic startup pressure gradient.

[0114] The following takes the reservoir pressure distribution and permeability loss after 3 years of production as an example to illustrate the changing pattern of reservoir permeability loss as the fracturing horizontal well is produced.

[0115] Fig. 9 The reservoir pressure distribution diagram at the time of 3 years of production according to the embodiment of the present disclosure is shown. Fig. 9 As shown, the formation pressure distribution after 3 years of horizontal well production, it can be seen that the pressure in the entire simulation area is lower than the original formation pressure, so reservoir permeability loss occurs in the entire simulation area.

[0116] Fig.10 The distribution diagram of the reservoir permeability loss rate at 3 years of production time according to the embodiment of the present disclosure is shown. Fig.10 As shown in the figure, the reservoir permeability loss after 3 years of horizontal well production shows that the lowest permeability loss in the entire simulation area is 14.421%, which is located at the four corners of the simulation area, which is also the farthest distance from the horizontal well. The maximum permeability loss is 67.948%, which occurs at the artificial fracture location.

[0117] The execution subject of the method for determining the dynamic loss of permeability may be a device for determining the dynamic loss of permeability. For example, the method for determining the dynamic loss of permeability may be executed by a terminal device or a server or other processing device, wherein the terminal device may be a user equipment (UE), a mobile device, a user terminal, a terminal, a cellular phone, a cordless phone, a personal digital assistant (PDA), a handheld device, a computing device, a vehicle-mounted device, a wearable device, etc. In some possible implementations, the method for determining the dynamic loss of permeability may be implemented by a processor calling computer-readable instructions stored in a memory.

[0118] Those skilled in the art will appreciate that, in the above method of specific implementation, the order in which the steps are written does not imply a strict execution order and does not constitute any limitation on the implementation process. The specific execution order of the steps should be determined by their functions and possible internal logic.

[0119] The present disclosure also proposes a device for determining dynamic permeability loss, which includes: an acquisition unit for acquiring original reservoir pressure and reservoir permeability; a first determination unit for determining a corresponding starting pressure gradient according to the reservoir permeability; a second determination unit for determining a reservoir pressure change according to the starting pressure gradient and the original reservoir pressure; and a third determination unit for determining a static confining pressure at any point in the reservoir according to the reservoir pressure change, and determining the permeability loss rate at any point in the reservoir based on the static confining pressure.

[0120] In some embodiments, the functions or modules included in the device provided by the embodiments of the present disclosure can be used to execute the method described in the above method embodiments. The specific implementation can refer to the description of the above method embodiments, and for the sake of brevity, it will not be repeated here.

[0121] The embodiment of the present disclosure also provides a computer-readable storage medium, on which computer program instructions are stored, and when the computer program instructions are executed by a processor, the above method is implemented. The computer-readable storage medium may be a non-volatile computer-readable storage medium.

[0122] The embodiment of the present disclosure also provides an electronic device, comprising: a processor; a memory for storing instructions executable by the processor; wherein the processor is configured to perform the above method. The electronic device can be provided as a terminal, a server or other forms of equipment.

[0123] Fig.118 is a block diagram of an electronic device 800 according to an exemplary embodiment. For example, the electronic device 800 may be a mobile phone, a computer, a digital broadcast terminal, a messaging device, a game console, a tablet device, a medical device, a fitness device, a personal digital assistant, or the like.

[0124] Reference Fig.11 , the electronic device 800 may include one or more of the following components: a processing component 802 , a memory 804 , a power component 806 , a multimedia component 808 , an audio component 810 , an input / output (I / O) interface 812 , a sensor component 814 , and a communication component 816 .

[0125] The processing component 802 generally controls the overall operation of the electronic device 800, such as operations associated with display, phone calls, data communications, camera operations, and recording operations. The processing component 802 may include one or more processors 820 to execute instructions to complete all or part of the steps of the above-mentioned method. In addition, the processing component 802 may include one or more modules to facilitate the interaction between the processing component 802 and other components. For example, the processing component 802 may include a multimedia module to facilitate the interaction between the multimedia component 808 and the processing component 802.

[0126] The memory 804 is configured to store various types of data to support operations on the electronic device 800. Examples of such data include instructions for any application or method operating on the electronic device 800, contact data, phone book data, messages, pictures, videos, etc. The memory 804 may be implemented by any type of volatile or non-volatile storage device or a combination thereof, such as static random access memory (SRAM), electrically erasable programmable read-only memory (EEPROM), erasable programmable read-only memory (EPROM), programmable read-only memory (PROM), read-only memory (ROM), magnetic memory, flash memory, magnetic disk, or optical disk.

[0127] The power supply component 806 provides power to the various components of the electronic device 800. The power supply component 806 may include a power management system, one or more power supplies, and other components associated with generating, managing, and distributing power to the electronic device 800.

[0128] The multimedia component 808 includes a screen that provides an output interface between the electronic device 800 and the user. In some embodiments, the screen may include a liquid crystal display (LCD) and a touch panel (TP). If the screen includes a touch panel, the screen may be implemented as a touch screen to receive input signals from the user. The touch panel includes one or more touch sensors to sense touch, slide, and gestures on the touch panel. The touch sensor may not only sense the boundaries of the touch or slide action, but also detect the duration and pressure associated with the touch or slide operation. In some embodiments, the multimedia component 808 includes a front camera and / or a rear camera. When the electronic device 800 is in an operating mode, such as a shooting mode or a video mode, the front camera and / or the rear camera may receive external multimedia data. Each front camera and rear camera may be a fixed optical lens system or have a focal length and optical zoom capability.

[0129] The audio component 810 is configured to output and / or input audio signals. For example, the audio component 810 includes a microphone (MIC), and when the electronic device 800 is in an operation mode, such as a call mode, a recording mode, and a voice recognition mode, the microphone is configured to receive an external audio signal. The received audio signal can be further stored in the memory 804 or sent via the communication component 816. In some embodiments, the audio component 810 also includes a speaker for outputting audio signals.

[0130] I / O interface 812 provides an interface between processing component 802 and peripheral interface modules, such as keyboards, click wheels, buttons, etc. These buttons may include but are not limited to: home button, volume button, start button, and lock button.

[0131] The sensor assembly 814 includes one or more sensors for providing various aspects of status assessment for the electronic device 800. For example, the sensor assembly 814 can detect the open / closed state of the electronic device 800, the relative positioning of the components, such as the display and keypad of the electronic device 800, and the sensor assembly 814 can also detect the position change of the electronic device 800 or a component of the electronic device 800, the presence or absence of contact between the user and the electronic device 800, the orientation or acceleration / deceleration of the electronic device 800, and the temperature change of the electronic device 800. The sensor assembly 814 may include a proximity sensor configured to detect the presence of a nearby object without any physical contact. The sensor assembly 814 may also include an optical sensor, such as a CMOS or CCD image sensor, for use in imaging applications. In some embodiments, the sensor assembly 814 may also include an acceleration sensor, a gyroscope sensor, a magnetic sensor, a pressure sensor, or a temperature sensor.

[0132] The communication component 816 is configured to facilitate wired or wireless communication between the electronic device 800 and other devices. The electronic device 800 can access a wireless network based on a communication standard, such as WiFi, 2G or 3G, or a combination thereof. In an exemplary embodiment, the communication component 816 receives a broadcast signal or broadcast-related information from an external broadcast management system via a broadcast channel. In an exemplary embodiment, the communication component 816 also includes a near field communication (NFC) module to facilitate short-range communication. For example, the NFC module can be implemented based on radio frequency identification (RFID) technology, infrared data association (IrDA) technology, ultra-wideband (UWB) technology, Bluetooth (BT) technology and other technologies.

[0133] In an exemplary embodiment, the electronic device 800 may be implemented by one or more application specific integrated circuits (ASICs), digital signal processors (DSPs), digital signal processing devices (DSPDs), programmable logic devices (PLDs), field programmable gate arrays (FPGAs), controllers, microcontrollers, microprocessors, or other electronic components to perform the above methods.

[0134] In an exemplary embodiment, a non-volatile computer-readable storage medium is also provided, such as a memory 804 including computer program instructions, which can be executed by a processor 820 of an electronic device 800 to perform the above method.

[0135] Fig.12 1 is a block diagram of an electronic device 1900 according to an exemplary embodiment. For example, the electronic device 1900 may be provided as a server. Fig.12 , the electronic device 1900 includes a processing component 1922, which further includes one or more processors, and a memory resource represented by a memory 1932 for storing instructions executable by the processing component 1922, such as an application. The application stored in the memory 1932 may include one or more modules, each corresponding to a set of instructions. In addition, the processing component 1922 is configured to execute instructions to perform the above method.

[0136] The electronic device 1900 may also include a power supply component 1926 configured to perform power management of the electronic device 1900, a wired or wireless network interface 1950 configured to connect the electronic device 1900 to a network, and an input / output (I / O) interface 1958. The electronic device 1900 may operate based on an operating system stored in the memory 1932, such as Windows Server™, Mac OS X™, Unix™, Linux™, FreeBSD™ or the like.

[0137] In an exemplary embodiment, a non-volatile computer-readable storage medium is also provided, such as a memory 1932 including computer program instructions, which can be executed by the processing component 1922 of the electronic device 1900 to perform the above method.

[0138] The present disclosure may be a system, a method and / or a computer program product. The computer program product may include a computer-readable storage medium carrying computer-readable program instructions for causing a processor to implement various aspects of the present disclosure.

[0139] A computer-readable storage medium may be a tangible device that can hold and store instructions used by an instruction execution device. A computer-readable storage medium may be, for example, but not limited to, an electrical storage device, a magnetic storage device, an optical storage device, an electromagnetic storage device, a semiconductor storage device, or any suitable combination of the above. More specific examples (a non-exhaustive list) of computer-readable storage media include: a portable computer disk, a hard disk, a random access memory (RAM), a read-only memory (ROM), an erasable programmable read-only memory (EPROM or flash memory), a static random access memory (SRAM), a portable compact disk read-only memory (CD-ROM), a digital versatile disk (DVD), a memory stick, a floppy disk, a mechanical encoding device, such as a punch card or a raised structure in a groove on which instructions are stored, and any suitable combination of the above. The computer-readable storage medium used herein is not to be interpreted as a transient signal itself, such as a radio wave or other freely propagating electromagnetic wave, an electromagnetic wave propagating through a waveguide or other transmission medium (e.g., a light pulse through a fiber optic cable), or an electrical signal transmitted through a wire.

[0140] The computer-readable program instructions described herein can be downloaded from a computer-readable storage medium to each computing / processing device, or downloaded to an external computer or external storage device via a network, such as the Internet, a local area network, a wide area network, and / or a wireless network. The network can include copper transmission cables, optical fiber transmissions, wireless transmissions, routers, firewalls, switches, gateway computers, and / or edge servers. The network adapter card or network interface in each computing / processing device receives the computer-readable program instructions from the network and forwards the computer-readable program instructions for storage in the computer-readable storage medium in each computing / processing device.

[0141] The computer program instructions for performing the operations of the present disclosure may be assembly instructions, instruction set architecture (ISA) instructions, machine instructions, machine-dependent instructions, microcode, firmware instructions, state setting data, or source code or object code written in any combination of one or more programming languages, including object-oriented programming languages, such as Smalltalk, C++, etc., and conventional procedural programming languages, such as "C" language or similar programming languages. The computer-readable program instructions may be executed entirely on the user's computer, partially on the user's computer, as a separate software package, partially on the user's computer, partially on a remote computer, or entirely on a remote computer or server. In the case of a remote computer, the remote computer may be connected to the user's computer through any type of network, including a local area network (LAN) or a wide area network (WAN), or may be connected to an external computer (e.g., using an Internet service provider to connect through the Internet). In some embodiments, by using the state information of the computer-readable program instructions to personalize an electronic circuit, such as a programmable logic circuit, a field programmable gate array (FPGA), or a programmable logic array (PLA), the electronic circuit may execute the computer-readable program instructions, thereby implementing various aspects of the present disclosure.

[0142] Various aspects of the present disclosure are described herein with reference to flowcharts and / or block diagrams of methods, devices (systems) and computer program products according to embodiments of the present disclosure. It should be understood that each box in the flowchart and / or block diagram and the combination of boxes in the flowchart and / or block diagram can be implemented by computer-readable program instructions.

[0143] These computer-readable program instructions can be provided to a processor of a general-purpose computer, a special-purpose computer, or other programmable data processing device, thereby producing a machine, so that when these instructions are executed by the processor of the computer or other programmable data processing device, a device that implements the functions / actions specified in one or more boxes in the flowchart and / or block diagram is generated. These computer-readable program instructions can also be stored in a computer-readable storage medium, and these instructions cause the computer, programmable data processing device, and / or other equipment to work in a specific manner, so that the computer-readable medium storing the instructions includes a manufactured product, which includes instructions for implementing various aspects of the functions / actions specified in one or more boxes in the flowchart and / or block diagram.

[0144] Computer-readable program instructions may also be loaded onto a computer, other programmable data processing apparatus, or other device so that a series of operating steps are performed on the computer, other programmable data processing apparatus, or other device to produce a computer-implemented process, thereby causing the instructions executed on the computer, other programmable data processing apparatus, or other device to implement the functions / actions specified in one or more boxes in the flowchart and / or block diagram.

[0145] The flow chart and block diagram in the accompanying drawings show the possible architecture, function and operation of the system, method and computer program product according to multiple embodiments of the present disclosure. In this regard, each square box in the flow chart or block diagram can represent a part of a module, program segment or instruction, and a part of the module, program segment or instruction includes one or more executable instructions for realizing the specified logical function. In some alternative implementations, the function marked in the square box can also occur in a sequence different from that marked in the accompanying drawings. For example, two continuous square boxes can actually be executed substantially in parallel, and they can sometimes be executed in reverse order, depending on the functions involved. It should also be noted that each square box in the block diagram and / or flow chart, and the combination of the square boxes in the block diagram and / or flow chart can be implemented with a dedicated hardware-based system that performs the specified function or action, or can be implemented with a combination of special hardware and computer instructions.

[0146] The embodiments of the present disclosure have been described above, and the above description is exemplary, not exhaustive, and is not limited to the disclosed embodiments. Many modifications and variations will be apparent to those of ordinary skill in the art without departing from the scope and spirit of the described embodiments. The selection of terms used herein is intended to best explain the principles of the embodiments, practical applications, or technical improvements to the technology in the market, or to enable other persons of ordinary skill in the art to understand the embodiments disclosed herein.

Claims

1. A method for determining dynamic permeability loss, It is characterized in that include: Obtain original reservoir pressure and reservoir permeability; According to the reservoir permeability, the corresponding starting pressure gradient is determined; wherein the method for determining the corresponding starting pressure gradient according to the reservoir permeability comprises: obtaining a first relationship between the reservoir permeability and the corresponding starting pressure gradient; based on the first relationship and the reservoir permeability or the updated reservoir permeability, determining the corresponding starting pressure gradient; Determine the reservoir pressure change according to the starting pressure gradient and the original reservoir pressure; wherein the method for determining the reservoir pressure change according to the starting pressure gradient and the original reservoir pressure comprises: determining the reservoir pressure distribution according to the starting pressure gradient; determining the reservoir pressure change according to the reservoir pressure distribution and the original reservoir pressure; Determine the static confining pressure at any point of the reservoir according to the reservoir pressure change, and determine the permeability loss rate at any point of the reservoir based on the static confining pressure; wherein, the method of determining the static confining pressure at any point of the reservoir according to the reservoir pressure change, and determining the permeability loss rate at any point of the reservoir based on the static confining pressure, comprises: obtaining a second relationship between the static confining pressure and the permeability loss rate, and determining the permeability loss rate at any point of the reservoir based on the static confining pressure or the static confining pressure corresponding to the updated reservoir permeability.

2. The method for determining the dynamic loss of permeability according to claim 1, It is characterized in that The method for determining the dynamic loss of permeability further includes: Step S1011: obtaining a preset determination time, an initial time and a set time step; Step S1012: within a preset calculation time, determining the reservoir pressure change corresponding to the time point of the set time step according to the starting pressure gradient corresponding to the initial time and the original reservoir pressure; Step S1014: determining the static confining pressure at any point of the reservoir according to the reservoir pressure change, and determining the permeability loss rate at any point of the reservoir corresponding to the time point of the set time step based on the static confining pressure; Step S1015: If the time point corresponding to the permeability loss rate is less than the preset determination time, update the reservoir permeability corresponding to the next set time step, and execute the method of steps S1012-S1014; until the time point is equal to the preset determination time, obtain the permeability loss rate at any point in the reservoir corresponding to the preset determination time.

3. The method for determining the dynamic loss of permeability according to claim 1 or 2, It is characterized in that Before obtaining the original reservoir pressure and reservoir permeability, the original reservoir pressure and reservoir permeability are determined. The method for determining the original reservoir pressure and reservoir permeability includes: Obtain the grid division diagram corresponding to the horizontal well physical model; The original reservoir pressure and reservoir permeability in the grid are determined according to the grid division diagram.

4. The method for determining the dynamic loss of permeability according to claim 3, It is characterized in that Before obtaining the grid division diagram corresponding to the horizontal well physical model, the grid division diagram corresponding to the horizontal well physical model is determined, and the determination method includes: Acquire a horizontal well physical model and parameters corresponding to the horizontal well physical model; The horizontal well physical model is meshed to determine a mesh diagram corresponding to the horizontal well physical model and parameters within the mesh of the mesh diagram.

5. The method for determining the dynamic loss of permeability according to claim 4, It is characterized in that Before obtaining the horizontal well physical model, the horizontal well physical model is determined, and the determination method includes: Get a 2D plan view of the horizontal well; If the complexity of the fractures in the two-dimensional plane diagram meets the preset conditions, fracture simulation is performed on the fracturing section and the horizontal section of the two-dimensional plane diagram according to the set fracture parameters to obtain the horizontal well physical model.

6. The method for determining the dynamic loss of permeability according to claim 4 or 5, It is characterized in that The method of meshing the horizontal well physical model to obtain a meshing diagram corresponding to the horizontal well physical model includes: Get the shape unit of the mesh; The horizontal well physical model is meshed according to the shape unit to obtain a meshed graph corresponding to the horizontal well physical model.

7. The method for determining the dynamic loss of permeability according to claim 5, It is characterized in that The method for simulating fractures in the fracturing section and the horizontal section of the two-dimensional plane diagram according to set fracture parameters comprises: Acquire set fracture parameters; wherein the fracture parameters include at least: fracture half-length, angle between the fracture and the horizontal section, number of fracture clusters in the fracturing section, and fracture pressure at the horizontal wellbore; According to the number of clusters of fractures in the fracturing section, the half-length of the fractures, the angle between the fractures and the horizontal section, and the pressure of the fractures in the wellbore of the horizontal well, the fracture simulation is performed on the two-dimensional plane diagram to obtain the physical model of the horizontal well.

8. The method for determining the dynamic loss of permeability according to claim 6, It is characterized in that The method of meshing the horizontal well physical model to obtain a meshing diagram corresponding to the horizontal well physical model further includes: Get the line elements of the mesh; The mesh division diagram corresponding to the horizontal well physical model is encrypted according to the line unit to obtain a final mesh division diagram and parameters within the mesh of the final mesh division diagram.

9. A device for determining dynamic loss of permeability, It is characterized in that include: An acquisition unit, used for acquiring original reservoir pressure and reservoir permeability; A first determining unit is used to determine a corresponding starting pressure gradient according to the reservoir permeability; wherein, determining the corresponding starting pressure gradient according to the reservoir permeability includes: obtaining a first relationship between the reservoir permeability and the corresponding starting pressure gradient; determining the corresponding starting pressure gradient based on the first relationship and the reservoir permeability or the updated reservoir permeability; A second determination unit is used to determine a reservoir pressure change according to the starting pressure gradient and the original reservoir pressure; wherein the determination of the reservoir pressure change according to the starting pressure gradient and the original reservoir pressure comprises: determining a reservoir pressure distribution according to the starting pressure gradient; determining a reservoir pressure change according to the reservoir pressure distribution and the original reservoir pressure; The third determination unit is used to determine the static confining pressure at any point of the reservoir according to the change of the reservoir pressure, and determine the permeability loss rate at any point of the reservoir based on the static confining pressure; wherein, the method for determining the static confining pressure at any point of the reservoir according to the change of the reservoir pressure, and determining the permeability loss rate at any point of the reservoir based on the static confining pressure, comprises: obtaining a second relationship between the static confining pressure and the permeability loss rate, and determining the permeability loss rate at any point of the reservoir based on the static confining pressure or the static confining pressure corresponding to the updated reservoir permeability.

10. An electronic device, It is characterized in that include: processor; a memory for storing processor-executable instructions; The processor is configured to call the instructions stored in the memory to execute the method described in any one of claims 1 to 8.

11. A computer readable storage medium having computer program instructions stored thereon, It is characterized in that When the computer program instructions are executed by a processor, the method according to any one of claims 1 to 8 is implemented.

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