Method, device and equipment for determining reservoir fracture conductivity

Abstract

The invention discloses a method, a device and equipment for determining reservoir fracture conductivity. The method comprises the following steps: acquiring fracture data of a target reservoir; based on the fracture data, determining a fracture width distribution result of a support fracture in the target reservoir, the fracture width distribution result including a continuous distribution result of the fracture width of the support fracture along the fracture length and fracture height direction of the support fracture; and on the basis of the fracture width distribution result and a predetermined mapping relation between the fracture width and the flow conductivity, the flow conductivity distribution of the target reservoir is determined, and the flow conductivity distribution represents the distribution of the flow conductivity of the supporting fracture of the target reservoir in the fracture length and fracture height directions of the supporting fracture. According to the method, more accurate and reliable flow conductivity distribution can be obtained, the flow conductivity of the support fracture in multiple dimensions can be predicted, and prediction of the flow conductivity distribution is more comprehensive.

Description

Technical Field

[0001] The present application relates to the technical field of tight sandstone reservoir transformation, and in particular to a method, device and equipment for determining reservoir fracture conductivity. Background Art

[0002] Hydraulic fracturing technology is currently the key technology for achieving efficient development of unconventional reservoirs. Viscous liquid is pumped into the well from the ground, and the reservoir is broken under high pressure at the bottom of the well to form hydraulic dynamic fractures. Liquid is used to carry proppants into the fractures to form support inside the fractures, so that the fractures are not completely closed, thereby establishing efficient oil and gas flow channels and achieving high oil and gas well production. Therefore, the size and flow performance of hydraulic dynamic fractures and propped fractures are crucial to the effect of fracturing transformation.

[0003] In order to better determine the conductivity of artificial fractures, the existing artificial fractures are determined by adding sand to fracturing. The existing determination of the conductivity of artificial fractures by adding sand to fracturing is mostly based on the experimental, numerical modeling and mathematical statistics perspectives, which to a certain extent achieves the prediction of the conductivity of artificial fractures. However, the current determination method has problems such as small determination scale, insufficient determination dimension, large difference from actual artificial fractures and inaccurate determination results. It is impossible to achieve the reasonable construction of the distribution profile of the conductivity of artificial fractures at the mine scale, and thus cannot support the design of fracturing schemes and the increase of oil and gas well production. Summary of the invention

[0004] The purpose of the embodiments of the present application is to provide a method, device and equipment for determining the conductivity of reservoir fractures, so as to solve the problem of inaccurate conductivity determination results.

[0005] In order to solve the above technical problems, the first aspect of this specification provides a method for determining reservoir fracture conductivity, comprising:

[0006] Acquire fracture data of target reservoir;

[0007] Based on the fracture data, determining a fracture width distribution result of the propped fracture in the target reservoir, wherein the fracture width distribution result includes a continuous distribution result of the fracture width of the propped fracture along the fracture length and fracture height directions of the propped fracture;

[0008] Based on the fracture width distribution result and a predetermined mapping relationship between fracture width and conductivity, the conductivity distribution of the target reservoir is determined, wherein the conductivity distribution characterizes the distribution of the conductivity of the propped fractures of the target reservoir along the fracture length and fracture height directions of the propped fractures.

[0009] In some embodiments, obtaining fracture data of a target reservoir includes:

[0010] Obtain core column profile of target reservoir;

[0011] The fracture data of the dynamic fractures of the core column section are collected, wherein the fracture data include fracture length data, fracture width data and fracture height data.

[0012] In some embodiments, determining the fracture width distribution result of the propped fractures in the target reservoir based on the fracture data includes:

[0013] Determining the filtration coefficient of the fracturing fluid in the dynamic fractures of the target reservoir based on the fracture length data and fracture height data of the dynamic fractures;

[0014] The fracture width distribution result is determined based on the fracture height data, the fracture length data, the fracture width data and the filtration coefficient.

[0015] In some embodiments, the fluid loss coefficient is determined by the following formula:

[0016]

[0017] Where L represents the half-length of the dynamic fracture, q represents the flow rate of the fracturing fluid, G represents the shear modulus of the target reservoir, ν represents the Poisson's ratio of the target reservoir, and H f It represents the height of dynamic fracture, μ represents the viscosity of fracturing fluid, and ψ represents the filtration coefficient of fracturing fluid.

[0018] In some embodiments, determining the slit width distribution result based on the slit height data, the slit length data, the slit width data and the filtration coefficient includes:

[0019] Determine a first fracture width distribution of the dynamic fracture of the target reservoir along the fracture height direction and the fracture length direction based on the fracture height data, the fracture length data, the fracture width data, a mapping relationship between the fracture length in the dynamic fracture of the target reservoir and the fracture height, and a mapping relationship between the fracture width and the fracture length of the dynamic fracture of the target reservoir;

[0020] Based on the mapping relationship between the filtration coefficient, the fracture width and the fracture height, and the mapping relationship between the fracture width and the fracturing time, determining a second fracture width distribution of the longitudinal section of the fracture at the fracture opening of the target reservoir;

[0021] The slit width distribution result is determined based on the first slit width distribution and the second slit width distribution.

[0022] In some embodiments, the second slit width distribution data is determined by the following formula:

[0023]

[0024]

[0025] Where W(0,t) represents the central width of the fracture mouth when the time of fracturing construction is t, t represents the time of fracturing construction, q represents the flow rate of fracturing fluid, G represents the shear modulus of the target reservoir, ν represents the Poisson's ratio of the target reservoir, and H f represents the height of the dynamic fracture, μ represents the viscosity of the fracturing fluid, ψ represents the filtration coefficient of the fracturing fluid, x represents the horizontal coordinate of the fracture on the longitudinal section of the fracture with the center of the fracture as the origin, and y represents the vertical coordinate of the fracture on the longitudinal section of the fracture with the center of the fracture as the origin.

[0026] In some embodiments, before determining the conductivity distribution of the target reservoir based on the fracture width distribution result and the predetermined mapping relationship between fracture width and conductivity, the method includes:

[0027] determining a target equilibrium flow rate of a proppant that props a fracture in the target reservoir;

[0028] Determining the equilibrium height of the target reservoir based on the mapping relationship between the equilibrium flow rate and the equilibrium height of the proppant and the target equilibrium flow rate;

[0029] It is determined that the conductivity of the propped fractures of the target reservoir above the equilibrium height is zero.

[0030] A second aspect of the present specification provides a device for determining reservoir fracture conductivity, comprising:

[0031] A data acquisition module, used to acquire fracture data of a target reservoir;

[0032] A fracture width determination module, configured to determine a fracture width distribution result of the propped fracture in the target reservoir based on the fracture data, wherein the fracture width distribution result includes a continuous distribution result of the fracture width of the propped fracture along the fracture length and fracture height directions of the propped fracture;

[0033] The conductivity determination module is used to determine the conductivity distribution of the target reservoir based on the fracture width distribution result and a predetermined mapping relationship between the fracture width and the conductivity, wherein the conductivity distribution characterizes the distribution of the conductivity of the propped fracture of the target reservoir along the fracture length and fracture height direction of the propped fracture.

[0034] The third aspect of this specification provides an electronic device, comprising: a memory and a processor, the processor and the memory are communicatively connected to each other, the memory stores computer instructions, and the processor implements the steps of any one of the methods described in the first aspect by executing the computer instructions.

[0035] A fourth aspect of the present specification provides a computer storage medium, wherein the computer storage medium stores computer program instructions, and when the computer program instructions are executed, the steps of any one of the methods described in the first aspect are implemented.

[0036] The method for determining the conductivity of reservoir fractures provided in the embodiment of this specification obtains the fracture data of the target reservoir, and based on the fracture data, determines the continuous fracture width distribution results of the supporting fractures in the target reservoir along the fracture length and fracture height directions of the supporting fractures, and then can determine the conductivity distribution of the target reservoir based on the fracture width distribution results, and the mapping relationship between the fracture width and the conductivity determined by simulating the fracture width data of the supporting fractures obtained by the experiment and the conductivity data of the supporting fractures, wherein the conductivity distribution characterizes the distribution of the conductivity of the supporting fractures of the target reservoir along the fracture length and fracture height directions of the supporting fractures. The present application can more accurately determine the width distribution results of the supporting fractures of the target reservoir through the measured fracture data, and can provide a basis for obtaining a true and reliable conductivity distribution; and the present application also simulates the mapping relationship between the fracture width and the conductivity through experimental data, and can obtain a more accurate conductivity distribution. In addition, the present application determines the width distribution results of the supporting fractures in the fracture length and fracture height directions, and can predict the conductivity of the supporting fractures in multiple dimensions, and the prediction of the conductivity distribution is more comprehensive. BRIEF DESCRIPTION OF THE DRAWINGS

[0037] In order to more clearly illustrate the implementation methods of the present application or the technical solutions in the prior art, the drawings required for use in the implementation methods or the description of the prior art will be briefly introduced below. Obviously, the drawings described below are only some implementation methods recorded in this application. For ordinary technicians in this field, other drawings can be obtained based on these drawings without paying creative labor.

[0038] Figure 1 Shown is a schematic flow chart of a method for determining reservoir fracture conductivity provided by an embodiment of the present application;

[0039] Figure 2 Shown is a flow chart of a method for determining a slit width distribution provided in an embodiment of the present application;

[0040] Figure 3 Shown is a schematic structural diagram of a dynamic crack provided in an embodiment of the present application;

[0041] Figure 4 Shown is a flow chart of another method for determining reservoir fracture conductivity provided by an embodiment of the present application;

[0042] Figure 5 Shown is a schematic diagram of a well extraction position provided in an embodiment of the present application;

[0043] Figure 6 The figure shows a curve schematic diagram of a mapping relationship between crack width and crack length provided in an embodiment of the present application;

[0044] Figure 7 The figure shows a linear relationship diagram between the slit width and the flow conductivity provided in an embodiment of the present application;

[0045] Figure 8 Shown is a schematic diagram of a flow conductivity distribution provided in an embodiment of the present application;

[0046] Fig. 9 It is a schematic diagram of a program module of a device for determining reservoir fracture conductivity provided by an embodiment of the present application;

[0047] Fig.10 Shown is a principle block diagram of an electronic device provided in an embodiment of the present application. DETAILED DESCRIPTION

[0048] In order to enable those skilled in the art to better understand the technical solutions in this application, the technical solutions in the embodiments of this application will be clearly and completely described below in conjunction with the drawings in the embodiments of this application. Obviously, the described embodiments are only part of the embodiments of this application, not all of the embodiments. Based on the embodiments in this application, all other embodiments obtained by ordinary technicians in this field without creative work should fall within the scope of protection of this application.

[0049] As mentioned above, the size and flow performance of dynamic fractures and propped fractures are crucial to the effect of fracturing transformation. The longer the propped fracture length, the higher the propped fracture height, and the greater the propped fracture conductivity, the greater the oil and gas output after fracturing, which reflects the better fracturing transformation effect. Since the reservoir is buried deep underground, artificial fractures cannot be directly seen, and people are quite limited in determining their length, width, height, and conductivity. At present, it is generally adopted to arrange equipment and facilities in the active wellbore on the ground, and use the changes in signals such as sound waves, electromagnetic waves, and temperature during fracturing to monitor the changes and morphology of artificial fractures, such as microseismic, wide-area electromagnetic method, and fiber optic monitoring of adjacent wells. To a certain extent, the changes in the length and height of artificial fractures have been realized, and concepts such as reservoir transformation volume have been proposed to quantify artificial fractures. However, these methods have more or less errors, which are mainly affected by reservoir heterogeneity, signal propagation strength, and the working principle of the equipment, resulting in a large difference between the determination results and the actual results. At the same time, this type of method can only identify artificial dynamic fractures, but cannot identify supporting fractures that truly contribute to production. Therefore, it is very necessary to better analyze and identify artificial dynamic fractures and supporting fractures. The results of the determination will strongly support the optimization of the design of fracturing schemes and further increase the production and efficiency of oil and gas wells.

[0050] In order to better determine the conductivity of artificial fractures, the existing artificial fractures using sand fracturing have been predicted from the perspectives of experiments, numerical models and mathematical statistics to a certain extent. However, the conductivity determined by this method is small in scale, insufficient in dimension, large in difference from actual artificial fractures and inaccurate in results. It is impossible to reasonably construct the distribution profile of the conductivity of artificial fractures at the mine scale, and has little support for the design of fracturing schemes and the increase in production of oil and gas wells.

[0051] Considering that the existing conductivity determination method only determines the width distribution of propped fractures by theoretical calculation, and the prediction dimensions of conductivity distribution are relatively few, this application proposes a method for determining multi-dimensional conductivity distribution based on measured fracture data of the reservoir.

[0052] Based on the above ideas, an embodiment of the present application provides a method for determining the conductivity of reservoir fractures, by acquiring fracture data of a target reservoir, and determining, based on the fracture data, continuous fracture width distribution results of propped fractures in the target reservoir along the fracture length and fracture height directions of the propped fractures, and then determining the conductivity distribution of the target reservoir based on the fracture width distribution results and a mapping relationship between fracture width and conductivity determined by simulating fracture width data of the propped fractures obtained by experiments and conductivity data of the propped fractures, wherein the conductivity distribution characterizes the distribution of the conductivity of the propped fractures of the target reservoir along the fracture length and fracture height directions of the propped fractures.

[0053] This application can more accurately determine the width distribution of the propped fractures of the target reservoir through measured fracture data, which can provide a basis for obtaining a true and reliable conductivity distribution; and this application also simulates the mapping relationship between fracture width and conductivity through experimental data, which can obtain a more accurate conductivity distribution. In addition, this application determines the width distribution of propped fractures in the fracture length and fracture height directions, which can predict the conductivity of propped fractures in multiple dimensions, and the prediction of conductivity distribution is more comprehensive.

[0054] It can be understood that the above method provided in the present application can be applied to electronic devices, and electronic devices can refer to electronic devices with data calculation, processing and storage capabilities. The electronic device can be a terminal such as a PC (Personal Computer), a tablet computer, a smart phone, a wearable device, an intelligent robot, etc.; it can also be a server. Among them, the server can be an independent physical server, or a server cluster or distributed system composed of multiple physical servers, or a cloud server that provides cloud computing services.

[0055] The following first introduces the method for determining reservoir fracture conductivity provided by the embodiment of the present application in conjunction with the accompanying drawings.

[0056] Figure 1 FIG. 1 is a flow chart of a method for determining reservoir fracture conductivity provided in an embodiment of the present application. Figure 1 As shown, the method may include:

[0057] S101: Acquire fracture data of a target reservoir.

[0058] It can be understood that since it is impossible to collect the fracture data of the propped fractures in the target reservoir, the fracture data of the dynamic fractures in the target reservoir can be collected to determine the fracture width distribution result of the propped fractures. That is, the fracture data obtained in step S101 is the fracture data of the dynamic fractures in the target reservoir. The fracture data may include the geometric size data of the dynamic fractures.

[0059] In some embodiments, obtaining fracture data of a target reservoir includes: obtaining a core column profile of the target reservoir; and collecting fracture data of dynamic fractures in the core column profile, wherein the fracture data includes fracture length data, fracture width data, and fracture height data.

[0060] In some embodiments, the core column profile may be obtained by:

[0061] (1) A horizontal well corresponding to the target reservoir is selected for hydraulic fracturing, and the horizontal wellbore trajectory of the horizontal well is perpendicular to the direction of the maximum horizontal principal stress. After the hydraulic fracturing is completed, relevant data of the real-time hydraulic fracturing process are collected, which may include engineering geological parameters (such as construction well section, Young's modulus, Poisson's ratio, shear modulus, minimum horizontal principal stress, etc.) and construction parameters (such as construction time, construction displacement, fracturing fluid viscosity, etc.).

[0062] (2) Drill a high-angle well within the range of 50 to 200 m from the horizontal section of the horizontal well to conduct conformal coring and take out the core within the range of 50 to 200 m from the horizontal well. The coring length can be determined based on the actual situation.

[0063] (3) The core column obtained in the previous step is divided along a direction perpendicular to the core cross section, and an electron microscope is scanned along the section to obtain a core column section containing dynamic fractures.

[0064] Furthermore, in some embodiments, the number of dynamic fractures can be marked on the core column section, and the lateral distance and longitudinal distance from each depth of the dynamic fracture to the horizontal wellbore can be measured according to the relative position of the wellbore trajectory of the highly deviated well and the horizontal well. The fracture length data of the dynamic fracture can be obtained based on the lateral distance, and the fracture height data of the dynamic fracture can be obtained based on the longitudinal distance.

[0065] S102: Determine a fracture width distribution result of the propped fracture in the target reservoir based on the fracture data, wherein the fracture width distribution result includes a continuous distribution result of the fracture width of the propped fracture along the fracture length and fracture height directions of the propped fracture.

[0066] In some embodiments, based on the fracture data, the fracture width distribution result of the propped fracture in the target reservoir is determined, including: based on the fracture length data and fracture height data of the dynamic fracture, determining the filtration coefficient of the fracturing fluid in the dynamic fracture of the target reservoir; based on the fracture height data, the fracture length data, the fracture width data and the filtration coefficient, determining the fracture width distribution result.

[0067] In some embodiments, determining the fluid loss coefficient of the fracturing fluid based on the fracture length data and fracture height data of the dynamic fractures may include: determining the mapping relationship between the fluid loss coefficient of the fracturing fluid and the fracture length and fracture height of the dynamic fractures, and then determining the fluid loss coefficient of the fracturing fluid based on the measured fracture length data and fracture height data of the dynamic fractures of the target reservoir. That is, the fluid loss coefficient of the fracturing fluid is calibrated through the measured data to obtain a fracturing fluid loss coefficient that is more consistent with the target reservoir, thereby making the calculated fracture width distribution results and conductivity distribution more consistent with the actual situation and more real and reliable.

[0068] In some embodiments, the fluid loss coefficient can be determined by the following formula:

[0069]

[0070] Where L represents the half-length of the dynamic fracture, q represents the flow rate of the fracturing fluid, G represents the shear modulus of the target reservoir, ν represents the Poisson's ratio of the target reservoir, and H f It represents the height of dynamic fracture, μ represents the viscosity of fracturing fluid, and ψ represents the filtration coefficient of fracturing fluid.

[0071] It can be understood that since the crack length and crack height data of the crack opening of the dynamic crack cannot be obtained through the measured data collection, the crack width distribution of the crack at the crack opening cannot be determined. However, the crack width at the crack opening, as the maximum crack width of the dynamic crack, can be calibrated by the measured data using the above formula (1) to calibrate the filtration coefficient, and then the crack width distribution at the crack opening can be calculated based on the calibrated filtration coefficient. The crack width distribution at the crack opening is used as the boundary constraint for determining the crack width distribution result of the supporting crack, which can obtain a more accurate and reliable crack width distribution result.

[0072] Figure 2 The figure is a flow chart of a method for determining the seam width distribution provided in an embodiment of the present application.

[0073] like Figure 2As shown, in some embodiments, determining the fracture width distribution result based on the fracture height data, the fracture length data, the fracture width data and the filtration coefficient may include:

[0074] S201: Determine a first fracture width distribution of the dynamic fractures of the target reservoir along the fracture height direction and the fracture length direction based on the fracture height data, the fracture length data, the fracture width data, a mapping relationship between the fracture length and the fracture height in the dynamic fractures of the target reservoir, and a mapping relationship between the fracture width and the fracture length of the dynamic fractures of the target reservoir.

[0075] In some embodiments, the dynamic fracture can be considered as an ellipsoid, and each cross section of the dynamic fracture can be considered as an ellipse. Figure 3 FIG. 1 is a schematic diagram of a dynamic crack structure provided in an embodiment of the present application. Figure 3 As shown, the dynamic crack can be regarded as an ellipsoid, and the center point of the ellipsoid is the center point of the crack mouth of the dynamic crack. A coordinate system can be constructed with the center point of the crack mouth of the dynamic crack as the origin, then the y-axis direction of the coordinate system can represent the crack width direction of the dynamic crack, the x-axis direction can represent the crack length direction of the dynamic crack, and the z-axis direction can represent the crack height direction of the dynamic crack. For the longitudinal section S of the dynamic crack, the mapping relationship between the crack width and crack height on the section can satisfy the ellipse equation, and the coefficients of the ellipse equation are respectively the crack height H of the dynamic crack in the longitudinal section f As well as the crack width, the crack height H of the dynamic crack in the longitudinal section can be calculated based on f , crack width and ellipse equation are used to determine the crack width distribution of the dynamic crack in the longitudinal section along the crack height direction.

[0076] Continue to refer Figure 3 As shown, in some embodiments, since the dynamic fracture can be regarded as an ellipsoid, the mapping relationship between the fracture width and the fracture length, and the mapping relationship between the fracture length and the fracture height of the dynamic fracture also satisfy the ellipse equation. Further, based on the ellipse equation and the measured fracture length data and fracture width data, the fracture width distribution of a single longitudinal section can be extended to multiple longitudinal sections of the dynamic fracture to obtain the fracture width distribution of the dynamic fracture in three-dimensional space. That is, the first fracture width distribution of the dynamic fracture along the fracture length direction and the fracture height direction is obtained.

[0077] In some embodiments, the first slit width distribution may be determined by:

[0078] The crack width data, crack length data and crack height data of the dynamic cracks of the core column section obtained by coring are integrated into the form of vectors, which can be expressed as dynamic crack width vector, dynamic crack length vector and dynamic crack height vector. According to the dynamic cracks of different longitudinal sections, the dynamic crack width vector, dynamic crack length vector and dynamic crack height vector belong to the dynamic cracks, respectively. The crack width, crack height and crack length of different cracks are projected onto the same crack by the projection method, so that the crack has the crack length value, the crack width value and the crack height value of the dynamic crack at multiple points (i.e., multiple longitudinal sections). Then, according to the ellipse equation, the first crack width distribution on the crack section corresponding to each point can be calculated.

[0079] S202: Based on the mapping relationship between the filtration coefficient, the fracture width and the fracture height, and the mapping relationship between the fracture width and the fracturing time, determine a second fracture width distribution of the longitudinal section of the fracture at the fracture opening of the target reservoir.

[0080] It can be understood that since the crack length and crack height data of the cracks at the crack opening of the dynamic cracks cannot be obtained through the measured data collection, the crack width distribution of the cracks at the crack opening cannot be determined. The crack width at the crack opening is the maximum crack width of the dynamic cracks, so it is necessary to calibrate the filtration coefficient using the measured data through formula (1). Then, in step S202, the second crack width distribution at the crack opening can be calculated based on the calibrated filtration coefficient, and the second crack width distribution at the crack opening is used as the boundary constraint condition for determining the crack width distribution result of the supporting crack, so that a more accurate and reliable crack width distribution result can be obtained.

[0081] In some embodiments, the second slit width distribution data is determined by the following formula:

[0082]

[0083]

[0084] Where W(0,t) represents the central width of the fracture mouth when the time of fracturing construction is t, t represents the time of fracturing construction, q represents the flow rate of fracturing fluid, G represents the shear modulus of the target reservoir, ν represents the Poisson's ratio of the target reservoir, and H f represents the fracture height of dynamic fractures, μ represents the viscosity of fracturing fluid, ψ represents the filtration coefficient of fracturing fluid, w represents the fracture width on the fracture longitudinal section at the fracture mouth of target reservoir, x represents the fracture horizontal coordinate on the fracture longitudinal section with the fracture center as the origin, and y represents the fracture vertical coordinate on the fracture longitudinal section with the fracture center as the origin.

[0085] It can be understood that the time of the fracturing construction is the time from the start of fracturing fluid injection to the completion of dynamic fracture formation. As the fracturing time increases, the width of the dynamic fracture opening will also change. The central width of the fracture opening (e.g. Figure 3The W(0, t) shown in FIG. 1 is substituted into formula (3). By enumerating the y values, a series of x values ​​are obtained using formula (3). The obtained x is the second slit width distribution.

[0086] S203: Determine the slit width distribution result based on the first slit width distribution and the second slit width distribution.

[0087] It can be understood that the first crack width distribution obtained in step S201 is discrete crack width distribution data, which is crack width distribution corresponding to multiple dynamic crack longitudinal sections obtained by obtaining crack data of multiple dynamic crack longitudinal sections. In step S203, the second crack width distribution obtained in step S202 can be used as a constraint condition for the crack width distribution result of the supporting crack, and the first crack width distribution obtained in step S201 is interpolated to obtain a continuous crack width distribution result, that is, the crack width distribution result of the supporting crack.

[0088] S103: Determine the conductivity distribution of the target reservoir based on the fracture width distribution result and a predetermined mapping relationship between the fracture width and the conductivity, wherein the conductivity distribution characterizes the distribution of the conductivity of the propped fracture of the target reservoir along the fracture length and fracture height of the propped fracture.

[0089] It can be understood that the predetermined mapping relationship between the crack width and the conductivity is determined by simulating the crack width data of the supporting crack and the conductivity data of the supporting crack obtained by the experiment. Specifically, the mapping relationship between the crack width and the conductivity is determined by the following method:

[0090] Assuming that the formation closure stress remains unchanged, that is, under the basic condition that the compaction effect of the proppant in the fracture is the same, the proppant on the wall of each propped fracture in the core column section is collected and weighed to obtain the proppant mass set. According to the core diameter and the proppant mass on the wall of the propped fracture, the proppant surface density set can be obtained.

[0091] Furthermore, the conductivity of the propped fracture can be measured by using an indoor conductivity test instrument, where the length, width, and height of the flow chamber are l, w, and h, respectively, where w represents the proppant filling thickness, which is the width of the propped fracture here. The mass of the proppant required to fill the flow chamber under each propped fracture width is obtained by the cross-sectional area of ​​the flow chamber and the surface density of the proppant, and then the calculated mass of the required proppant is filled into the flow chamber to perform a conductivity test experiment, where the flow chamber is used to simulate an artificial fracture.

[0092] During the experiment, data such as fluid velocity, fluid viscosity, diversion chamber height, diversion chamber length, and pressure difference between upstream and downstream of the diversion chamber can be collected in the propped fracture. Then, based on the relationship between the diversion capacity and the diversion chamber width and related parameters of the fluid, the diversion capacity under different diversion chamber widths can be determined. Then, based on the diversion chamber width and the corresponding diversion capacity, the mapping relationship between the fracture width and the diversion capacity is simulated, and a linear equation characterizing the mapping relationship between the diversion capacity and the fracture width is obtained.

[0093] In some embodiments, the flow guiding capacity of the flow guiding chamber corresponding to different flow guiding chamber widths can be determined by the following formula:

[0094]

[0095] Among them, WK f represents the conductivity of the diversion chamber, that is, the conductivity of the propped fracture, Q represents the flow velocity of the fluid during the experiment, μ1 represents the viscosity of the fluid during the experiment, h represents the height of the diversion chamber, l represents the length of the diversion chamber, w represents the width of the diversion chamber, and ΔP represents the pressure difference between the upstream and downstream of the diversion chamber.

[0096] In some embodiments, the linear relationship between the slit width and the flow conductivity can be expressed by the following formula:

[0097] WK f =kw+s Formula (5)

[0098] Here, k represents the slope and s represents the intercept.

[0099] In some embodiments, since the proppant cannot completely fill the dynamic fracture, there is an equilibrium height of the proppant in the dynamic fracture. Below the equilibrium height, the proppant completely fills the proppant fracture, and the distribution of conductivity below the equilibrium height can be determined by the mapping relationship between the fracture width and the conductivity and the fracture width distribution result. Above the equilibrium height, there is no proppant, so there is no fluid conductivity, that is, the conductivity above the equilibrium height is 0. Since the equilibrium height of the proppant is related to the stabilization velocity of the proppant, the resistance velocity of migration, and the equilibrium flow rate, the equilibrium height of the proppant can be determined by determining the equilibrium flow rate of the proppant. The method for determining the equilibrium height will be combined with Figure 4 Provide a detailed introduction.

[0100] Figure 4 Shown is a flow chart of another method for determining reservoir fracture conductivity provided in an embodiment of the present application.

[0101] like Figure 4 As shown, in some embodiments, before step S103, that is, before determining the conductivity distribution of the target reservoir based on the fracture width distribution result and the predetermined mapping relationship between fracture width and conductivity, the method includes:

[0102] S104: Determine a target equilibrium flow rate of a proppant that props the fracture in the target reservoir.

[0103] In some embodiments, taking a certain point in a propped fracture as an example, the equilibrium flow rate of the proppant can be determined by calculating the settling velocity of the proppant. It can be understood that the settling velocity is related to the flow state, proppant concentration, fracture wall effect, and Reynolds number of the proppant, and the relationship can be shown in the following Table 1:

[0104] Table 1

[0105]

[0106] It can be understood that the above Table 1 represents the relationship between the Reynolds number, the resistance coefficient and the concentration correction coefficient. f It can express the volume fraction of liquid in the proppant, which is equivalent to the porosity and Reynolds number R ep =ρ f d p v p / μ,ρ p It can represent the true density of proppant particles; d p It can represent the proppant particle support; ρ f can represent the proppant density; g can represent the acceleration due to gravity.

[0107] Considering the influence of the artificial crack wall effect on the settlement velocity, the wall correction coefficient f w To make corrections, the wall correction coefficient can be calculated as follows:

[0108]

[0109] Wherein, w may represent the width of the supporting crack. It can be understood that, for 1<Rep≤100, the wall correction coefficient calculated by the above formula may be obtained by linear interpolation.

[0110] Further, the settling velocity of the proppant can be determined based on the wall correction factor calculated by the above formula, and the free settling velocity and concentration correction factor in Table 1. The settling velocity of the proppant can be determined by the following formula:

[0111] v t =f c f w v p Formula (7)

[0112] Among them, v t Indicates the settling velocity of the proppant.

[0113] In some embodiments, the relationship between the equilibrium flow rate, the resistance velocity, and the equilibrium height satisfies the following formula:

[0114]

[0115]

[0116] Among them, v EQ It can be expressed as the equilibrium flow rate of the proppant, h EQ It can represent the equilibrium height of the proppant, v WEQ It can represent the resistance velocity at equilibrium, q can represent the flow rate of the cross section, μ f Can represent the viscosity of liquid, R h Can represent the hydraulic radius.

[0117] In some embodiments, the relationship between the resistance velocity of proppant migration and the equilibrium flow rate satisfies the following formula:

[0118]

[0119] Among them, v EQ1 The equilibrium flow rate of the proppant representing laminar flow, v EQ2 The equilibrium velocity of the proppant representing turbulent flow, ρ sl represents the density of the sand mixing liquid, ρ f represents the density of the liquid, S represents the ratio of sand and gravel in the proppant, and φ represents the porosity of the sand pile.

[0120] It can be understood that the equilibrium flow rate of the propped fracture can be obtained by using the above formulas (6) to (10) and Table 1.

[0121] S105: Determine the equilibrium height of the target reservoir based on the mapping relationship between the equilibrium flow rate and the equilibrium height of the proppant and the target equilibrium flow rate.

[0122] In some embodiments, the balance signal may be determined by the following formula:

[0123]

[0124] Among them, H f Indicates the crack height of dynamic cracks, H EQ Indicates the equilibrium height of the propped crack.

[0125] S106: Determine that the conductivity of the propped fractures of the target reservoir above the equilibrium height is zero.

[0126] Further, in some embodiments, in step S103, determining the conductivity distribution of the target reservoir based on the fracture width distribution result and a predetermined mapping relationship between fracture width and conductivity includes:

[0127] Based on the fracture width distribution result and the mapping relationship between fracture width and conductivity, the conductivity distribution of the propped fractures of the target reservoir below the equilibrium height is determined.

[0128] The method for determining the conductivity of reservoir fractures provided in the embodiment of the present application determines the filtration coefficient of the fracturing fluid and the longitudinal cross-section seam width distribution at the seam mouth through the measured fracture data, and adopts the conductivity test experiment to simulate the mapping relationship between the seam width and the conductivity, so that the accuracy of the seam width distribution result and the mapping relationship between the seam width and the conductivity is higher. Then, based on the predetermined mapping relationship between the seam width and the conductivity and the seam width distribution result, the distribution results of the conductivity in the seam length and seam height directions are obtained. The embodiment of the present application fully integrates the three dimensions of the coring experiment, theoretical model calculation and indoor experimental test at the mine scale. The calculation process supports each other and is mutually premised. The calculation conductivity result is highly accurate, and it can achieve effective prediction of the distribution of artificial fracture conductivity from point to line and then to the surface at the mine scale, and obtain the distribution of conductivity in three-dimensional space, which can then support the optimization of the fracturing scheme design and the increase in production and efficiency of oil and gas wells after pressure.

[0129] The method for determining reservoir fracture conductivity provided in the embodiments of the present application is further introduced below in conjunction with specific embodiments.

[0130] In this embodiment, taking the tight gas Y3 well in a certain area of ​​the Sichuan Basin as an example, the method for determining the conductivity of energy storage fractures provided in the embodiment of the present application is used to predict the distribution result of the conductivity in the artificial fractures after horizontal well fracturing, which may specifically include the following steps:

[0131] S1. Well Y3 was selected for hydraulic fracturing. The horizontal wellbore trajectory of this well was perpendicular to the direction of the maximum horizontal principal stress. Wide-area electromagnetic monitoring was carried out at the same time. Relevant data were collected after the hydraulic fracturing, including engineering geological parameters (construction well section, Young's modulus E, Poisson's ratio v, shear modulus G, minimum horizontal principal stress Pσ), construction parameters (construction time t, construction displacement Q, fracturing fluid viscosity u). The collected data can be shown in Table 2 below:

[0132] Table 2

[0133]

[0134] S2. Drill a high-angle well within the range of 50 to 200 m from the horizontal section of the Y3 well to conduct conformal coring. Take out the core within the range of 50 to 200 m from the horizontal well. The coring length is L. The relative position relationship between the two wells is as follows: Figure 5 shown.

[0135] S3. The core column with a length of L is divided along the direction perpendicular to the core cross section, and an electron microscope is scanned along the section to obtain a core column section including dynamic fractures and partial support fractures.

[0136] S4. Mark the depth and number of dynamic cracks and propping cracks on the core column section. The number of dynamic cracks and propping cracks is represented by m and n, respectively, where m = 18 and n = 15; and record the depth vector Dm of the dynamic cracks and measure the width w of the dynamic cracks. m Get the dynamic seam width vector Wm.

[0137] S5. According to the relative positions of the wellbore trajectories of the highly deviated well and the horizontal well, the lateral distance L from each depth in the depth vector Dm to the horizontal wellbore is measured. m , and the longitudinal distance H m , and the dynamic seam length vector Lm and dynamic seam height vector Hm are obtained respectively.

[0138] S6. Assume that the longitudinal section of the artificial fracture in the formation is an ellipse, and the fracture height H f During the extension process, H f Equal to twice the maximum value of the dynamic seam height vector Hm, where H f =32.5m;

[0139] S7. Determine the relationship between the crack length and the crack height at any time (i.e., the formula (1) in the previous text), and the maximum dynamic crack length here is the maximum value in the dynamic crack length vector Lm. In this embodiment, the maximum dynamic crack length is L=173.6. The fracturing fluid loss coefficient ψ in this embodiment can be determined by formula (1) and the crack height and crack length to calibrate the fracturing fluid loss coefficient. Furthermore, based on the calibrated fracturing fluid loss coefficient, the mapping relationship between the crack width and the crack length can be obtained. This relationship can be as follows: Figure 6 It can be understood that as the crack length (i.e., crack length) increases, the crack width (i.e., crack width) gradually decreases.

[0140] S8, according to the fracturing fluid loss coefficient ψ obtained in step S8 = 0.0002 m / min 1 / 2 , the central crack width at the seam mouth after the fracturing construction is completed can be obtained, that is, the central crack width at the seam mouth is calculated by the formula (2) in the previous text. In this embodiment, the central width of the seam mouth at the end of the construction is calculated to be W=0.063m. According to the formula (3) in the previous text, the second seam width distribution on the longitudinal section of the crack at the seam mouth at the end of the construction can be obtained. The second seam width distribution calculated here can be used as the boundary constraint condition of the seam width distribution result.

[0141] S9, according to the dynamic crack width vector Wm, dynamic crack length vector Lm, and dynamic crack height vector Hm obtained from coring, they belong to different artificial cracks respectively. The crack width, crack height, and crack length of different cracks are projected onto the same crack by the projection method, so that the crack has the dynamic crack length, dynamic crack width, and dynamic crack height values ​​at multiple points. Then, according to the ellipse equation, the first crack width distribution on the crack section corresponding to each point can be calculated.

[0142] The second crack width distribution and the first crack width distribution are obtained in S10, step S8 and step S9 respectively, but they are not continuous. Therefore, the two-dimensional interpolation function in MATLAB can be used to interpolate the continuous crack width distribution results in the entire crack length direction according to the crack width distribution in step S8 and step S9, that is, the crack width distribution results of the supporting cracks.

[0143] S11. Assuming that the formation closure stress remains unchanged and the proppant filling degree of each propped fracture wall is the same, that is, the compaction strength of the proppant in the fracture is the same, collect the proppant on each propped fracture wall and weigh it to obtain the proppant mass set M. According to the core diameter and the proppant mass on the proppant fracture wall, the proppant surface density set ρ can be obtained.

[0144] S12. Use an indoor conductivity tester to measure the conductivity of the propped fracture. The length, width, and height of the diversion chamber are l, w, and h, respectively. W is the proppant filling thickness, which is the width of the propped fracture. The mass of the proppant required to be filled at each proppant width is obtained by the cross-sectional area of ​​the diversion chamber and the proppant surface density. Then, the conductivity value at each width can be obtained by using the formula (4) in the previous text. Based on the width and its corresponding conductivity, the formula (5) in the previous text, i.e., the mapping relationship between the fracture width and the conductivity, can be obtained.

[0145] In this embodiment, the mapping relationship between the simulated slit width and the flow conductivity can be expressed as follows: Figure 7 shown. Figure 7 The horizontal axis represents the width of the supporting crack (i.e., the width of the supporting crack), and the vertical axis represents the conductivity. The k in formula (5) obtained by simulation is 3.8396, and s is 1.771.

[0146] S13. Based on Table 1 and formulas (6) to (10) in step S104 above, the equilibrium flow velocity of the propped fracture can be calculated. In the specific calculation, the sand-carrying liquid mixture is calculated according to the turbulent state, and the results are 2.13 m / s and 0.21 m / s respectively. At this time, the correctness of the flow state needs to be further verified. The Reynolds number Rep=16324>3000 is calculated, and the flow state satisfies, so the equilibrium flow velocity of 2.13 m / s is correct.

[0147] S14. After obtaining the equilibrium flow velocity, the equilibrium height can be obtained by using the formula (11) in the previous text, and the equilibrium height H of a certain point in the support crack can be calculated. EQ =22.5m.

[0148] S15, the equilibrium height of a certain point in the artificial fracture is calculated through step S13 and step S14, and the equilibrium height of the entire propped fracture can be obtained by using this method. At the same time, there is no proppant filling above the equilibrium height, so the conductivity is 0D·cm, and below the equilibrium height, the linear relationship between the fracture width and the conductivity obtained in step S12 and the fracture width distribution result obtained in step S10 can be used to obtain the conductivity values ​​at different positions, thereby obtaining the conductivity distribution of the propped fracture.

[0149] In this embodiment, the flow conductivity distribution obtained based on the above steps S1 to S15 can be as follows: Figure 8 As shown in the figure, different gray values ​​can represent the conductivity values ​​corresponding to the fracture height and fracture length. The horizontal axis represents half the fracture length of the supporting fracture, and the vertical axis represents the fracture height of the supporting fracture.

[0150] The embodiment of the present application also provides a device for determining the conductivity of reservoir fractures. Fig. 9 FIG. 1 is a schematic diagram of a program module of a device for determining reservoir fracture conductivity provided in an embodiment of the present application. Fig. 9 As shown, the device 900 for determining reservoir fracture conductivity may include:

[0151] The data acquisition module 901 is used to acquire fracture data of the target reservoir.

[0152] The fracture width determination module 902 is used to determine the fracture width distribution result of the propped fracture in the target reservoir based on the fracture data, wherein the fracture width distribution result includes the continuous distribution result of the fracture width of the propped fracture along the fracture length and fracture height direction of the propped fracture.

[0153] The conductivity determination module 903 is used to determine the conductivity distribution of the target reservoir based on the fracture width distribution result and the mapping relationship between the fracture width and the conductivity, wherein the mapping relationship between the fracture width and the conductivity is determined by simulating the fracture width data of the propped fractures and the conductivity data of the propped fractures obtained through experiments, and the conductivity distribution characterizes the distribution of the conductivity of the propped fractures of the target reservoir along the fracture length and fracture height directions of the propped fractures.

[0154] The description and functions of the above-mentioned units can be understood by referring to the content of the method for determining the conductivity of reservoir fractures, and will not be repeated here.

[0155] The present specification also provides a computer storage medium, wherein the computer storage medium stores computer program instructions, and when the computer program instructions are executed, the steps of the method for determining reservoir fracture conductivity are implemented.

[0156] The present specification also provides a computer program product, comprising a computer program, wherein when the computer program is executed by a processor, the steps of the method for determining the reservoir fracture conductivity are implemented.

[0157] The embodiment of the present invention further provides an electronic device, such as Fig.10 As shown, the electronic device may include a processor 1001 and a memory 1002, wherein the processor 1001 and the memory 1002 may be connected via a bus or other means. Fig.10 The example of connecting through bus is taken in the following.

[0158] The processor 1001 may be a central processing unit (CPU). The processor 1001 may also be other general-purpose processors, digital signal processors (DSP), application-specific integrated circuits (ASIC), field-programmable gate arrays (FPGA) or other programmable logic devices, discrete gate or transistor logic devices, discrete hardware components, or a combination of the above chips.

[0159] The memory 1002 is a non-transitory computer-readable storage medium that can be used to store non-transitory software programs, non-transitory computer executable programs and modules, such as program instructions / modules corresponding to the method for determining reservoir fracture conductivity in an embodiment of the present invention (for example, Fig. 9 The processor 1001 executes various functional applications and data processing of the processor by running the non-transient software programs, instructions and modules stored in the memory 1002, that is, the method for determining the reservoir fracture conductivity in the above method embodiment is implemented.

[0160] The memory 1002 may include a program storage area and a data storage area, wherein the program storage area may store an operating system, an application required by at least one function; the data storage area may store data created by the processor 1001, etc. In addition, the memory 1002 may include a high-speed random access memory, and may also include a non-volatile memory, such as at least one disk storage device, a flash memory device, or other non-volatile solid-state storage device. In some embodiments, the memory 1002 may optionally include a memory remotely arranged relative to the processor 1001, and these remote memories may be connected to the processor 1001 via a network. Examples of the above-mentioned network include, but are not limited to, the Internet, an intranet, a local area network, a mobile communication network, and combinations thereof.

[0161] The one or more modules are stored in the memory 1002, and when executed by the processor 1001, the following is performed: Figure 1 The method for determining reservoir fracture conductivity in the illustrated embodiment.

[0162] The specific details of the above electronic device can be understood by referring to the corresponding descriptions and effects in the above method embodiments, and will not be repeated here.

[0163] The present specification also provides a computer storage medium, wherein the computer storage medium stores computer program instructions, and when the computer program instructions are executed, the steps of the method for determining reservoir fracture conductivity are implemented.

[0164] The present specification also provides a computer program product, comprising a computer program, wherein when the computer program is executed by a processor, the steps of the method for determining the reservoir fracture conductivity are implemented.

[0165] Those skilled in the art can understand that all or part of the processes in the above-mentioned embodiments can be implemented by instructing the relevant hardware through a computer program, and the program can be stored in a computer-readable storage medium, and when the program is executed, it can include the processes of the embodiments of the above-mentioned methods. Among them, the storage medium can be a disk, an optical disk, a read-only memory (ROM), a random access memory (RAM), a flash memory, a hard disk drive (HDD) or a solid-state drive (SSD), etc.; the storage medium can also include a combination of the above-mentioned types of memory.

[0166] Each embodiment in this specification is described in a progressive manner, and the same or similar parts between the various embodiments can be referenced to each other, and each embodiment focuses on the differences from other embodiments.

[0167] The systems, devices, modules or units described in the above embodiments may be implemented by computer chips or entities, or by products with certain functions.

[0168] For the convenience of description, the above device is described in various units according to their functions. Of course, when implementing the present application, the functions of each unit can be implemented in the same or multiple software and / or hardware.

[0169] It can be known from the description of the above implementation methods that those skilled in the art can clearly understand that the present application can be implemented by means of software plus a necessary general hardware platform. Based on such an understanding, the technical solution of the present application can be essentially or partly contributed to the prior art in the form of a software product, which can be stored in a storage medium such as ROM / RAM, a magnetic disk, an optical disk, etc., and includes several instructions for enabling a computer device (which can be a personal computer, a server, or a network device, etc.) to execute certain parts of the methods of each implementation method of the present application.

[0170] The present application can be used in many general or special computer system environments or configurations, such as personal computers, server computers, handheld or portable devices, tablet devices, multiprocessor systems, microprocessor-based systems, set-top boxes, programmable consumer electronic devices, network PCs, minicomputers, mainframe computers, distributed computing environments including any of the above systems or devices, etc.

[0171] The present application may be described in the general context of computer-executable instructions executed by a computer, such as program modules. Generally, program modules include routines, programs, objects, components, data structures, etc. that perform specific tasks or implement specific abstract data types. The present application may also be practiced in distributed computing environments where tasks are performed by remote processing devices connected through a communication network. In a distributed computing environment, program modules may be located in local and remote computer storage media, including storage devices.

[0172] Although the present application has been described through embodiments, those skilled in the art will appreciate that there are many modifications and variations to the present application without departing from the spirit of the present application, and it is intended that the appended claims include these modifications and variations without departing from the spirit of the present application.

Claims

1. A method for determining reservoir fracture conductivity, characterized in that: include: Acquire fracture data of target reservoir; Based on the fracture data, determining a fracture width distribution result of the propped fracture in the target reservoir, wherein the fracture width distribution result includes a continuous distribution result of the fracture width of the propped fracture along the fracture length and fracture height directions of the propped fracture; Based on the fracture width distribution result and a predetermined mapping relationship between fracture width and conductivity, the conductivity distribution of the target reservoir is determined, wherein the conductivity distribution characterizes the distribution of the conductivity of the propped fractures of the target reservoir along the fracture length and fracture height directions of the propped fractures.

2. The method according to claim 1, characterized in that Obtain fracture data of target reservoir, including: Obtain core column profile of target reservoir; The fracture data of the dynamic fractures of the core column section are collected, wherein the fracture data include fracture length data, fracture width data and fracture height data.

3. The method according to claim 2, characterized in that Determining the fracture width distribution result of the propped fractures in the target reservoir based on the fracture data includes: Determining the filtration coefficient of the fracturing fluid in the dynamic fractures of the target reservoir based on the fracture length data and fracture height data of the dynamic fractures; The fracture width distribution result is determined based on the fracture height data, the fracture length data, the fracture width data and the filtration coefficient.

4. The method according to claim 3, characterized in that The filtration coefficient is determined by the following formula: Where L represents the half-length of the dynamic fracture, q represents the flow rate of the fracturing fluid, G represents the shear modulus of the target reservoir, ν represents the Poisson's ratio of the target reservoir, and H f It represents the height of dynamic fracture, μ represents the viscosity of fracturing fluid, and ψ represents the filtration coefficient of fracturing fluid.

5. The method according to claim 3, characterized in that: Determining the fracture width distribution result based on the fracture height data, the fracture length data, the fracture width data and the filtration coefficient includes: Determine a first fracture width distribution of the dynamic fracture of the target reservoir along the fracture height direction and the fracture length direction based on the fracture height data, the fracture length data, the fracture width data, a mapping relationship between the fracture length in the dynamic fracture of the target reservoir and the fracture height, and a mapping relationship between the fracture width and the fracture length of the dynamic fracture of the target reservoir; Based on the mapping relationship between the filtration coefficient, the fracture width and the fracture height, and the mapping relationship between the fracture width and the fracturing time, determining a second fracture width distribution of the longitudinal section of the fracture at the fracture opening of the target reservoir; The slit width distribution result is determined based on the first slit width distribution and the second slit width distribution.

6. The method according to claim 4, characterized in that The second slit width distribution data is determined by the following formula: Where W(0,t) represents the central width of the fracture mouth when the time of fracturing construction is t, t represents the time of fracturing construction, q represents the flow rate of fracturing fluid, G represents the shear modulus of the target reservoir, ν represents the Poisson's ratio of the target reservoir, and H f represents the fracture height of dynamic fractures, μ represents the viscosity of fracturing fluid, ψ represents the filtration coefficient of fracturing fluid, w represents the fracture width on the fracture longitudinal section at the fracture mouth of target reservoir, x represents the fracture horizontal coordinate on the fracture longitudinal section with the fracture center as the origin, and y represents the fracture vertical coordinate on the fracture longitudinal section with the fracture center as the origin.

7. The method according to claim 1, characterized in that Before determining the conductivity distribution of the target reservoir based on the fracture width distribution result and the predetermined mapping relationship between the fracture width and the conductivity, the method includes: determining a target equilibrium flow rate of a proppant that props a fracture in the target reservoir; Determining the equilibrium height of the target reservoir based on the mapping relationship between the equilibrium flow rate and the equilibrium height of the proppant and the target equilibrium flow rate; It is determined that the conductivity of the propped fractures of the target reservoir above the equilibrium height is zero.

8. A device for determining reservoir fracture conductivity, characterized in that: include: A data acquisition module, used to acquire fracture data of a target reservoir; A fracture width determination module, configured to determine a fracture width distribution result of the propped fracture in the target reservoir based on the fracture data, wherein the fracture width distribution result includes a continuous distribution result of the fracture width of the propped fracture along the fracture length and fracture height directions of the propped fracture; The conductivity determination module is used to determine the conductivity distribution of the target reservoir based on the fracture width distribution result and a predetermined mapping relationship between the fracture width and the conductivity, wherein the conductivity distribution characterizes the distribution of the conductivity of the propped fracture of the target reservoir along the fracture length and fracture height direction of the propped fracture.

9. An electronic device, characterized in that: include: A memory and a processor, wherein the processor and the memory are communicatively connected to each other, the memory stores computer instructions, and the processor implements the steps of the method according to any one of claims 1 to 7 by executing the computer instructions.

10. A computer storage medium, characterized in that: The computer storage medium stores computer program instructions, and when the computer program instructions are executed, the steps of the method according to any one of claims 1 to 7 are implemented.

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