Method and system for determining plane heterogeneity of tight sandstone reservoir and storage medium

Abstract

The invention discloses a tight sandstone reservoir plane heterogeneity determination method and system and a storage medium, and belongs to the technical field of reservoir plane heterogeneity measurement. The characterization of the hole permeability parameters of the horizontal well and the adjacent vertical well is carried out, and the variation coefficient of the parameters is utilized to describe the plane heterogeneity characteristics of the reservoir, so that the limitation of describing the plane heterogeneity by a single parameter is reduced. According to the peak value in the statistical histogram of the interval transit time of the vertical well and the horizontal well, the anisotropy correction coefficient of the horizontal well is determined, and then the porosity and permeability of the horizontal well subjected to anisotropy correction are calculated. According to the method, the constraint of the horizontal well is considered, and the plane heterogeneity of the tight sandstone reservoir can be accurately reflected through the porosity and permeability of the horizontal well at each well depth position in the horizontal well section of the target reservoir and the porosity and permeability of the adjacent vertical well of the horizontal well at each well depth position in the well section of the target reservoir.

Description

Technical Field

[0001] The present invention belongs to the technical field of reservoir plane heterogeneity measurement, and in particular relates to a method, system and storage medium for determining the plane heterogeneity of a tight sandstone reservoir. Background Art

[0002] Reservoir heterogeneity refers to the uneven changes in the spatial distribution and properties (such as lithology, physical properties, oil content) and microscopic pore structure of the reservoir in a certain sedimentary environment in three-dimensional space. The plane heterogeneity of the reservoir refers to the heterogeneity caused by the uneven spatial distribution of parameters such as the geometry, size, continuity and porosity and permeability of a single reservoir sand body; horizontal wells have the characteristics of continuously recording information such as physical properties and oil content through the formation, and can continuously reflect the heterogeneous change characteristics of reservoir parameters in the plane. For tight sandstone reservoirs, describing the heterogeneity of the reservoir has a great guiding significance for well site deployment and development plan optimization. Therefore, it is necessary to carry out research on the evaluation of planar reservoir heterogeneity.

[0003] In recent years, there have been many methods for evaluating reservoir heterogeneity, which can be roughly divided into two categories: one is a method for characterizing the heterogeneity of super-heterogeneous oil and gas reservoirs (CN 110242291 B). Liu Jinhua, Ge Zhengjun et al. (2019) processed the permeability data into a normal distribution based on the permeability slippage analysis, and optimized multiple parameters. The entropy weight mathematical algorithm was used to calculate the heterogeneity comprehensive index, thereby quantitatively describing the planar heterogeneity of the reservoir. This method only considers the use of vertical well data to evaluate reservoir heterogeneity based on data such as porosity and permeability variation coefficient, and does not consider the constraints of horizontal well strike on heterogeneity; the second type is a reservoir heterogeneity characterization method under a horizontal well regular development well network (CN105651676B). Zhang Xianguo, Zhang Tao, et al. (2018) proposed a three-dimensional formation model of the target layer based on the comprehensive use of well logging and three-dimensional seismic data. The model was used to simulate the permeability curve of the wellhead area of ​​the horizontal well, and finally the heterogeneity parameters were calculated in combination with the permeability curve of the vertical well. The heterogeneity evaluation of this patent still relies on the vertical well data at the wellhead of each well, and does not consider the length, orientation and heterogeneity changes of the encountered formations of the horizontal well section. The evaluation results are greatly affected by the abnormal permeability values. Summary of the invention

[0004] In order to overcome the shortcomings of the above-mentioned prior art, the purpose of the present invention is to provide a method, system and storage medium for determining the planar heterogeneity of a tight sandstone reservoir, which is used to solve technical problems such as the existing method does not consider the constraints of the horizontal well strike on the heterogeneity and the evaluation results are greatly affected by the abnormal permeability values.

[0005] In order to achieve the above object, the present invention adopts the following technical solutions:

[0006] The present invention discloses a method for determining the plane heterogeneity of a tight sandstone reservoir, comprising the following steps:

[0007] S1: Obtain the porosity and permeability at each well depth in the horizontal well section of the horizontal well in the target reservoir, and the porosity and permeability at each well depth in the well section of the horizontal well adjacent to the vertical well in the target reservoir; then calculate the reservoir physical property parameters at each well depth in the horizontal well section of the target reservoir and the reservoir physical property parameters at each well depth in the well section of the horizontal well adjacent to the vertical well in the target reservoir according to the determined porosity and permeability at each well depth;

[0008] S2: Segmenting the horizontal well section of each horizontal well located in the target reservoir, and determining the variance of the reservoir physical property parameters of each section of the horizontal well section of each horizontal well located in the target reservoir based on the reservoir physical property parameters at each well depth in the horizontal well section of each horizontal well located in the target reservoir;

[0009] S3: based on the reservoir physical property parameters at each well depth in the well section of each vertical well located in the target reservoir, respectively determine the variance of the reservoir physical property parameters of the well section of each vertical well located in the target reservoir;

[0010] S4: Based on the variance of the reservoir physical property parameters of each section of the horizontal well section of each horizontal well located in the target reservoir and the variance of the reservoir physical property parameters of the section of the adjacent vertical well of each horizontal well located in the target reservoir, a plane contour map of the variance of the reservoir physical property parameters is determined, thereby determining the plane heterogeneity of the target reservoir.

[0011] Further, in S1, the process of obtaining the porosity and permeability at each well depth in the horizontal well section of the horizontal well located in the target reservoir, and the porosity and permeability at each well depth in the well section of the adjacent vertical well of the horizontal well located in the target reservoir, includes the following steps:

[0012] S11: Acquire well logging data of a horizontal well section of a horizontal well located in a target reservoir and well logging data of a well section of a vertical well adjacent to the horizontal well located in the target reservoir;

[0013] S12: Based on the logging data of the horizontal well section of the horizontal well located in the target reservoir and the logging data of the well section of the horizontal well adjacent to the vertical well located in the target reservoir, determine the porosity and permeability at each well depth in the horizontal well section of the horizontal well located in the target reservoir and the porosity and permeability at each well depth in the well section of the horizontal well adjacent to the vertical well located in the target reservoir.

[0014] Further, based on the well logging data of the horizontal well section of the horizontal well located in the target reservoir and the well logging data of the well section of the horizontal well adjacent to the vertical well located in the target reservoir, the process of determining the porosity and permeability at each well depth in the horizontal well section of the horizontal well located in the target reservoir and the porosity and permeability at each well depth in the well section of the horizontal well adjacent to the vertical well located in the target reservoir comprises the following steps:

[0015] S121: Obtaining the actual measured acoustic time difference curve of the horizontal well section of each horizontal well located in the target reservoir; performing frequency statistics of different acoustic time difference values ​​on the actual measured acoustic time difference curve of the horizontal well section of each horizontal well located in the target reservoir to obtain a first acoustic time difference frequency statistical histogram; and then obtaining the acoustic time difference corresponding to the highest frequency in the first acoustic time difference frequency statistical histogram as the acoustic time difference of the horizontal well section of the target reservoir;

[0016] Step S122: obtaining the actual measured acoustic time difference curves of the well sections of each adjacent vertical well of each horizontal well located in the target reservoir; performing frequency statistics of different acoustic time difference values ​​on the actual measured acoustic time difference curves of the well sections of each adjacent vertical well of each horizontal well located in the target reservoir to obtain a second acoustic time difference frequency statistical histogram; and then obtaining the acoustic time difference corresponding to the highest frequency in the second acoustic time difference frequency statistical histogram as the acoustic time difference of the vertical well section of the target reservoir;

[0017] Step S123:

[0018] Based on the acoustic time difference of the horizontal well section of the target reservoir and the acoustic time difference of the vertical well section of the target reservoir, the acoustic time difference anisotropy coefficient of the horizontal well section of the target reservoir is determined; wherein the acoustic time difference anisotropy coefficient of the horizontal well section of the target reservoir is determined by the following formula:

[0019] λΔt=Δtv÷Δth;

[0020] Among them, λΔt is the acoustic time difference anisotropy coefficient of the horizontal well section of the target reservoir; Δth is the acoustic time difference of the horizontal well section of the target reservoir, μs / m; Δtv is the acoustic time difference of the vertical well section of the target reservoir, μs / m;

[0021] Step S124:

[0022] The actual measured acoustic time difference curve of the horizontal well section of each horizontal well located in the target reservoir is corrected by using the acoustic time difference anisotropy coefficient of the horizontal well section of the target reservoir; wherein the correction is performed by the following formula:

[0023] Δtc=λΔt×Δth;

[0024] Among them, λΔt is the acoustic time difference anisotropy coefficient of the horizontal well section of the target reservoir; Δtc is the corrected acoustic time difference of the horizontal well section of a horizontal well located in the target reservoir, μs / m; Δth is the actual measured acoustic time difference of the horizontal well section of the horizontal well located in the target reservoir, μs / m;

[0025] Step S125: Based on the corrected acoustic time difference of the horizontal well section of each horizontal well located in the target reservoir and the actually measured acoustic time difference curve of the well section of each adjacent vertical well of each horizontal well located in the target reservoir, the core calibration logging method is used to respectively determine the porosity at each well depth position in the horizontal well section of each horizontal well located in the target reservoir and the porosity at each well depth position in the well section of the adjacent vertical well of each horizontal well located in the target reservoir;

[0026] Step S126: Based on the porosity of each horizontal well at each well depth in the horizontal well section of the target reservoir and the porosity of each horizontal well's adjacent vertical well in the target reservoir, the core calibration logging method is used to determine the permeability of each horizontal well at each well depth in the horizontal well section of the target reservoir and the permeability of each horizontal well's adjacent vertical well in the target reservoir.

[0027] Furthermore, in S1,

[0028] Furthermore, in S2, the variance of the reservoir physical property parameters of each section of the horizontal well section of each horizontal well located in the target reservoir is determined by the following formula:

[0029]

[0030] Among them, σ z is the variance of the reservoir physical property parameter of a certain section in the horizontal well section of the target reservoir of a horizontal well; z(i) is the i-th reservoir physical property parameter value of the section in the horizontal well section of the target reservoir of the horizontal well; n is the total number of reservoir physical property parameter values ​​of the section in the horizontal well section of the target reservoir of the horizontal well, and its value is determined by the porosity and permeability interval and the length of the section; is the average value of each reservoir physical property parameter of the horizontal well section of the target reservoir of the horizontal well;

[0031] Said

[0032] Among them, Δl is the length of the segment; h i Divided into porosity and permeability value intervals.

[0033] Further, in S2, segmenting the horizontal well section of each horizontal well located in the target reservoir is achieved by:

[0034] The horizontal well section of each horizontal well located in the target reservoir is segmented according to a well depth of 400 m.

[0035] Further, in S3, the variance of the reservoir physical property parameters of each vertical well located in the target reservoir is determined by the following formula:

[0036]

[0037] Among them, σ z1 is the variance of the reservoir physical property parameter of the well section of a vertical well located in the target reservoir; Z(I) is the Ith reservoir physical property parameter value of the well section of the vertical well located in the target reservoir; N is the total number of reservoir physical property parameter values ​​of the well section of the vertical well located in the target reservoir; is the average value of each reservoir physical property parameter value of the well section of the vertical well located in the target reservoir;

[0038] The value of N is determined by the porosity, permeability interval and the effective thickness of the target reservoir;

[0039] Δh is the effective thickness of the target reservoir, and Δh is the porosity and permeability value interval.

[0040] Further, in S4, the planar heterogeneity of the target reservoir is determined according to the following criteria:

[0041] When the variance of reservoir physical property parameters is less than 1.6, the plane heterogeneity is weak;

[0042] When the variance of reservoir physical property parameters is 1.6 to 2.4, the plane heterogeneity is moderate;

[0043] When the variance of reservoir physical property parameters is greater than 2.4, the plane heterogeneity is strong.

[0044] The present invention also discloses a system for determining plane heterogeneity of a tight sandstone reservoir, comprising a reservoir physical property parameter determination module, a first variance determination module, a second variance determination module and a plane heterogeneity determination module;

[0045] The reservoir physical property parameter determination module is used to obtain the porosity and permeability at each well depth in the horizontal well section of the horizontal well located in the target reservoir and the porosity and permeability at each well depth in the well section of the horizontal well adjacent to the vertical well located in the target reservoir; further, determine the reservoir physical property parameters at each well depth in the horizontal well section of the horizontal well located in the target reservoir and the reservoir physical property parameters at each well depth in the well section of the horizontal well adjacent to the vertical well located in the target reservoir;

[0046] The first variance determination module is used to segment the horizontal well section of each horizontal well located in the target reservoir, and determine the variance of the reservoir physical property parameters of each section of the horizontal well section of each horizontal well located in the target reservoir based on the reservoir physical property parameters of each well depth position in the horizontal well section of each horizontal well located in the target reservoir; the second variance determination module is used to determine the variance of the reservoir physical property parameters of each section of the vertical well located in the target reservoir based on the reservoir physical property parameters of each well depth position in the section of each vertical well located in the target reservoir;

[0047] The planar heterogeneity determination module is used to determine the planar contour map of the variance of the reservoir physical property parameters based on the variance of the reservoir physical property parameters of each section of the horizontal well section of each horizontal well located in the target reservoir and the variance of the reservoir physical property parameters of the well section of each vertical well located in the target reservoir, thereby determining the planar heterogeneity of the target reservoir.

[0048] The present invention also discloses a computer-readable storage medium, on which instructions are stored. When the instructions are executed by a processor, the steps of any one of the methods described in claim 1 to claim 8 are implemented.

[0049] Compared with the prior art, the present invention has the following beneficial effects:

[0050] The present invention discloses a method for determining the plane heterogeneity of a tight sandstone reservoir under the constraint of a horizontal well. By carrying out the characterization of the porosity and permeability parameters of the horizontal well and the adjacent vertical well, the coefficient of variation of the parameter is used to characterize the plane heterogeneity characteristics of the reservoir, thereby reducing the limitation of describing the plane heterogeneity with a single parameter. According to the peak value in the statistical histogram of the acoustic time difference between the vertical well and the horizontal well, the anisotropy correction coefficient of the horizontal well is determined, and then the porosity and permeability of the horizontal well after anisotropy correction are calculated. Combined with the standard deviation σ Z of the porosity and permeability parameters in the vertical well and the horizontal section in the horizontal well, a plane contour map is drawn to divide the plane heterogeneity of the tight sandstone reservoir; the method takes into account the constraint of the horizontal well, and can accurately reflect the plane heterogeneity of the tight sandstone reservoir through the porosity and permeability at each well depth in the horizontal well section of the horizontal well located in the target reservoir and the porosity and permeability at each well depth in the well section of the adjacent vertical well located in the target reservoir of the horizontal well. BRIEF DESCRIPTION OF THE DRAWINGS

[0051] Figure 1 A flowchart of the method disclosed in the present invention;

[0052] Figure 2 The acoustic time difference frequency statistical histogram of the horizontal well section of the target reservoir;

[0053] Figure 3 The acoustic time difference frequency statistical histogram of the vertical well section of the target reservoir;

[0054] Figure 4 Schematic diagram of the heterogeneity of the target reservoir of Well A;

[0055] Figure 5 Schematic diagram of the heterogeneity of the target reservoir of Well B;

[0056] Figure 6 is the variance σ of the reservoir physical property parameter Z of 79 vertical wells and 7 horizontal wells in the target reservoir Z Plane contour map of . DETAILED DESCRIPTION

[0057] In order to enable those skilled in the art to better understand the scheme of the present invention, the technical scheme in the embodiments of the present invention will be clearly and completely described below in conjunction with the drawings in the embodiments of the present invention. Obviously, the described embodiments are only part of the embodiments of the present invention, not all of the embodiments. Based on the embodiments of the present invention, all other embodiments obtained by ordinary technicians in this field without creative work should fall within the scope of protection of the present invention.

[0058] The present invention discloses a method for determining the plane heterogeneity of a tight sandstone reservoir. Figure 1 As shown, the method comprises the following steps:

[0059] Step S1: Obtain the porosity and permeability of each well depth (measured well depth) in the horizontal well section of the horizontal well in the target reservoir and the porosity and permeability of each well depth (measured well depth) in the well section of the horizontal well adjacent to the vertical well in the target reservoir; then, determine the reservoir physical property parameters at each well depth in the horizontal well section of the target reservoir and the reservoir physical property parameters at each well depth in the well section of the horizontal well adjacent to the vertical well in the target reservoir; wherein,

[0060] Step S2: segmenting the horizontal well section of each horizontal well located in the target reservoir, and determining the variance of the reservoir physical property parameters of each section of the horizontal well section of each horizontal well located in the target reservoir based on the reservoir physical property parameters at each well depth in the horizontal well section of each horizontal well located in the target reservoir;

[0061] Step S3: based on the reservoir physical property parameters at each well depth in the well section of each vertical well located in the target reservoir, respectively determine the variance of the reservoir physical property parameters of the well section of each vertical well located in the target reservoir;

[0062] Step S4: Based on the variance of the reservoir physical property parameters of each section of the horizontal well section of each horizontal well located in the target reservoir and the variance of the reservoir physical property parameters of the well section of each vertical well located in the target reservoir, a planar contour map of the variance of the reservoir physical property parameters is determined, thereby determining the planar heterogeneity of the target reservoir.

[0063] Further, in step S1, obtaining the porosity and permeability at each well depth (measured well depth) in a horizontal well section of a horizontal well located in a target reservoir and the porosity and permeability at each well depth (measured well depth) in a well section of a vertical well adjacent to the horizontal well located in the target reservoir includes:

[0064] Step S11: acquiring well logging data of a horizontal well section of a horizontal well located in a target reservoir and well logging data of a well section of a vertical well adjacent to the horizontal well located in the target reservoir;

[0065] Among them, well logging data can be collected using well logging instruments;

[0066] Step S12: determining the porosity and permeability at each well depth in the horizontal well section of the horizontal well located in the target reservoir and the porosity and permeability at each well depth in the well section of the horizontal well adjacent to the vertical well located in the target reservoir based on the well logging data of the horizontal well in the horizontal well section and the well logging data of the horizontal well adjacent to the vertical well located in the target reservoir;

[0067] Among them, the porosity data and permeability data can be obtained by, but not limited to, processing the well logging data in an existing manner;

[0068] Furthermore, in step S12, based on the well logging data of the horizontal well section of the horizontal well located in the target reservoir and the well logging data of the well section of the adjacent vertical well of the horizontal well located in the target reservoir, determining the porosity and permeability at each well depth in the horizontal well section of the horizontal well located in the target reservoir and the porosity and permeability at each well depth in the well section of the adjacent vertical well of the horizontal well located in the target reservoir includes:

[0069] Step S121: obtaining the actual measured acoustic time difference curve of the horizontal well section of each horizontal well located in the target reservoir; performing frequency statistics of different acoustic time difference values ​​on the actual measured acoustic time difference curve of the horizontal well section of each horizontal well located in the target reservoir to obtain a first acoustic time difference frequency statistical histogram; and then obtaining the acoustic time difference corresponding to the highest frequency in the first acoustic time difference frequency statistical histogram as the acoustic time difference of the horizontal well section of the target reservoir;

[0070] Step S122: obtaining the actual measured acoustic time difference curves of the well sections of each adjacent vertical well of each horizontal well located in the target reservoir; performing frequency statistics of different acoustic time difference values ​​on the actual measured acoustic time difference curves of the well sections of each adjacent vertical well of each horizontal well located in the target reservoir to obtain a second acoustic time difference frequency statistical histogram; and then obtaining the acoustic time difference corresponding to the highest frequency in the second acoustic time difference frequency statistical histogram as the acoustic time difference of the vertical well section of the target reservoir;

[0071] Step S123:

[0072] Based on the acoustic time difference of the horizontal well section of the target reservoir and the acoustic time difference of the vertical well section of the target reservoir, the acoustic time difference anisotropy coefficient of the horizontal well section of the target reservoir is determined; wherein the acoustic time difference anisotropy coefficient of the horizontal well section of the target reservoir is determined by the following formula:

[0073] λΔt=Δtv÷Δth;

[0074] Among them, λΔt is the acoustic time difference anisotropy coefficient of the horizontal well section of the target reservoir; Δth is the acoustic time difference of the horizontal well section of the target reservoir, μs / m; Δtv is the acoustic time difference of the vertical well section of the target reservoir, μs / m;

[0075] Step S124:

[0076] The actual measured acoustic time difference curve of the horizontal well section of each horizontal well located in the target reservoir is corrected by using the acoustic time difference anisotropy coefficient of the horizontal well section of the target reservoir; wherein the correction is performed by the following formula:

[0077] Δtc=λΔt×Δth;

[0078] Among them, λΔt is the acoustic time difference anisotropy coefficient of the horizontal well section of the target reservoir; Δtc is the corrected acoustic time difference of the horizontal well section of a horizontal well located in the target reservoir, μs / m; Δth is the actual measured acoustic time difference of the horizontal well section of the horizontal well located in the target reservoir, μs / m;

[0079] Step S125: Based on the corrected acoustic time difference of the horizontal well section of each horizontal well located in the target reservoir and the actually measured acoustic time difference curve of the well section of each adjacent vertical well of each horizontal well located in the target reservoir, the core calibration logging method is used to respectively determine the porosity at each well depth position in the horizontal well section of each horizontal well located in the target reservoir and the porosity at each well depth position in the well section of the adjacent vertical well of each horizontal well located in the target reservoir;

[0080] Step S126: Based on the porosity of each horizontal well at each well depth in the horizontal well section of the target reservoir and the porosity of each horizontal well's adjacent vertical well in the target reservoir, the core calibration logging method is used to determine the permeability of each horizontal well at each well depth in the horizontal well section of the target reservoir and the permeability of each horizontal well's adjacent vertical well in the target reservoir.

[0081] Furthermore, in step S2, the variance of the reservoir physical property parameters of each section of the horizontal well section of each horizontal well located in the target reservoir is determined by the following formula:

[0082]

[0083] Among them, σ z is the variance of the reservoir physical property parameters of a certain section in the horizontal well section of a horizontal well in the target reservoir; z(i) is the i-th reservoir physical property parameter value of the section in the horizontal well section of the horizontal well in the target reservoir; n is the total number of reservoir physical property parameter values ​​of the section in the horizontal well section of the horizontal well in the target reservoir, and its value is determined by the porosity and permeability value interval and the length of the section. In a specific embodiment, n=ΔI / h_ i (ΔI is the length of the segment, h_ i is the porosity and permeability value interval. When the porosity and permeability are determined using the logging curve, h_ i is the value interval of the logging curve); It is the average value of each reservoir physical property parameter in the horizontal well section of the target reservoir of the horizontal well.

[0084] Furthermore, in step S2, segmenting the horizontal well section of each horizontal well located in the target reservoir is achieved by:

[0085] The horizontal well section of each horizontal well located in the target reservoir is segmented according to a well depth of 400 m (measured well depth);

[0086] In a specific embodiment, (a) according to the well depth (measured well depth) from shallow to deep, the root end of the horizontal well section of the horizontal well located in the target reservoir is used as the starting point to the position where the well depth increases by 400m as the first section of the horizontal well section of the horizontal well located in the target reservoir; (b) the end point of the first section is used as the starting point of the second section to the position where the well depth increases by 400m as the second section of the horizontal well section of the horizontal well located in the target reservoir, and so on (the end point of the i-th section is used as the starting point of the i+1-th section to the position where the well depth increases by 400m as the i+1-th section of the horizontal well section of the horizontal well located in the target reservoir); (c) when the depth of the remaining well section is less than 400m, the remaining well section is used as the last section of the horizontal well section of the horizontal well located in the target reservoir.

[0087] Furthermore, in step S3, the variance of the reservoir physical property parameters of each vertical well located in the target reservoir is determined by the following formula:

[0088]

[0089] Among them, σ z1 is the variance of the reservoir physical property parameter of the well section of a vertical well located in the target reservoir; Z(I) is the Ith reservoir physical property parameter value of the well section of the vertical well located in the target reservoir; N is the total number of reservoir physical property parameter values ​​of the well section of the vertical well located in the target reservoir; is the average value of each reservoir physical parameter value of the well section of the vertical well located in the target reservoir. Its value is determined by the porosity, permeability value interval and the effective thickness of the target reservoir. (Δh is the effective thickness of the target reservoir, Δh is the porosity and permeability interval, when the porosity and permeability are determined using the logging curve, H I is the value interval of the logging curve)

[0090] Furthermore, in step S4, the planar heterogeneity of the target reservoir is determined according to the following criteria:

[0091] (a) When the variance of reservoir physical property parameters is less than 1.6, the plane heterogeneity is weak;

[0092] (b) When the variance of reservoir physical property parameters is 1.6-2.4, the plane heterogeneity is moderate;

[0093] (c) When the variance of reservoir physical property parameters is greater than 2.4, the plane heterogeneity is strong.

[0094] It should be noted that the terms "first", "second", etc. in the specification and claims of the present invention and the above-mentioned drawings are used to distinguish similar objects, and are not necessarily used to describe a specific order or sequence. It should be understood that the data used in this way can be interchanged where appropriate, so that the embodiments of the present invention described herein can be implemented in an order other than those illustrated or described herein. In addition, the terms "including" and "having" and any variations thereof are intended to cover non-exclusive inclusions, for example, a process, method, system, product or device that includes a series of steps or units is not necessarily limited to those steps or units that are clearly listed, but may include other steps or units that are not clearly listed or inherent to these processes, methods, products or devices.

[0095] The present invention also provides a system for determining the plane heterogeneity of a tight sandstone reservoir, which can implement the above-mentioned method for determining the plane heterogeneity of a tight sandstone reservoir, and the system comprises:

[0096] Reservoir physical property parameter determination module 21: used to obtain the porosity and permeability of each well depth (measured well depth) in the horizontal well section of the horizontal well located in the target reservoir, and the porosity and permeability of each well depth (measured well depth) in the well section of the horizontal well adjacent to the vertical well located in the target reservoir; further, determine the reservoir physical property parameters of each well depth in the horizontal well section of the horizontal well located in the target reservoir, and the reservoir physical property parameters of each well depth in the well section of the adjacent vertical well located in the target reservoir; wherein,

[0097] The first variance determination module 22 is used to segment the horizontal well section of each horizontal well located in the target reservoir, and determine the variance of the reservoir physical property parameters of each section of the horizontal well section of each horizontal well located in the target reservoir based on the reservoir physical property parameters at each well depth in the horizontal well section of each horizontal well located in the target reservoir;

[0098] The second variance determination module 23 is used to determine the variance of the reservoir physical property parameters of each vertical well in the target reservoir section based on the reservoir physical property parameters at each well depth in the well section of each vertical well in the target reservoir;

[0099] Planar heterogeneity determination module 24: used to determine the planar contour map of the variance of reservoir physical property parameters based on the variance of reservoir physical property parameters of each section of the horizontal well section of each horizontal well located in the target reservoir and the variance of reservoir physical property parameters of each section of the vertical well located in the target reservoir, so as to determine the planar heterogeneity of the target reservoir.

[0100] Furthermore, the reservoir physical property parameter determination module 21 includes:

[0101] Well logging data acquisition submodule 211: used to acquire well logging data of a horizontal well section of a horizontal well located in a target reservoir and well logging data of a well section of a vertical well adjacent to the horizontal well located in the target reservoir;

[0102] Porosity and permeability determination submodule 212: used to determine the porosity and permeability at each well depth in the horizontal well section of the horizontal well located in the target reservoir and the porosity and permeability at each well depth in the well section of the adjacent vertical well located in the target reservoir based on the well logging data of the horizontal well section of the horizontal well located in the target reservoir and the well logging data of the horizontal well section of the adjacent vertical well located in the target reservoir;

[0103] Furthermore, the porosity and permeability determination submodule 212 includes:

[0104] The first acoustic time difference determination unit 2121 is used to obtain the actual measured acoustic time difference curve of the horizontal well section of each horizontal well located in the target reservoir; perform frequency statistics of different acoustic time difference values ​​on the actual measured acoustic time difference curve of the horizontal well section of each horizontal well located in the target reservoir to obtain a first acoustic time difference frequency statistical histogram; and then obtain the acoustic time difference corresponding to the highest frequency in the first acoustic time difference frequency statistical histogram as the acoustic time difference of the horizontal well section of the target reservoir

[0105] The second acoustic time difference determination unit 2122 is used to obtain the actual measured acoustic time difference curve of the well section of each adjacent vertical well of each horizontal well located in the target reservoir; perform frequency statistics of different acoustic time difference values ​​on the actual measured acoustic time difference curve of the well section of each adjacent vertical well of each horizontal well located in the target reservoir to obtain a second acoustic time difference frequency statistical histogram; and then obtain the acoustic time difference corresponding to the highest frequency in the second acoustic time difference frequency statistical histogram as the acoustic time difference of the vertical well section of the target reservoir

[0106] The anisotropy coefficient determination unit 2123 is used to determine the acoustic transit time anisotropy coefficient of the horizontal well section of the target reservoir based on the acoustic transit time of the horizontal well section of the target reservoir and the acoustic transit time of the vertical well section of the target reservoir; wherein the acoustic transit time anisotropy coefficient of the horizontal well section of the target reservoir is determined by the following formula:

[0107] λΔt=Δtv÷Δth;

[0108] Among them, λΔt is the acoustic time difference anisotropy coefficient of the horizontal well section of the target reservoir; Δth is the acoustic time difference of the horizontal well section of the target reservoir, μs / m; Δtv is the acoustic time difference of the vertical well section of the target reservoir, μs / m;

[0109] Correction unit 2124: used to correct the actual measured acoustic wave time difference curve of the horizontal well section of each horizontal well located in the target reservoir by using the acoustic wave time difference anisotropy coefficient of the horizontal well section of the target reservoir; wherein the correction is performed by the following formula:

[0110] Δtc=λΔt×Δth;

[0111] Among them, λΔt is the acoustic time difference anisotropy coefficient of the horizontal well section of the target reservoir; Δtc is the corrected acoustic time difference of the horizontal well section of a horizontal well located in the target reservoir, μs / m; Δth is the actual measured acoustic time difference of the horizontal well section of the horizontal well located in the target reservoir, μs / m;

[0112] Porosity determination unit 2125: used to determine the porosity at each well depth in the horizontal well section of each horizontal well located in the target reservoir and the porosity at each well depth in the well section of each horizontal well adjacent to the vertical well located in the target reservoir, respectively, using a core calibration logging method, based on the corrected acoustic time difference of the horizontal well section of each horizontal well located in the target reservoir and the actually measured acoustic time difference curve of the well section of each adjacent vertical well of each horizontal well located in the target reservoir;

[0113] Permeability determination unit 2125: used to determine the permeability of each horizontal well in the target reservoir at each depth and the permeability of each vertical well adjacent to each horizontal well in the target reservoir at each depth based on the porosity of each horizontal well at each depth in the horizontal well section of the target reservoir and the porosity of each vertical well adjacent to each horizontal well in the target reservoir, using the core calibration logging method.

[0114] Further, the first variance determination module 22 determines the variance of the reservoir physical property parameters of each section of the horizontal well section of each horizontal well located in the target reservoir by the following formula:

[0115]

[0116] In the formula, σ Z is the variance of the reservoir physical property parameter of a certain section in the horizontal well section of a horizontal well in the target reservoir; Z(i) is the i-th reservoir physical property parameter value of the section in the horizontal well section of the horizontal well in the target reservoir; n is the total number of reservoir physical property parameter values ​​of the section in the horizontal well section of the horizontal well in the target reservoir, and its value is determined by the porosity and permeability value interval and the length of the section. In a specific embodiment, (Δl is the length of the segment, h i is the porosity and permeability value interval. When the porosity and permeability are determined using logging curves, h i is the value interval of the logging curve); It is the average value of each reservoir physical property parameter value in the horizontal well section of the horizontal well in the target reservoir.

[0117] Furthermore, the first variance determination module 22 implements segmentation of the horizontal well section of each horizontal well located in the target reservoir in the following manner:

[0118] The horizontal well section of each horizontal well located in the target reservoir is divided into sections with a well depth of 400 m (measured well depth).

[0119] Furthermore, the second variance determination module 23 determines the variance of the reservoir physical property parameters of each vertical well in the target reservoir section by the following formula:

[0120]

[0121] Among them, σ z1 is the variance of the reservoir physical property parameter of a vertical well in the target reservoir; Z(I) is the Ith reservoir physical property parameter value of the vertical well in the target reservoir; N is the total number of reservoir physical property parameter values ​​of the vertical well in the target reservoir, and its value is determined by the porosity, permeability interval and the effective thickness of the target reservoir. In a specific embodiment, (Δh is the effective thickness of the target reservoir, h i is the porosity and permeability value interval. When the porosity and permeability are determined using logging curves, h i is the value interval of the logging curve; It is the average value of each reservoir physical property parameter in the well section of the vertical well located in the target reservoir.

[0122] Further, the planar heterogeneity determination module 24 determines the planar heterogeneity of the target reservoir according to the following standards:

[0123] (a) When the variance of reservoir physical property parameters is less than 1.6, the plane heterogeneity is weak;

[0124] (b) When the variance of reservoir physical property parameters is 1.6-2.4, the plane heterogeneity is moderate;

[0125] (c) When the variance of reservoir physical property parameters is greater than 2.4, the plane heterogeneity is strong.

[0126] The embodiment of the present invention also provides a storage medium. The storage medium stores one or more programs. The storage medium may include a volatile memory, such as a random access memory; the memory may also include a non-volatile memory, such as a read-only memory, a flash memory, a hard disk or a solid-state drive; the memory may also include a combination of the above-mentioned types of memory.

[0127] When one or more programs in the storage medium can be executed by one or more processors to implement the steps of the above-mentioned method for determining the planar heterogeneity of a tight sandstone reservoir, please refer to the above-mentioned embodiment of the method for determining the planar heterogeneity of a tight sandstone reservoir for details.

[0128] An embodiment of the present invention provides a device suitable for determining the planar heterogeneity of a tight sandstone reservoir, the device comprising: a processor communication interface, a memory and a communication bus, wherein the processor, the communication interface and the memory communicate with each other via the communication bus;

[0129] Memory, used to store computer programs;

[0130] The processor is used to execute the program stored in the memory to implement the steps of the above-mentioned method for determining the planar heterogeneity of the tight sandstone reservoir. For details, please refer to the above-mentioned embodiment of the method for determining the planar heterogeneity of the tight sandstone reservoir, which will not be repeated here.

[0131] Example 1

[0132] In this example, the Chang 8 tight sandstone reservoir in a certain area of ​​a certain basin is used as the target reservoir for heterogeneity determination. Specifically, this example determines the heterogeneity of the target reservoir by the following method:

[0133] Step 1: Use logging instruments to collect logging data of the horizontal well section of the horizontal well located in the target reservoir and the logging data of the well section of the adjacent vertical well located in the target reservoir of the horizontal well, and process the logging data to determine the porosity of the horizontal well section of the horizontal well located in the target reservoir. and permeability K curve and the porosity of the well section of the adjacent vertical well located in the target reservoir of the horizontal well and permeability K curve.

[0134] In order to more accurately determine the porosity The permeability K curve is used to perform anisotropic correction on the actual measured acoustic time difference of the horizontal well section of each horizontal well located in the target reservoir in the following way:

[0135] (a) obtaining an actual measured acoustic time difference curve of a horizontal well section of each horizontal well located in a target reservoir; performing frequency statistics of different acoustic time difference values ​​on the actual measured acoustic time difference curve of a horizontal well section of each horizontal well located in a target reservoir to obtain a first acoustic time difference frequency statistical histogram; and then obtaining the acoustic time difference corresponding to the highest frequency in the first acoustic time difference frequency statistical histogram as the acoustic time difference Δt of the horizontal well section of the target reservoir. h ;in, Figure 2 is the acoustic time difference frequency statistical histogram of the horizontal well section of the target reservoir (i.e., the first acoustic time difference frequency statistical histogram). The acoustic time difference corresponding to the highest frequency point is 215.0μs / m. Based on this, Δt is determined h The value is 215.0μs / m;

[0136] (b) obtaining the actual measured acoustic time difference curves of the well sections of each adjacent vertical well of each horizontal well located in the target reservoir; performing frequency statistics of different acoustic time difference values ​​on the actual measured acoustic time difference curves of the well sections of each adjacent vertical well of each horizontal well located in the target reservoir to obtain a second acoustic time difference frequency statistical histogram; and then obtaining the acoustic time difference corresponding to the highest frequency in the second acoustic time difference frequency statistical histogram as the acoustic time difference Δt of the vertical well section of the target reservoir v ;in, Figure 3is the acoustic time difference frequency statistical histogram of the vertical well section of the target reservoir (i.e., the second acoustic time difference frequency statistical histogram). The acoustic time difference corresponding to the highest frequency point is 225.3μs / m. Based on this, Δt is determined v The value is 225.3μs / m.

[0137] (c) According to the determined Δt h and Δt c The following formula is used to determine the acoustic time difference anisotropy coefficient λ of the horizontal well section of the target reservoir Δt =Δt v / Δt h =225.3 / 215.0=1.048;

[0138] (d) Using the acoustic time difference anisotropy coefficient λ of the horizontal well section of the target reservoir Δt , the actual measured acoustic time difference curve of the horizontal well section of each horizontal well located in the target reservoir is corrected; wherein, the correction is performed by the following formula: Δt c =λ Δt ×Δt h ; where Δt c is the corrected acoustic time difference of the horizontal well section in the target reservoir of a horizontal well, μs / m; Δt h It is the acoustic wave time difference actually measured in the horizontal well section of the horizontal well located in the target reservoir, μs / m.

[0139] The porosity of the horizontal well section of each horizontal well in the target reservoir is determined by using the corrected acoustic time difference of the horizontal well section of each horizontal well located in the target reservoir and the actual measured acoustic time difference curve of the well section of the adjacent vertical well of each horizontal well located in the target reservoir, and the core calibration logging method is used. The permeability K curve and the porosity of the vertical wells adjacent to each horizontal well in the target reservoir and permeability K curve; among them, porosity And the permeability K is determined by the following formula:

[0140]

[0141]

[0142] In the formula, Δt c is the acoustic time difference μs / m; is the porosity, %; K is the permeability, mD.

[0143] Step 2: Porosity of the horizontal well section in the target reservoir and permeability K curve and the porosity of the well section of the adjacent vertical well located in the target reservoir of the horizontal well and permeability K curve, determine the reservoir physical property parameter Z curve of the horizontal well section located in the target reservoir and the reservoir physical property parameter Z curve of the well section of the horizontal well adjacent to the vertical well located in the target reservoir; wherein,

[0144] Step 3: Based on the reservoir property parameter Z curve of each vertical well in the target reservoir, determine the normal distribution diagram of the reservoir property parameter Z of each vertical well in the target reservoir, and then determine the variance σ of the reservoir property parameter Z of each vertical well in the target reservoir by the following formula: Z ;

[0145]

[0146] In the formula, σ z1 is the variance of the reservoir physical property parameters of a vertical well in the target reservoir; Z(I) is the Ith reservoir physical property parameter value of the vertical well in the target reservoir; N is the total number of reservoir physical property parameter values ​​of the vertical well in the target reservoir, and its value is determined by the sampling interval of the logging curve (i.e., the porosity and permeability sampling interval) and the effective thickness of the target reservoir. In this embodiment, the sampling interval of the logging curve is 0.125 m. (Δh is the effective thickness of the target reservoir); It is the average value of each reservoir physical property parameter in the well section of the vertical well located in the target reservoir.

[0147] Combining the shape and variance σ of the normal distribution graph Z , the heterogeneity of the target reservoir in a single vertical well can be determined. For formations with stronger heterogeneity, the normal distribution of Z values ​​is wider, and the corresponding variance σ Z On the contrary, the weaker the heterogeneity of the stratum, the narrower the normal distribution of the Z value, and the corresponding variance σ Z The smaller the value is. Figure 4 and Figure 5 As shown, Figure 4 The Z value distribution of the reservoir physical property parameters of the target reservoir in the well shown is relatively wide, with a variance of σ Z The value of is 0.872, which reflects that the target reservoir in this well has strong heterogeneity. Figure 5 The distribution of reservoir physical property parameters Z value of the target reservoir in the well shown is narrow, and the variance σ Z The value of is 0.279, reflecting that the heterogeneity of the target reservoir in this well is weak.

[0148] Step 4: Segment the horizontal well section of each horizontal well located in the target reservoir, and determine the normal distribution diagram of the reservoir physical property parameter Z of each section of the horizontal well section of each horizontal well located in the target reservoir based on the reservoir physical property parameter Z curve of the horizontal well section of each horizontal well located in the target reservoir, and then determine the variance σ of the reservoir physical property parameter Z of each section of the horizontal well section of each horizontal well located in the target reservoir. Z ;

[0149] The segmentation is performed as follows:

[0150] (a) From shallow to deep well depth, the root end of the horizontal well section located in the target reservoir is taken as the starting point to the position where the well depth increases by 400m as the first section of the horizontal well section located in the target reservoir; (b) The end point of the first section is taken as the starting point of the second section to the position where the well depth increases by 400m as the second section of the horizontal well section located in the target reservoir, and so on (the end point of the i-th section is taken as the starting point of the i+1-th section to the position where the well depth increases by 400m as the i+1-th section of the horizontal well section located in the target reservoir); (c) When the remaining well depth is less than 400m, this remaining section is taken as the last section of the horizontal well section located in the target reservoir.

[0151] The variance of the reservoir physical property parameters of each section of the horizontal well section of each horizontal well located in the target reservoir is determined by the following formula:

[0152]

[0153] In the formula, σ Z is the variance of the reservoir physical property parameters of a certain section in the horizontal well section of a horizontal well in the target reservoir; Z(i) is the i-th reservoir physical property parameter value of the section in the horizontal well section of the horizontal well in the target reservoir; n is the total number of reservoir physical property parameter values ​​of the section in the horizontal well section of the horizontal well in the target reservoir, and its value is determined by the sampling interval of the logging curve (i.e., the porosity and permeability sampling interval) and the length of the section. In this embodiment, the sampling interval of the logging curve is 0.125m. (Δl is the length of the section, and all sections except the last one are 400m, that is, n of all sections except the last one is 3200).

[0154] Step 5: Based on the variance σ of the reservoir physical property parameter Z of each horizontal well section in the target reservoir Z and the variance σ of Z of each vertical well in the target reservoir Z , determine the variance σ of reservoir physical property parameter Z Z Plane contour map of the target reservoir is used to determine the planar heterogeneity of the target reservoir;

[0155] The heterogeneity judgment criteria are shown in Table 1.

[0156] Table 1

[0157] Planar heterogeneity <![CDATA[σ Z Value]]> Weak heterogeneity ≤1.6 Medium heterogeneity 1.6-2.4 Strong heterogeneity ≥2.4

[0158] In this example, the method described in the present invention is used to process 79 vertical wells and 7 horizontal wells of the target reservoir, and the variance σ of the reservoir physical property parameter Z of the target reservoir is obtained. Z The plane contour map of Figure 6 As shown. Figure 6 It can be seen that the heterogeneity of the target reservoir is weak in the west and northeast, while the heterogeneity of the Shun 174 well area in the southeast and middle is strong. The heterogeneity of the Shun 15 and Shun 148 well areas is moderate. Using the method shown in the present invention, the planar heterogeneity distribution law of the target reservoir can be accurately determined, providing a reference for the exploration direction and sand body selection.

[0159] The above contents are only for explaining the technical idea of ​​the present invention and cannot be used to limit the protection scope of the present invention. Any changes made on the basis of the technical solution in accordance with the technical idea proposed by the present invention shall fall within the protection scope of the claims of the present invention.

Claims

1. A method for determining the plane heterogeneity of a tight sandstone reservoir, characterized in that: The following steps are involved: S1: Obtain the porosity and permeability at each well depth in the horizontal well section of the horizontal well in the target reservoir, and the porosity and permeability at each well depth in the well section of the horizontal well adjacent to the vertical well in the target reservoir; then calculate the reservoir physical property parameters at each well depth in the horizontal well section of the target reservoir and the reservoir physical property parameters at each well depth in the well section of the horizontal well adjacent to the vertical well in the target reservoir according to the determined porosity and permeability at each well depth; S2: Segmenting the horizontal well section of each horizontal well located in the target reservoir, and determining the variance of the reservoir physical property parameters of each section of the horizontal well section of each horizontal well located in the target reservoir based on the reservoir physical property parameters at each well depth in the horizontal well section of each horizontal well located in the target reservoir; S3: based on the reservoir physical property parameters at each well depth in the well section of each vertical well located in the target reservoir, respectively determine the variance of the reservoir physical property parameters of the well section of each vertical well located in the target reservoir; S4: Based on the variance of the reservoir physical property parameters of each section of the horizontal well section of each horizontal well located in the target reservoir and the variance of the reservoir physical property parameters of the section of the adjacent vertical well of each horizontal well located in the target reservoir, a plane contour map of the variance of the reservoir physical property parameters is determined, thereby determining the plane heterogeneity of the target reservoir.

2. A method for determining plane heterogeneity of a tight sandstone reservoir according to claim 1, characterized in that: In S1, the process of obtaining the porosity and permeability at each well depth in the horizontal well section of the horizontal well located in the target reservoir, and the porosity and permeability at each well depth in the well section of the adjacent vertical well of the horizontal well located in the target reservoir, includes the following steps: S11: Acquire well logging data of a horizontal well section of a horizontal well located in a target reservoir and well logging data of a well section of a vertical well adjacent to the horizontal well located in the target reservoir; S12: Based on the logging data of the horizontal well section of the horizontal well located in the target reservoir and the logging data of the well section of the horizontal well adjacent to the vertical well located in the target reservoir, determine the porosity and permeability at each well depth in the horizontal well section of the horizontal well located in the target reservoir and the porosity and permeability at each well depth in the well section of the horizontal well adjacent to the vertical well located in the target reservoir.

3. According to the method for determining the planar heterogeneity of a tight sandstone reservoir according to claim 2, in S12, based on the logging data of the horizontal well section of the horizontal well located in the target reservoir and the logging data of the well section of the horizontal well adjacent to the vertical well located in the target reservoir, the process of determining the porosity and permeability at each well depth in the horizontal well section of the horizontal well located in the target reservoir and the porosity and permeability at each well depth in the well section of the horizontal well adjacent to the vertical well located in the target reservoir comprises the following steps: S121: Obtaining the actual measured acoustic time difference curve of the horizontal well section of each horizontal well located in the target reservoir; performing frequency statistics of different acoustic time difference values ​​on the actual measured acoustic time difference curve of the horizontal well section of each horizontal well located in the target reservoir to obtain a first acoustic time difference frequency statistical histogram; and then obtaining the acoustic time difference corresponding to the highest frequency in the first acoustic time difference frequency statistical histogram as the acoustic time difference of the horizontal well section of the target reservoir; Step S122: obtaining the actual measured acoustic time difference curves of the well sections of each adjacent vertical well of each horizontal well located in the target reservoir; performing frequency statistics of different acoustic time difference values ​​on the actual measured acoustic time difference curves of the well sections of each adjacent vertical well of each horizontal well located in the target reservoir to obtain a second acoustic time difference frequency statistical histogram; and then obtaining the acoustic time difference corresponding to the highest frequency in the second acoustic time difference frequency statistical histogram as the acoustic time difference of the vertical well section of the target reservoir; Step S123: Based on the acoustic time difference of the horizontal well section of the target reservoir and the acoustic time difference of the vertical well section of the target reservoir, the acoustic time difference anisotropy coefficient of the horizontal well section of the target reservoir is determined; wherein the acoustic time difference anisotropy coefficient of the horizontal well section of the target reservoir is determined by the following formula: λΔt=Δtv÷Δth; Among them, λΔt is the acoustic time difference anisotropy coefficient of the horizontal well section of the target reservoir; Δth is the acoustic time difference of the horizontal well section of the target reservoir, μs / m; Δtv is the acoustic time difference of the vertical well section of the target reservoir, μs / m; Step S124: The actual measured acoustic time difference curve of the horizontal well section of each horizontal well located in the target reservoir is corrected by using the acoustic time difference anisotropy coefficient of the horizontal well section of the target reservoir; wherein the correction is performed by the following formula: Δtc=λΔt×Δth; Among them, λΔt is the acoustic time difference anisotropy coefficient of the horizontal well section of the target reservoir; Δtc is the corrected acoustic time difference of the horizontal well section of a horizontal well located in the target reservoir, μs / m; Δth is the actual measured acoustic time difference of the horizontal well section of the horizontal well located in the target reservoir, μs / m; Step S125: Based on the corrected acoustic time difference of the horizontal well section of each horizontal well located in the target reservoir and the actually measured acoustic time difference curve of the well section of each adjacent vertical well of each horizontal well located in the target reservoir, the core calibration logging method is used to respectively determine the porosity at each well depth position in the horizontal well section of each horizontal well located in the target reservoir and the porosity at each well depth position in the well section of the adjacent vertical well of each horizontal well located in the target reservoir; Step S126: Based on the porosity of each horizontal well at each well depth in the horizontal well section of the target reservoir and the porosity of each horizontal well's adjacent vertical well in the target reservoir, the core calibration logging method is used to determine the permeability of each horizontal well at each well depth in the horizontal well section of the target reservoir and the permeability of each horizontal well's adjacent vertical well in the target reservoir.

4. A method for determining planar heterogeneity of a tight sandstone reservoir according to claim 1, characterized in that: S1, the 5. The method for determining the planar heterogeneity of a tight sandstone reservoir according to claim 1, characterized in that: In S2, the variance of the reservoir physical property parameters of each section of the horizontal well section of each horizontal well located in the target reservoir is determined by the following formula: Among them, σ z is the variance of the reservoir physical property parameters of a certain section in the horizontal well section of the target reservoir of a certain horizontal well; z(i) is the i-th reservoir physical property parameter value of the section in the horizontal well section of the target reservoir of the horizontal well; n is the total number of reservoir physical property parameter values ​​of the section in the horizontal well section of the target reservoir of the horizontal well, and its value is determined by the porosity and permeability interval and the length of the section; is the average value of each reservoir physical property parameter of the horizontal well section of the target reservoir of the horizontal well; Said Among them, Δl is the length of the segment; h i Divided into porosity and permeability value intervals.

6. A method for determining planar heterogeneity of a tight sandstone reservoir according to claim 1, characterized in that: In S2, segmenting the horizontal well section of each horizontal well located in the target reservoir is achieved by: The horizontal well section of each horizontal well located in the target reservoir is segmented according to a well depth of 400 m.

7. A method for determining planar heterogeneity of a tight sandstone reservoir according to claim 1, characterized in that: In S3, the variance of the reservoir physical property parameters of each vertical well located in the target reservoir is determined by the following formula: Among them, σ z1 is the variance of the reservoir physical property parameter of the well section of a vertical well located in the target reservoir; Z(I) is the Ith reservoir physical property parameter value of the well section of the vertical well located in the target reservoir; N is the total number of reservoir physical property parameter values ​​of the well section of the vertical well located in the target reservoir; is the average value of each reservoir physical property parameter value of the well section of the vertical well located in the target reservoir; The value of N is determined by the porosity, permeability interval and the effective thickness of the target reservoir; Δh is the effective thickness of the target reservoir, and Δh is the porosity and permeability value interval.

8. A method for determining plane heterogeneity of a tight sandstone reservoir according to claim 1, characterized in that: In S4, the planar heterogeneity of the target reservoir is determined according to the following criteria: When the variance of reservoir physical property parameters is less than 1.6, the plane heterogeneity is weak; When the variance of reservoir physical property parameters is 1.6 to 2.4, the plane heterogeneity is moderate; When the variance of reservoir physical property parameters is greater than 2.4, the plane heterogeneity is strong.

9. A system for determining plane heterogeneity of tight sandstone reservoirs, characterized in that: It includes a reservoir physical property parameter determination module, a first variance determination module, a second variance determination module and a plane heterogeneity determination module; The reservoir physical property parameter determination module is used to obtain the porosity and permeability at each well depth in the horizontal well section of the horizontal well located in the target reservoir and the porosity and permeability at each well depth in the well section of the horizontal well adjacent to the vertical well located in the target reservoir; further, determine the reservoir physical property parameters at each well depth in the horizontal well section of the horizontal well located in the target reservoir and the reservoir physical property parameters at each well depth in the well section of the horizontal well adjacent to the vertical well located in the target reservoir; The first variance determination module is used to segment the horizontal well section of each horizontal well located in the target reservoir, and determine the variance of the reservoir physical property parameters of each section of the horizontal well section of each horizontal well located in the target reservoir based on the reservoir physical property parameters of each well depth position in the horizontal well section of each horizontal well located in the target reservoir; the second variance determination module is used to determine the variance of the reservoir physical property parameters of each section of the vertical well located in the target reservoir based on the reservoir physical property parameters of each well depth position in the section of each vertical well located in the target reservoir; The planar heterogeneity determination module is used to determine the planar contour map of the variance of the reservoir physical property parameters based on the variance of the reservoir physical property parameters of each section of the horizontal well section of each horizontal well located in the target reservoir and the variance of the reservoir physical property parameters of the well section of each vertical well located in the target reservoir, thereby determining the planar heterogeneity of the target reservoir.

10. A computer-readable storage medium, characterized in that: The computer-readable storage medium stores instructions, and when the instructions are executed by the processor, the steps of any one of the methods described in claim 1 to claim 8 are implemented.

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