Reservoir fracture identification methods, devices, electronic equipment and storage media

Abstract

This application provides a method, apparatus, electronic device, and storage medium for reservoir fracture identification. The method includes acquiring gas logging data of a target reservoir; wherein the gas logging data includes at least the total hydrocarbon values ​​at various depths in the target reservoir; determining the locations of abnormal depths in the target reservoir based on the total hydrocarbon values ​​at various depths, and determining the degree of anomalousness of the total hydrocarbon values ​​corresponding to each abnormal depth; and determining the degree of fracture development at each abnormal depth based on the degree of anomalousness of the total hydrocarbon values ​​corresponding to each abnormal depth. This method can quickly and cost-effectively identify fractures even in well locations with limited logging and seismic data. It can quickly, intuitively, cost-effectively, and quantitatively identify and locate fractures in shale formations, providing a basis for shale sweet spot evaluation and horizontal well fracturing.

Description

Technical Field

[0001] This application relates to the field of petroleum exploration technology, and in particular to a method, apparatus, electronic device and storage medium for reservoir fracture identification. Background Technology

[0002] my country's shale gas resources are characterized by large reserves and significant exploitation potential. Commercial exploitation of shale gas from the Wufeng Formation to the Longmaxi Formation has been achieved in the Weiyuan-Changning, Fuling, and Nanchuan blocks, with the Fuling block producing 7.46 billion cubic meters of gas in 2020. The development of fractures in shale formations leads to significant differences in production and fracturing efficiency; therefore, identifying fractures in shale formations is crucial for shale gas development.

[0003] Currently, there are various methods for identifying natural fractures in shale formations, including core identification (geological methods), well logging identification, and seismic prediction. In geological methods, different types of fractures can be identified through core observation and isotope measurements; or, the final response charts of fracture-developed and non-developed sections can be obtained by combining sonic transit time and resistivity curves with natural gamma curves. In well logging methods, different types of fractures in the formation can be identified and fracture parameters quantitatively calculated using imaging logging data; or, shale fractures can be identified through sonic logging processing or by using fracture information from imaging logging. In seismic methods for predicting and identifying fractures, post-stack seismic data can be processed to identify the planar distribution characteristics of fractures or to use curvature to represent the degree of fracture development. However, seismic data has a significant advantage in predicting large-scale fractures, but it cannot effectively represent small fractures (fracture length less than 1m) within a single well.

[0004] Whether using geological methods, well logging methods, or seismic methods, fracture identification mainly relies on well logging or seismic data. However, in the exploration or early development stages of shale oil and gas, well logging and seismic data are scarce. In particular, most horizontal wells currently do not undergo well logging and coring due to high costs, except for gamma ray (GR) logging and only one well per platform. This makes it impossible to obtain well logging and seismic data, which undoubtedly limits or restricts the application of well logging and seismic methods in fracture identification. Summary of the Invention

[0005] To address the aforementioned problems, this application provides a method, apparatus, electronic device, and storage medium for identifying reservoir fractures, which solves the technical problem of difficulty in identifying formation fractures in the absence of well logging and seismic data in the prior art.

[0006] In a first aspect, this application provides a method for identifying reservoir fractures, the method comprising:

[0007] Obtain gas logging data of the target reservoir; wherein, the gas logging data includes at least the total hydrocarbon values ​​at various depths in the target reservoir;

[0008] Based on the total hydrocarbon values ​​measured at various depths in the target reservoir, the locations of abnormal depths in the target reservoir are determined, and the degree of abnormality of the total hydrocarbon values ​​measured at each abnormal depth in the target reservoir is determined.

[0009] Based on the degree of anomaly in the total hydrocarbon values ​​at each anomaly depth in the target reservoir, the degree of fracture development at each anomaly depth in the target reservoir is determined.

[0010] According to an embodiment of this application, optionally, in the above-described reservoir fracture identification method, the gas logging data further includes organic matter abundance;

[0011] Determining the location of abnormal depths in the target reservoir based on the total hydrocarbon values ​​measured at various depths includes the following steps:

[0012] The locations of abnormal depths in the target reservoir are determined based on the total hydrocarbon values ​​and organic matter abundance at various depths.

[0013] According to an embodiment of this application, optionally, in the above-described reservoir fracture identification method, determining the location of abnormal depths in the target reservoir based on the total hydrocarbon values ​​and organic matter abundance at various depths in the target reservoir includes the following steps:

[0014] The total hydrocarbon values ​​measured at each depth in the target reservoir are normalized to obtain the normalized results of the total hydrocarbon values ​​measured at each depth in the target reservoir.

[0015] Based on the normalized results of the total hydrocarbon values ​​at each depth location in the target reservoir and the organic matter abundance at each depth location in the target reservoir, the abnormal depth locations in the target reservoir are determined.

[0016] Wherein, the normalized result of the total hydrocarbon value of the gas measurement at the abnormal depth location in the target reservoir is greater than or equal to the first preset threshold, and the corresponding organic matter abundance is greater than or equal to the second preset threshold.

[0017] According to an embodiment of this application, optionally, in the above-described reservoir fracture identification method, the first preset threshold is determined through the following steps:

[0018] Obtain gas logging data, core data, and imaging logging data from the reference reservoir;

[0019] The total hydrocarbon values ​​at each depth location in the reference reservoir are normalized to obtain the normalized results of the total hydrocarbon values ​​at each depth location in the reference reservoir.

[0020] Fracture identification is performed on the core data and imaging logging data of the reference reservoir to determine the fracture development at various depths in the reference reservoir.

[0021] The first preset threshold is determined based on the normalized results of the total hydrocarbon values ​​at each depth location in the reference reservoir and the fracture development at each depth location in the reference reservoir.

[0022] According to an embodiment of this application, optionally, in the above-described reservoir fracture identification method, the second preset threshold is determined through the following steps:

[0023] The second preset threshold is determined based on the organic matter abundance at each depth location in the reference reservoir and the fracture development at each depth location in the reference reservoir.

[0024] According to an embodiment of this application, optionally, in the above-described reservoir fracture identification method, the normalization processing of the total hydrocarbon values ​​at each depth location in the target reservoir to obtain the normalized results of the total hydrocarbon values ​​at each depth location in the target reservoir includes the following steps:

[0025] The total hydrocarbon values ​​at each depth in the target reservoir are normalized using the following formula to obtain the normalized results of the total hydrocarbon values ​​at each depth in the target reservoir:

[0026]

[0027] Among them, H i0 This is the normalized result of the total hydrocarbon value measured at a depth of i.

[0028] H i The total hydrocarbon value measured at a depth of i;

[0029] H Min The maximum value of total hydrocarbon measurements at all depths in the target reservoir;

[0030] H Max It is the minimum total hydrocarbon value measured at all depths in the target reservoir.

[0031] According to an embodiment of this application, optionally, in the above-described reservoir fracture identification method, determining the degree of anomaly in the total hydrocarbon values ​​at each abnormal depth location in the target reservoir includes the following steps:

[0032] Calculate the difference between the normalized result of the total hydrocarbon value measured by gas at each abnormal depth location in the target reservoir and the first preset threshold.

[0033] The degree of anomalousness of the total hydrocarbon values ​​at each anomalous depth location in the target reservoir is determined based on the difference between the normalized result of the total hydrocarbon values ​​at each anomalous depth location and the first preset threshold.

[0034] According to an embodiment of this application, optionally, in the above-described reservoir fracture identification method, the organic matter abundance includes organic carbon content.

[0035] According to an embodiment of this application, optionally, in the above-described reservoir fracture identification method, the degree of fracture development at each abnormal depth location in the target reservoir is positively correlated with the degree of abnormality of the corresponding total hydrocarbon value.

[0036] Secondly, this application provides a reservoir fracture identification device, the device comprising:

[0037] The acquisition module is used to acquire gas logging data of the target reservoir; wherein, the gas logging data includes at least the total hydrocarbon values ​​at various depths in the target reservoir;

[0038] The first identification module is used to determine the abnormal depth location in the target reservoir based on the total hydrocarbon values ​​at each depth location in the target reservoir, and to determine the degree of abnormality of the total hydrocarbon values ​​at each abnormal depth location in the target reservoir.

[0039] The second identification module is used to determine the degree of fracture development at each abnormal depth location in the target reservoir based on the degree of abnormality of the total hydrocarbon values ​​at each abnormal depth location in the target reservoir.

[0040] Thirdly, this application provides an electronic device including a memory and a processor, wherein the memory stores a computer program that, when executed by the processor, performs the reservoir fracture identification method as described in any one of the first aspects.

[0041] Fourthly, this application provides a storage medium storing a computer program that can be executed by one or more processors and can be used to implement the reservoir fracture identification method as described in any one of the first aspects.

[0042] Compared with the prior art, one or more embodiments of the above solutions may have the following advantages or beneficial effects:

[0043] This application provides a method, apparatus, electronic device, and storage medium for reservoir fracture identification. The method includes acquiring gas logging data of a target reservoir; wherein the gas logging data includes at least the total hydrocarbon values ​​at various depths in the target reservoir; determining the locations of abnormal depths in the target reservoir based on the total hydrocarbon values ​​at various depths, and determining the degree of anomalousness of the total hydrocarbon values ​​corresponding to each abnormal depth; and determining the degree of fracture development at each abnormal depth based on the degree of anomalousness of the total hydrocarbon values ​​corresponding to each abnormal depth. This method can quickly and cost-effectively identify fractures even in well locations with limited logging and seismic data. It can quickly, intuitively, cost-effectively, and quantitatively identify and locate fractures in shale formations, providing a basis for shale sweet spot evaluation and horizontal well fracturing. Attached Figure Description

[0044] The present application will be described in more detail below based on embodiments and with reference to the accompanying drawings:

[0045] Figure 1 A schematic flowchart illustrating a reservoir fracture identification method provided in an embodiment of this application;

[0046] Figure 2 This is a schematic diagram of gas logging data at a reference well location JY5 in the Longmaxi Formation, provided in an embodiment of this application.

[0047] Figure 3 This is a schematic diagram of gas logging data at another reference well location JY8 in the Longmaxi Formation, provided in an embodiment of this application.

[0048] Figure 4 This is a schematic diagram of the imaging logging results at another reference well location SY3 in the Longmaxi Formation provided in this application embodiment;

[0049] Figure 5 A schematic diagram of gas logging data at the aforementioned reference well location SY3 provided in this application embodiment;

[0050] Figure 6 The normalized results of total hydrocarbon values ​​and scatter plots of organic matter abundance at various depths for the above-mentioned reference well locations provided in the embodiments of this application are shown.

[0051] Figure 7 A schematic diagram of gas logging data at a target well location JY10 in the Longmaxi Formation provided in this embodiment of the application;

[0052] Figure 8 This is a schematic diagram of gas logging data at another target well location PY1 in the Longmaxi Formation provided in an embodiment of this application.

[0053] Figure 9A schematic diagram of the fracture identification results for the target well location PY1 provided in this application embodiment;

[0054] Figure 10 This is a schematic diagram of the structure of a reservoir fracture identification device provided in an embodiment of this application;

[0055] In the accompanying drawings, the same parts are referred to by the same reference numerals, and the drawings are not drawn to scale. Detailed Implementation

[0056] The following detailed description of the embodiments of this application, in conjunction with the accompanying drawings, will provide a thorough understanding of how this application uses technical means to solve technical problems and achieve corresponding technical effects, enabling its implementation. The embodiments of this application and the various features within them can be combined with each other without conflict, and all resulting technical solutions are within the protection scope of this application.

[0057] Furthermore, numerous specific details are set forth in the following description for purposes of explanation, in order to provide a thorough understanding of the embodiments of the invention. However, it will be apparent to those skilled in the art that the invention may be practiced without the specific details herein or the particular methods described.

[0058] Example 1

[0059] Figure 1 Please refer to the flowchart illustrating a reservoir fracture identification method provided in this application embodiment. Figure 1 This embodiment provides a method for identifying reservoir fractures, including:

[0060] Step S110: Obtain gas logging data of the target reservoir; wherein the gas logging data includes at least the total hydrocarbon values ​​at various depths in the target reservoir.

[0061] Gas logging of total hydrocarbons is one of the essential objective data that must be recorded in the field. As long as a well is drilled, gas logging data will inevitably be available. It is relatively easier to obtain than high-cost data such as wellbore coring, conventional logging, imaging logging, and 3D seismic logging, providing necessary convenience for fracture identification based on gas logging.

[0062] Gas logging primarily involves analyzing the content and composition of natural gas in drilling fluid to determine the properties of formation fluids and indirectly evaluate the reservoir. Gas logging can promptly detect oil and gas layers and provide early warnings of engineering accidents such as well kicks and blowouts.

[0063] The hydrocarbon gases carried by drilling fluids are soluble. They are soluble not only in petroleum but also in water, thus forming a reservoir of dissolved gases. For example, methane's solubility in petroleum is 10 times that in water. If methane's solubility in petroleum is 1, then ethane is 5.5, propane is 18.5, and hydrocarbons larger than butane can be mixed with petroleum in any proportion. Carbon dioxide and hydrogen sulfide are slightly more soluble in petroleum than in water, while nitrogen is not easily soluble in petroleum.

[0064] Hydrocarbon gases are generally stored in three states: free state, dissolved state, and adsorbed state.

[0065] During oil exploration drilling, when an oil and gas reservoir is opened, the oil and gas enter the drilling fluid through permeation and diffusion. The drilling fluid then carries the gas to the surface, where it is removed by a degassing device. The removed gas is then fed into a gas chromatograph via a gas pipeline. The sample gas fed into the gas chromatograph directly enters a flame ionization analyzer (FID) for analysis and outputs the results, which are called the total hydrocarbon value (the total content of hydrocarbon gases in the sample gas).

[0066] Optionally, the gas logging data may also include organic matter abundance.

[0067] Preferably, the organic matter abundance includes total organic carbon (TOC).

[0068] Organic matter abundance is crucial to the formation of hydrocarbons in a stratigraphic unit, serving as the material basis for hydrocarbon generation and a vital foundation for assessing the hydrocarbon generation potential of source rocks. Commonly used organic matter abundance indicators include total organic carbon (TOC), soluble hydrocarbons (S1), pyrolytic hydrocarbons (S2), oil production potential (Pg), and chloroform bitumen A in source rock pyrolysis parameters.

[0069] Step S120: Based on the total hydrocarbon values ​​at various depths in the target reservoir, determine the location of the abnormal depth in the target reservoir, and determine the degree of abnormality of the total hydrocarbon values ​​at each abnormal depth in the target reservoir.

[0070] When the gas logging data also includes organic matter abundance, step S120 includes the following steps:

[0071] The locations of abnormal depths in the target reservoir are determined based on the total hydrocarbon values ​​and organic matter abundance at various depths.

[0072] Optionally, in step S120, determining the location of anomalies in the target reservoir based on the total hydrocarbon values ​​and organic matter abundance at various depths includes the following steps:

[0073] S122: Normalize the total hydrocarbon values ​​at each depth location in the target reservoir to obtain the normalized results of the total hydrocarbon values ​​at each depth location in the target reservoir.

[0074] S124: Determine the abnormal depth locations in the target reservoir based on the normalized results of the total hydrocarbon values ​​measured at each depth in the target reservoir and the organic matter abundance at each depth in the target reservoir.

[0075] Wherein, the normalized result of the total hydrocarbon value of the gas measurement at the abnormal depth location in the target reservoir is greater than or equal to the first preset threshold, and the corresponding organic matter abundance is greater than or equal to the second preset threshold.

[0076] This can be understood as follows: when the normalized result of the total hydrocarbon value at a certain depth is less than the first preset threshold, or the corresponding organic matter abundance is less than the second preset threshold, it indicates that the depth is a normal depth and there is no crack development.

[0077] Generally speaking, the higher the abundance of organic matter, the higher the total hydrocarbon value measured by gas. However, in the fracture development section, there will be a sudden increase and peak in the total hydrocarbon value, which indicates the presence of fractures.

[0078] The first and second preset thresholds mentioned above can be set according to actual conditions and needs.

[0079] Correspondingly, in step S120, determining the degree of anomaly in the total hydrocarbon values ​​at each anomaly depth location in the target reservoir includes the following steps:

[0080] S126: Calculate the difference between the normalized result of the total hydrocarbon value measured by gas at each abnormal depth location in the target reservoir and the first preset threshold.

[0081] S128: Based on the difference between the normalized result of the total hydrocarbon value at each abnormal depth location in the target reservoir and the first preset threshold, determine the degree of abnormality of the total hydrocarbon value at each abnormal depth location in the target reservoir.

[0082] Optionally, step S122 includes the following steps:

[0083] The total hydrocarbon values ​​at each depth in the target reservoir are normalized using the following formula to obtain the normalized results of the total hydrocarbon values ​​at each depth:

[0084]

[0085] Among them, H i0 This is the normalized result of the total hydrocarbon value measured at a depth of i.

[0086] H i The total hydrocarbon value measured at a depth of i;

[0087] H Min The maximum value of total hydrocarbon measurements at all depths in the target reservoir;

[0088] H Max It is the minimum total hydrocarbon value measured at all depths in the target reservoir.

[0089] Step S130: Determine the degree of fracture development at each abnormal depth location in the target reservoir based on the degree of anomalousness of the total hydrocarbon values ​​at each abnormal depth location.

[0090] The degree of fracture development at each abnormal depth in the target reservoir is positively correlated with the degree of abnormality in the corresponding total hydrocarbon values ​​measured by gas chromatography.

[0091] The greater the degree of anomaly in the total hydrocarbon value at the location of the anomaly depth, the greater the degree of fracture development at that location.

[0092] The development of high-angle fractures in the core samples is consistent with the high values ​​and spikes in total hydrocarbon anomalies, and the fractured sections in the shale correspond to high values ​​in total hydrocarbon anomalies in gas chromatography. This is because the presence of high-angle fractures in the shale facilitates the flow of shale gas from nearby shale layers, leading to vertical migration of shale gas and interlayer migration. The distance of shale gas migration depends on the length of the fractures.

[0093] This application provides a method for identifying reservoir fractures. The method includes acquiring gas logging data of a target reservoir; wherein the gas logging data includes at least the total hydrocarbon values ​​at various depths in the target reservoir; determining the locations of abnormal depths in the target reservoir based on the total hydrocarbon values ​​at various depths, and determining the degree of anomalousness of the total hydrocarbon values ​​corresponding to each abnormal depth; and determining the degree of fracture development at each abnormal depth based on the degree of anomalousness of the total hydrocarbon values ​​corresponding to each abnormal depth. This method can quickly and cost-effectively identify fractures even in well locations with limited logging and seismic data. It can quickly, intuitively, cost-effectively, and quantitatively identify and locate fractures in shale formations, providing a basis for shale sweet spot evaluation and horizontal well fracturing.

[0094] Example 2

[0095] This application provides a schematic flowchart of another reservoir fracture identification method. This embodiment provides a reservoir fracture identification method, including:

[0096] Step S210: Obtain gas logging data of the target reservoir; wherein the gas logging data includes at least the total hydrocarbon values ​​at various depths in the target reservoir.

[0097] Gas logging of total hydrocarbons is one of the essential objective data that must be recorded in the field. As long as a well is drilled, gas logging data will inevitably be available. It is relatively easier to obtain than high-cost data such as wellbore coring, conventional logging, imaging logging, and 3D seismic logging, providing necessary convenience for fracture identification based on gas logging.

[0098] Gas logging primarily involves analyzing the content and composition of natural gas in drilling fluid to determine the properties of formation fluids and indirectly evaluate the reservoir. Gas logging can promptly detect oil and gas layers and provide early warnings of engineering accidents such as well kicks and blowouts.

[0099] The hydrocarbon gases carried by drilling fluids are soluble. They are soluble not only in petroleum but also in water, thus forming a reservoir of dissolved gases. For example, methane's solubility in petroleum is 10 times that in water. If methane's solubility in petroleum is 1, then ethane is 5.5, propane is 18.5, and hydrocarbons larger than butane can be mixed with petroleum in any proportion. Carbon dioxide and hydrogen sulfide are slightly more soluble in petroleum than in water, while nitrogen is not easily soluble in petroleum.

[0100] Hydrocarbon gases are generally stored in three states: free state, dissolved state, and adsorbed state.

[0101] During oil exploration drilling, when an oil and gas reservoir is opened, the oil and gas enter the drilling fluid through permeation and diffusion. The drilling fluid then carries the gas to the surface, where it is removed by a degassing device. The removed gas is then fed into a gas chromatograph via a gas pipeline. The sample gas fed into the gas chromatograph directly enters a flame ionization analyzer (FID) for analysis and outputs the results, which are called the total hydrocarbon value (the total content of hydrocarbon gases in the sample gas).

[0102] Optionally, the gas logging data may also include organic matter abundance.

[0103] Preferably, the organic matter abundance includes total organic carbon (TOC).

[0104] Organic matter abundance is crucial to the formation of hydrocarbons in a stratigraphic unit, serving as the material basis for hydrocarbon generation and a vital foundation for assessing the hydrocarbon generation potential of source rocks. Commonly used organic matter abundance indicators include total organic carbon (TOC), soluble hydrocarbons (S2), pyrolytic hydrocarbons (S2), oil production potential (Pg), and chloroform bitumen A in the source rock pyrolysis parameters.

[0105] Step S220: Based on the total hydrocarbon values ​​at various depths in the target reservoir, determine the location of the abnormal depth in the target reservoir, and determine the degree of abnormality of the total hydrocarbon values ​​at each abnormal depth in the target reservoir.

[0106] When the gas logging data also includes organic matter abundance, step S220 includes the following steps:

[0107] The locations of abnormal depths in the target reservoir are determined based on the total hydrocarbon values ​​and organic matter abundance at various depths.

[0108] Optionally, in step S220, determining the location of anomalies in the target reservoir based on the total hydrocarbon values ​​and organic matter abundance at various depths includes the following steps:

[0109] S222: Normalize the total hydrocarbon values ​​at each depth location in the target reservoir to obtain the normalized results of the total hydrocarbon values ​​at each depth location in the target reservoir.

[0110] S224: Determine the abnormal depth locations in the target reservoir based on the normalized results of the total hydrocarbon values ​​measured at each depth in the target reservoir and the organic matter abundance at each depth in the target reservoir.

[0111] Wherein, the normalized result of the total hydrocarbon value of the gas measurement at the abnormal depth location in the target reservoir is greater than or equal to the first preset threshold, and the corresponding organic matter abundance is greater than or equal to the second preset threshold.

[0112] This can be understood as follows: when the normalized result of the total hydrocarbon value at a certain depth is less than the first preset threshold, or the corresponding organic matter abundance is less than the second preset threshold, it indicates that the depth is a normal depth and there is no crack development.

[0113] Generally speaking, the higher the abundance of organic matter, the higher the total hydrocarbon value measured by gas. However, in the fracture development section, there will be a sudden increase and peak in the total hydrocarbon value, which indicates the presence of fractures.

[0114] Optionally, the first preset threshold is determined through the following steps:

[0115] (a) Obtain gas logging data, core data and imaging logging data of the reference reservoir;

[0116] (b) Normalize the total hydrocarbon values ​​at each depth location in the reference reservoir to obtain the normalized results of the total hydrocarbon values ​​at each depth location in the reference reservoir.

[0117] (c) Identify fractures in the core data and imaging logging data of the reference reservoir to determine the fracture development at various depths in the reference reservoir;

[0118] (d) Determine the first preset threshold based on the normalized results of the total hydrocarbon values ​​at each depth location in the reference reservoir and the fracture development at each depth location in the reference reservoir.

[0119] Correspondingly, the second preset threshold is determined through the following steps:

[0120] The second preset threshold is determined based on the organic matter abundance at each depth location in the reference reservoir and the fracture development at each depth location in the reference reservoir.

[0121] Fracture identification in a single well can be achieved through core logging and imaging logging when conditions permit. Furthermore, core logging and imaging logging provide direct, effective, and objective data for fracture identification, and are the most reliable evidence to verify fractures identified by logging, seismic analysis, or other methods. However, most wells do not undergo core sampling or imaging logging.

[0122] Therefore, in this application, by referring to the total hydrocarbon value and organic matter abundance of the reservoir (the reservoir with known core and imaging logging data), and combining the fractures identified by core observation and imaging logging, the minimum threshold values ​​of the total hydrocarbon value and organic matter abundance corresponding to the presence of fracture development can be determined, namely the aforementioned first and second preset thresholds, thereby establishing a shale fracture identification model from a geological perspective.

[0123] This enables rapid and low-cost fracture identification even in well locations (reservoirs) with limited logging and seismic data. It allows for the rapid, intuitive, low-cost, and quantitative identification and location of fractures in shale reservoirs, providing a basis for shale sweet spot evaluation and horizontal well fracturing.

[0124] Optionally, a scatter plot of the reference reservoir at various depths can be constructed using the normalized result of the total hydrocarbon value measured by gas as the vertical axis and organic matter plugging as the horizontal axis. Based on the first and second preset thresholds determined above, outlier boundary lines can be drawn on the scatter plot to construct a quantitative fracture identification map.

[0125] Based on the fracture quantitative identification map constructed above, when identifying fractures in the target reservoir, the normalized results of the total hydrocarbon values ​​at each depth location in the target reservoir and the organic matter abundance at each depth location in the target reservoir can be used to place each depth location in the target reservoir into the map above, thereby identifying the abnormal depth locations in the target reservoir.

[0126] Correspondingly, in step S220, determining the degree of anomaly in the total hydrocarbon values ​​at each anomalous depth location in the target reservoir includes the following steps:

[0127] S226: Calculate the difference between the normalized result of the total hydrocarbon value measured by gas at each abnormal depth location in the target reservoir and the first preset threshold.

[0128] S228: Based on the difference between the normalized result of the total hydrocarbon value at each abnormal depth location in the target reservoir and the first preset threshold, determine the degree of abnormality of the total hydrocarbon value at each abnormal depth location in the target reservoir.

[0129] Optionally, step S222 includes the following steps:

[0130] The total hydrocarbon values ​​at each depth in the target reservoir are normalized using the following formula to obtain the normalized results of the total hydrocarbon values ​​at each depth:

[0131]

[0132] Among them, H i0 This is the normalized result of the total hydrocarbon value measured at a depth of i.

[0133] H i The total hydrocarbon value measured at a depth of i;

[0134] H Min The maximum value of total hydrocarbon measurements at all depths in the target reservoir;

[0135] H Max It is the minimum total hydrocarbon value measured at all depths in the target reservoir.

[0136] Step S230: Determine the degree of fracture development at each abnormal depth location in the target reservoir based on the degree of anomalousness of the total hydrocarbon values ​​at each abnormal depth location.

[0137] The degree of fracture development at each abnormal depth in the target reservoir is positively correlated with the degree of abnormality in the corresponding total hydrocarbon values ​​measured by gas chromatography.

[0138] The greater the degree of anomaly in the total hydrocarbon value at the location of the anomaly depth, the greater the degree of fracture development at that location.

[0139] The development of high-angle fractures in the core samples is consistent with the high values ​​and spikes in total hydrocarbon anomalies, and the fractured sections in the shale correspond to high values ​​in total hydrocarbon anomalies in gas chromatography. This is because the presence of high-angle fractures in the shale facilitates the flow of shale gas from nearby shale layers, leading to vertical migration of shale gas and interlayer migration. The distance of shale gas migration depends on the length of the fractures.

[0140] This application provides a method for identifying reservoir fractures. The method includes acquiring gas logging data of a target reservoir; wherein the gas logging data includes at least the total hydrocarbon values ​​at various depths in the target reservoir; determining the locations of abnormal depths in the target reservoir based on the total hydrocarbon values ​​at various depths, and determining the degree of anomalousness of the total hydrocarbon values ​​corresponding to each abnormal depth; and determining the degree of fracture development at each abnormal depth based on the degree of anomalousness of the total hydrocarbon values ​​corresponding to each abnormal depth. This method can quickly and cost-effectively identify fractures even in well locations with limited logging and seismic data. It can quickly, intuitively, cost-effectively, and quantitatively identify and locate fractures in shale formations, providing a basis for shale sweet spot evaluation and horizontal well fracturing.

[0141] Example 3

[0142] Based on Embodiment 1 and Embodiment 2, this embodiment illustrates the methods described in Embodiment 1 and Embodiment 2 through specific implementation examples.

[0143] In this embodiment, three well locations JY5, JY8, and SY3 of the Longmaxi Formation were selected as reference well locations (reference reservoirs).

[0144] Based on total hydrocarbon values ​​from gas logging and organic matter abundance (such as total organic carbon content, TOC), combined with fractures identified through core observation and imaging logging, a geological model for identifying shale fractures was established. Fractures were categorized according to their location: lower-level fractures (layers 1 to 5), middle-level fractures, and upper-level fractures.

[0145] Core observation revealed 14 and 10 bedding-parallel calcite shear fractures (tectonic fractures) in layers 3 and 4 at well location JY5, respectively. Layer 1 showed two locations with 18 small high-angle fracture networks, the longest of which was 40 cm. The formation dips steeply (approximately 30°).

[0146] like Figure 2As shown, gas logging data revealed that well JY5 belongs to a lower-developed shale section with high TOC values. Within this lower shale section, TOC values ​​are high and relatively stable with minimal variation. However, abrupt increases in total hydrocarbons occur in sub-layers 1 and 3, and between the top of sub-layer 3 and the bottom of sub-layer 4. Other formations are relatively smooth, likely due to fracture development. At well location JY5, the average TOC of sub-layers 8 and 9 is 1.33%, corresponding to an average total hydrocarbon value of 0.09, showing no significant anomaly in total hydrocarbons. Therefore, fractures are not developed in this section. At well location JY5, the average TOC of sub-layers 5 and 6 is 2.0%, stable, while the total hydrocarbon value fluctuates between 0.06 and 2.32%, with a positive correlation between total hydrocarbons and increasing TOC. Therefore, sub-layers 5 and 6 (middle part) show no anomaly in total hydrocarbons and no fracture development. At well location JY5, the average TOC at the bottom of sub-layer 4 is 2.7%, with a relatively significant abrupt increase in total hydrocarbons, indicating a fracture development section. In addition, in sub-layers 1 and 2, the average TOC is 3.4%, and the total hydrocarbon value suddenly increases from 1.56% to 13.01%, showing an abnormally high total hydrocarbon value. Therefore, sub-layers 1 and 2 are identified as fracture development sections. The above fracture development areas coincide with the steepening of the formation and the presence of bedding shear fractures (equivalent to medium-angle fractures) observed in the core. In other words, in the core, the high-angle fracture at well location JY5 only developed in the lower layer. Compared with the adjacent strata, the TOC value changed relatively little, while the total hydrocarbons in the gas analysis showed a sudden increase. The TOC value in the middle part of well location JY5 did not change abruptly, and the gas analysis was also relatively normal, which is consistent with the characteristic of undeveloped fractures in the core.

[0147] Core observations revealed that fractures were more developed at well location JY8. Six high-angle fractures were observed in the upper 7 to 9 layers, particularly concentrated between 2740m and 2758m. Seven high-angle fractures were observed in the middle 4 to 6 layers, with five of them at depths of 2782m to 2792m, each with a length greater than 0.3m. High-angle fractures were mainly observed in the lower 1 to 3 layers. Additionally, a large high-angle fracture with a length of 80cm was observed in the nodular limestone of the Linxiang Formation.

[0148] like Figure 3As shown, gas logging data revealed that well JY8 belongs to a centrally developed shale section with moderate TOC values. Within this central shale section, the TOC values ​​of layers 6 and 7 remained stable without anomalies. However, the total hydrocarbon data at well JY8 showed a sharp, abrupt increase in the total hydrocarbon response from the top of layer 4 to layer 7. These peaks reflect high-angle fracture development, corresponding to the fracture development locations observed in the core samples. In other words, the total hydrocarbon value at well JY8 in the nodular limestone of the Linxiang Formation also exhibited an abnormal peak, corresponding to a fracture development section, consistent with the high-angle fracture development observed in the core samples. Generally, limestone does not generate hydrocarbons; such high total hydrocarbon values ​​originate from the upper layer 1, indicating that fractures connect the upper layers, allowing shale gas to migrate downwards into the limestone.

[0149] Core observations revealed significant variations in the dip angle of the formation at well location SY3. A fault was encountered at layer 3, leading to the development of numerous repeated and fault-derived fractures in layers 1 to 3. Core data showed 93 high-angle fractures in layers 6 to 9, mainly distributed between 2669m and 2689m, with small and dense fracture openings.

[0150] In addition, such as Figure 4 As shown, imaging logging (FMI) results at well location SY3 indicate that layer 7 has a large number of high-resistance and high-conductivity fractures, layer 6 has relatively few fractures at the bottom, layers 1 to 5 and repeated layers 1 to 3 have a large number of fractures, and more than 100 high-angle fractures were observed in the core of the lower layers 1 to 3, forming a fracture network, which is concentrated in the well intervals of 2967m to 2980m and 2987 to 2991m.

[0151] like Figure 5As shown, gas logging data reveals that well SY3 belongs to an upper-developed shale section with low TOC values. Gas logging data from layers 1 to 9 at well SY3 shows significant fluctuations in total hydrocarbons; therefore, overall, fractures are more developed at well SY3 than at well JY5. In the upper shale section, the TOC values ​​of layers 8 and 9 are the lowest and remain relatively stable, while the total hydrocarbon values ​​of layers 8 and 9 are the highest, exhibiting an unusually high peak. At well location SY3, the average TOC at the top of layer 9 is 0.6%, with the total hydrocarbon value showing some fluctuation, suddenly increasing from 0.86% to 8.32% with a peak, indicating a fractured section in the core. At the bottom of layer 9 and the top of layer 8, the average TOC is 0.83%, with the total hydrocarbon value fluctuating between 0.83% and 4.79% without abnormal fluctuations, indicating relatively undeveloped fractures. At the bottom of layer 8 and layers 6 and 7, the average TOC is 0.93%, while the total hydrocarbon value shows an unusually steep increase with a peak, suddenly increasing from 1.21% to 11.28%, indicating a fractured section. Of course, layers 4 to 7 also show unusually high total hydrocarbon values ​​and peaks, which is consistent with the overall highly developed fractures observed or identified in the core and imaging logging of this well. The average TOC of layers 3 to 4 is 1.99%, with a slight increase from top to bottom. The total hydrocarbon value increases from 2.03% to 21.63%, indicating a significant anomaly in total hydrocarbons. Therefore, layers 3 to 4 are fracture-developed sections. In the repeated layers 1 to 3, the total hydrocarbon value of layers 1 to 2 increases significantly from 2.41% to 8.43%, indicating that these are all fracture-developed sections in the core.

[0152] In other words, at well location SY3, the overall fractures are very well developed, especially in the upper 7-9 layers and the lower 1-3 layers, where the corresponding total hydrocarbon values ​​are relatively high. In the middle 6 layers and some sections of the 5 layers, the fractures are relatively underdeveloped, and the corresponding total hydrocarbon values ​​are relatively stable.

[0153] In summary, the development of high-angle fractures in the core is consistent with the high values ​​and peaks of total hydrocarbon anomalies, and the fracture development section in shale corresponds to the high values ​​of total hydrocarbon anomalies in gas chromatography. This is because the presence of high-angle fractures in shale facilitates the flow of shale gas in nearby shale layers, leading to vertical migration of shale gas and the phenomenon of stratification. The distance of shale gas migration depends on the length of the fracture.

[0154] The total hydrocarbon values ​​at each depth in the above reference well location (reservoir) are normalized using the following formula to obtain the normalized results of the total hydrocarbon values ​​at each depth:

[0155]

[0156] Among them, H i0 This is the normalized result of the total hydrocarbon value measured at a depth of i.

[0157] H i The total hydrocarbon value measured at a depth of i;

[0158] H Min The maximum value of total hydrocarbon values ​​measured by gas at all depths (layers 1 to 9) in the target reservoir;

[0159] H Max It is the minimum total hydrocarbon value measured by gas at all depths (layers 1 to 9) in the target reservoir.

[0160] Subsequently, using the normalized total hydrocarbon values ​​from gas logging as the ordinate and organic matter plugging as the abscissa, a scatter plot was constructed at various depths within the aforementioned reference well locations (reservoirs), as shown below. Figure 6 As shown.

[0161] Among them, as TOC gradually increases, the normalized total hydrocarbon data (normalized results of gas logging total hydrocarbon values) are concentrated below 0.4, which also indicates that the total hydrocarbon values ​​of the above three reference well locations are considered normal if they do not exceed 30% of the maximum value; however, values ​​exceeding 0.4 are considered abnormal and are delineated as fracture-developed sections, such as... Figure 6 The upper-middle and upper-right regions defined by the black dashed lines (i.e., normalized total hydrocarbon value ≥ 0.4, TOC ≥ 0.5%) reflect the interruption between the abrupt, peak-like abnormally high total hydrocarbon value and the normal, smooth total hydrocarbon value. Therefore, 0.4 is used as the boundary line for abnormal values ​​of normalized total hydrocarbon (first preset threshold Value1), and 0.5% is used as the boundary line for abnormal values ​​of TOC (second preset threshold Value2), as the boundary for judging crack development, thereby constructing a quantitative crack identification map.

[0162] Based on this standard, and according to the determined first preset threshold Value1, the normalized total hydrocarbon value (0.4) at well location YJ5 is restored to the corresponding total hydrocarbon value of 3.96%, the total hydrocarbon value at well location JY8 is 5.72%, the total hydrocarbon value at well location SY1 is 3.97%, and the total hydrocarbon value at well location SY3 is 6.8%, and the location of fracture development in different wells is quantitatively determined.

[0163] It can be found that the fracture development sections obtained by the quantitative identification method at well locations such as JY5 and JY8 match the fractures observed by core or imaging logging quite well, which indicates the reliability of the quantitative method.

[0164] Subsequently, taking the target well locations (reservoirs) JY10 and PY1 as examples, the gas logging data for both are as follows: Figure 7 and 8 As shown, fractures can be directly identified in the absence of core samples and imaging logging data, and fracture-developed intervals can be qualitatively and effectively identified based on gas logging responses.

[0165] like Figure 7As shown, well JY10 is a fractured well with fractures in both the upper and lower sections. The top of layer 9, in the interval from 2627m to 2635m, shows an average total hydrocarbon content of 3.14%, exhibiting a significant anomaly and a spike, while the corresponding average logging TOC is 0.9%, indicating abnormally high total hydrocarbon content but low logging TOC, suggesting fracture development at the top of layer 9. However, the middle and bottom of layer 9 show no significant anomalies in total hydrocarbon content. Furthermore, layers 3 to 8 show total hydrocarbon values ​​fluctuating between 0.31% and 5.82%, with an average of 3.25%, and a corresponding average logging TOC of 1.98%. Notably, abnormal changes and spikes in total hydrocarbon content are observed at 2675m, 2690m, and 2747m, indicating the presence of fractures. Layers 1 to 2 show a sudden increase in total hydrocarbon content from 2.33% to 13.56%, exhibiting a spike, but the average logging TOC remains stable at 3.63%, indicating this section as a fractured region.

[0166] like Figure 8 As shown, well location PY1 belongs to the lower fracture type. The total hydrocarbon fluctuations in gas logging for layers 5 to 9 are not very significant. Overall, the variation in TOC logging is consistent with the corresponding variation in total hydrocarbon values. The average TOC logging value is 1.65%, and the corresponding total hydrocarbon value is 2.15%, indicating underdeveloped fractures. For layers 1 to 4, the average TOC logging value is 3.11%, with relatively stable changes and smooth TOC curves. The total hydrocarbon values ​​fluctuate greatly between 0.16% and 22.56%. Figure 8 The presence of abrupt changes and spikes indicates that crack segments have developed in layers 1, 3, and 4.

[0167] like Figure 9 As shown, further, based on the gas logging data, the fractures at well location PY1 were identified using the aforementioned quantitative identification method (quantitative identification map). It was found that well location PY1 contains four fracture development segments, namely between 2127.5m~2128.6m, 2133.2m~2134.6m, 2138.1m~2153.4m, and 2154.8m~2157.5m. Among them, the latter two segments have the highest total hydrocarbon values. Compared with adjacent segments with the same TOC value, the total hydrocarbon value shows a sudden increase, and the fractures in these two segments should be the most developed. Therefore, the fracture development zones at well location PY1 are determined to be between 2127.5m and 2128.6m in sub-layer 1, 2133.2m and 2134.6m in sub-layers 3 and 4, the top of sub-layer 5, and the bottom of sub-layer 6, between 2138.1m and 2153.4m and 2154.8m and 2157.5m.

[0168] Therefore, in gas logging where total hydrocarbons are abnormally high and spiked, while TOC is high and its variation is small or low, the intervals can be identified as fractured zones. This is because fractures connect to adjacent strata, allowing shale gas to spread through layers; on the other hand, fractures can also serve as shale gas enrichment sites. Therefore, when drilling encounters fractures, especially high-angle fractures, gas logging will show a high anomaly that does not match the TOC.

[0169] Example 4

[0170] Figure 10 Please refer to the structural schematic diagram of a reservoir fracture identification device provided in this application embodiment. Figure 10 This embodiment provides a reservoir fracture identification device 100, including an acquisition module 110, a first identification module 120, and a second identification module 130.

[0171] The acquisition module 110 is used to acquire gas logging data of the target reservoir; wherein, the gas logging data includes at least the total hydrocarbon values ​​of gas at various depth locations in the target reservoir;

[0172] The first identification module 120 is used to determine the abnormal depth location in the target reservoir based on the total hydrocarbon values ​​at each depth location in the target reservoir, and to determine the degree of abnormality of the total hydrocarbon values ​​at each abnormal depth location in the target reservoir.

[0173] The second identification module 130 is used to determine the degree of fracture development at each abnormal depth location in the target reservoir based on the degree of abnormality of the total hydrocarbon values ​​at each abnormal depth location in the target reservoir.

[0174] Optionally, the gas logging data may also include organic matter abundance;

[0175] The first identification module 120 is also used for:

[0176] The locations of abnormal depths in the target reservoir are determined based on the total hydrocarbon values ​​and organic matter abundance at various depths.

[0177] Optionally, the first identification module 120 includes:

[0178] The normalization unit is used to normalize the total hydrocarbon values ​​at each depth location in the target reservoir to obtain the normalized results of the total hydrocarbon values ​​at each depth location in the target reservoir.

[0179] The first determining unit is used to determine the abnormal depth location in the target reservoir based on the normalized result of the total hydrocarbon value measured by gas at each depth location in the target reservoir and the organic matter abundance at each depth location in the target reservoir.

[0180] Wherein, the normalized result of the total hydrocarbon value of the gas measurement at the abnormal depth location in the target reservoir is greater than or equal to the first preset threshold, and the corresponding organic matter abundance is greater than or equal to the second preset threshold.

[0181] Optionally, the first preset threshold is determined through the following steps:

[0182] Obtain gas logging data, core data, and imaging logging data from the reference reservoir;

[0183] The total hydrocarbon values ​​at each depth location in the reference reservoir are normalized to obtain the normalized results of the total hydrocarbon values ​​at each depth location in the reference reservoir.

[0184] Fracture identification is performed on the core data and imaging logging data of the reference reservoir to determine the fracture development at various depths in the reference reservoir.

[0185] The first preset threshold is determined based on the normalized results of the total hydrocarbon values ​​at each depth location in the reference reservoir and the fracture development at each depth location in the reference reservoir.

[0186] Optionally, the second preset threshold is determined through the following steps:

[0187] The second preset threshold is determined based on the organic matter abundance at each depth location in the reference reservoir and the fracture development at each depth location in the reference reservoir.

[0188] Optionally, the normalization unit is also used for:

[0189] The total hydrocarbon values ​​at each depth in the target reservoir are normalized using the following formula to obtain the normalized results of the total hydrocarbon values ​​at each depth in the target reservoir:

[0190]

[0191] Among them, H i0 This is the normalized result of the total hydrocarbon value measured at a depth of i.

[0192] H i The total hydrocarbon value measured at a depth of i;

[0193] H Min The maximum value of total hydrocarbon measurements at all depths in the target reservoir;

[0194] H Max It is the minimum total hydrocarbon value measured at all depths in the target reservoir.

[0195] Optionally, the second identification module 130 includes:

[0196] The calculation unit is used to calculate the difference between the normalized result of the total hydrocarbon value measured by gas at each abnormal depth location in the target reservoir and the first preset threshold.

[0197] The second determining unit is used to determine the degree of abnormality of the total hydrocarbon values ​​at each abnormal depth location in the target reservoir based on the difference between the normalized result of the total hydrocarbon values ​​at each abnormal depth location in the target reservoir and the first preset threshold.

[0198] Optionally, the organic matter abundance includes the organic carbon content.

[0199] Optionally, the degree of fracture development at each abnormal depth location in the target reservoir is positively correlated with the degree of abnormality in the corresponding total hydrocarbon values ​​measured by gas chromatography.

[0200] Specific embodiments of the reservoir fracture identification method based on the above modules have been described in detail in Embodiment 1 and Embodiment 2, and will not be repeated here.

[0201] Example 5

[0202] This embodiment provides an electronic device, which may be a mobile phone, computer, or tablet computer, etc., including a memory and a processor. The memory stores a calculator program, which, when executed by the processor, implements the reservoir fracture identification method as described in Embodiment 1 or Embodiment 2. It is understood that the electronic device may further include an input / output (I / O) interface and communication components.

[0203] The processor is used to execute all or part of the steps in the reservoir fracture identification method as described in Embodiment 1 or Embodiment 2. The memory is used to store various types of data, which may include, for example, instructions for any application or method in the electronic device, as well as application-related data.

[0204] The processor may be implemented as an Application Specific Integrated Circuit (ASIC), Digital Signal Processor (DSP), Digital Signal Processing Device (DSPD), Programmable Logic Device (PLD), Field Programmable Gate Array (FPGA), controller, microcontroller, microprocessor, or other electronic components, and is used to execute the reservoir fracture identification method in Embodiment 1 or Embodiment 2 above.

[0205] The memory can be implemented by any type of volatile or non-volatile storage device or a combination thereof, such as Static Random Access Memory (SRAM), Electrically Erasable Programmable Read-Only Memory (EEPROM), Erasable Programmable Read-Only Memory (EPROM), Programmable Read-Only Memory (PROM), Read-Only Memory (ROM), magnetic storage, flash memory, magnetic disk, or optical disk.

[0206] Example 6

[0207] This embodiment also provides a computer-readable storage medium, such as flash memory, hard disk, multimedia card, card-type memory (e.g., SD or DX memory), random access memory (RAM), static random access memory (SRAM), read-only memory (ROM), electrically erasable programmable read-only memory (EEPROM), programmable read-only memory (PROM), magnetic memory, disk, optical disk, server, app store, etc., which stores a computer program. When the computer program is executed by a processor, it can implement the following method steps:

[0208] Step S110: Obtain gas logging data of the target reservoir; wherein the gas logging data includes at least the total hydrocarbon values ​​at various depths in the target reservoir;

[0209] Step S120: Based on the total hydrocarbon values ​​at various depths in the target reservoir, determine the location of the abnormal depth in the target reservoir, and determine the degree of abnormality of the total hydrocarbon values ​​at each abnormal depth in the target reservoir.

[0210] Step S130: Determine the degree of fracture development at each abnormal depth location in the target reservoir based on the degree of anomalousness of the total hydrocarbon values ​​at each abnormal depth location.

[0211] For specific implementation details of the above method steps, please refer to Embodiment 1 and Embodiment 2. These details will not be repeated here.

[0212] In summary, this application provides a reservoir fracture identification method, apparatus, electronic device, and storage medium. The method includes acquiring gas logging data of a target reservoir; wherein the gas logging data includes at least the total hydrocarbon values ​​at various depths in the target reservoir; determining the locations of abnormal depths in the target reservoir based on the total hydrocarbon values ​​at various depths, and determining the degree of anomalousness of the total hydrocarbon values ​​corresponding to each abnormal depth; and determining the degree of fracture development at each abnormal depth based on the degree of anomalousness of the total hydrocarbon values ​​corresponding to each abnormal depth. This method can quickly and cost-effectively identify fractures even in well locations with limited logging and seismic data. It can quickly, intuitively, cost-effectively, and quantitatively identify and locate fractures in shale formations, providing a basis for shale sweet spot evaluation and horizontal well fracturing.

[0213] It should be noted that, in this document, the terms "comprising," "including," or any other variations thereof are intended to cover non-exclusive inclusion, such that a process, method, article, or apparatus that comprises a list of elements includes not only those elements but also other elements not expressly listed, or elements inherent to such a process, method, article, or apparatus. Unless otherwise specified, an element defined by the phrase "comprising one..." does not exclude the presence of other identical elements in the process, method, article, or apparatus that includes said element.

[0214] Although the embodiments disclosed in this application are as described above, the content is merely for the purpose of facilitating understanding of this application and is not intended to limit this application. Any person skilled in the art to which this application pertains may make any modifications and changes in the form and details of the implementation without departing from the spirit and scope disclosed in this application; however, the scope of patent protection of this application shall still be determined by the scope defined in the appended claims.

Claims

1. A method for identifying reservoir fractures, characterized in that, The method includes: Obtain gas logging data of the target reservoir; wherein, the gas logging data includes at least the total hydrocarbon values ​​at various depths in the target reservoir; the gas logging data also includes organic matter abundance; Based on the total hydrocarbon and organic matter abundance at various depths in the target reservoir, the abnormal depth locations in the target reservoir are determined, and the degree of abnormality of the total hydrocarbon values ​​at each abnormal depth location in the target reservoir is determined. Based on the degree of anomaly in the total hydrocarbon values ​​at each anomaly depth in the target reservoir, the degree of fracture development at each anomaly depth in the target reservoir is determined. Determining the location of abnormal depths in the target reservoir based on total hydrocarbon values ​​and organic matter abundance at various depths includes the following steps: The total hydrocarbon values ​​measured at each depth in the target reservoir are normalized to obtain the normalized results of the total hydrocarbon values ​​measured at each depth in the target reservoir. Based on the normalized results of the total hydrocarbon values ​​at each depth location in the target reservoir and the organic matter abundance at each depth location in the target reservoir, the abnormal depth locations in the target reservoir are determined. Wherein, the normalized result of the total hydrocarbon value of the gas measurement at the abnormal depth location in the target reservoir is greater than or equal to the first preset threshold, and the corresponding organic matter abundance is greater than or equal to the second preset threshold.

2. The method according to claim 1, characterized in that, The first preset threshold is determined through the following steps: Obtain gas logging data, core data, and imaging logging data from the reference reservoir; The total hydrocarbon values ​​at each depth location in the reference reservoir are normalized to obtain the normalized results of the total hydrocarbon values ​​at each depth location in the reference reservoir. Fracture identification is performed on the core data and imaging logging data of the reference reservoir to determine the fracture development at various depths in the reference reservoir. The first preset threshold is determined based on the normalized results of the total hydrocarbon values ​​at each depth location in the reference reservoir and the fracture development at each depth location in the reference reservoir.

3. The method according to claim 2, characterized in that, The second preset threshold is determined through the following steps: The second preset threshold is determined based on the organic matter abundance at each depth location in the reference reservoir and the fracture development at each depth location in the reference reservoir.

4. The method according to claim 1, characterized in that, The normalization of total hydrocarbon values ​​at various depths in the target reservoir is performed to obtain normalized results for the total hydrocarbon values ​​at various depths in the target reservoir, including the following steps: The total hydrocarbon values ​​at each depth in the target reservoir are normalized using the following formula to obtain the normalized results of the total hydrocarbon values ​​at each depth in the target reservoir: in, This represents the normalized result of the total hydrocarbon value measured at depth i. Let i be the total hydrocarbon value measured at a depth of i. This refers to the maximum total hydrocarbon value measured at all depths within the target reservoir. It is the minimum total hydrocarbon value measured at all depths in the target reservoir.

5. The method according to claim 1, characterized in that, Determining the degree of anomaly in the total hydrocarbon values ​​at each anomalous depth location in the target reservoir includes the following steps: Calculate the difference between the normalized result of the total hydrocarbon value measured by gas at each abnormal depth location in the target reservoir and the first preset threshold. The degree of anomalousness of the total hydrocarbon values ​​at each anomalous depth location in the target reservoir is determined based on the difference between the normalized result of the total hydrocarbon values ​​at each anomalous depth location and the first preset threshold.

6. The method according to claim 1, characterized in that, The organic matter abundance includes the organic carbon content.

7. The method according to claim 1, characterized in that, The degree of fracture development at each anomalous depth location in the target reservoir is positively correlated with the degree of anomalousness of the corresponding total hydrocarbon values ​​in gas chromatography.

8. A reservoir fracture identification device, characterized in that, The device includes: The acquisition module is used to acquire gas logging data of the target reservoir; wherein, the gas logging data includes at least the total hydrocarbon values ​​at various depths in the target reservoir; the gas logging data also includes organic matter abundance. The first identification module is used to determine the abnormal depth location in the target reservoir based on the total hydrocarbon value and organic matter abundance at each depth location in the target reservoir, and to determine the degree of abnormality of the total hydrocarbon value corresponding to each abnormal depth location in the target reservoir. The second identification module is used to determine the degree of fracture development at each abnormal depth location in the target reservoir based on the degree of abnormality of the total hydrocarbon values ​​at each abnormal depth location in the target reservoir. The first identification module includes: The normalization unit is used to normalize the total hydrocarbon values ​​at each depth location in the target reservoir to obtain the normalized results of the total hydrocarbon values ​​at each depth location in the target reservoir. The first determining unit is used to determine the abnormal depth location in the target reservoir based on the normalized result of the total hydrocarbon value measured by gas at each depth location in the target reservoir and the organic matter abundance at each depth location in the target reservoir. Wherein, the normalized result of the total hydrocarbon value of the gas measurement at the abnormal depth location in the target reservoir is greater than or equal to the first preset threshold, and the corresponding organic matter abundance is greater than or equal to the second preset threshold.

9. An electronic device, characterized in that, It includes a memory and a processor, wherein the memory stores a computer program that, when executed by the processor, performs the reservoir fracture identification method as described in any one of claims 1 to 7.

10. A storage medium, characterized in that, The computer program stored in the storage medium can be executed by one or more processors and can be used to implement the reservoir fracture identification method as described in any one of claims 1 to 7.

Images