Shale gas content prediction method and device and electronic equipment

Abstract

The invention relates to the technical field of shale gas exploration, and discloses a shale gas content prediction method and device and electronic equipment. According to the shale gas content prediction method, hydrocarbon generation efficiency of different evolution degrees and a total organic carbon recovery coefficient of to-be-predicted shale are obtained; acquiring data of the shale to be predicted; the total shale gas generation amount per unit mass in different evolution stages is calculated through a formula (1); obtaining the storage coefficient of the prediction target area and the dynamic change of the prediction target area in the geological period; the dynamic change of the shale gas content is obtained through the unit mass shale gas generation amount in the different evolution stages and the storage coefficient, and the total shale gas content in the different evolution stages is obtained through a formula (2). According to the technical scheme, dynamic prediction of the gas content of the shale in the geological period is achieved based on changes of the gas generation capacity and the storage capacity of the shale in the geological period, the purpose of analyzing and evaluating the gas content of the shale is achieved, and the method has important application value in the fields of unconventional oil-gas exploration and the like.

Description

Technical Field

[0001] The present invention relates to the technical field of shale gas exploration, and in particular to a method, a device and an electronic device for predicting shale gas content. Background Art

[0002] Shale gas refers to natural gas that exists in organic-rich shale layers in free, adsorbed, and dissolved states, among which free and adsorbed states are the main forms of existence. Changes in pore structure, temperature, pressure and other conditions have an important impact on shale gas content and free gas content, but shale gas content is more constrained by its own gas generation capacity and preservation coefficient. The total amount of natural gas contained in shale is affected by both the amount of natural gas generated and the amount of natural gas that escapes through diffusion. However, the accumulation and enrichment of natural gas in shale is a dynamic geological process. The gas content and gas structure of shale will change with changes in geological conditions, and even change over time under the influence of diffusion.

[0003] At present, the analysis and evaluation of shale gas content runs through the whole process from shale gas exploration and evaluation to development and production. According to the type of data basis and process flow, the methods for obtaining shale gas content parameters mainly include six types: pre-drilling seismic interpretation, drilling-logging-well interpretation, field testing, experimental calculation, geological analysis and production testing.

[0004] The invention with patent number CN20211136937.2 proposes an artificial intelligence prediction method for shale gas content based on machine learning. It removes outliers from the measured values ​​of core gas content, normalizes the P-wave velocity, density, natural gamma and measured gas content, and then introduces relaxation variables and uses data mapping to build a support vector regression prediction model. The P-wave velocity and density are used as inputs, and the shale core gas content is used as output. The support vector regression prediction model is used to obtain the predicted gas content based on leave-one-out cross validation; or the natural gamma, P-wave velocity, and density are used as inputs, and the shale core gas content is used as output. The support vector regression prediction model is used to obtain the predicted gas content based on leave-one-out cross validation. The invention uses machine learning methods to obtain high-precision shale gas content through core, logging and seismic data.

[0005] The invention with patent number CN201910423134.7 proposes a method and system for calculating the gas content of shale formations. A visualization view corresponding to the formation to be measured is established based on the element logging data of the formation to be measured, and the maximum relative content of the silicon element in the irrelevant part of the view is selected as the demarcation element value of the element logging data of the formation to be measured; and the demarcation element value is used to calculate and determine the combination value of the gas content sensitive elements of the formation to be measured; then the combination value of the gas content sensitive elements of the formation to be measured is input into a gas content determination model constructed using training formation data at the same depth as the formation to be measured, and the output data of the model is the gas content result of the formation to be measured.

[0006] The invention with patent number CN202010947411.7 proposes a shale gas content prediction method, device, electronic equipment and medium, by respectively determining the main controlling factors of shale adsorbed gas, free gas and dissolved gas in the current work area; according to the regression analysis method, respectively establish adsorbed gas, free gas and dissolved gas content prediction models; based on the prediction model, establish a shale gas content prediction model to achieve the purpose of effectively and systematically predicting shale adsorbed gas, free gas, dissolved gas and total gas content.

[0007] The invention with patent number CN201711290825.1 proposes a method and device for determining the gas content of shale. By fitting the isothermal adsorption data of organic matter and the isothermal adsorption data of clay minerals respectively, the adsorption gas volume map of organic matter and the adsorption gas volume map of clay minerals are obtained; the organic matter adsorption amount of organic matter under formation temperature and formation pressure is determined from the adsorption gas volume map of organic matter, and the clay mineral adsorption amount of clay minerals under formation temperature and formation pressure is determined from the adsorption gas volume map of clay minerals; based on the organic matter adsorption amount, the clay mineral adsorption amount and formation parameter information, the shale gas content at the drilling position in the target shale reservoir is determined.

[0008] The invention with patent number CN201810705447.7 proposes a method for calculating shale gas content, which first collects experimental data and then inputs the collected experimental data into a shale gas content calculation model to obtain the shale gas content under reservoir conditions, or inputs the collected experimental data into the shale gas content calculation model to obtain a curve of pressure and shale gas content, and then obtains the shale gas content under reservoir conditions from the curve.

[0009] The basic principles, key points and conditions of use of the methods in the above patents are different, but they are mainly static representations of the current shale gas content, while ignoring the dynamic changes of shale's own gas generation and preservation capabilities in geological periods. Therefore, it is particularly important to develop a dynamic prediction method for shale gas content based on shale's own gas generation and preservation coefficients. Summary of the invention

[0010] The present application provides a shale gas content prediction method, device and electronic equipment to solve the above-mentioned technical problem that the prior art ignores the dynamic changes of shale's own gas generation and preservation capabilities in geological periods.

[0011] According to one aspect of the present application, an embodiment provides a method for predicting shale gas content, including:

[0012] Obtaining hydrocarbon generation efficiency and total organic carbon recovery coefficient of different evolution degrees of shale to be predicted, wherein the shale to be predicted is selected from immature shales of different organic matter types;

[0013] Acquiring data of the shale to be predicted, wherein the data includes residual total organic carbon, organic matter type and thermal evolution degree of organic matter;

[0014] The total gas production per unit mass of shale at different evolution stages is calculated using the following formula:

[0015] G 生 =TOC 残余 ×f×R 气 (1)

[0016] In the formula, G 生 is the total gas generation per unit mass of shale, in m 3 / t;TOC 残余 is the residual organic carbon, in %; f is the total organic carbon recovery coefficient at different evolution stages; R 气 is the shale hydrocarbon generation efficiency, in m 3 / t.toc;

[0017] Obtain the preservation coefficient of the predicted target area and its dynamic changes in geological time;

[0018] The dynamic change of shale gas content is obtained by using the shale gas production per unit mass at different evolution stages and the preservation coefficient, wherein the total shale gas content at different evolution stages is obtained by formula (2):

[0019] G=G 生 ×k (2)

[0020] Where G is the total gas content of shale, in m 3 / t;G 生 is the total gas generation per unit mass of shale, in m 3 / t; k is the preservation coefficient at different evolution stages.

[0021] In one embodiment, the immature shale refers to shale with organic matter abundance, organic matter type and mineral composition similar to those of the shale formation in the predicted target area, and a vitrinite reflectance Ro or an equivalent vitrinite reflectance less than or equal to 0.7%.

[0022] In one embodiment, the hydrocarbon generation efficiency refers to the hydrocarbon generation per unit mass of organic matter, and the hydrocarbon generation per unit mass of organic matter includes oil generation and gas generation; and / or,

[0023] The total organic carbon recovery coefficient refers to the ratio of the original total organic carbon to the residual total organic carbon at different evolution stages.

[0024] In one embodiment, the hydrocarbon generation efficiency and the organic carbon recovery coefficient are obtained by a hydrocarbon generation thermal simulation experiment; the hydrocarbon generation thermal simulation experiment is carried out using a metal autoclave, a glass tube, a gold tube-autoclave, a diamond pressure chamber, a compaction simulation or a formation pore hot pressure hydrocarbon generation and expulsion simulation experiment.

[0025] In one embodiment, the residual total organic carbon refers to the residual organic matter content of the source rock after hydrocarbon generation and expulsion; and / or,

[0026] The degree of thermal evolution of organic matter is obtained by one or more parameters including burial depth, measured formation temperature, vitrinite reflectance, soluble organic matter conversion rate, sterane and terpene isomerization parameters, rock pyrolysis parameters, and kerogen H / C and O / C atomic ratio.

[0027] In one embodiment, the residual organic matter content is obtained by one or more methods including well logging interpretation, field testing, and experimental calculation.

[0028] In one embodiment, the preservation coefficient and its dynamic changes during geological periods are obtained by analogy with known areas.

[0029] According to one aspect of the present application, an embodiment provides a shale gas content prediction device, comprising:

[0030] The first acquisition module is used to obtain the hydrocarbon generation efficiency and total organic carbon recovery coefficient of different evolution degrees of the shale to be predicted, wherein the shale to be predicted is selected from immature shales of different organic matter types;

[0031] A second acquisition module is used to acquire data of the shale to be predicted, wherein the data includes residual total organic carbon, organic matter type and thermal evolution degree of organic matter;

[0032] The first processing module is used to calculate the total gas generation per unit mass of shale at different evolution stages. The calculation formula is:

[0033] G 生 =TOC 残余 ×f×R 气 (1)

[0034] In the formula, G 生 is the total gas generation per unit mass of shale, in m 3 / t;TOC 残余is the residual organic carbon, in %; f is the total organic carbon recovery coefficient at different evolution stages; R 气 is the shale hydrocarbon generation efficiency, in m 3 / t.toc;

[0035] A third acquisition module is used to obtain the preservation coefficient of the predicted target area and its dynamic changes in the geological period; and

[0036] The second processing module is used to obtain the dynamic change of shale gas content by using the shale gas production per unit mass at different evolution stages and the preservation coefficient, wherein the total shale gas content at different evolution stages is obtained by formula (2):

[0037] G=G 生 ×k (2)

[0038] Where G is the total gas content of shale, in m 3 / t;G 生 is the total gas generation per unit mass of shale, in m 3 / t; k is the preservation coefficient at different evolution stages.

[0039] According to one aspect of the present application, an embodiment provides an electronic device, including:

[0040] Memory; and

[0041] processor;

[0042] Wherein, the memory is used to store one or more computer instructions; the one or more computer instructions are executed by the processor to implement the shale gas content prediction method as described in any one of the above.

[0043] According to one aspect of the present application, an embodiment provides a readable storage medium having computer instructions stored thereon; wherein, when the computer instructions are executed by a processor, a shale gas content prediction method as described in any one of the above items is implemented.

[0044] The technical solutions of the above embodiments of the present application start from the shale's own gas generation and preservation capabilities, and based on the changes in the shale's own gas generation and preservation capabilities during the geological period, realize the dynamic prediction of the shale gas content during the geological period, and achieve the purpose of analyzing and evaluating the gas content of shale, which has important application value in the fields of unconventional oil and gas exploration. BRIEF DESCRIPTION OF THE DRAWINGS

[0045] Figure 1 is a flow chart of a method for predicting shale gas content in an embodiment;

[0046] Figure 2 is a flow chart of a method for predicting shale gas content in an embodiment;

[0047] Figure 3 is a schematic diagram of hydrocarbon generation efficiency at different evolution stages in an embodiment;

[0048] Figure 4 is a schematic diagram of the total organic carbon recovery coefficient at different evolution stages in an embodiment;

[0049] Figure 5 is a schematic diagram of obtaining an analog area preservation coefficient in an embodiment;

[0050] Figure 6 The following is a schematic diagram of the prediction results of the total gas content of shale at different evolution stages and the comparison with the total gas content of well logging in an embodiment;

[0051] Figure 7 The present invention is a structural diagram of a shale gas content prediction device in an embodiment. DETAILED DESCRIPTION

[0052] It should be noted that, in the absence of conflict, the embodiments and features in the embodiments of the present application can be combined with each other. The present application will be described in detail below with reference to the accompanying drawings and in combination with the embodiments.

[0053] In order to enable those skilled in the art to better understand the present application, the technical solutions in the embodiments of the present application will be clearly and completely described below in conjunction with the drawings in the embodiments of the present application. Obviously, the described embodiments are only embodiments of a part of the present application, not all embodiments. Based on the embodiments in the present application, all other embodiments obtained by ordinary technicians in the field without creative work should fall within the scope of protection of the present application.

[0054] It should be noted that the terms "first", "second" etc. in the present application are used to distinguish similar objects, and need not be used to describe a specific order or sequential order. It should be understood that the data used in this way can be interchanged in appropriate circumstances, so that the embodiments of the present application described here. In addition, the terms "including" and "having" and any of their variations are intended to cover non-exclusive inclusions, for example, the process, method, system, product or equipment comprising a series of steps or units need not be limited to those steps or units clearly listed, but may include other steps or units that are not clearly listed or inherent to these processes, methods, products or equipment.

[0055] It should be understood that when an element (such as a layer, film, region, or substrate) is described as being "on" another element, the element may be directly on the other element, or there may be an intermediate element. Moreover, in this application, when an element is described as being "connected" to another element, the element may be "directly connected" to the other element, or "connected" to the other element through a third element.

[0056] Embodiment 1

[0057] Please refer to Figure 1 An embodiment provides a method for predicting shale gas content, comprising the following steps:

[0058] S1. Obtain the hydrocarbon generation efficiency and total organic carbon recovery coefficient of different evolutionary degrees of the shale to be predicted; wherein, the shale to be predicted is selected from immature shales of different organic matter types; the immature shale refers to shale with organic matter abundance, organic matter type and mineral composition similar to those of the shale formation in the prediction target area, and the vitrinite reflectance Ro or equivalent vitrinite reflectance is less than or equal to 0.7%. Preferably, according to actual conditions, the vitrinite reflectance Ro or equivalent vitrinite reflectance is less than or equal to 0.5%. wherein, the hydrocarbon generation efficiency refers to the amount of hydrocarbons generated per unit mass of organic matter, and the amount of hydrocarbons generated per unit mass of organic matter includes oil generation and gas generation. Preferably, the hydrocarbon generation efficiency refers to the amount of hydrocarbons generated per unit mass of organic matter obtained through a hydrocarbon generation thermal simulation experiment, including oil generation and gas generation. In addition, the total organic carbon recovery coefficient refers to the ratio of the original total organic carbon to the residual total organic carbon at different evolutionary stages.

[0059] Furthermore, the hydrocarbon generation efficiency and the organic carbon recovery coefficient are obtained by utilizing a hydrocarbon generation thermal simulation experiment; the hydrocarbon generation thermal simulation experiment is conducted by using a metal autoclave, a glass tube, a gold tube-autoclave, a diamond pressure chamber, a compaction simulation or a formation pore hot pressure hydrocarbon generation and expulsion simulation experiment.

[0060] S2. Acquire data of the shale to be predicted, wherein the data includes residual total organic carbon, organic matter type and thermal evolution degree of organic matter;

[0061] S3. Calculate the total gas generation per unit mass of shale at different evolution stages. The calculation formula is:

[0062] G 生 =TOC 残余 ×f×R 气 (1)

[0063] In the formula, G 生 is the total gas generation per unit mass of shale, in m 3 / t;TOC 残余 is the residual organic carbon, in %; f is the total organic carbon recovery coefficient at different evolution stages; R 气 is the shale hydrocarbon generation efficiency, in m 3 / t.toc. The residual total organic carbon refers to the residual organic matter content of the source rock after hydrocarbon generation and expulsion; preferably, the residual organic matter content is obtained by one or more methods of logging interpretation, field testing, and experimental calculation. In addition, the degree of thermal evolution of organic matter is obtained by one or more parameters of burial depth, measured formation temperature, vitrinite reflectance, soluble organic matter conversion rate, sterane and terpene isomerization parameters, rock pyrolysis parameters, and kerogen H / C and O / C atomic ratio.

[0064] S4. Obtain the preservation coefficient of the predicted target area and its dynamic changes in the geological period. The preservation coefficient and its dynamic changes in the geological period are obtained by analogy with known areas. More specifically, and with better results, the preservation coefficient and its dynamic changes in the geological period are obtained by the burial history, structural evolution process and degree of known wells in a unified preservation system or an analogous preservation system.

[0065] S5. The dynamic change of shale gas content is obtained by using the shale gas production per unit mass at different evolution stages and the preservation coefficient, wherein the total shale gas content at different evolution stages is obtained by formula (2):

[0066] G=G 生 ×k (2)

[0067] Where G is the total gas content of shale, in m 3 / t;G 生 is the total gas generation per unit mass of shale, in m 3 / t; k is the preservation coefficient at different evolution stages.

[0068] Regarding step S2, the reasoning process of formula (1) is:

[0069]

[0070] In the formula, G 生 is the total gas generation per unit mass of shale, in m 3 / t; S is the effective shale distribution area, unit is km 2 or m 2 ; H is the effective shale thickness, in m; ρ - shale density, g / cm 3 or t / m 3 ;TOC 残余 is the residual organic carbon, in %; f is the total organic carbon recovery coefficient at different evolution stages; R 气 is the shale hydrocarbon generation efficiency, in m 3 / t.toc.

[0071] The above-mentioned shale gas content prediction method, for gas-bearing shales, realizes the dynamic prediction of shale gas content based on the changes in the shale's own gas generation and preservation capabilities during the geological period, and achieves the purpose of analyzing and evaluating the gas content of shale. It has important application value in the fields of unconventional oil and gas exploration and other fields.

[0072] Embodiment 2

[0073] The following will describe the technical solution of the present invention with the thoughts of the inventor, which will help those skilled in the art to be familiar with the idea of ​​the present invention. Among them, some technical points are explained in detail, so that those skilled in the art can fully understand the technical solution of the present invention.

[0074] Please refer to Figure 2-Figure 6 An embodiment provides a method for predicting shale gas content, comprising the following steps:

[0075] Step 101. Select immature shales of different organic matter types and use a hydrocarbon generation thermal simulation experiment to obtain hydrocarbon generation efficiency and organic carbon recovery coefficient of shales of different evolution degrees;

[0076] Step 102. Obtain data on residual total organic carbon, organic matter type, and thermal evolution degree of organic matter in the shale to be predicted;

[0077] Step 103: Calculate and obtain the total gas generation per unit mass of shale at different evolution stages;

[0078] Step 104. Obtain the preservation coefficient of the predicted target area and its dynamic changes in the geological period by analogy with the known area;

[0079] Step 105: Obtain the dynamic change of shale gas content using the shale gas production per unit mass and preservation coefficient at different evolution stages.

[0080] In one example, in step 101, immature shale refers to shale with similar organic matter abundance, organic matter type, and mineral composition to the shale formation in the prediction area, and a vitrinite reflectance Ro (or equivalent vitrinite reflectance) less than or equal to 0.5%. According to actual conditions, Ro can be relaxed to a maximum of 0.7%.

[0081] In one example, the hydrocarbon generation efficiency refers to the amount of gas generated per unit mass of organic matter obtained through a hydrocarbon generation thermal simulation experiment. Figure 3 A schematic diagram of gas generation efficiency at different evolution stages is shown. Further, in step 101, the thermal simulation experiment is a formation pore thermal pressure hydrocarbon generation and expulsion simulation experiment.

[0082] In one instance, the total organic carbon recovery factor refers to the ratio of the original total organic carbon to the residual total organic carbon at different evolutionary stages; Figure 4A schematic diagram of the total organic carbon recovery coefficient at different evolution stages of the formation pore thermal pressure hydrocarbon generation and expulsion simulation experiment is shown.

[0083] In one example, the residual total organic carbon refers to the residual organic matter content of the source rock after hydrocarbon generation and expulsion, which can be obtained through experimental testing.

[0084] In one example, the degree of thermal evolution of organic matter can be obtained by burial depth and measured formation temperature, vitrinite reflectance, etc.

[0085] In one example, the total gas generation per unit mass of shale at different evolution stages can be obtained by formula (1):

[0086]

[0087] In the formula, G 生 is the total gas generation per unit mass of shale, in m 3 / t; S is the effective shale distribution area, unit is km 2 or m 2 ; H is the effective shale thickness, in m; ρ is the shale density, in g / cm 3 or t / m 3 ;TOC 残余 is the residual organic carbon, in %; f is the total organic carbon recovery coefficient at different evolution stages; R 气 is the shale hydrocarbon generation efficiency, in m 3 / t.toc.

[0088] In one example, the preservation coefficient and its dynamic changes in geological time can be obtained by the burial history and structural evolution process and degree of a unified preservation system or a known well that can be compared to the preservation system. Figure 5 A schematic diagram showing the analog zone preservation coefficients.

[0089] In one example, the total gas content of shale at different evolution stages can be obtained by formula (2):

[0090] G=G 生 ×k (2)

[0091] Where G is the total gas content of shale, in m 3 / t;G 生 is the total gas generation per unit mass of shale, in m 3 / t; k is the preservation coefficient at different evolution stages. Figure 6 The results of total gas content prediction of shale at different evolution stages and the comparison with total gas content from well logging are shown.

[0092] Embodiment 3

[0093] Please refer to Figure 7An embodiment provides a shale gas content prediction device, wherein:

[0094] The first acquisition module 10 is used to obtain the hydrocarbon generation efficiency and total organic carbon recovery coefficient of different evolutionary degrees of the shale to be predicted, wherein the shale to be predicted is selected from immature shales of different organic matter types, and the immature shale refers to shale with organic matter abundance, organic matter type and mineral composition similar to those of the shale formation in the prediction target area, and the vitrinite reflectance Ro or equivalent vitrinite reflectance is less than or equal to 0.7%, the hydrocarbon generation efficiency refers to the hydrocarbon generation per unit mass of organic matter, and the hydrocarbon generation per unit mass of organic matter includes oil generation and gas generation, and the total organic carbon recovery coefficient refers to the ratio of the original total organic carbon to the residual total organic carbon at different evolutionary stages; wherein the hydrocarbon generation efficiency and the organic carbon recovery coefficient are obtained by using a hydrocarbon generation thermal simulation experiment; the hydrocarbon generation thermal simulation experiment is carried out by using a metal autoclave, a glass tube, a gold tube-autoclave, a diamond pressure chamber, a compaction simulation or a formation pore hot pressure hydrocarbon generation and expulsion simulation experiment;

[0095] The second acquisition module 20 is used to acquire the data of the shale to be predicted, wherein the data includes residual total organic carbon, organic matter type and organic matter thermal evolution degree, the residual total organic carbon refers to the residual organic matter content of the source rock after hydrocarbon generation and expulsion, and the organic matter thermal evolution degree is obtained by one or more parameters selected from burial depth, measured formation temperature, vitrinite reflectance, soluble organic matter conversion rate, sterane and terpene isomerization parameters, rock pyrolysis parameters, and kerogen H / C and O / C atomic ratio; wherein the residual organic matter content is obtained by one or more methods selected from well logging interpretation, field testing, and experimental calculation;

[0096] The first processing module 30 is used to calculate the total gas generation per unit mass of shale at different evolution stages. The calculation formula is:

[0097] G 生 =TOC 残余 ×f×R 气 (1)

[0098] In the formula, G 生 is the total gas generation per unit mass of shale, in m 3 / t;TOC 残余 is the residual organic carbon, in %; f is the total organic carbon recovery coefficient at different evolution stages; R 气 is the shale hydrocarbon generation efficiency, in m 3 / t.toc;

[0099] The third acquisition module 40 is used to obtain the preservation coefficient of the predicted target area and its dynamic changes in the geological period by analogy with the known area;

[0100] The second processing module 50 is used to obtain the dynamic change of shale gas content by using the shale gas production per unit mass at different evolution stages and the preservation coefficient, wherein the total shale gas content at different evolution stages is obtained by formula (2):

[0101] G=G 生 ×k (2)

[0102] Where G is the total gas content of shale, in m 3 / t;G 生 is the total gas generation per unit mass of shale, in m 3 / t; k is the preservation coefficient at different evolution stages.

[0103] It should be noted that the above-mentioned shale gas content prediction device is used to implement the shale gas content prediction method in the above-mentioned embodiments, and each module in the device corresponds to each step in the method.

[0104] Embodiment 4

[0105] Based on the same inventive concept, an embodiment of the present application provides an electronic device, comprising: a memory and a processor; wherein the memory is used to store one or more computer instructions; the one or more computer instructions are executed by the processor to perform the shale gas content prediction method described in any one of the above embodiments.

[0106] Embodiment 5

[0107] Based on the same inventive concept, an embodiment of the present application provides a readable storage medium, on which computer instructions are stored; wherein, when the computer instructions are executed by a processor, the shale gas content prediction method described in any one of the above embodiments is implemented.

[0108] Among them, the above one or more computer instructions can be formed into a program.

[0109] The above program can be run in the processor, or it can be stored in the memory (or computer-readable medium), which includes permanent and non-permanent, removable and non-removable media. Information storage can be achieved by any method or technology. Information can be computer-readable instructions, data structures, program modules or other data. Examples of computer storage media include, but are not limited to, phase change memory (PRAM), static random access memory (SRAM), dynamic random access memory (DRAM), other types of random access memory (RAM), read-only memory (ROM), electrically erasable programmable read-only memory (EEPROM), flash memory or other memory technology, read-only compact disk read-only memory (CD-ROM), digital versatile disk (DVD) or other optical storage, magnetic cassettes, tape disk storage or other magnetic storage devices or any other non-transmission media that can be used to store information that can be accessed by a computing device. As defined in this article, computer-readable media does not include transitory computer-readable media (transit media), such as modulated data signals and carrier waves.

[0110] These computer programs can also be loaded onto a computer or other programmable data processing device so that a series of operating steps are executed on the computer or other programmable device to produce a computer-implemented process, so that the instructions executed on the computer or other programmable device provide instructions for implementing the process. Figure 1 A process or multiple processes and / or boxes Figure 1 The steps of the functions specified in one or more blocks can be implemented by different modules corresponding to different steps.

[0111] The above description is only the preferred embodiment of the present application and is not intended to limit the present application. For those skilled in the art, the present application may have various modifications and variations. Any modification, equivalent replacement, improvement, etc. made within the spirit and principle of the present application shall be included in the protection scope of the present application.

Claims

1. A method for predicting shale gas content, characterized in that: include: Obtaining hydrocarbon generation efficiency and total organic carbon recovery coefficient of different evolution degrees of shale to be predicted, wherein the shale to be predicted is selected from immature shales of different organic matter types; Acquiring data of the shale to be predicted, wherein the data includes residual total organic carbon, organic matter type and thermal evolution degree of organic matter; The total gas production per unit mass of shale at different evolution stages is calculated using the following formula: G 生 =TOC 残余 ×f×R 气 (1) In the formula, G 生 is the total gas generation per unit mass of shale, in m 3 / t;TOC 残余 is the residual organic carbon, in %; f is the total organic carbon recovery coefficient at different evolution stages; R 气 is the shale hydrocarbon generation efficiency, unit is m 3 / t.toc; Obtain the preservation coefficient of the predicted target area and its dynamic changes in geological time; The dynamic change of shale gas content is obtained by using the shale gas production per unit mass at different evolution stages and the preservation coefficient, wherein the total shale gas content at different evolution stages is obtained by formula (2): G=G 生 ×k(2) Where G is the total gas content of shale, in m 3 / t;G 生 is the total gas generation per unit mass of shale, in m 3 / t; k is the preservation coefficient at different evolution stages.

2. A shale gas content prediction method according to claim 1, characterized in that: The immature shale refers to shale with organic matter abundance, organic matter type and mineral composition similar to those of the shale formation in the predicted target area, and a vitrinite reflectance Ro or an equivalent vitrinite reflectance less than or equal to 0.7%.

3. The method for predicting shale gas content according to claim 1, characterized in that: The hydrocarbon generation efficiency refers to the hydrocarbon generation per unit mass of organic matter, and the hydrocarbon generation per unit mass of organic matter includes oil generation and gas generation; and / or, The total organic carbon recovery coefficient refers to the ratio of the original total organic carbon to the residual total organic carbon at different evolution stages.

4. A shale gas content prediction method according to claim 1 or 3, characterized in that: The hydrocarbon generation efficiency and the organic carbon recovery coefficient are obtained by using a hydrocarbon generation thermal simulation experiment; the hydrocarbon generation thermal simulation experiment is carried out by using a metal autoclave, a glass tube, a gold tube-autoclave, a diamond pressure chamber, a compaction simulation or a formation pore hot pressure hydrocarbon generation and expulsion simulation experiment.

5. The method for predicting shale gas content according to claim 1, characterized in that: The residual total organic carbon refers to the residual organic matter content of the source rock after hydrocarbon generation and expulsion; and / or, The degree of thermal evolution of organic matter is obtained by one or more parameters including burial depth, measured formation temperature, vitrinite reflectance, soluble organic matter conversion rate, sterane and terpene isomerization parameters, rock pyrolysis parameters, and kerogen H / C and O / C atomic ratio.

6. A shale gas content prediction method according to claim 5, characterized in that: The residual organic matter content is obtained by one or more methods including well logging interpretation, field testing, and experimental calculation.

7. A shale gas content prediction method according to claim 1, characterized in that: The preservation coefficient and its dynamic changes in geological time are obtained by analogy with known areas.

8. A shale gas content prediction device, characterized in that: include: The first acquisition module is used to obtain the hydrocarbon generation efficiency and total organic carbon recovery coefficient of different evolution degrees of the shale to be predicted, wherein the shale to be predicted is selected from immature shales of different organic matter types; A second acquisition module is used to acquire data of the shale to be predicted, wherein the data includes residual total organic carbon, organic matter type and thermal evolution degree of organic matter; The first processing module is used to calculate the total gas generation per unit mass of shale at different evolution stages. The calculation formula is: G 生 =TOC 残余 ×f×R 气 (1) In the formula, G 生 is the total gas generation per unit mass of shale, in m 3 / t;TOC 残余 is the residual organic carbon, in %; f is the total organic carbon recovery coefficient at different evolution stages; R 气 is the shale hydrocarbon generation efficiency, unit is m 3 / t.toc; A third acquisition module is used to obtain the preservation coefficient of the predicted target area and its dynamic changes in the geological period; and The second processing module is used to obtain the dynamic change of shale gas content by using the shale gas production per unit mass at different evolution stages and the preservation coefficient, wherein the total shale gas content at different evolution stages is obtained by formula (2): G=G 生 ×k(2) Where G is the total gas content of shale, in m 3 / t;G 生 is the total gas generation per unit mass of shale, in m 3 / t; k is the preservation coefficient at different evolution stages.

9. An electronic device, characterized in that: include: Memory; and processor; Wherein, the memory is used to store one or more computer instructions; the one or more computer instructions are executed by the processor to implement the shale gas content prediction method described in any one of claims 1 to 7.

10. A readable storage medium, characterized in that: The readable storage medium stores computer instructions; wherein, when the computer instructions are executed by a processor, the shale gas content prediction method according to any one of claims 1 to 7 is implemented.

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