Method and device for acquiring gas content of shale gas while drilling, electronic equipment and storage medium

Abstract

The invention relates to the technical field of gas-bearing property monitoring of shale gas while drilling, in particular to a method and device for acquiring gas-bearing property of shale gas while drilling, electronic equipment and a storage medium, the method for acquiring gas-bearing property of shale gas while drilling comprises the following steps: establishing a reservoir type classification standard based on porosity and total gas content; according to the standard, obtaining a total gas content range corresponding to each type of the reservoir type classification standard; and establishing a scatter diagram of the organic carbon content and the total gas content, and obtaining the organic carbon content corresponding to each type of the reservoir type classification standard according to the total gas content range corresponding to each type of the reservoir type classification standard, thereby establishing the shale reservoir type classification standard based on the organic carbon content. According to the method, the total gas content of the shale gas while drilling is obtained, and compared with a traditional accurate and high-cost method for analyzing the gas content in a closed coring laboratory, the method does not need to send the rock core to the laboratory, so that the cost is greatly reduced, and large-scale field evaluation while drilling on a production field is realized.

Description

Technical Field

[0001] The present invention relates to the technical field of shale gas gas content monitoring while drilling, and specifically relates to a method, device, electronic equipment and storage medium for obtaining shale gas gas content while drilling. Background Art

[0002] In shale gas exploration and development, shale gas content refers to the total amount of natural gas contained per ton of rock, converted to standard conditions (pressure 101.325 kPa, temperature 25°C). This includes free gas, adsorbed gas, and trace dissolved gas, with adsorbed gas and free gas being the primary components. The free gas content depends primarily on reservoir porosity, water saturation, and the number of natural fractures. Adsorbed gas is generally assessed using isothermal adsorption curves to evaluate its maximum adsorption capacity. A more accurate method for determining gas content is closed coring, followed by rapid laboratory analysis. This method is costly and unsuitable for large-scale, on-site assessment of shale gas content. Furthermore, the process is slow, significantly limiting its real-time evaluation of development wells.

[0003] Patent application publication number CN109063296A discloses a method for calculating shale gas content while drilling. The method includes: establishing calculation models for shale gas components (loss gas, desorbed gas, and residual gas) based on correlation analysis of regional core gas content analysis components with rock cuttings gamma ray spectroscopy uranium content and total hydrocarbons from gas logging; integrating these component calculation models to form a shale gas content calculation model; and performing while-drilling calculation of shale gas content based on the shale gas content calculation model. This method uses three components of shale gas content from core analysis as the basis for establishing a gas content interpretation model, which is more objective than other data (adsorbed gas and free gas from well logging interpretation) and addresses the lack of methods for calculating shale gas content while drilling.

[0004] Patent application publication number CN108107182A discloses a method for determining the free and adsorbed gas content in shale gas. This method collects gas samples from different temperature ranges during shale gas field analysis experiments during shale gas drilling. The method combines the total gas content of the field analysis with data from methane carbon isotope experiments to determine the free and adsorbed gas content in shale gas. This method can quickly determine the free and adsorbed gas content of a shale layer and directly correlates it with the shale gas content, reducing the influence of intermediate parameters and improving the accuracy of the results. This method is easy to implement and scale. Summary of the Invention

[0005] The present invention provides a method, device, electronic device and storage medium for obtaining the gas content of shale gas while drilling, which overcomes the shortcomings of the above-mentioned existing technologies and can effectively solve the problem that the existing core gas content analysis method is not suitable for on-site evaluation of shale gas content.

[0006] One of the technical solutions of the present invention is achieved through the following measures: a method for obtaining gas content of shale gas while drilling, comprising: Obtain porosity and organic carbon content of several shale samples of known reservoir types; Calculating the corresponding total gas content based on the porosity and organic carbon content of the shale samples of the plurality of known reservoir types; Drawing a scatter plot of porosity and total gas content of the shale samples of the several known reservoir types, and establishing a reservoir type classification standard based on porosity and total gas content; According to the reservoir type classification standard based on porosity and gas content, the total gas content range corresponding to each category of the reservoir type classification standard is obtained; Establishing a scatter plot of the organic carbon content and the total gas content, obtaining the organic carbon content corresponding to each category of the reservoir type classification standard based on the total gas content range corresponding to each category of the reservoir type classification standard, thereby establishing a shale reservoir type classification standard based on organic carbon content; For shale samples of unknown reservoir type belonging to the same block, the organic carbon content of the shale samples of the unknown reservoir type is obtained, and the reservoir type of the shale samples of the unknown reservoir type is identified by comparing them with the shale reservoir type classification standard based on the organic carbon content.

[0007] The reservoir type can generally be learned through well logging interpretation.

[0008] The following is a further optimization and / or improvement of one of the above-mentioned technical solutions: For the shale in Jimusar block or Santanghu block, the total gas content is calculated as follows: When K=0.0115P-0.0153, Q=33.572(T2 / T1) -0.583 ; When K=0.0013P 2.975 When, Q=0.6228TOC-0.2952; When K=0.0089e 0.6922P When, Q=1.3803TOC-4.0148; Where: K is the permeability of the shale sample, mD; P is the porosity of the shale sample, %; Q is the total gas content of the shale gas sample at the same well depth as the shale sample, m 3 / t; TOC is the organic carbon content of the shale sample, %; T2 is the maximum value of total hydrocarbons in the abnormal gas logging section of the shale gas sample at the same well depth as the shale sample, %; T1 is the total hydrocarbon base value in the abnormal gas logging section of the shale gas sample at the same well depth as the shale sample, %.

[0009] The scatter plot of porosity and total gas content of the shale samples of the known reservoir types is drawn with the porosity as the abscissa and the total gas content as the ordinate.

[0010] The scatter plot of the organic carbon content and the total gas content has the total gas content as the horizontal axis and the organic carbon content as the vertical axis.

[0011] The second technical solution of the present invention is achieved by the following measures: a device for obtaining the gas content of shale gas while drilling according to the first technical solution is provided, comprising: Porosity and organic carbon content acquisition module: obtains the porosity and organic carbon content of several shale samples of known reservoir types; Total gas content acquisition module: calculates the corresponding total gas content based on the porosity and organic carbon content of the shale samples of the known reservoir types; A first classification standard module: drawing a scatter plot of porosity and total gas content of the shale samples of the known reservoir types, and establishing a reservoir type classification standard based on porosity and total gas content; A total gas content range acquisition module is configured to obtain the total gas content range corresponding to each type of the reservoir type classification standard according to the reservoir type classification standard based on porosity and gas content; The second classification standard module is used to establish a scatter plot of the organic carbon content and the total gas content, and obtain the organic carbon content corresponding to each category of the reservoir type classification standard according to the total gas content range corresponding to each category of the reservoir type classification standard, thereby establishing a shale reservoir type classification standard based on the organic carbon content; Reservoir gas content identification module: For shale samples of unknown reservoir type belonging to the same block, the organic carbon content of the shale samples of the unknown reservoir type is obtained, and the reservoir type of the shale samples of the unknown reservoir type is identified by comparing them with the shale reservoir type classification standard based on organic carbon content.

[0012] The following is a further optimization and / or improvement of the second technical solution of the above invention: The above-mentioned total gas content acquisition module includes a total gas content calculation unit, The total gas content calculation unit is used to calculate the total gas content of the shale in the Jimusar block or the shale in the Santanghu block. The total gas content is calculated according to the following formula: When K=0.0115P-0.0153, Q=33.572(T2 / T1) -0.583 ; When K=0.0013P 2.975 When, Q=0.6228TOC-0.2952; When K=0.0089e 0.6922PWhen, Q=1.3803TOC-4.0148; Where: K is the permeability of the shale sample, mD; P is the porosity of the shale sample, %; Q is the total gas content of the shale gas sample at the same well depth as the shale sample, m 3 / t; TOC is the organic carbon content of the shale sample, %; T2 is the maximum value of total hydrocarbons in the abnormal gas logging section of the shale gas sample at the same well depth as the shale sample, %; T1 is the total hydrocarbon base value in the abnormal gas logging section of the shale gas sample at the same well depth as the shale sample, %.

[0013] The first classification standard module includes a first drawing unit, The first drawing unit draws a scatter plot of the porosity and total gas content of the shale samples of the known reservoir types, with the porosity as the abscissa and the total gas content as the ordinate.

[0014] The second classification standard module includes a second drawing unit, The second drawing unit: the scatter plot of the organic carbon content and the total gas content has the total gas content as the horizontal axis and the organic carbon content as the vertical axis.

[0015] The third technical solution of the present invention is achieved through the following measures: an electronic device, including a processor and a memory, wherein the memory stores a computer program, and the computer program is loaded and executed by the processor to implement the method for obtaining shale gas content while drilling as described in one of the technical solutions.

[0016] The fourth technical solution of the present invention is achieved through the following measures: a storage medium, on which a computer program that can be read by a computer is stored, and the computer program is configured to execute the method for obtaining the gas content of shale gas while drilling as described in one of the technical solutions when running.

[0017] One of the key technical points of the present invention is to achieve the determination of the total gas content of shale gas while drilling. Compared with the traditional accurate but costly closed coring laboratory gas content analysis method, this method does not need to send the core to the laboratory, which greatly reduces the cost and realizes large-scale on-site evaluation while drilling at the production site. At the same time, it overcomes the disadvantages of the slow process of the traditional method, can provide gas content data for development wells in real time, quickly obtain results during the drilling process, and provide timely and critical basis for subsequent mining decisions, greatly improving the efficiency of exploration and development, reducing the time wasted waiting for analysis results, and effectively promoting shale gas exploration and development in the direction of high efficiency and low cost, providing technical support for the rational development and utilization of shale gas resources. In addition, the second key technical point of the present invention is to establish a shale reservoir type classification standard based on organic carbon content through the relationship between the total gas content and organic carbon content, providing a new method for the rapid identification of shale gas reservoir types. BRIEF DESCRIPTION OF THE DRAWINGS

[0018] Attachment Figure 1 This is a scatter plot of the permeability, porosity, total gas content, and total hydrocarbon peak-to-base ratio of the AA block.

[0019] Attachment Figure 2 This is one of the scatter plots of permeability, porosity, total gas content, and TOC in the AA block.

[0020] Attachment Figure 3 This is the second scatter plot of permeability, porosity, total gas content, and TOC in the AA block.

[0021] Attachment Figure 4 This is a scatter plot of the total gas content and the porosity of the well logging in the AA block.

[0022] Attachment Figure 5 This is a scatter plot of TOC and total gas content in the AA block. DETAILED DESCRIPTION

[0023] The present invention is not limited to the following embodiments, and specific implementation methods can be determined based on the technical solutions of the present invention and actual conditions.

[0024] In the present invention, it should be noted that the terms "first", "second", etc. are only used to facilitate the description of the present invention and simplify the description, and do not indicate or imply that the device or element referred to must have a specific orientation, be constructed and operate in a specific orientation. Therefore, they cannot be understood as limiting the present invention.

[0025] The percentages in the present invention are all by mass unless otherwise specified.

[0026] The total hydrocarbon peak-to-base ratio (Ys) is the ratio of the total hydrocarbon peak to the total hydrocarbon base value. The total hydrocarbon peak refers to the highest concentration of hydrocarbon gas detected during gas logging.

[0027] In the present invention, the porosity may be the porosity of cuttings while drilling described in the patent document with publication number CN119164823A (title: Method for Obtaining Porosity of Cuttings While Drilling).

[0028] In existing technologies, a relatively accurate method for determining gas content is to use closed coring, which is then quickly sent to a laboratory for analysis. This method is costly and unsuitable for large-scale on-site evaluation of shale gas content. Furthermore, the process is slow and has significant limitations for real-time evaluation of development wells.

[0029] The present invention will be further described below in conjunction with the embodiments: Example 1: A method for obtaining shale gas content while drilling, comprising: Obtain porosity and organic carbon content of several shale samples of known reservoir types; Calculating the corresponding total gas content based on the porosity and organic carbon content of the shale samples of the plurality of known reservoir types; Drawing a scatter plot of porosity and total gas content of the shale samples of the several known reservoir types, and establishing a reservoir type classification standard based on porosity and total gas content; According to the reservoir type classification standard based on porosity and gas content, the total gas content range corresponding to each category of the reservoir type classification standard is obtained; Establishing a scatter plot of the organic carbon content and the total gas content, obtaining the organic carbon content corresponding to each category of the reservoir type classification standard based on the total gas content range corresponding to each category of the reservoir type classification standard, thereby establishing a shale reservoir type classification standard based on organic carbon content; For shale samples of unknown reservoir type belonging to the same block, the organic carbon content of the shale samples of the unknown reservoir type is obtained, and the reservoir type of the shale samples of the unknown reservoir type is identified by comparing them with the shale reservoir type classification standard based on the organic carbon content.

[0030] Example 2: As an optimization of the above example, for the shale in the Jimusar block or the shale in the Santanghu block, the total gas content is calculated as follows: When K=0.0115P-0.0153, Q=33.572(T2 / T1) -0.583 ; When K=0.0013P 2.975 When, Q=0.6228TOC-0.2952; When K=0.0089e 0.6922P When, Q=1.3803TOC-4.0148; Where: K is the permeability of the shale sample, mD; P is the porosity of the shale sample, %; Q is the total gas content of the shale gas sample at the same well depth as the shale sample, m 3 / t; TOC is the organic carbon content of the shale sample, %; T2 is the maximum value of total hydrocarbons in the abnormal gas logging section of the shale gas sample at the same well depth as the shale sample, %; T1 is the total hydrocarbon base value in the abnormal gas logging section of the shale gas sample at the same well depth as the shale sample, % If K and P do not satisfy the above relationship, the total gas content is obtained by using existing methods, such as using closed coring to measure the total gas content of the core.

[0031] It can be seen from the total gas content calculation formula that the organic carbon content is the independent variable for calculating the total gas content. Therefore, after establishing a scatter plot of the organic carbon content and the total gas content, the organic carbon content corresponding to the total gas content range corresponding to each category of the reservoir type classification standard can be obtained, thereby obtaining the organic carbon content corresponding to each category of the reservoir type classification standard.

[0032] The higher the porosity, the more easily gas accumulates in the reservoir, and the higher the formation gas content (i.e., the total gas content in this application). Permeability refers to the ability of gas to flow within a reservoir. The higher the permeability, the faster the gas migrates within the reservoir, and the higher the formation gas content (i.e., the total gas content in this application). Therefore, the total gas content is related to porosity and permeability.

[0033] Based on the correlation between total gas content, porosity and permeability, data fitting was performed using the permeability, porosity, T1, T2, organic carbon content of several shale samples and the total gas content of shale samples cored at the same well depth as the shale samples. The goodness of fit (R 2 ) The mathematical model with a higher degree of fit is the calculation formula for the final total gas content (details are as follows). A higher degree of fit means R 2 Greater than 0.71.

[0034] For example, Figure 1 As shown in the figure, through data fitting, it is found that when the porosity and permeability meet K=0.0115P-0.0153, the total gas content, T1, T2, and organic carbon content meet: Q=33.572 (T2 / T1) -0.583 .

[0035] like Figure 2 As shown, when porosity and permeability satisfy K=0.0013P 2.975 When , the total gas content and organic carbon content satisfy: Q=0.6228TOC-0.2952.

[0036] like Figure 3 As shown, when porosity and permeability satisfy K=0.0089e 0.6922P When , the total gas content and organic carbon content satisfy: Q=1.3803TOC-4.0148.

[0037] Since it is relatively expensive to measure the total gas content using sealed coring shale samples, after obtaining the above-mentioned total gas content calculation formula, the corresponding total gas content calculation formula can be selected based on the relationship between porosity and permeability to calculate the total gas content.

[0038] During gas logging, the total hydrocarbon curve is a crucial tool for on-site logging technicians to detect and identify abnormal oil and gas indications. Under normal drilling conditions, if the formation lithology encountered is stable and the fluid properties within the formation remain unchanged, the total hydrocarbon content will remain relatively stable during logging, and the total hydrocarbon curve will fluctuate slightly. However, under the influence of various factors, such as drilling conditions, changes in formation fluid pressure, and changes in the total amount of hydrocarbon components, the total hydrocarbon curve can easily exhibit abnormal changes.

[0039] Gas testing abnormalities This refers to the phenomenon in which the total hydrocarbon content significantly increases above the background gas logging value (i.e., total hydrocarbon base value or baseline concentration) when drilling into an oil and gas reservoir due to the infiltration or diffusion of gases contained in the fractured rock and formations into the drilling fluid. Gas logging anomalies are the most intuitive logging parameter characteristics for identifying oil and gas reservoirs. The maximum total hydrocarbon value in the anomalous gas logging section is the maximum total hydrocarbon value in the anomalous gas logging section on the total hydrocarbon curve.

[0040] Normally, full hydrocarbon logging data remains stable within a certain range with minimal fluctuations. This value is called the full hydrocarbon base value. When real-time logging data rises to more than 1.5 times the base value, it is considered a full hydrocarbon logging anomaly. This is reflected on the logging curve as an increase in the curve amplitude by more than 1.5 times. The full hydrocarbon base value for the anomalous gas logging segment is the full hydrocarbon base value for the anomalous segment on the full hydrocarbon logging curve.

[0041] Example 3: As an optimization of the above example, a scatter plot of the porosity and total gas content of the shale samples of the known reservoir types is drawn, with the porosity as the horizontal axis and the total gas content as the vertical axis.

[0042] Example 4: As an optimization of the above example, the scatter plot of the organic carbon content and the total gas content has the total gas content as the horizontal axis and the organic carbon content as the vertical axis.

[0043] Example 5: A device using the method for obtaining shale gas content while drilling described in the above embodiment comprises: Porosity and organic carbon content acquisition module: obtains the porosity and organic carbon content of several shale samples of known reservoir types; Total gas content acquisition module: calculates the corresponding total gas content based on the porosity and organic carbon content of the shale samples of the known reservoir types; A first classification standard module: drawing a scatter plot of porosity and total gas content of the shale samples of the known reservoir types, and establishing a reservoir type classification standard based on porosity and total gas content; A total gas content range acquisition module is configured to obtain the total gas content range corresponding to each type of the reservoir type classification standard according to the reservoir type classification standard based on porosity and gas content; The second classification standard module is used to establish a scatter plot of the organic carbon content and the total gas content, and obtain the organic carbon content corresponding to each category of the reservoir type classification standard according to the total gas content range corresponding to each category of the reservoir type classification standard, thereby establishing a shale reservoir type classification standard based on the organic carbon content; Reservoir gas content identification module: For shale samples of unknown reservoir type belonging to the same block, the organic carbon content of the shale samples of the unknown reservoir type is obtained, and the reservoir type of the shale samples of the unknown reservoir type is identified by comparing them with the shale reservoir type classification standard based on organic carbon content.

[0044] Example 6: As an optimization of the above example, the total gas content calculation unit includes a total gas content calculation subunit, The total gas content calculation subunit is used to calculate the total gas content of the shale in the Jimusar block or the shale in the Santanghu block. The total gas content is calculated according to the following formula: When K=0.0115P-0.0153, Q=33.572(T2 / T1) -0.583 ; When K=0.0013P 2.975 When, Q=0.6228TOC-0.2952; When K=0.0089e 0.6922P When, Q=1.3803TOC-4.0148; Where: K is the permeability of the shale sample, mD; P is the porosity of the shale sample, %; Q is the total gas content of the shale gas sample at the same well depth as the shale sample, m 3 / t; TOC is the organic carbon content of the shale sample, %; T2 is the maximum value of total hydrocarbons in the abnormal gas logging section of the shale gas sample at the same well depth as the shale sample, %; T1 is the total hydrocarbon base value in the abnormal gas logging section of the shale gas sample at the same well depth as the shale sample, %.

[0045] Example 7: As an optimization of the above-mentioned Example 5, the first classification standard module includes a first drawing unit, The first drawing unit draws a scatter plot of the porosity and total gas content of the shale samples of the known reservoir types, with the porosity as the abscissa and the total gas content as the ordinate.

[0046] Example 8: As an optimization of the above-mentioned Example 5, the second classification standard module includes a second drawing unit, The second drawing unit: the scatter plot of the organic carbon content and the total gas content has the total gas content as the horizontal axis and the organic carbon content as the vertical axis.

[0047] Example 9: An electronic device includes a processor and a memory, wherein the memory stores a computer program, and the computer program is loaded and executed by the processor to implement the method for obtaining shale gas content while drilling as described in the above embodiment.

[0048] Example 10: A storage medium having a computer program readable by a computer stored thereon, wherein the computer program is configured to execute the method for obtaining gas content of shale gas while drilling as described in the above embodiment when running.

[0049] Example 11: Taking the Jimusar block shale as an example, the method for obtaining the gas content of shale gas while drilling according to the present invention is described.

[0050] 1) Here, the total gas content of shale gas mainly includes adsorbed gas and free gas, according to the three changes in permeability and porosity ( Figures 1 to 3 ), using TOC and total hydrocarbon peak-to-base ratio of gas logging, the corresponding scatter plots of total gas content and total hydrocarbon peak-to-base ratio were established ( Figure 1 The right figure), the scatter plot of total gas content and TOC ( Figures 2 to 3 (right image).

[0051] Depend on Figure 1 It can be seen that the correlation between permeability and porosity is a linear positive correlation ( Figure 1 The left figure shows that the correlation between the total gas content and the total hydrocarbon peak base ratio (permeability and porosity) is negative ( Figure 1 (right image).

[0052] Depend on Figures 2 to 3 It can be seen that the correlation between permeability and porosity is basically positive ( Figures 2 to 3 The left figure shows that the total gas content and TOC corresponding to the permeability and porosity are linearly positively correlated ( Figures 2 to 3 right image), especially Figure 2 In the right figure, the goodness of fit of the fitting formula of the total gas content and TOC is as high as 0.919, indicating that the total gas content and TOC are highly positively correlated.

[0053] The positive correlation between total gas content and TOC provides a basis for establishing a shale reservoir type classification standard based on organic carbon content using TOC as a parameter.

[0054] 2) Combined with the reservoir type interpreted by well logging, use the total gas content and the porosity of the well logging to draw a scatter plot of the porosity and total gas content (such as Figure 4 ), and establish reservoir type classification standards based on porosity and total gas content (see Table 1); The total gas content is calculated as follows: When K=0.0115P-0.0153, Q=33.572(T2 / T1) -0.583 ; When K=0.0013P 2.975 When, Q=0.6228TOC-0.2952; When K=0.0089e 0.6922P When, Q=1.3803TOC-4.0148; Where: K is the permeability of the shale sample, mD; P is the porosity of the shale sample, %; Q is the total gas content of the shale gas sample at the same well depth as the shale sample, m 3 / t; TOC is the organic carbon content of the shale sample, %; T2 is the maximum value of total hydrocarbons in the abnormal gas logging section of the shale gas sample at the same well depth as the shale sample, %; T1 is the total hydrocarbon base value in the abnormal gas logging section of the shale gas sample at the same well depth as the shale sample, %.

[0055] 3) According to the reservoir type interpreted by well logging (Table 1), the total gas content is intersected with TOC ( Figure 5 ). Figure 5 It was found that except for 6 shale samples from Class I reservoirs with TOC less than or equal to 3.5%, the TOC of shale samples from most other Class I reservoirs was greater than 3.5%; except for 1 shale sample from Class II reservoir with TOC greater than 5%, the TOC of shale samples from other Class II-III reservoirs was 2.0% to 3.5%. Therefore, shales were divided into three categories according to TOC: good oil source rock, medium oil source rock, and poor oil source rock. A shale reservoir type classification standard based on organic carbon content was established (Table 2), and organic carbon TOC = 2% was used as the lower limit of whether there is industrial production capacity.

[0056] The above technical features respectively constitute the embodiments of the present invention, which have strong adaptability and implementation effect. Non-essential technical features can be added or removed according to actual needs to meet the requirements of different situations.

[0057] Table 1 .

[0058] Table 2 .

Claims

1. A method for obtaining shale gas content while drilling, characterized in that: include: Obtain porosity and organic carbon content of several shale samples of known reservoir types; Calculating the corresponding total gas content based on the porosity and organic carbon content of the shale samples of the plurality of known reservoir types; Drawing a scatter plot of porosity and total gas content of the shale samples of the several known reservoir types, and establishing a reservoir type classification standard based on porosity and total gas content; According to the reservoir type classification standard based on porosity and gas content, the total gas content range corresponding to each category of the reservoir type classification standard is obtained; Establishing a scatter plot of the organic carbon content and the total gas content, obtaining the organic carbon content corresponding to each category of the reservoir type classification standard based on the total gas content range corresponding to each category of the reservoir type classification standard, thereby establishing a shale reservoir type classification standard based on organic carbon content; For shale samples of unknown reservoir type belonging to the same block, the organic carbon content of the shale samples of the unknown reservoir type is obtained, and the reservoir type of the shale samples of the unknown reservoir type is identified by comparing them with the shale reservoir type classification standard based on the organic carbon content.

2. The method for obtaining shale gas content while drilling according to claim 1, characterized in that: For the shale in the Jimusar block or the shale in the Santanghu block, the total gas content is calculated as follows: When K=0.0115P-0.0153, Q=33.572(T2 / T1) -0.583 ; When K=0.0013P 2.975 When, Q=0.6228TOC-0.2952; When K=0.0089e 0.6922P When, Q=1.3803TOC-4.0148; Where: K is the permeability of the shale sample, mD; P is the porosity of the shale sample, %; Q is the total gas content of the shale gas sample at the same well depth as the shale sample, m 3 / t; TOC is the organic carbon content of shale samples, %; T2 is the maximum value of total hydrocarbons in the abnormal gas logging section of the shale gas sample at the same well depth as the shale sample, %; T1 is the basic value of total hydrocarbons in the abnormal gas logging section of the shale gas sample at the same well depth as the shale sample, %.

3. The method for obtaining shale gas content while drilling according to claim 1 or 2, characterized in that: Draw a scatter plot of porosity and total gas content of the shale samples of the known reservoir types, with the porosity as the abscissa and the total gas content as the ordinate; Or / and, the scatter plot of the organic carbon content and the total gas content has the total gas content as the horizontal axis and the organic carbon content as the vertical axis.

4. A device using the method for obtaining shale gas content while drilling according to any one of claims 1 to 3, characterized in that: include: Porosity and organic carbon content acquisition module: obtains the porosity and organic carbon content of several shale samples of known reservoir types; Total gas content acquisition module: calculates the corresponding total gas content based on the porosity and organic carbon content of the shale samples of the known reservoir types; A first classification standard module: drawing a scatter plot of porosity and total gas content of the shale samples of the known reservoir types, and establishing a reservoir type classification standard based on porosity and total gas content; A total gas content range acquisition module is configured to obtain the total gas content range corresponding to each type of the reservoir type classification standard according to the reservoir type classification standard based on porosity and gas content; The second classification standard module is used to establish a scatter plot of the organic carbon content and the total gas content, and obtain the organic carbon content corresponding to each category of the reservoir type classification standard according to the total gas content range corresponding to each category of the reservoir type classification standard, thereby establishing a shale reservoir type classification standard based on the organic carbon content; Reservoir gas content identification module: For shale samples of unknown reservoir type belonging to the same block, the organic carbon content of the shale samples of the unknown reservoir type is obtained, and the reservoir type of the shale samples of the unknown reservoir type is identified by comparing them with the shale reservoir type classification standard based on organic carbon content.

5. The device according to claim 4, characterized in that The total gas content acquisition module includes a total gas content calculation unit. The total gas content calculation unit is used to calculate the total gas content of the shale in the Jimusar block or the shale in the Santanghu block. The total gas content is calculated according to the following formula: When K=0.0115P-0.0153, Q=33.572(T2 / T1) -0.583 ; When K=0.0013P 2.975 When, Q=0.6228TOC-0.2952; When K=0.0089e 0.6922P When, Q=1.3803TOC-4.0148; Where: K is the permeability of the shale sample, mD; P is the porosity of the shale sample, %; Q is the total gas content of the shale gas sample at the same well depth as the shale sample, m 3 / t; TOC is the organic carbon content of shale samples, %; T2 is the maximum value of total hydrocarbons in the abnormal gas logging section of the shale gas sample at the same well depth as the shale sample, %; T1 is the basic value of total hydrocarbons in the abnormal gas logging section of the shale gas sample at the same well depth as the shale sample, %.

6. The device according to claim 4 or 5, characterized in that Draw a scatter plot of porosity and total gas content of the shale samples of the known reservoir types, with the porosity as the abscissa and the total gas content as the ordinate; Or / and, the scatter plot of the organic carbon content and the total gas content has the total gas content as the horizontal axis and the organic carbon content as the vertical axis.

7. An electronic device, characterized in that: The method comprises a processor and a memory, wherein a computer program is stored in the memory, and the computer program is loaded and executed by the processor to implement the method for obtaining gas content of shale gas while drilling as claimed in any one of claims 1 to 3.

8. A storage medium, characterized in that: The storage medium stores a computer program that can be read by a computer, and the computer program is configured to execute the method for obtaining gas content of shale gas while drilling according to any one of claims 1 to 3 when running.

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