A shale oil in-situ oil and gas content determination method, device, equipment and medium

Abstract

The present application discloses a kind of shale oil in-situ oil and gas content determination method, device, equipment and medium, it is related to shale gas exploration and development technical field, the present application is frozen pyrolysis and analytical gas test to the core sample of pressure-maintained coring and conventional coring, respectively calculate free oil extraction drilling loss coefficient and analytical gas loss coefficient, to quantify the loss of hydrocarbons in experimental process, and combining with the light hydrocarbon loss coefficient of different time placement and heavy hydrocarbon correction coefficient, further correct hydrocarbon loss, this process considers the difference of hydrocarbon loss amount under different experimental steps, different experimental methods, the oil content and gas content in situ are recovered respectively, finally restore oil content and gas content under in-situ formation conditions, improve the evaluation accuracy of shale oiliness and gasiness.

Description

Technical Field

[0001] This invention relates to the field of shale gas exploration and development technology, and in particular to a method, apparatus, equipment and medium for in-situ determination of oil and gas content in shale oil. Background Technology

[0002] As a key component of unconventional oil and gas resources, the oil content of shale oil is a crucial indicator for shale oil site selection and resource calculation, directly impacting the developability and commercial value of target formations. Therefore, accurately determining the oil content of shale is a critical step in the shale oil exploration and development process.

[0003] Currently, rock pyrolysis has become one of the main technical means for characterizing shale oil content due to its advantages of simple operation and rapid analysis; the free hydrocarbon parameter S1 (C7-C) generated during pyrolysis... 32 Hydrocarbon composition is an important geochemical indicator, widely used to calculate shale oil content and evaluate movable oil content. It can be seen that the current method is limited to obtaining a single free hydrocarbon parameter S1 value, and fails to comprehensively consider various factors in the hydrocarbon loss process, such as oil and gas loss during drilling, the degree of light hydrocarbon loss and heavy hydrocarbon correction, thus affecting the accurate evaluation of shale oil and gas content. Summary of the Invention

[0004] This invention provides a method, apparatus, equipment, and medium for in-situ determination of oil and gas content in shale oil. It can solve the problem that existing methods are limited to obtaining a single free hydrocarbon parameter S1 value and fail to comprehensively consider various factors in the hydrocarbon loss process, such as oil and gas loss during drilling, the degree of light hydrocarbon loss, and heavy hydrocarbon correction, which affects the accurate evaluation of shale oil and gas content.

[0005] This invention provides a method for in-situ determination of hydrocarbon content in shale oil, comprising the following steps:

[0006] The first core sample of shale was obtained by the pressure-holding coring method, and the free oil content and gas content of the first core sample were obtained.

[0007] The second core sample of shale was obtained using the conventional coring method. The residual oil content, pyrolysis hydrocarbon content and residual gas content of the second core sample were obtained, as well as the residual free oil content of the second core sample.

[0008] Based on the free oil content and the residual oil content after drilling, the free oil loss coefficient after drilling was obtained to characterize the loss of free oil in the core sample; based on the gas content and the residual gas content after drilling, the desorbed gas loss coefficient after drilling was obtained to characterize the loss of gas in the core sample; based on the residual oil content after drilling and the residual free oil content after drilling, the light hydrocarbon loss coefficient after drilling was obtained to characterize the loss of light hydrocarbons in the core sample.

[0009] The heavy hydrocarbon content and kerogen content of the second core sample were obtained, and the heavy hydrocarbon correction coefficient characterizing the heavy hydrocarbon loss of the core sample was obtained based on the heavy hydrocarbon content and kerogen content.

[0010] Based on the residual free oil content, light hydrocarbon loss coefficient, free oil drilling loss coefficient, pyrolysis hydrocarbon content, heavy hydrocarbon correction coefficient, desorption gas loss coefficient, and residual gas content after drilling, the oil and gas content of shale oil under in-situ formation conditions is obtained.

[0011] Preferably, obtaining the free oil content and gas content includes:

[0012] Two core samples, A and B, were obtained using pressure-holding coring.

[0013] The A core sample was sealed at ultra-low temperature. The core sample was cut and crushed into 200-mesh powder under liquid nitrogen purging. The core powder sample was placed in a pyrolysis apparatus and kept at 300℃ for 3 minutes to obtain the free oil content S1.

[0014] Core sample B was cryogenically sealed and then dissected under continuous liquid nitrogen priming. Desorption gas detection parameters and corresponding time points were measured and recorded using a desorption device at a set desorption temperature to obtain a desorption time-desorption gas volume data table. The desorption gas content was calculated. The desorbed core sample was then fragmented and desorbed again to obtain residual gas test records. The gas content and lost gas content were calculated. The sum of the desorption gas content, gas content, and lost gas content is the gas content V.

[0015] Preferably, obtaining the residual oil content, pyrolysis hydrocarbon content, and residual gas content after drilling includes:

[0016] Multiple core samples were obtained using conventional core sampling, and two of these core samples were designated as core samples C and D.

[0017] Core sample C was cryogenically sealed and then, under liquid nitrogen purging, core samples were cut, sealed, and crushed into 200-mesh powder. The core powder was then placed in a pyrolysis apparatus and kept at 300°C for 3 minutes to obtain the residual oil content S1 from the drilling. * The pyrolysis hydrocarbon content S2 was obtained by heating the temperature to 600℃ at a rate of 25℃ per minute.

[0018] Core sample D was cryogenically sealed and then dissected under continuous liquid nitrogen priming. Desorption parameters and corresponding time points were measured and recorded using a desorption device at a set desorption temperature to obtain a desorption time-desorption gas volume data table. The desorption gas content was calculated. The desorbed core sample was then fragmented and desorbed again to obtain residual gas test records. The gas content and lost gas content were calculated. The sum of the desorption gas content, the remaining gas content, and the lost gas content is the residual gas content V upon drilling. * .

[0019] Preferably, obtaining the residual free oil content includes:

[0020] For core samples remaining after conventional core sampling, the samples were placed at room temperature for 1 hour, 2 hours, 4 hours, 8 hours, 24 hours, 48 ​​hours, 96 hours, 192 hours, and 360 hours, respectively, and then crushed. The core powder samples were placed in a pyrolysis apparatus and kept at 300℃ for 3 minutes to obtain the residual free oil content S1 at each time point. (1) S1 (2) S1 (4) ...S1 (360) The residual free oil content S1 at each time point (1) S1 (2) S1 (4) ...S1 (360) As residual free oil content .

[0021] Preferably, the free oil drilling loss coefficient The method of obtaining it is:

[0022] ;

[0023] in: S 1 indicates the free oil content; S 1 * Indicates the content of residual oil after drilling; Indicates the density of the core sample;

[0024] The desorption gas loss coefficient The method of obtaining it is:

[0025] ;

[0026] in: V Indicates gas content; V * This indicates the residual gas content after drilling;

[0027] The light hydrocarbon loss coefficient The method of obtaining it is:

[0028] ;

[0029] in: S 1 * Indicates the content of residual oil after drilling; This indicates the residual free oil content at each time point.

[0030] Preferably, the process of obtaining the heavy hydrocarbon correction coefficient includes:

[0031] Obtain a core sample from a conventional core. After crushing the sample at room temperature, place the core powder sample into a pyrolysis apparatus. Maintain a constant temperature of 200℃ for 1 minute to obtain the light oil content. Then, increase the temperature at 25℃ per minute to 350℃ and maintain a constant temperature for 1 minute to obtain the light-medium oil content. Continue increasing the temperature at the same rate to 450℃ and maintain a constant temperature for 1 minute to obtain the heavy hydrocarbon content (S). 2-1 Finally, the temperature was raised to 600℃ again at the same rate to obtain the kerogen content S. 2-2 ;

[0032] Based on the heavy hydrocarbon content S 2-1 and kerogen content S 2-2 Obtain the heavy hydrocarbon correction factor, the heavy hydrocarbon correction factor The method of obtaining it is:

[0033] .

[0034] Preferably, the oil and gas content under the in-situ formation conditions of the shale oil is... Y The method of obtaining it is:

[0035] ;

[0036] in: Indicates the residual free oil content; Indicates the light hydrocarbon loss coefficient; Indicates the free oil extraction loss coefficient; Indicates the content of pyrolytic hydrocarbons; Indicates the correction factor for heavy hydrocarbons; Indicates the analytical gas loss coefficient; V * This indicates the residual gas content after drilling.

[0037] This invention also provides an in-situ shale oil hydrocarbon content measuring device, comprising:

[0038] The experimental module is used to obtain the first core sample of shale using the pressure-holding coring method, and to obtain the free oil content and gas content of the first core sample.

[0039] The second core sample of shale was obtained using the conventional coring method. The residual oil content, pyrolysis hydrocarbon content and residual gas content of the second core sample were obtained, as well as the residual free oil content of the second core sample.

[0040] The hydrocarbon loss module is used to obtain the free oil loss coefficient, which characterizes the loss of free oil in the core sample, based on the free oil content and the residual oil content after drilling; the desorbed gas loss coefficient, which characterizes the loss of gas in the core sample, based on the gas content and the residual gas content after drilling; and the light hydrocarbon loss coefficient, which characterizes the loss of light hydrocarbons in the core sample, based on the residual oil content after drilling and the residual free oil content.

[0041] The heavy hydrocarbon content and kerogen content of the second core sample were obtained, and the heavy hydrocarbon correction coefficient characterizing the heavy hydrocarbon loss of the core sample was obtained based on the heavy hydrocarbon content and kerogen content.

[0042] The correction module is used to obtain the oil and gas content of shale oil under in-situ formation conditions based on the residual free oil content, light hydrocarbon loss coefficient, free oil drilling loss coefficient, pyrolysis hydrocarbon content, heavy hydrocarbon correction coefficient, desorption gas loss coefficient, and residual gas content after drilling.

[0043] This invention also provides an electronic device, including a memory and a processor;

[0044] The memory is used to store computer programs;

[0045] When the processor executes the computer program stored in the memory, it implements the steps of the in-situ shale oil hydrocarbon content determination method described above.

[0046] This invention also provides a computer-readable storage medium for storing a computer program, which, when executed by a processor, implements the steps of the in-situ shale oil hydrocarbon content determination method described above.

[0047] This invention provides a method, apparatus, equipment, and medium for in-situ determination of oil and gas content in shale oil, which has the following advantages compared with the prior art:

[0048] This invention quantifies hydrocarbon loss during the experiment by conducting on-site cryopreservation pyrolysis and gas extraction tests on core samples from pressure-controlled and conventional core sampling. The free oil extraction loss coefficient and gas extraction loss coefficient are calculated separately. Furthermore, hydrocarbon loss is corrected by combining the light hydrocarbon loss coefficient and heavy hydrocarbon correction coefficient obtained at different storage times. This process considers the differences in hydrocarbon loss under different experimental steps and methods, taking into account oil and gas loss during extraction, the degree of light hydrocarbon loss, and heavy hydrocarbon correction. The in-situ oil and gas content is recovered separately to obtain the in-situ formation oil and gas content, thus improving the accuracy of shale oil and gas content assessment. Attached Figure Description

[0049] Figure 1 This is a schematic diagram of the overall process for determining the in-situ hydrocarbon content of shale oil according to an embodiment of the present invention;

[0050] Figure 2 The free oil content S1 obtained by pressure-maintaining coring in an embodiment of the present invention is compared with the residual free oil S1 obtained after drilling in conventional coring. * Comparison diagram;

[0051] Figure 3 The residual free oil content (S1) after different storage times, as provided in this embodiment of the invention, is analyzed using a method for in-situ determination of hydrocarbon content in shale oil. (x) Schematic diagram of the relationship changing over time;

[0052] Figure 4 The heavy hydrocarbon content S in an in-situ method for determining the hydrocarbon content of shale oil provided in this embodiment of the invention. 2-1 and kerogen content S 2-2 A schematic diagram showing the proportion of S2 in the pyrolysis hydrocarbon content. Detailed Implementation

[0053] To make the above-mentioned objects, features, and advantages of the present invention more apparent and understandable, specific embodiments of the present invention will be described in detail below with reference to the accompanying drawings. Many specific details are set forth in the following description to provide a thorough understanding of the present invention. However, the present invention can be practiced in many other ways different from those described herein, and those skilled in the art can make similar modifications without departing from the spirit of the present invention. Therefore, the present invention is not limited to the specific embodiments disclosed below.

[0054] See Figure 1 This invention provides a method for in-situ determination of hydrocarbon content in shale oil, comprising the following steps:

[0055] Step 1: Select multiple sampling points according to the requirements. At each sampling point, two core samples, A and B, are obtained by pressure-holding coring. Sample A is frozen and sealed, then pulverized and pyrolyzed to obtain the free oil content S1 by volume mass. Sample B is frozen and sealed, then pulverized and pyrolyzed to obtain the gas content V by volume desorption gas test.

[0056] Step Two: Select multiple sampling points according to requirements. At each sampling point, obtain a total of twelve core samples through conventional core sampling. Two of these samples are cryopreserved, flushed, and crushed before undergoing pyrolysis experiments and desorption gas tests to determine the residual oil content (S1) after drilling. * pyrolysis hydrocarbon content S2 and residual gas content V after drilling * Another sample was pulverized at room temperature and then subjected to multi-temperature pyrolysis to obtain the heavy hydrocarbon content S. 2-1 and kerogen content S 2-2 .

[0057] Step 3: The remaining nine samples from the conventional core extraction were subjected to pyrolysis experiments after being placed for 1 hour, 2 hours, 4 hours, 8 hours, 24 hours, 48 ​​hours, 96 hours, 192 hours, and 360 hours, respectively, to obtain residual free oil S1. (1) S1 (2) S1 (4) ...S1 (360) Right now .

[0058] Step 4: Compare the free oil content S1 and the residual oil content S1 obtained in Steps 1 and 2 respectively. * And gas content V and residual gas content V after drilling * Calculate the free oil extraction loss coefficient. and the gas loss coefficient .

[0059] Free oil drilling loss coefficient Represented as:

[0060] .

[0061] Analyzing gas loss coefficient Represented as:

[0062] .

[0063] in: This indicates the density of the core sample.

[0064] Step 5: Compare the residual oil content S1 obtained in Steps 2 and 3 respectively. * The residual free oil content S1 after different storage times (x) The light hydrocarbon loss coefficient after placement at different time periods was calculated.

[0065] The light hydrocarbon loss coefficient after placement is expressed as: :

[0066] .

[0067] Step Six: The heavy hydrocarbon content S obtained in Step Two 2-1 and kerogen content S 2-2 The heavy hydrocarbon correction factor was calculated. .

[0068] Heavy hydrocarbon correction factor Represented as:

[0069] .

[0070] Step 7: Obtain various coefficients and data through the above steps: Obtaining oil and gas content under in-situ formation conditions for shale oil Y :

[0071] .

[0072] Specifically:

[0073] Step 1: Select multiple sampling points according to requirements. At each sampling point, two core samples, A and B, are obtained by pressure-holding coring. Sample A is frozen and sealed, then pulverized and pyrolyzed to obtain the free oil content S1 by volume mass. Sample B is frozen and sealed, then pulverized and pyrolyzed to obtain the gas content V by volume desorption gas test.

[0074] Pressure-maintaining coring technology is a method to obtain core samples that retain the integrity of reservoir fluids. Before the core is lowered into the well, it is filled with sealing fluid using appropriate tools. During the core drilling process, the core is continuously sealed, which can prevent the gas and light components in the crude oil from escaping due to the pressure and temperature drop when the core is brought to the surface from the bottom of the well.

[0075] The free oil content S1 was obtained by freezing and sealing followed by liquid nitrogen pulverization and pyrolysis: After obtaining the core sample by pressure-controlled core sampling, it was immediately sealed at ultra-low temperature and then sent to the corresponding warehouse for freezing and storage for a certain period of time; the core sample was cut and crushed into 200-mesh powder under liquid nitrogen purging, and the core powder sample was placed in a RockEval 6 pyrolysis instrument and kept at 300℃ for 3 minutes to obtain the free oil content S1.

[0076] The gas content V is obtained by cryogenically desorption-gas volume method after cryogenic sealing: another core sample obtained at a selected sampling point through pressure-controlled core sampling is also cryogenically sealed and then sent to the corresponding library for cryogenic storage for a certain period of time; the core sample is cut under continuous liquid nitrogen purging, and the desorption gas detection parameters and corresponding time points are measured and recorded using a desorption device at a set desorption temperature to obtain a desorption time-desorption gas volume data table, from which the desorption gas content can be calculated. The desorbed core sample is then broken up and desorbed again to obtain residual gas test records, from which the precipitated gas content and lost gas content can be calculated. The sum of the three is the gas content V.

[0077] Step Two: Select multiple sampling points according to requirements. At each sampling point, obtain a total of twelve core samples through conventional core sampling. Two of these samples are cryopreserved, flushed, and crushed before undergoing pyrolysis experiments and desorption gas tests to determine the residual oil content (S1) after drilling. * pyrolysis hydrocarbon content S2 and residual gas content V after drilling * Another sample was pulverized at room temperature and then subjected to multi-temperature pyrolysis to obtain the heavy hydrocarbon content S. 2-1 and kerogen content S 2-2 ;

[0078] Free hydrocarbon content S1 *The free oil content S2 was obtained by cryogenic sealing followed by liquid nitrogen pulverization and pyrolysis: After obtaining core samples through conventional core sampling, they were immediately cryogenically sealed and then sent to the appropriate storage facility for cryogenic preservation for a certain period of time; under liquid nitrogen purging, the core samples were cut, crushed into 200-mesh powder samples in a sealed environment, and the core powder samples were placed in a RockEval 6 pyrolysis apparatus and kept at 300℃ for 3 minutes to obtain the free oil content S1. * Then, the temperature is increased to 600°C at a rate of 25°C per minute to obtain the pyrolytic hydrocarbon content S2.

[0079] Residual gas content V during drilling * Gas content (V) is obtained through cryogenic desorption / gas volume analysis after cryopreservation. A core sample obtained from a selected sampling point using conventional core sampling is cryopreserved and then stored in a cryopreservation facility for a certain period. The core sample is then sectioned under continuous liquid nitrogen priming. Desorption parameters and corresponding time points are measured and recorded using a desorption device at a set desorption temperature to obtain a desorption time-desorption gas volume data table, from which the desorption gas content can be calculated. The desorbed core sample is then fragmented and desorbed again to obtain residual gas test records, allowing for the calculation of the released gas content and lost gas content. The sum of these three values ​​is the gas content (V). * .

[0080] Heavy hydrocarbon content S 2-1 and kerogen content S 2-2 The following results were obtained through multi-stage pyrolysis experiments: A core sample obtained from a selected sampling point using conventional core sampling was crushed at room temperature. The core powder sample was then placed in a RockEval 6 pyrolysis apparatus. After holding at 200℃ for 1 minute to obtain light oil content, the temperature was increased to 350℃ at a rate of 25℃ per minute and held for 1 minute to obtain light-medium oil. The temperature was then further increased at the same rate to 450℃ and held for 1 minute to obtain heavy hydrocarbon content (S). 2-1 Finally, the temperature was raised to 600℃ again at the same rate to obtain the kerogen content S. 2-2 .like Figure 2 The figure shows the free oil content S1 obtained from pressure-holding coring and the residual free oil S1 after drilling lift obtained from conventional coring. * contrast.

[0081] Step 3: After the remaining nine samples from the conventional core sampling were placed for 1 hour, 2 hours, 4 hours, 8 hours, 24 hours, 48 ​​hours, 96 hours, 192 hours, and 360 hours respectively, pyrolysis experiments were conducted to obtain residual free oil S1. (1) S1 (2) S1 (4) ...S1 (360) Right now .

[0082] The placement time and the number of core samples can be flexibly selected according to actual needs.

[0083] Residual free oil S1 (1) S1 (2) S1 (4) ...S1 (360) The remaining eight core samples, obtained through conventional core sampling at selected sampling points, were ground at room temperature for 1 hour, 2 hours, 4 hours, 8 hours, 24 hours, 48 ​​hours, 96 hours, 192 hours, and 360 hours, respectively. The core powder samples were then placed in a RockEval 6 pyrolysis apparatus and kept at 300℃ for 3 minutes to obtain the residual free oil content S1. (1) S1 (2) S1 (4) ...S1 (360) Right now .like Figure 3 The figure shows the residual free oil containing S1 after being left for different periods of time. (x) Relationships that change over time.

[0084] Step 4: Compare the free oil content S1 and the residual oil content S1 obtained in Steps 1 and 2 respectively. * And gas content V and residual gas content V after drilling * Calculate the free oil extraction loss coefficient. and the gas loss coefficient .

[0085] Step 5: Compare the residual oil content S1 obtained in Steps 2 and 3 respectively. * The residual free oil content S1 after different storage times (x) The light hydrocarbon loss coefficient after placement at different time periods was calculated.

[0086] Step 6: The heavy hydrocarbon content S obtained in Step 2 2-1 and kerogen content S 2-2 The heavy hydrocarbon correction factor was calculated. .like Figure 4 As shown, the heavy hydrocarbon content S 2-1 and kerogen content S 2-2 A schematic diagram showing the proportion of S2 in the pyrolysis hydrocarbon content.

[0087] Step 7: Obtain various coefficients and data through the above steps: Obtaining oil and gas content under in-situ formation conditions for shale oil Y .

[0088] The method of this invention includes seven steps: the first step is to conduct on-site pyrolysis experiments and desorption gas tests on pressure-holding coring samples to obtain the free oil content S1 and gas content V; the second step is to conduct on-site pyrolysis experiments, multi-temperature-level pyrolysis, and desorption gas tests on conventional coring samples to obtain the residual free oil content S1 after drilling. * , content of pyrolytic hydrocarbons S 2、 Heavy hydrocarbon content S 2-1 Kerogen content S 2-2 and residual gas content V * The third step involves conducting pyrolysis experiments on conventionally cored samples after different storage times to obtain the residual free oil content S1. (x) The fourth step is to calculate the free oil extraction loss coefficient. and the gas loss coefficient Step 5: Calculate the light hydrocarbon loss coefficient after placement. Step 6: Based on the obtained heavy hydrocarbon content S 2-1 and the content of hydrocarbons in kerogen pyrolysis S 2-2 The heavy hydrocarbon correction factor Kweight is calculated; the in-situ oil and gas content Y is obtained in the seventh step.

[0089] This invention quantifies hydrocarbon loss during the experiment by conducting on-site cryogenic pyrolysis and desorption gas tests on pressure-controlled coring and conventional coring samples, respectively calculating the free oil extraction loss coefficient and the desorption gas loss coefficient. Furthermore, it corrects hydrocarbon loss by combining the light hydrocarbon loss coefficient and heavy hydrocarbon correction coefficient obtained after different storage times, and finally restores the oil and gas content under the original formation conditions.

[0090] This invention recovers the in-situ oil and gas content separately, taking into account the differences in hydrocarbon loss due to different experimental steps and methods. It avoids the errors caused by using a single fixed coefficient in traditional methods, and comprehensively considers the impact of experimental steps, methods, and time on hydrocarbon loss. This significantly improves the accuracy of in-situ oil and gas content evaluation, compensates for the errors caused by hydrocarbon loss in existing technologies, and avoids the errors caused by using a single fixed coefficient. At the same time, it solves the problem of inaccurate in-situ oil and gas content evaluation for shale oil, providing a scientific basis for the exploration and development of unconventional oil and gas resources. It helps to optimize resource assessment and development plans, and has broad application prospects in unconventional oil and gas fields such as shale oil and tight oil, providing important technical support for the energy industry.

[0091] This invention, through innovative experimental design and data processing methods, significantly improves the accuracy of recovering in-situ oil and gas content underground, providing a scientific basis for the exploration and development of unconventional oil and gas resources, and has important theoretical value and practical application significance.

[0092] The embodiments described above are merely illustrative of several implementations of the present invention, and while the descriptions are relatively specific and detailed, they should not be construed as limiting the scope of the invention patent. It should be noted that those skilled in the art can make various modifications and improvements without departing from the concept of the present invention, and these all fall within the protection scope of the present invention. Therefore, the protection scope of this invention patent should be determined by the appended claims.

Claims

1. A method for in-situ determination of hydrocarbon content in shale oil, characterized in that, Includes the following steps: The first core sample of shale was obtained by the pressure-holding coring method, and the free oil content and gas content of the first core sample were obtained. The second core sample of shale was obtained using the conventional coring method. The residual oil content, pyrolysis hydrocarbon content and residual gas content of the second core sample were obtained, as well as the residual free oil content of the second core sample. Based on the free oil content and the residual oil content after drilling, the free oil loss coefficient after drilling was obtained to characterize the loss of free oil in the core sample; based on the gas content and the residual gas content after drilling, the desorbed gas loss coefficient after drilling was obtained to characterize the loss of gas in the core sample; based on the residual oil content after drilling and the residual free oil content after drilling, the light hydrocarbon loss coefficient after drilling was obtained to characterize the loss of light hydrocarbons in the core sample. The heavy hydrocarbon content and kerogen content of the second core sample were obtained, and the heavy hydrocarbon correction coefficient characterizing the heavy hydrocarbon loss of the core sample was obtained based on the heavy hydrocarbon content and kerogen content. Based on the residual free oil content, light hydrocarbon loss coefficient, free oil drilling loss coefficient, pyrolysis hydrocarbon content, heavy hydrocarbon correction coefficient, desorption gas loss coefficient, and residual gas content after drilling, the oil and gas content of shale oil under in-situ formation conditions is obtained. The determination of the residual free oil content includes: For core samples remaining after conventional core sampling, the samples were placed at room temperature for 1 hour, 2 hours, 4 hours, 8 hours, 24 hours, 48 ​​hours, 96 hours, 192 hours, and 360 hours, respectively, and then crushed. The core powder samples were placed in a pyrolysis apparatus and kept at 300℃ for 3 minutes to obtain the residual free oil content S1 at each time point. (1) S1 (2) S1 (4) ...S1 (360) The residual free oil content S1 at each time point (1) S1 (2) S1 (4) ...S1 (360) As residual free oil content ; The process of obtaining the heavy hydrocarbon correction coefficient includes: Obtain a core sample from a conventional core. After crushing the sample at room temperature, place the core powder sample into a pyrolysis apparatus. Maintain a constant temperature of 200℃ for 1 minute to obtain the light oil content. Then, increase the temperature at 25℃ per minute to 350℃ and maintain a constant temperature for 1 minute to obtain the light-medium oil content. Continue increasing the temperature at the same rate to 450℃ and maintain a constant temperature for 1 minute to obtain the heavy hydrocarbon content (S). 2-1 Finally, the temperature was raised to 600℃ again at the same rate to obtain the kerogen content S. 2-2 ; Based on the heavy hydrocarbon content S 2-1 and kerogen content S 2-2 Obtain the heavy hydrocarbon correction factor, the heavy hydrocarbon correction factor The method of obtaining it is: ； in: This indicates the density of the core sample.

2. The method for in-situ determination of hydrocarbon content in shale oil according to claim 1, characterized in that, Obtain the free oil content and gas content, including: Two core samples, A and B, were obtained using pressure-holding coring. The A core sample was sealed at ultra-low temperature. The core sample was cut and crushed into 200-mesh powder under liquid nitrogen purging. The core powder sample was placed in a pyrolysis apparatus and kept at 300℃ for 3 minutes to obtain the free oil content S1. Core sample B was cryogenically sealed and then dissected under continuous liquid nitrogen priming. Desorption gas detection parameters and corresponding time points were measured and recorded using a desorption device at a set desorption temperature to obtain a desorption time-desorption gas volume data table. The desorption gas content was calculated. The desorbed core sample was then fragmented and desorbed again to obtain residual gas test records. The gas content and lost gas content were calculated. The sum of the desorption gas content, gas content, and lost gas content is the gas content V.

3. The method for in-situ determination of hydrocarbon content in shale oil according to claim 2, characterized in that, Obtain the residual oil content, pyrolysis hydrocarbon content, and residual gas content after drilling, including: Multiple core samples were obtained using conventional core sampling, and two of these core samples were designated as core samples C and D. Core sample C was cryogenically sealed and then, under liquid nitrogen purging, core samples were cut, sealed, and crushed into 200-mesh powder. The core powder was then placed in a pyrolysis apparatus and kept at 300°C for 3 minutes to obtain the residual oil content S1 from the drilling. * The pyrolysis hydrocarbon content S2 was obtained by heating the temperature to 600℃ at a rate of 25℃ per minute. Core sample D was cryogenically sealed and then dissected under continuous liquid nitrogen priming. Desorption parameters and corresponding time points were measured and recorded using a desorption device at a set desorption temperature to obtain a desorption time-desorption gas volume data table. The desorption gas content was calculated. The desorbed core sample was then fragmented and desorbed again to obtain residual gas test records. The gas content and lost gas content were calculated. The sum of the desorption gas content, the remaining gas content, and the lost gas content is the residual gas content V upon drilling. * .

4. The method for in-situ determination of hydrocarbon content in shale oil according to claim 3, characterized in that, The free oil drilling loss coefficient The method of obtaining it is: ； in: S 1 indicates free oil content; S 1 * Indicates the content of residual oil after drilling; This indicates the density of the core sample; The desorption gas loss coefficient The method of obtaining it is: ； in: V Indicates gas content; V * This indicates the residual gas content after drilling; The light hydrocarbon loss coefficient The method of obtaining it is: ； in: S 1 * Indicates the content of residual oil after drilling; This indicates the residual free oil content at each time point.

5. The method for in-situ determination of hydrocarbon content in shale oil according to claim 4, characterized in that, The oil and gas content under the in-situ formation conditions of the shale oil Y The method of obtaining it is: ； in: Indicates the residual free oil content; Indicates the light hydrocarbon loss coefficient; Indicates the free oil extraction loss coefficient; Indicates the content of pyrolytic hydrocarbons; Indicates the correction factor for heavy hydrocarbons; Indicates the analytical gas loss coefficient; V * This indicates the residual gas content after drilling.

6. A device for in-situ determination of hydrocarbon content in shale oil, characterized in that, include: The experimental module is used to obtain the first core sample of shale using the pressure-holding coring method, and to obtain the free oil content and gas content of the first core sample. The second core sample of shale was obtained using the conventional coring method. The residual oil content, pyrolysis hydrocarbon content and residual gas content of the second core sample were obtained, as well as the residual free oil content of the second core sample. The hydrocarbon loss module is used to obtain the free oil loss coefficient, which characterizes the loss of free oil in the core sample, based on the free oil content and the residual oil content after drilling; the desorbed gas loss coefficient, which characterizes the loss of gas in the core sample, based on the gas content and the residual gas content after drilling; and the light hydrocarbon loss coefficient, which characterizes the loss of light hydrocarbons in the core sample, based on the residual oil content after drilling and the residual free oil content. The heavy hydrocarbon content and kerogen content of the second core sample were obtained, and the heavy hydrocarbon correction coefficient characterizing the heavy hydrocarbon loss of the core sample was obtained based on the heavy hydrocarbon content and kerogen content. The correction module is used to obtain the oil and gas content of shale oil under in-situ formation conditions based on the residual free oil content, light hydrocarbon loss coefficient, free oil drilling loss coefficient, pyrolysis hydrocarbon content, heavy hydrocarbon correction coefficient, desorption gas loss coefficient, and residual gas content after drilling. The determination of the residual free oil content includes: For core samples remaining after conventional core sampling, the samples were placed at room temperature for 1 hour, 2 hours, 4 hours, 8 hours, 24 hours, 48 ​​hours, 96 hours, 192 hours, and 360 hours, respectively, and then crushed. The core powder samples were placed in a pyrolysis apparatus and kept at 300℃ for 3 minutes to obtain the residual free oil content S1 at each time point. (1) S1 (2) S1 (4) ...S1 (360) The residual free oil content S1 at each time point (1) S1 (2) S1 (4) ...S1 (360) As residual free oil content ; The process of obtaining the heavy hydrocarbon correction coefficient includes: Obtain a core sample from a conventional core. After crushing the sample at room temperature, place the core powder sample into a pyrolysis apparatus. Maintain a constant temperature of 200℃ for 1 minute to obtain the light oil content. Then, increase the temperature at 25℃ per minute to 350℃ and maintain a constant temperature for 1 minute to obtain the light-medium oil content. Continue increasing the temperature at the same rate to 450℃ and maintain a constant temperature for 1 minute to obtain the heavy hydrocarbon content (S). 2-1 Finally, the temperature was raised to 600℃ again at the same rate to obtain the kerogen content S. 2-2 ; Based on the heavy hydrocarbon content S 2-1 and kerogen content S 2-2 Obtain the heavy hydrocarbon correction factor, the heavy hydrocarbon correction factor The method of obtaining it is: ； in: This indicates the density of the core sample.

7. An electronic device, characterized in that, include: Memory and processor; The memory is used to store computer programs; When the processor executes the computer program stored in the memory, it implements the steps of the method for determining the in-situ oil and gas content of shale oil as described in any one of claims 1 to 5.

8. A computer-readable storage medium, characterized in that, Used to store a computer program, which, when executed by a processor, implements the steps of a method for determining the in-situ hydrocarbon content of shale oil as described in any one of claims 1 to 5.

Images