Oil gas filling identification method, system, equipment and medium

Abstract

The invention relates to the technical field of oil-gas exploration, and discloses an oil-gas filling identification method, system and equipment and a medium, which are used for recovering hydrocarbon fluid characteristics in an oil-gas filling process on the basis of microcosmic fine analysis of inclusion fluorescence characteristics, inclusion in-situ hydrocarbon chromaticity parameters and the like. The method effectively avoids the problems of judgment distortion, errors and the like caused by application of crude oil biomarkers in current oil reservoirs. Meanwhile, heterogeneity of reservoirs on a plane and a section of a research area is fully considered, comparison, optimization and verification are carried out in a manner of combining macroscopic characteristics of the inclusion and multiple parameters of in-situ hydrocarbon biomarkers in the inclusion in a dense-level sampling manner from a microscopic perspective, and the oil and gas filling direction and the oil and gas enrichment strata series can be effectively and accurately judged; and the unreliability of recovering oil and gas filling by a single method is avoided, and the method has great popularization and application values.

Description

Technical Field

[0001] The present invention relates to the technical field of oil and gas exploration, and in particular to an oil and gas filling identification method, system, equipment and medium. Background Art

[0002] At present, the most widely used methods for identifying oil and gas filling are mainly based on the characteristics of geochemical biomarker compounds of crude oil in current oil reservoirs, using oil source comparison method, nitrogen compound tracer method, etc., but each method has its own limitations. For example, for basins with multiple sets of source rocks and multiple depressions, the use of oil source comparison method for oil and gas filling identification will produce serious deviations and misjudgments, and it is difficult to identify the main oil and gas sources and migration directions. For basins where biodegradation has occurred, the use of nitrogen compound tracer method will seriously distort the identification results.

[0003] Therefore, a new method for identifying oil and gas injection is urgently needed to efficiently and accurately identify the oil and gas injection direction and oil and gas rich strata. Summary of the invention

[0004] The present invention provides an oil and gas charging identification method, system, equipment and medium, which are used to solve the defect that the existing oil and gas charging identification method is difficult to accurately identify the oil and gas charging direction and the oil and gas enrichment layer system.

[0005] The present invention provides an oil and gas filling identification method, comprising:

[0006] Acquire inclusion characteristic data and pore characteristic data of a reservoir sample to be tested, wherein the reservoir sample to be tested contains a plurality of hydrocarbon inclusions, and the inclusion characteristic data includes inclusion fluorescence characteristic data and inclusion hydrocarbon characteristic data, and the pore characteristic data includes pore fluid characteristic data and pore fluid fluorescence characteristic data;

[0007] According to the fluorescence characteristic data of the inclusions and the fluorescence characteristic data of the pore fluid, multiple hydrocarbon inclusions in the reservoir sample to be tested are divided into deep inclusions and shallow inclusions;

[0008] Obtaining biomarker compound data of deep inclusions and biomarker compound data of shallow inclusions, and obtaining a first biomarker compound parameter characterizing maturity and biodegradation degree, a second biomarker compound parameter characterizing parent material source, and a third biomarker compound parameter characterizing migration based on the biomarker compound data of the deep inclusions and the biomarker compound data of the shallow inclusions;

[0009] According to the first biomarker compound parameter, the second biomarker compound parameter and the third biomarker compound parameter, the biomarker compound parameters of the deep inclusions and the shallow inclusions are calibrated, and the oil and gas filling direction and the oil and gas enrichment strata of the reservoir sample to be tested are obtained.

[0010] In one embodiment, the inclusion fluorescence characteristic data includes any one of the following characteristics or any combination thereof: yellow, yellow-green, blue-white; the inclusion hydrocarbon characteristic data includes any one of the following characteristics or any combination thereof: heavy oil, medium oil, light oil, oil and gas, natural gas; the pore fluid characteristic data includes any one of the following characteristics or any combination thereof: oil-free, medium oil, light oil; the pore fluid fluorescence characteristic data includes any one of the following characteristics or any combination thereof: light yellow, yellow-green, blue-white-yellow-green, blue-white.

[0011] In one embodiment, the method of dividing a plurality of hydrocarbon inclusions in the reservoir sample to be tested into deep inclusions and shallow inclusions according to the inclusion fluorescence characteristic data and the pore fluid fluorescence characteristic data comprises:

[0012] The inclusion fluorescence characteristic data and pore fluid fluorescence characteristic data of multiple hydrocarbon inclusions in the reservoir sample to be tested are calibrated according to the depth, and the multiple hydrocarbon inclusions in the reservoir sample to be tested are divided into deep inclusions and shallow inclusions.

[0013] In one embodiment, the method of calibrating the inclusion fluorescence characteristic data and the pore fluid fluorescence characteristic data of the plurality of hydrocarbon inclusions in the reservoir sample to be tested according to the depth, and dividing the plurality of hydrocarbon inclusions in the reservoir sample to be tested into deep inclusions and shallow inclusions, comprises:

[0014] Hydrocarbon inclusions whose fluorescence characteristic data indicate that they are light oil are classified as deep inclusions;

[0015] Hydrocarbon inclusions whose fluorescence characteristic data indicate heavy oil or medium oil are classified as shallow inclusions.

[0016] In one embodiment, the first biomarker compound parameter includes a maturity parameter and a biodegradation degree parameter, wherein the maturity parameter includes any one of the following or any combination thereof: MPI, F1, S / R, and the biodegradation degree parameter includes the main peak carbon and / or 25-NHC 29 / C 30 H; the second biomarker compound parameters include any one of the following or any combination thereof: Pr / Ph, G (gammacerane) / RC31H, Pr / nC17, C28+29TT / Ts, SF, triaromatic dinostane / triaromatic sterane of the normal alkane series; the third biomarker compound parameters include any one of the following or any combination thereof: MDR, 2,4- / 1,4-DMDBT, 4,6- / 1,4-DMDBT, ββ / ααC29.

[0017] In one embodiment, the biomarker compound parameter calibration of the deep inclusions and the shallow inclusions is performed according to the first biomarker compound parameter, the second biomarker compound parameter and the third biomarker compound parameter, and the oil and gas filling direction and the oil and gas enrichment layer of the reservoir sample to be tested are obtained, including:

[0018] According to the first biomarker compound parameter, the oil and gas charging period and the enrichment / loss degree of the reservoir sample to be tested are obtained;

[0019] Based on the oil and gas charging period and crude oil enrichment / loss degree of the reservoir sample to be tested, and according to the second biomarker compound parameter, the oil and gas enrichment layer system of the reservoir sample to be tested is obtained;

[0020] According to the third biomarker compound parameter, the oil and gas charging direction of the reservoir sample to be tested is obtained.

[0021] In one embodiment, obtaining the oil and gas charging period and crude oil enrichment / loss degree of the reservoir sample to be tested according to the first biomarker compound parameter includes:

[0022] According to the maturity parameter in the first biomarker compound parameter, the crude oil density in the deep part where the deep inclusion is located and the crude oil density in the shallow part where the shallow inclusion is located in the reservoir sample to be tested are obtained;

[0023] According to the crude oil density in the deep part where the deep inclusions are located and in the shallow part where the shallow inclusions are located in the reservoir sample to be tested, the oil and gas filling period in the deep part where the deep inclusions are located and in the shallow part where the shallow inclusions are located in the reservoir sample to be tested is obtained;

[0024] Based on the oil and gas filling periods in the deep part where the deep inclusions are located and the shallow part where the shallow inclusions are located in the reservoir sample to be tested, and according to the biodegradation degree parameter in the first biomarker compound parameter, the crude oil enrichment / loss degree in the deep part where the deep inclusions are located and the shallow part where the shallow inclusions are located in the reservoir sample to be tested is obtained.

[0025] In one embodiment, the oil and gas filling period in the deep part where the deep inclusions are located and the shallow part where the shallow inclusions are located in the reservoir sample to be tested, and the degree of crude oil enrichment / loss in the deep part where the deep inclusions are located and the shallow part where the shallow inclusions are located in the reservoir sample to be tested, according to the biodegradation degree parameter in the first biomarker compound parameter, include:

[0026] When the deep inclusions in the reservoir sample to be tested are located in the deep part and / or the shallow inclusions in the shallow part, there is 25-NHC in the biodegradation degree parameter 29 / C 30 When the degraded crude oil is characterized by H, it is determined that there is a phenomenon of crude oil loss in the deep part where the deep inclusions are located and / or in the shallow part where the shallow inclusions are located in the reservoir sample to be tested;

[0027] Based on the oil and gas filling periods in the deep part where the deep inclusions are located and the shallow part where the shallow inclusions are located in the reservoir sample to be tested, and according to the location of the undegraded crude oil represented by the main peak carbon in the biodegradation degree parameter, the enrichment / loss degree of crude oil in the deep part where the deep inclusions are located and the shallow part where the shallow inclusions are located in the reservoir sample to be tested is obtained.

[0028] In one embodiment, the method of obtaining the oil and gas enrichment strata of the reservoir sample to be tested based on the oil and gas charging period and the degree of enrichment / loss of the reservoir sample to be tested and the second biomarker compound parameter comprises:

[0029] According to the second biomarker compound parameter, the difference in oil and gas properties between the deep part where the deep inclusion is located and the shallow part where the shallow inclusion is located in the reservoir sample to be tested is obtained;

[0030] Based on the oil and gas charging period and enrichment / loss degree of the reservoir sample to be tested, combined with the difference in oil and gas properties between the deep part where the deep inclusions are located and the shallow part where the shallow inclusions are located in the reservoir sample to be tested, the deep part where the deep inclusions indicating a better parent material source are located or the shallow part where the shallow inclusions are located are determined as the location of the oil and gas enriched stratum in the reservoir sample to be tested.

[0031] In one embodiment, obtaining the oil and gas charging direction of the reservoir sample to be tested according to the third biomarker compound parameter includes:

[0032] According to the changes of MDR, 2,4- / 1,4-DMDBT, 4,6- / 1,4-DMDBT in the third biomarker compound parameters in the deep part where the deep inclusions are located and the shallow part where the shallow inclusions are located in the reservoir sample to be tested, the oil and gas charging direction of the reservoir sample to be tested is obtained;

[0033] According to the changes of ββ / ααC29 in the third biomarker compound parameter in the deep part where the deep inclusions are located and in the shallow part where the shallow inclusions are located in the reservoir sample to be tested, the oil and gas charging direction of the reservoir sample to be tested is verified.

[0034] The present invention also provides an oil and gas filling identification system, comprising:

[0035] The data acquisition module is used to: acquire the inclusion characteristic data and pore characteristic data of the reservoir sample to be tested, wherein the reservoir sample to be tested contains a plurality of hydrocarbon inclusions, and the inclusion characteristic data includes inclusion fluorescence characteristic data and inclusion hydrocarbon characteristic data, and the pore characteristic data includes pore fluid characteristic data and pore fluid fluorescence characteristic data;

[0036] A classification module is used to: classify multiple hydrocarbon inclusions in the reservoir sample to be tested into deep inclusions and shallow inclusions according to the inclusion fluorescence characteristic data and the pore fluid fluorescence characteristic data;

[0037] The biomarker parameter acquisition module is used to: obtain the biomarker compound data of the deep inclusions and the biomarker compound data of the shallow inclusions, and obtain the first biomarker compound parameter representing the maturity and biodegradation degree, the second biomarker compound parameter representing the parent material source, and the third biomarker compound parameter representing migration according to the biomarker compound data of the deep inclusions and the biomarker compound data of the shallow inclusions;

[0038] The oil and gas filling identification module is used to calibrate the biomarker compound parameters of deep inclusions and shallow inclusions according to the first biomarker compound parameter, the second biomarker compound parameter and the third biomarker compound parameter, and obtain the oil and gas filling direction and oil and gas enrichment layer system of the reservoir sample to be tested.

[0039] The present invention also provides an electronic device, comprising a processor and a memory storing a computer program, wherein the processor implements any of the above-mentioned oil and gas filling identification methods when executing the computer program.

[0040] The present invention also provides a non-transitory computer-readable storage medium on which a computer program is stored. When the computer program is executed by a processor, any of the above-mentioned oil and gas filling identification methods is implemented.

[0041] The present invention also provides a computer program product, which includes a computer program. The computer program can be stored on a non-transitory computer-readable storage medium. When the computer program is executed by a processor, the computer can execute any of the above-mentioned oil and gas filling identification methods.

[0042] The oil and gas filling identification method, system, equipment and medium provided by the present invention divide multiple hydrocarbon inclusions in the reservoir sample to be tested into deep inclusions and shallow inclusions according to the fluorescence characteristic data of the inclusions and the fluorescence characteristic data of the pore fluid, and then calibrate the biomarker compound parameters of the deep inclusions and the shallow inclusions according to the first biomarker compound parameter, the second biomarker compound parameter and the third biomarker compound parameter, and obtain the oil and gas filling direction and the oil and gas enrichment stratum of the reservoir sample to be tested, which can efficiently and accurately identify the oil and gas filling direction and the oil and gas enrichment stratum, help oil and gas exploration decision-making, and effectively improve the success rate of exploring oil and gas reservoirs.

[0043] The present invention provides a method, system, equipment and medium for identifying oil and gas filling. Based on microscopic fine analysis of the fluorescence characteristics of inclusions, the colorimetric parameters of in-situ hydrocarbons in inclusions, etc., the method can restore the characteristics of hydrocarbon fluids in the oil and gas filling process. The method effectively avoids the problems of distortion and error caused by the use of crude oil biomarkers in current oil reservoirs. At the same time, the heterogeneity of the reservoir in the plane and section of the study area is fully considered. From a microscopic perspective, the method uses a combination of macroscopic characteristics of inclusions and multi-parameters of in-situ hydrocarbon biomarkers in inclusions to conduct comparison, optimization and verification in a dense sampling manner. The direction of oil and gas filling and the oil and gas enrichment strata can be effectively and accurately judged, avoiding the unreliability of restoring oil and gas filling by a single method. The method has great value for promotion and application. BRIEF DESCRIPTION OF THE DRAWINGS

[0044] In order to more clearly illustrate the technical solutions in the present invention or the prior art, the drawings required for use in the embodiments or the description of the prior art will be briefly introduced below. Obviously, the drawings described below are some embodiments of the present invention. For ordinary technicians in this field, other drawings can be obtained based on these drawings without paying creative work.

[0045] Figure 1 A schematic flow chart of an oil and gas charging identification method provided by the present invention.

[0046] Figure 2 This is an example diagram of the distribution of fluorescence characteristics of inclusions.

[0047] Figure 3 This is an example diagram of the distribution of the first biomarker compound parameters.

[0048] Figure 4 This is an example diagram of the distribution of parameters of the second biomarker compound.

[0049] Figure 5 This is an example diagram of the parameter distribution of the third biomarker compound.

[0050] Figure 6 The present invention provides a schematic structural diagram of an oil and gas filling identification system.

[0051] Figure 7 This is a schematic structural diagram of an electronic device provided by the present invention. DETAILED DESCRIPTION

[0052] In order to make the purpose, technical solution and advantages of the present invention clearer, the technical solution of the present invention will be clearly and completely described below in conjunction with the drawings in the present invention. Obviously, the described embodiments are part of the embodiments of the present invention, not all of the embodiments, and they should not be understood as limitations on the present invention. Based on the embodiments of the present invention, all other embodiments obtained by ordinary technicians in this field without creative work are within the scope of protection of the present invention. In the description of the present invention, it should be understood that the terms used are only for descriptive purposes and cannot be understood as indicating or implying relative importance.

[0053] Oil and gas migration is a long process in geological history. During the migration of oil and gas in the strata, they will react with the reservoir and be retained in the diagenetic cement of the reservoir to form inclusions, which show different characteristics under fluorescence. At the same time, the hydrocarbons retained in the inclusions can reflect the material composition of oil and gas migration in geological history. The biomarker compound characteristics of hydrocarbons in the inclusions can be seen by using the colorimetric analysis of inclusions. However, there is currently no method to identify oil and gas injection from the microscopic perspective of diagenetic minerals.

[0054] Combine the following Figure 1-Figure 7 The oil and gas filling identification method, system, device and medium provided by the present invention are described. It should be noted that the execution subject of the oil and gas filling identification method provided by the present invention can be any network side device / terminal side device that meets the technical requirements, such as an oil and gas filling identification device.

[0055] Figure 1 Schematic diagram of the flow chart of the oil and gas filling identification method provided by the present invention. Figure 1 The present invention provides a method for identifying oil and gas filling, which may include:

[0056] Step S110, obtaining inclusion characteristic data and pore characteristic data of the reservoir sample to be tested, wherein the reservoir sample to be tested contains multiple hydrocarbon inclusions, and the inclusion characteristic data includes inclusion fluorescence characteristic data and inclusion hydrocarbon characteristic data, and the pore characteristic data includes pore fluid characteristic data and pore fluid fluorescence characteristic data.

[0057] Specifically, the inclusion fluorescence characteristic data include any one of the following characteristics or any combination thereof: yellow, yellow-green, and blue-white; the inclusion hydrocarbon characteristic data include any one of the following characteristics or any combination thereof: heavy oil, medium oil, light oil, oil and gas, and natural gas; the pore fluid characteristic data include any one of the following characteristics or any combination thereof: oil-free, medium oil, and light oil; the pore fluid fluorescence characteristic data include any one of the following characteristics or any combination thereof: light yellow, yellow-green, blue-white-yellow-green, and blue-white.

[0058] The fluorescence characteristics of inclusions of different colors reflect the physical properties of hydrocarbons in the inclusions. Yellow represents a relatively high density (basically greater than 0.85g / cm 3 ), darker heavy oil, yellow-green represents medium density (0.8-0.85g / cm 3 ) of medium crude oil, blue and white represent light density (less than 0.8g / cm 3 ) is a light oil rich in natural gas. Similarly, the fluorescence characteristics of pore fluids of different colors reflect different pore fluid characteristics. Blue-white-yellow-green is a transitional color, and the density of crude oil is between light oil and medium crude oil.

[0059] Specifically, step S110 can select reservoir samples based on equal spacing. For example, reservoirs of different depths can be sampled at equal intervals, and the spacing depends on the overall thickness of the reservoir. For example, a 500m thick reservoir can be sampled at a spacing of 10m, and 50 reservoir samples are preferably taken from each layer; taking two sets of reservoirs as an example, each sampling well will obtain 100 reservoir samples, and the number of sampling wells in each study area is preferably greater than 2.

[0060] Step S120: Divide the multiple hydrocarbon inclusions in the reservoir sample to be tested into deep inclusions and shallow inclusions according to the inclusion fluorescence characteristic data and the pore fluid fluorescence characteristic data.

[0061] In one embodiment, step S120 calibrates the inclusion fluorescence characteristic data and pore fluid fluorescence characteristic data of multiple hydrocarbon inclusions in the reservoir sample to be tested according to the depth, and classifies hydrocarbon inclusions whose inclusion fluorescence characteristic data indicate light oil as deep inclusions, and classifies hydrocarbon inclusions whose inclusion fluorescence characteristic data indicate heavy oil or medium oil as shallow inclusions.

[0062] Step S130, obtaining biomarker compound data of deep inclusions and biomarker compound data of shallow inclusions, and obtaining a first biomarker compound parameter characterizing maturity and biodegradation degree, a second biomarker compound parameter characterizing parent material origin, and a third biomarker compound parameter characterizing migration based on the biomarker compound data of the deep inclusions and the biomarker compound data of the shallow inclusions.

[0063] Specifically, the first biomarker compound parameter includes a maturity parameter and a biodegradation degree parameter, wherein the maturity parameter includes any one of the following or any combination thereof: MPI, F1, S / R, and the biodegradation degree parameter includes the main peak carbon and / or 25-NHC 29 / C 30H; the second biomarker compound parameters include any one of the following or any combination thereof: Pr / Ph, G (gammacerane) / RC31H, Pr / nC17, C28+29TT / Ts, SF, triaromatic dinostane / triaromatic sterane of the normal alkane series; the third biomarker compound parameters include any one of the following or any combination thereof: MDR, 2,4- / 1,4-DMDBT, 4,6- / 1,4-DMDBT, ββ / ααC29.

[0064] Biomarker compounds refer to compounds in hydrocarbons that have characteristic and stable carbon skeletons and retain the carbon skeleton of their original precursors that can be identified and traced. The ratio between the contents of different biomarker compounds identified experimentally is used as a biomarker compound parameter. For example, if the content of biomarker compound A is m and the content of biomarker compound B is n, then the parameter A / B = m / n. The inheritance of the carbon skeleton structure allows some biomarker compounds to retain information representing the source of the parent material. Some biomarker compounds show regular changes with the thermal evolution of organic matter, and some ratio parameters of their isomers are often used as maturity parameters. Due to the particularity of the molecular structure, some biomarker compounds form molecular bonds with the drainage layer. With the increase of migration distance, the maturity shows regular changes, thereby characterizing the migration direction. For example, the aromatic hydrocarbon indicators MDR, 2,4- / 1,4-DMDBT, and 4,6- / 1,4-DMDBT decrease with the increase of migration distance, and the saturated hydrocarbon indicator C 29 ββ / αα increases with the increase of migration distance.

[0065] Step S140, calibrating the biomarker compound parameters of the deep inclusions and the shallow inclusions according to the first biomarker compound parameter, the second biomarker compound parameter and the third biomarker compound parameter, and obtaining the oil and gas filling direction and the oil and gas rich layer system of the reservoir sample to be tested, wherein the oil and gas rich layer system refers to the depth and layer system where the oil and gas mainly accumulate in the longitudinal direction.

[0066] In one embodiment, step S140 may include:

[0067] Step S1401: Obtain the oil and gas charging period and the degree of enrichment / loss of the reservoir sample to be tested according to the first biomarker compound parameter.

[0068] Specifically, step S1401 may include:

[0069] According to the maturity parameter in the first biomarker compound parameter, the crude oil density in the deep part where the deep inclusion is located and the crude oil density in the shallow part where the shallow inclusion is located in the reservoir sample to be tested are obtained;

[0070] According to the crude oil density in the deep part where the deep inclusions are located and in the shallow part where the shallow inclusions are located in the reservoir sample to be tested, the oil and gas filling period in the deep part where the deep inclusions are located and in the shallow part where the shallow inclusions are located in the reservoir sample to be tested is obtained;

[0071] Based on the oil and gas filling period in the deep part where the deep inclusions are located and the shallow part where the shallow inclusions are located in the reservoir sample to be tested, the crude oil enrichment / loss degree in the deep part where the deep inclusions are located and the shallow part where the shallow inclusions are located in the reservoir sample to be tested is obtained according to the biodegradation degree parameter in the first biomarker compound parameter. Specifically, when there is 25-NHC in the biodegradation degree parameter in the deep part where the deep inclusions are located and / or in the shallow part where the shallow inclusions are located in the reservoir sample to be tested, 29 / C 30 When there is degraded crude oil characterized by H, it is determined that there is crude oil loss in the deep part where the deep inclusions are located and / or in the shallow part where the shallow inclusions are located in the reservoir sample to be tested; based on the oil and gas filling period in the deep part where the deep inclusions are located and the shallow part where the shallow inclusions are located in the reservoir sample to be tested, according to the position of the undegraded crude oil characterized by the main peak carbon in the biodegradation degree parameter, the crude oil enrichment / loss degree in the deep part where the deep inclusions are located and the shallow part where the shallow inclusions are located in the reservoir sample to be tested is obtained.

[0072] Step S1402, based on the oil and gas charging period and crude oil enrichment / loss degree of the reservoir sample to be tested, and according to the second biomarker compound parameter, the oil and gas enrichment stratum of the reservoir sample to be tested is obtained;

[0073] Specifically, step S1402 may include:

[0074] According to the second biomarker compound parameter, the difference in oil and gas properties between the deep part where the deep inclusions are located and the shallow part where the shallow inclusions are located in the reservoir sample to be tested is obtained. Among them, the difference in oil and gas properties between the deep part where the deep inclusions are located and the shallow part where the shallow inclusions are located in the reservoir sample to be tested is mainly obtained based on the comparison of the parameter values ​​of the second biomarker compound parameter. For example, C28+29TT / Ts and SF, the larger the parameter value, the better the parent material source. For another example, Pr / nC17, the smaller the parameter value, the better the parent material source.

[0075] Based on the oil and gas charging period and enrichment / loss degree of the reservoir sample to be tested, combined with the difference in oil and gas properties between the deep part where the deep inclusions are located and the shallow part where the shallow inclusions are located in the reservoir sample to be tested, the deep part where the deep inclusions indicating a better parent material source are located or the shallow part where the shallow inclusions are located are determined as the location of the oil and gas enriched stratum in the reservoir sample to be tested.

[0076] Step S1403: Obtain the oil and gas charging direction of the reservoir sample to be tested according to the third biomarker compound parameter.

[0077] Specifically, step S1403 may include:

[0078] According to the changes of MDR, 2,4- / 1,4-DMDBT, 4,6- / 1,4-DMDBT in the third biomarker compound parameters in the deep part where the deep inclusions are located and the shallow part where the shallow inclusions are located in the reservoir sample to be tested, the oil and gas charging direction of the reservoir sample to be tested is obtained;

[0079] According to the changes of ββ / ααC29 in the third biomarker compound parameter in the deep part where the deep inclusions are located and in the shallow part where the shallow inclusions are located in the reservoir sample to be tested, the oil and gas charging direction of the reservoir sample to be tested is verified.

[0080] The following is a specific example to illustrate how to determine the oil and gas filling direction and oil and gas rich strata in the Bodong low uplift area of ​​the Bohai Bay Basin by using the oil and gas filling identification method provided by the present invention.

[0081] Two sampling wells were determined at an equal interval of 5 km in the Bodong low-rise area of ​​the Bohai Bay Basin. The reservoir of each well was sampled at an equal interval of 10 m, and 40-50 reservoir samples were sampled from each well; a total of 100 reservoir samples were taken from the two wells as the reservoir samples to be tested.

[0082] The obtained reservoir samples were extracted with dilute hydrochloric acid and then ground to obtain 100 rock thin sections.

[0083] The rock thin sections are identified and observed under fluorescence. A high-resolution microscope + automated image recognition computer is used to distinguish and count the inclusions. The inclusion fluorescence characteristic data and inclusion hydrocarbon characteristic data of the inclusions in each rock thin section are recorded, and the pore fluid characteristic data and pore fluid fluorescence characteristic data in the pores are identified. The inclusion fluorescence characteristic data includes any of the following characteristics or any combination thereof: yellow, yellow-green, blue-white; the inclusion hydrocarbon characteristic data includes any of the following characteristics or any combination thereof: heavy oil, medium oil, light oil, oil and gas, natural gas; the pore fluid characteristic data includes any of the following characteristics or any combination thereof: no oil, medium oil, light oil; the pore fluid fluorescence characteristic data includes any of the following characteristics or any combination thereof: light yellow, yellow-green, blue-white-yellow-green, blue-white.

[0084] The fluorescence characteristic data of the inclusions and the fluorescence characteristic data of the pore fluid in the reservoir sample to be tested are calibrated according to the depth (see Figure 2), it can be seen that the pore fluorescence characteristics and inclusion fluorescence characteristics have a good correlation with depth. According to the depth, the inclusions can be divided into two categories: deep inclusions and shallow inclusions. At the same time, the reservoir samples to be tested can be divided into shallow reservoirs (i.e., the shallow part where the shallow inclusions are located) and deep reservoirs (i.e., the deep part where the deep inclusions are located). ① The inclusion fluorescence of the shallow reservoir is mainly light yellow and yellow-green, representing heavy oil and heavy oil. At the same time, from the distribution of pore oil content, it shows that there is no oil, which can be called the upper oil-bearing layer system; ② The inclusion fluorescence of the deep reservoir shows blue-white and light oil characteristics. At the same time, from the distribution of pore oil content, it shows that it is mainly light oil, which can be called the lower oil-bearing layer system.

[0085] The hydrocarbons in the two types of inclusions were taken out to conduct chromatographic analysis of saturated hydrocarbons and aromatic hydrocarbons, and the biomarker compound data of deep inclusions and shallow inclusions were obtained. Based on the biomarker compound data of deep inclusions and shallow inclusions, the first biomarker compound parameter characterizing maturity and biodegradation, the second biomarker compound parameter characterizing the source of the parent material, and the third biomarker compound parameter characterizing migration were obtained. The first biomarker compound parameter, the second biomarker compound parameter, and the third biomarker compound parameter can be calibrated according to the depth, and then the oil and gas filling direction and oil and gas enrichment strata in the Bodong low uplift area of ​​the Bohai Bay Basin are analyzed.

[0086] (1) See Figure 3 According to the first biomarker compound parameter combination MPI, F1, S / R, main peak carbon, 25-NHC 29 / C 30 H, analysis of oil and gas charging period and crude oil enrichment / loss degree: crude oil maturity is calculated by MPI, F1, S / R parameters. The results show that both deep and shallow reservoirs are charged with two kinds of crude oil. The crude oil with Ro = 0.6% has a higher density and is heavy crude oil. The corresponding inclusion fluorescence is yellow or yellow-green. The crude oil with Ro = 1.3% has a lower density and is light crude oil. The corresponding inclusion fluorescence is blue-white. That is, in the geological history, both deep and shallow reservoirs have developed two crude oil charges. From the 25-NHC 29 / C 30 H, 25-NHC also exists in both deep and shallow reservoirs. 29 / C 30H, that is, there is a phenomenon of crude oil loss, and the main peak carbon parameter characterizing the undegraded crude oil is mainly developed in the deep reservoir, indicating that the degraded and lost crude oil is mainly the heavy crude oil charged in the first phase, that is, the crude oil charged in the first phase of the deep reservoir and the shallow reservoir has lost. The main peak carbon parameter characterizes the undegraded crude oil, that is, the light oil charged in the second phase. From the distribution of parameters, it is mainly concentrated in the deep reservoir. Therefore, it is believed that although the heavy crude oil charged in the first phase of the deep reservoir has been lost, the light crude oil in the second phase is further charged and enriched, while the light oil charged in the second phase of the shallow reservoir is very little, mainly the residual part left after the heavy crude oil charged in the first phase is lost. Therefore, through the combination of the first biomarker compound parameters, it can be judged that the deep reservoir is the main oil and gas enrichment layer, and the shallow reservoir is mainly residual oil and gas, not the main enrichment layer.

[0087] (2) See Figure 4 According to the second biomarker compound parameter combination Pr / Ph, G (gammacerane)

[0088] / RC31H, Pr / nC17, C28+29TT / Ts, SF, tristanol / tristanol, to judge the properties of oil and gas. From the distribution of parameters, the difference in oil and gas properties between deep reservoirs and shallow reservoirs is obvious. The oil and gas Pr / nC17 and Pr / Ph of deep reservoirs are lower than those of shallow reservoirs, while G (gammacerane) / RC31H, Pr / nC17, tristanol / tristanol are higher than those of shallow reservoirs, which confirms that there are differences in oil and gas properties between deep reservoirs and shallow reservoirs. Since shallow reservoirs are residual oil after biodegradation, the parameters Pr / nC17 and Pr / Ph that characterize poor parent material sources are high, while the parameters G (gammacerane) / RC31H, Pr / nC17, tristanol / tristanol are lower than those of deep reservoirs. The deep reservoir is mainly rich in light oil injected in the second phase, so the parameter combination characterizing the source of parent material is due to the shallow reservoir. Therefore, the deep reservoir is the main oil and gas enrichment layer, and the shallow reservoir indicates that the small amount of residual oil and gas is not the main oil and gas enrichment layer.

[0089] (3) See Figure 5, the migration direction of oil and gas was analyzed based on the third biomarker compound parameter combination MDR, 2,4- / 1,4-DMDBT, 4,6- / 1,4-DMDBT, and ββ / ααC29. This type of parameter is mainly developed in deep reservoirs, and the shallow reservoirs have a low degree of development of this type of parameter due to biodegradation. From the relationship between the change of parameters and depth, MDR, 2,4- / 1,4-DMDBT, and 4,6- / 1,4-DMDBT in deep reservoirs all become smaller as the depth becomes shallower, which means that the deep oil and gas mainly migrate from bottom to top. The characteristic of the migration index ββ / ααC29 increasing with depth also confirms that the deep reservoir oil and gas migrate from bottom to top, that is, the deep reservoir oil and gas have the characteristic of vertical upward migration.

[0090] The oil and gas filling identification method, system, equipment and medium provided by the present invention divide multiple hydrocarbon inclusions in the reservoir sample to be tested into deep inclusions and shallow inclusions according to the fluorescence characteristic data of the inclusions and the fluorescence characteristic data of the pore fluid, and then calibrate the biomarker compound parameters of the deep inclusions and the shallow inclusions according to the first biomarker compound parameter, the second biomarker compound parameter and the third biomarker compound parameter, and obtain the oil and gas filling direction and the oil and gas enrichment stratum of the reservoir sample to be tested, which can efficiently and accurately identify the oil and gas filling direction and the oil and gas enrichment stratum, help oil and gas exploration decision-making, and effectively improve the success rate of exploring oil and gas reservoirs.

[0091] The present invention provides a method, system, equipment and medium for identifying oil and gas filling. Based on microscopic fine analysis of the fluorescence characteristics of inclusions, the colorimetric parameters of in-situ hydrocarbons in inclusions, etc., the method can restore the characteristics of hydrocarbon fluids in the oil and gas filling process. The method effectively avoids the problems of distortion and error caused by the use of crude oil biomarkers in current oil reservoirs. At the same time, the heterogeneity of the reservoir in the plane and section of the study area is fully considered. From a microscopic perspective, the method uses a combination of macroscopic characteristics of inclusions and multi-parameters of in-situ hydrocarbon biomarkers in inclusions to conduct comparison, optimization and verification in a dense sampling manner. The direction of oil and gas filling and the oil and gas enrichment strata can be effectively and accurately judged, avoiding the unreliability of restoring oil and gas filling by a single method. The method has great value for promotion and application.

[0092] The oil and gas filling identification system provided by the present invention is described below. The oil and gas filling identification system described below and the oil and gas filling identification method described above can be referenced to each other.

[0093] Reference Figure 6 The present invention provides an oil and gas filling identification system, which may include:

[0094] The data acquisition module is used to: acquire the inclusion characteristic data and pore characteristic data of the reservoir sample to be tested, wherein the reservoir sample to be tested contains a plurality of hydrocarbon inclusions, and the inclusion characteristic data includes inclusion fluorescence characteristic data and inclusion hydrocarbon characteristic data, and the pore characteristic data includes pore fluid characteristic data and pore fluid fluorescence characteristic data;

[0095] A classification module is used to: classify multiple hydrocarbon inclusions in the reservoir sample to be tested into deep inclusions and shallow inclusions according to the inclusion fluorescence characteristic data and the pore fluid fluorescence characteristic data;

[0096] The biomarker parameter acquisition module is used to: obtain the biomarker compound data of the deep inclusions and the biomarker compound data of the shallow inclusions, and obtain the first biomarker compound parameter representing the maturity and biodegradation degree, the second biomarker compound parameter representing the parent material source, and the third biomarker compound parameter representing migration according to the biomarker compound data of the deep inclusions and the biomarker compound data of the shallow inclusions;

[0097] The oil and gas filling identification module is used to calibrate the biomarker compound parameters of deep inclusions and shallow inclusions according to the first biomarker compound parameter, the second biomarker compound parameter and the third biomarker compound parameter, and obtain the oil and gas filling direction and oil and gas enrichment layer system of the reservoir sample to be tested.

[0098] In one embodiment, the classification module may include:

[0099] The calibration submodule is used to calibrate the inclusion fluorescence characteristic data and pore fluid fluorescence characteristic data of multiple hydrocarbon inclusions in the reservoir sample to be tested according to the depth, and divide the multiple hydrocarbon inclusions in the reservoir sample to be tested into deep inclusions and shallow inclusions.

[0100] In one embodiment, the calibration submodule may include:

[0101] The first submodule is used to: classify hydrocarbon inclusions whose inclusion fluorescence characteristic data indicates that they are light oil as deep inclusions;

[0102] The second submodule is used to classify hydrocarbon inclusions whose fluorescence characteristic data indicate that they are heavy oil or medium oil as shallow inclusions.

[0103] In one embodiment, the oil and gas charging identification module may include:

[0104] The first analysis submodule is used to obtain the oil and gas charging period and the enrichment / loss degree of the reservoir sample to be tested according to the first biomarker compound parameter;

[0105] The second analysis submodule is used to obtain the oil and gas enrichment layer of the reservoir sample to be tested based on the oil and gas charging period and crude oil enrichment / loss degree of the reservoir sample to be tested and the second biomarker compound parameter;

[0106] The third analysis submodule is used to obtain the oil and gas charging direction of the reservoir sample to be tested according to the third biomarker compound parameter.

[0107] In one embodiment, the first analysis submodule may include:

[0108] The crude oil density obtaining submodule is used to obtain the crude oil density of the deep part where the deep inclusions are located and the shallow part where the shallow inclusions are located in the reservoir sample to be tested according to the maturity parameter in the first biomarker compound parameter;

[0109] The oil and gas charging period analysis submodule is used to obtain the oil and gas charging period in the deep part where the deep inclusion is located and the shallow part where the shallow inclusion is located in the reservoir sample to be tested according to the crude oil density in the deep part where the deep inclusion is located and the shallow part where the shallow inclusion is located in the reservoir sample to be tested;

[0110] The first enrichment layer analysis submodule is used to obtain the degree of crude oil enrichment / loss in the deep part where the deep inclusions are located and the shallow part where the shallow inclusions are located in the reservoir sample to be tested, based on the oil and gas filling periods in the deep part where the deep inclusions are located and the shallow part where the shallow inclusions are located in the reservoir sample to be tested, and according to the biodegradation degree parameter in the first biomarker compound parameter.

[0111] In one embodiment, the first enrichment series analysis submodule may include:

[0112] The judgment submodule is used to: when the 25-NHC in the biodegradation degree parameter exists in the deep part where the deep inclusion is located and / or the shallow part where the shallow inclusion is located in the reservoir sample to be tested 29 / C 30 When the degraded crude oil is characterized by H, it is determined that there is a phenomenon of crude oil loss in the deep part where the deep inclusions are located and / or in the shallow part where the shallow inclusions are located in the reservoir sample to be tested;

[0113] The submodule for obtaining the degree of crude oil enrichment / loss is used to obtain the degree of crude oil enrichment / loss in the deep part where the deep inclusions are located and the shallow part where the shallow inclusions are located in the reservoir sample to be tested, based on the oil and gas filling periods in the deep part where the deep inclusions are located and the shallow part where the shallow inclusions are located in the reservoir sample to be tested, and according to the position of the undegraded crude oil represented by the main peak carbon in the biodegradation degree parameter.

[0114] In one embodiment, the second analysis submodule may include:

[0115] The oil and gas property difference analysis submodule is used to: obtain the oil and gas property difference between the deep part where the deep inclusion is located and the shallow part where the shallow inclusion is located in the reservoir sample to be tested according to the second biomarker compound parameter;

[0116] The second enrichment stratum analysis submodule is used to: based on the oil and gas filling period and enrichment / loss degree of the reservoir sample to be tested, combined with the difference in oil and gas properties between the deep part where the deep inclusions are located and the shallow part where the shallow inclusions are located in the reservoir sample to be tested, determine the deep part where the deep inclusions indicating a better parent material source are located or the shallow part where the shallow inclusions are located as the location of the oil and gas enrichment stratum in the reservoir sample to be tested.

[0117] In one embodiment, the third analysis submodule may include:

[0118] The oil and gas charging direction analysis submodule is used to obtain the oil and gas charging direction of the reservoir sample to be tested according to the changes of MDR, 2,4- / 1,4-DMDBT, 4,6- / 1,4-DMDBT in the third biomarker compound parameters in the deep part where the deep inclusions are located and the shallow part where the shallow inclusions are located in the reservoir sample to be tested;

[0119] The verification submodule is used to verify the oil and gas filling direction of the reservoir sample to be tested according to the changes of ββ / ααC29 in the third biomarker compound parameter in the deep part where the deep inclusions are located and the shallow part where the shallow inclusions are located in the reservoir sample to be tested.

[0120] Figure 7 An example of a physical structure diagram of an electronic device is shown in FIG. Figure 7 As shown, the electronic device may include: a processor 810, a communication interface 820, a memory 830 and a communication bus 840, wherein the processor 810, the communication interface 820 and the memory 830 communicate with each other via the communication bus 840. The processor 810 may call the logic instructions in the memory 830 to execute the oil and gas filling identification method, which includes:

[0121] Acquire inclusion characteristic data and pore characteristic data of a reservoir sample to be tested, wherein the reservoir sample to be tested contains a plurality of hydrocarbon inclusions, and the inclusion characteristic data includes inclusion fluorescence characteristic data and inclusion hydrocarbon characteristic data, and the pore characteristic data includes pore fluid characteristic data and pore fluid fluorescence characteristic data;

[0122] According to the fluorescence characteristic data of the inclusions and the fluorescence characteristic data of the pore fluid, multiple hydrocarbon inclusions in the reservoir sample to be tested are divided into deep inclusions and shallow inclusions;

[0123] Obtaining biomarker compound data of deep inclusions and biomarker compound data of shallow inclusions, and obtaining a first biomarker compound parameter characterizing maturity and biodegradation degree, a second biomarker compound parameter characterizing parent material source, and a third biomarker compound parameter characterizing migration based on the biomarker compound data of the deep inclusions and the biomarker compound data of the shallow inclusions;

[0124] According to the first biomarker compound parameter, the second biomarker compound parameter and the third biomarker compound parameter, the biomarker compound parameters of the deep inclusions and the shallow inclusions are calibrated, and the oil and gas filling direction and the oil and gas enrichment strata of the reservoir sample to be tested are obtained.

[0125] In addition, the logic instructions in the above-mentioned memory 830 can be implemented in the form of a software functional unit and can be stored in a computer-readable storage medium when it is sold or used as an independent product. Based on such an understanding, the technical solution of the present invention, in essence, or the part that contributes to the prior art or the part of the technical solution, can be embodied in the form of a software product, and the computer software product is stored in a storage medium, including a number of instructions for a computer device (which can be a personal computer, a server, or a network device, etc.) to perform all or part of the steps of the method described in each embodiment of the present invention. The aforementioned storage medium includes: U disk, mobile hard disk, read-only memory (ROM, Read-Only Memory), random access memory (RAM, Random Access Memory), disk or optical disk and other media that can store program codes.

[0126] On the other hand, the present invention further provides a computer program product, the computer program product includes a computer program, the computer program can be stored in a non-transitory computer-readable storage medium, when the computer program is executed by a processor, the computer can execute the oil and gas charging identification method provided by the above methods, the method includes:

[0127] Acquire inclusion characteristic data and pore characteristic data of a reservoir sample to be tested, wherein the reservoir sample to be tested contains a plurality of hydrocarbon inclusions, and the inclusion characteristic data includes inclusion fluorescence characteristic data and inclusion hydrocarbon characteristic data, and the pore characteristic data includes pore fluid characteristic data and pore fluid fluorescence characteristic data;

[0128] According to the fluorescence characteristic data of the inclusions and the fluorescence characteristic data of the pore fluid, multiple hydrocarbon inclusions in the reservoir sample to be tested are divided into deep inclusions and shallow inclusions;

[0129] Obtaining biomarker compound data of deep inclusions and biomarker compound data of shallow inclusions, and obtaining a first biomarker compound parameter characterizing maturity and biodegradation degree, a second biomarker compound parameter characterizing parent material source, and a third biomarker compound parameter characterizing migration based on the biomarker compound data of the deep inclusions and the biomarker compound data of the shallow inclusions;

[0130] According to the first biomarker compound parameter, the second biomarker compound parameter and the third biomarker compound parameter, the biomarker compound parameters of the deep inclusions and the shallow inclusions are calibrated, and the oil and gas filling direction and the oil and gas enrichment strata of the reservoir sample to be tested are obtained.

[0131] In another aspect, the present invention further provides a non-transitory computer-readable storage medium having a computer program stored thereon, which is implemented when the computer program is executed by a processor to execute the oil and gas charging identification method provided by the above methods, the method comprising:

[0132] Acquire inclusion characteristic data and pore characteristic data of a reservoir sample to be tested, wherein the reservoir sample to be tested contains a plurality of hydrocarbon inclusions, and the inclusion characteristic data includes inclusion fluorescence characteristic data and inclusion hydrocarbon characteristic data, and the pore characteristic data includes pore fluid characteristic data and pore fluid fluorescence characteristic data;

[0133] According to the fluorescence characteristic data of the inclusions and the fluorescence characteristic data of the pore fluid, multiple hydrocarbon inclusions in the reservoir sample to be tested are divided into deep inclusions and shallow inclusions;

[0134] Obtaining biomarker compound data of deep inclusions and biomarker compound data of shallow inclusions, and obtaining a first biomarker compound parameter characterizing maturity and biodegradation degree, a second biomarker compound parameter characterizing parent material source, and a third biomarker compound parameter characterizing migration based on the biomarker compound data of the deep inclusions and the biomarker compound data of the shallow inclusions;

[0135] According to the first biomarker compound parameter, the second biomarker compound parameter and the third biomarker compound parameter, the biomarker compound parameters of the deep inclusions and the shallow inclusions are calibrated, and the oil and gas filling direction and the oil and gas enrichment strata of the reservoir sample to be tested are obtained.

[0136] The device embodiments described above are merely illustrative, wherein the units described as separate components may or may not be physically separated, and the components displayed as units may or may not be physical units, that is, they may be located in one place, or they may be distributed on multiple network units. Some or all of the modules may be selected according to actual needs to achieve the purpose of the scheme of this embodiment. Ordinary technicians in this field can understand and implement it without paying creative labor.

[0137] Through the description of the above implementation methods, those skilled in the art can clearly understand that each implementation method can be implemented by means of software plus a necessary general hardware platform, and of course, it can also be implemented by hardware. Based on this understanding, the above technical solution is essentially or the part that contributes to the prior art can be embodied in the form of a software product, and the computer software product can be stored in a computer-readable storage medium, such as ROM / RAM, a disk, an optical disk, etc., including a number of instructions for a computer device (which can be a personal computer, a server, or a network device, etc.) to execute the methods described in each embodiment or some parts of the embodiments.

[0138] Finally, it should be noted that the above embodiments are only used to illustrate the technical solutions of the present invention, rather than to limit it. Although the present invention has been described in detail with reference to the aforementioned embodiments, those skilled in the art should understand that they can still modify the technical solutions described in the aforementioned embodiments, or make equivalent replacements for some of the technical features therein. However, these modifications or replacements do not deviate the essence of the corresponding technical solutions from the spirit and scope of the technical solutions of the embodiments of the present invention.

Claims

1. A method for identifying oil and gas filling, characterized in that: include: Acquire inclusion characteristic data and pore characteristic data of a reservoir sample to be tested, wherein the reservoir sample to be tested contains a plurality of hydrocarbon inclusions, and the inclusion characteristic data includes inclusion fluorescence characteristic data and inclusion hydrocarbon characteristic data, and the pore characteristic data includes pore fluid characteristic data and pore fluid fluorescence characteristic data; According to the fluorescence characteristic data of the inclusions and the fluorescence characteristic data of the pore fluid, multiple hydrocarbon inclusions in the reservoir sample to be tested are divided into deep inclusions and shallow inclusions; Obtaining biomarker compound data of deep inclusions and biomarker compound data of shallow inclusions, and obtaining a first biomarker compound parameter characterizing maturity and biodegradation degree, a second biomarker compound parameter characterizing parent material source, and a third biomarker compound parameter characterizing migration based on the biomarker compound data of the deep inclusions and the biomarker compound data of the shallow inclusions; According to the first biomarker compound parameter, the second biomarker compound parameter and the third biomarker compound parameter, the biomarker compound parameters of the deep inclusions and the shallow inclusions are calibrated, and the oil and gas filling direction and the oil and gas enrichment strata of the reservoir sample to be tested are obtained.

2. The oil and gas charging identification method according to claim 1, characterized in that: The fluorescence characteristic data of inclusions include any one of the following characteristics or any combination thereof: yellow, yellow-green, blue-white; the hydrocarbon characteristic data of inclusions include any one of the following characteristics or any combination thereof: heavy oil, medium oil, light oil, oil and gas, natural gas; the pore fluid characteristic data include any one of the following characteristics or any combination thereof: oil-free, medium oil, light oil; the fluorescence characteristic data of pore fluids include any one of the following characteristics or any combination thereof: light yellow, yellow-green, blue-white-yellow-green, blue-white; The first biomarker compound parameter includes a maturity parameter and a biodegradation degree parameter. The maturity parameter includes any one of the following or any combination thereof: MPI, F1, S / R. The biodegradation degree parameter includes main peak carbon and / or 25-NHC. 29 / C 30 H; the second biomarker compound parameters include any one of the following or any combination thereof: Pr / Ph, G (gammacerane) / RC31H, Pr / nC17, C28+29TT / Ts, SF, triaromatic dinostane / triaromatic sterane of the normal alkane series; the third biomarker compound parameters include any one of the following or any combination thereof: MDR, 2,4- / 1,4-DMDBT, 4,6- / 1,4-DMDBT, ββ / ααC29.

3. The oil and gas filling identification method according to claim 2 is characterized in that: The method divides a plurality of hydrocarbon inclusions in the reservoir sample to be tested into deep inclusions and shallow inclusions according to the inclusion fluorescence characteristic data and the pore fluid fluorescence characteristic data, including: The inclusion fluorescence characteristic data and the pore fluid fluorescence characteristic data of the multiple hydrocarbon inclusions in the reservoir sample to be tested are calibrated according to the depth, and the multiple hydrocarbon inclusions in the reservoir sample to be tested are divided into deep inclusions and shallow inclusions; Preferably, the method of calibrating the inclusion fluorescence characteristic data and the pore fluid fluorescence characteristic data of the multiple hydrocarbon inclusions in the reservoir sample to be tested according to the depth, and dividing the multiple hydrocarbon inclusions in the reservoir sample to be tested into deep inclusions and shallow inclusions, comprises: Hydrocarbon inclusions whose fluorescence characteristic data indicate that they are light oil are classified as deep inclusions; Hydrocarbon inclusions whose fluorescence characteristic data indicate heavy oil or medium oil are classified as shallow inclusions.

4. The oil and gas filling identification method according to claim 3 is characterized in that: The method calibrates the biomarker compound parameters of the deep inclusions and the shallow inclusions according to the first biomarker compound parameter, the second biomarker compound parameter and the third biomarker compound parameter, and obtains the oil and gas filling direction and the oil and gas enrichment strata of the reservoir sample to be tested, including: According to the first biomarker compound parameter, the oil and gas charging period and the enrichment / loss degree of the reservoir sample to be tested are obtained; Based on the oil and gas charging period and crude oil enrichment / loss degree of the reservoir sample to be tested, and according to the second biomarker compound parameter, the oil and gas enrichment layer system of the reservoir sample to be tested is obtained; According to the third biomarker compound parameter, the oil and gas charging direction of the reservoir sample to be tested is obtained.

5. The oil and gas filling identification method according to claim 4 is characterized in that: The method of obtaining the oil and gas charging period and the degree of crude oil enrichment / loss of the reservoir sample to be tested according to the first biomarker compound parameter includes: According to the maturity parameter in the first biomarker compound parameter, the crude oil density in the deep part where the deep inclusion is located and the crude oil density in the shallow part where the shallow inclusion is located in the reservoir sample to be tested are obtained; According to the crude oil density in the deep part where the deep inclusions are located and in the shallow part where the shallow inclusions are located in the reservoir sample to be tested, the oil and gas filling period in the deep part where the deep inclusions are located and in the shallow part where the shallow inclusions are located in the reservoir sample to be tested is obtained; Based on the oil and gas charging periods in the deep part where the deep inclusions are located and the shallow part where the shallow inclusions are located in the reservoir sample to be tested, and according to the biodegradation degree parameter in the first biomarker compound parameter, the crude oil enrichment / loss degree in the deep part where the deep inclusions are located and the shallow part where the shallow inclusions are located in the reservoir sample to be tested is obtained; Preferably, the oil and gas filling period based on the deep part where the deep inclusions are located and the shallow part where the shallow inclusions are located in the reservoir sample to be tested, and the degree of crude oil enrichment / loss in the deep part where the deep inclusions are located and the shallow part where the shallow inclusions are located in the reservoir sample to be tested, according to the biodegradation degree parameter in the first biomarker compound parameter, comprises: When the deep inclusions in the reservoir sample to be tested are located in the deep part and / or the shallow inclusions in the shallow part, there is 25-NHC in the biodegradation degree parameter 29 / C 30 When the degraded crude oil is characterized by H, it is determined that there is a phenomenon of crude oil loss in the deep part where the deep inclusions are located and / or in the shallow part where the shallow inclusions are located in the reservoir sample to be tested; Based on the oil and gas filling periods in the deep part where the deep inclusions are located and the shallow part where the shallow inclusions are located in the reservoir sample to be tested, and according to the location of the undegraded crude oil represented by the main peak carbon in the biodegradation degree parameter, the enrichment / loss degree of crude oil in the deep part where the deep inclusions are located and the shallow part where the shallow inclusions are located in the reservoir sample to be tested is obtained.

6. The oil and gas charging identification method according to claim 5, characterized in that: The method of obtaining the oil and gas enrichment strata of the reservoir sample to be tested based on the oil and gas charging period and the degree of enrichment / loss of the reservoir sample to be tested and the second biomarker compound parameter includes: According to the second biomarker compound parameter, the difference in oil and gas properties between the deep part where the deep inclusion is located and the shallow part where the shallow inclusion is located in the reservoir sample to be tested is obtained; Based on the oil and gas charging period and enrichment / loss degree of the reservoir sample to be tested, combined with the difference in oil and gas properties between the deep part where the deep inclusions are located and the shallow part where the shallow inclusions are located in the reservoir sample to be tested, the deep part where the deep inclusions indicating a better parent material source are located or the shallow part where the shallow inclusions are located are determined as the location of the oil and gas enriched stratum in the reservoir sample to be tested.

7. The oil and gas filling identification method according to claim 6, characterized in that: The step of obtaining the oil and gas charging direction of the reservoir sample to be tested according to the third biomarker compound parameter includes: According to the changes of MDR, 2,4- / 1,4-DMDBT, 4,6- / 1,4-DMDBT in the third biomarker compound parameters in the deep part where the deep inclusions are located and the shallow part where the shallow inclusions are located in the reservoir sample to be tested, the oil and gas charging direction of the reservoir sample to be tested is obtained; According to the changes of ββ / ααC29 in the third biomarker compound parameter in the deep part where the deep inclusions are located and in the shallow part where the shallow inclusions are located in the reservoir sample to be tested, the oil and gas charging direction of the reservoir sample to be tested is verified.

8. An oil and gas filling identification system, characterized in that: include: The data acquisition module is used to: acquire the inclusion characteristic data and pore characteristic data of the reservoir sample to be tested, wherein the reservoir sample to be tested contains a plurality of hydrocarbon inclusions, and the inclusion characteristic data includes inclusion fluorescence characteristic data and inclusion hydrocarbon characteristic data, and the pore characteristic data includes pore fluid characteristic data and pore fluid fluorescence characteristic data; A classification module is used to: classify multiple hydrocarbon inclusions in the reservoir sample to be tested into deep inclusions and shallow inclusions according to the inclusion fluorescence characteristic data and the pore fluid fluorescence characteristic data; The biomarker parameter acquisition module is used to: obtain the biomarker compound data of the deep inclusions and the biomarker compound data of the shallow inclusions, and obtain the first biomarker compound parameter representing the maturity and biodegradation degree, the second biomarker compound parameter representing the parent material source, and the third biomarker compound parameter representing migration according to the biomarker compound data of the deep inclusions and the biomarker compound data of the shallow inclusions; The oil and gas filling identification module is used to calibrate the biomarker compound parameters of deep inclusions and shallow inclusions according to the first biomarker compound parameter, the second biomarker compound parameter and the third biomarker compound parameter, and obtain the oil and gas filling direction and oil and gas enrichment layer system of the reservoir sample to be tested.

9. An electronic device comprising a memory, a processor, and a computer program stored in the memory and executable on the processor, wherein: When the processor executes the program, the oil and gas filling identification method as described in any one of claims 1 to 7 is implemented.

10. A non-transitory computer-readable storage medium having a computer program stored thereon, characterized in that: When the computer program is executed by a processor, the oil and gas filling identification method according to any one of claims 1 to 7 is implemented.

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