A method for recovering the hydrocarbon accumulation process of ultra-deep carbonate rocks in superimposed basins

Abstract

A method for restoring the oil and gas accumulation process of ultra-deep carbonate rocks in superimposed basins relates to the technical field of oil and gas exploration, and specifically comprises the following steps: obtaining geological data of a study area, collecting reservoir and source rock samples, analyzing and determining the oil and gas sources and organic geochemical characteristics of source rocks, establishing a geological evolution history, determining the hydrocarbon generation peak of source rocks, analyzing reservoir rock samples, clarifying the relationship between pores and fractures and karstification, determining the development period of reservoir dissolution windows and reservoir effectiveness according to karstification conditions, determining the development of different types of transport systems and predicting their distribution, determining the oil and gas filling periods and times, restoring the key period of reservoir oil and gas accumulation and the current paleostructure, conducting oil and gas migration direction, accumulation and preservation condition analysis, and restoring the entire process of oil and gas accumulation; the present invention restores the oil and gas accumulation process based on the time-space matching relationship between various elements of oil and gas accumulation, and restores the entire process of oil and gas accumulation in a more systematic, dynamic and accurate manner.

Description

Technical Field

[0001] The present invention relates to the technical field of oil and gas exploration, and in particular to a method for recovering the ultra-deep carbonate oil and gas accumulation process in a superimposed basin. Background Art

[0002] In recent years, oil and gas exploration has gradually advanced to the deep strata of superimposed basins. Since superimposed basins have experienced multiple stages of tectonic movement and sedimentation, the deep strata are buried at great depths, source rocks have multiple stages of hydrocarbon generation and expulsion, reservoir heterogeneity is strong, multiple stages of karstification, the types of transport systems are diverse, the directions of oil and gas migration and adjustment are changeable, and the effectiveness of traps is unclear, resulting in complex conditions and main controlling factors for oil and gas accumulation, which brings many complexities and uncertainties to deep oil and gas exploration.

[0003] At present, the research on the oil and gas accumulation process in ultra-deep carbonate rocks in superimposed basins mainly focuses on hydrocarbon generation in source rocks, reservoir evolution and the distribution of fault transport systems. There is no further discussion on the dynamic process of hydrocarbon generation and expulsion in source rocks, the transport capacity in the process of reservoir evolution, the favorable formation conditions of dissolution windows, the dual effects of destructiveness and transportability of faults, the effectiveness of closures and oil and gas accumulation, the adjustment of oil and gas by tectonic movements, and the temporal and spatial matching relationship between various factors. As a result, the recovery of the accumulation process and the understanding of the main controlling factors of oil and gas accumulation are not objective and comprehensive, which further leads to low exploration success rate and exploration effect.

[0004] Therefore, the oil and gas migration mode, trap effectiveness, and the influence of tectonic movement on oil and gas migration and adjustment should be further analyzed on the basis of comprehensive analysis of the oil and gas sources in the target reservoirs, thermal evolution and hydrocarbon generation and expulsion of the main source rocks, development conditions and periods of high-quality reservoirs, types of transport systems, and dynamic processes of multi-stage oil and gas accumulation, filling, destruction, and readjustment time, and finally the oil and gas accumulation process should be restored. Only this systematic, time- and space-based organic combination of methods can more accurately describe the ultra-deep carbonate oil and gas accumulation process in superimposed basins, systematically and objectively deepen exploration knowledge, reduce exploration risks, and improve exploration results. Summary of the invention

[0005] In view of this, the object of the present invention is to provide a method for recovering the ultra-deep carbonate oil and gas accumulation process in superimposed basins, so as to accurately describe the ultra-deep carbonate oil and gas accumulation process in superimposed basins.

[0006] In order to solve at least one of the above technical problems, the technical solution provided by the present invention is:

[0007] A method for recovering the hydrocarbon accumulation process of ultra-deep carbonate rocks in superimposed basins is provided, which mainly comprises the following steps:

[0008] Step S1: Obtain geological data of the study area, conduct reservoir core observation and description, collect natural gas, crude oil, asphalt samples and reservoir rock samples in the reservoir, and collect source rock samples, wherein the geological data include structural-sedimentary data, drilling stratification data, seismic interpretation data, logging lithology data, and caprock distribution data;

[0009] Step S2: Analyze and test the natural gas samples, crude oil samples and source rock samples in the reservoir respectively, and compare the test results to determine the source of oil and gas and the organic geochemical characteristics of the source rock;

[0010] Step S3: combining the organic geochemical characteristics of the source rock in step S2 with the geological data and drilling stratification data in step S1, establishing the burial history of the formation, the thermal evolution history of the source rock, the hydrocarbon generation history of the source rock, the paleo-geothermal history of the reservoir, and the paleo-stratigraphic pressure history of the reservoir, and drawing a diagram of the burial history of the formation and the thermal evolution history of the source rock, as well as a diagram of the hydrocarbon generation potential history of the source rock-the paleo-geothermal history of the reservoir-the paleo-stratigraphic pressure history of the reservoir, to determine the hydrocarbon generation peak of the source rock;

[0011] Step S4: Analyze reservoir rock samples to study reservoir petrological characteristics, pore and fracture development, diagenesis type, and clarify the independent or symbiotic relationship between pores and fractures and karstification;

[0012] Step S5: According to the karstification situation, select reservoir rock samples to carry out dissolution experiments, and determine the development period of the reservoir dissolution window on the source rock hydrocarbon generation potential history-reservoir paleo-geothermal history-reservoir paleo-pressure history diagram based on the experimental results under different temperature and pressure conditions. Select the common interval of paleo-geothermal and paleo-pressure where dolomite and calcite undergo a large amount of dissolution as the dissolution window and determine the period. Determine the reservoir effectiveness based on the hydrocarbon generation peak of the source rock in step S3, and further determine the distribution range of the effective reservoir based on the geological data in step S1.

[0013] Step S6: Based on the structural-sedimentary data and seismic interpretation data in step S1, fault identification and fault activity period judgment are performed, and the transport capacity of the fault is further analyzed to determine the development of the fault-type transport system at a macroscopic level;

[0014] Step S7: According to the reservoir core observation description results in step S1, the development, filling and distribution density of pores, fractures and holes are determined, and combined with the independent or symbiotic relationship between pores and fractures and the development of karstification in step S4, the development of microscopic pore-type, fracture-type and pore-fracture-type conduction systems in the reservoir is determined. Combined with the structural-sedimentary data, drilling stratification data, seismic interpretation data and logging lithology data in step S1, and the development of the fault-type conduction system in step S6, the distribution of various types of conduction systems is comprehensively predicted.

[0015] Step S8: Conduct fluid inclusion fluorescence and fluid inclusion temperature measurement experiments using the reservoir rock samples in step S1, determine the oil and gas filling period and time based on the experimental results, conduct rhenium-osmium isotope dating experiments using the asphalt samples in step S1, determine the high-maturity oil and gas filling based on the principle of narrowing the time range, further quantitatively characterize the high-maturity oil and gas filling time, and determine its range on the burial history of the formation and the thermal evolution history of the source rock.

[0016] Step S9: Based on the oil and gas filling period and time in step S8 and the high-maturity oil and gas filling time as the key period of oil and gas accumulation, based on the seismic interpretation data in step S1, the paleostructure of the key period of oil and gas accumulation in the reservoir is restored, and the traps, structural hydrocarbon-controlling ridges and streamline distribution maps of the paleostructure in the key period of reservoir accumulation are drawn, as well as the traps, structural hydrocarbon-controlling ridges and streamline distribution maps of the current structure of the reservoir are drawn;

[0017] Step S10: Based on the ancient structural surface map of the key period of reservoir accumulation and the current structural surface map of the reservoir drawn in step S9, combined with the distribution range of the effective reservoir in step S5, further analysis of oil and gas migration direction, accumulation and preservation conditions is carried out;

[0018] Step S11: Draw the distribution map of ancient structural closures, structural hydrocarbon-controlling ridges and streamlines during the critical period of reservoir formation in step S10, as well as the distribution map of current structural closures, structural hydrocarbon-controlling ridges and streamlines of the reservoir, compare the oil and gas migration and accumulation characteristics of different periods, clarify the critical period of oil and gas accumulation and the current process of oil and gas migration, accumulation and adjustment, draw the oil and gas accumulation process map, and restore the entire process of oil and gas accumulation.

[0019] The technical effects of the present invention are:

[0020] 1. The present invention takes into account the temporal and spatial matching relationship between various elements of oil and gas accumulation, fully considers the reservoir effectiveness under karst action, and further describes the accumulation elements of the transport system and structural control of hydrocarbon ridges.

[0021] 2. The present invention uses the temporal and spatial matching relationship among the various elements of oil and gas accumulation, combined with the transport system, closure, oil and gas migration direction, and oil and gas migration start-up conditions, to more accurately identify the accumulation process and the effectiveness of accumulation, and avoid the singleness and one-sidedness of the accumulation elements.

[0022] 3. The present invention uses the temporal and spatial matching relationship among various elements of oil and gas accumulation to regularly depict the dynamic process of hydrocarbon generation in source rocks, the development conditions and effectiveness of karst reservoirs, the oil and gas conductivity of reservoirs, and the temporal and spatial matching relationship of oil and gas migration and accumulation in the key period of accumulation, so as to comprehensively restore the oil and gas accumulation process and restore the entire process of oil and gas accumulation in a more systematic, dynamic and accurate manner. BRIEF DESCRIPTION OF THE DRAWINGS

[0023] In order to more clearly illustrate the technical solutions of the embodiments of the present invention, the drawings required for use in the embodiments will be briefly introduced below. It should be understood that the following drawings only show certain embodiments of the present invention and therefore should not be regarded as limiting the scope. For ordinary technicians in this field, other related drawings can be obtained based on these drawings without paying creative work.

[0024] Figure 1 It is the overall flow chart of the present invention;

[0025] Figure 2 It is the stratum burial history and source rock thermal evolution history diagram in the present invention;

[0026] Figure 3 It is the hydrocarbon generation potential history of source rock-reservoir paleo-geothermal history-reservoir paleo-pressure history diagram in the present invention;

[0027] Figure 4 It is a diagram showing the development of pore and fracture-type transport systems observed in rock thin sections in the present invention;

[0028] Figure 5 This is a diagram showing the results of a calcite and dolomite dissolution experiment in carbonate rocks of the present invention;

[0029] Figure 6 It is the trap, structural hydrocarbon-controlling ridge and streamline analysis diagram of the reservoir paleostructure in the present invention;

[0030] Figure 7 It is the trap, structural hydrocarbon-controlling ridge and streamline analysis diagram of the current structure of the reservoir in the present invention;

[0031] Figure 8 It is a diagram of the oil and gas accumulation process in the present invention. DETAILED DESCRIPTION

[0032] The present invention will be further described in detail below in conjunction with the embodiments and drawings.

[0033] In order to make the purpose, technical solutions and advantages of the embodiments of the present invention clearer, the technical solutions in the embodiments of the present invention will be clearly and completely described below in conjunction with the drawings in the embodiments of the present invention. Obviously, the described embodiments are part of the embodiments of the present invention, not all of the embodiments. 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. Therefore, the following detailed description of the embodiments of the present invention provided in the drawings is not intended to limit the scope of the invention claimed for protection, but merely represents selected embodiments of the present invention.

[0034] Example:

[0035] Taking a certain area in the Tarim Basin as an example, it is a multi-stage superimposed basin, in which the Lower Cambrian subsalt reservoir has good quality and well-developed source rocks. Due to the great burial depth of the strata and the multiple stages of tectonic movements, the oil and gas accumulation process is complex. The entire process of oil and gas generation, migration, adjustment, and accumulation is the main factor restricting the exploration progress.

[0036] like Figure 1 As shown, the present invention specifically comprises the following steps:

[0037] Step S1: Obtain geological data of the study area, conduct reservoir core observation and description, collect natural gas, crude oil, asphalt samples and reservoir rock samples in the reservoir, and collect source rock samples, wherein the geological data include structural-sedimentary data, drilling stratification data, seismic interpretation data, logging lithology data, and caprock distribution data;

[0038] Step S2: Analyze and test the natural gas samples, crude oil samples and source rock samples in the reservoir respectively. Perform kerogen stable carbon isotope, kerogen type, chromatography, and chromatography-mass spectrometry experimental analysis on the source rock samples. Compare the test results to determine the source of oil and gas. Perform total organic carbon content, rock pyrolysis, and kerogen vitrinite reflectance measurements on the source rocks to determine the organic geochemical characteristics of the source rocks. The experimental results show that the organic carbon content of the source rocks in this area is 1.2%, the vitrinite reflectance is 4.3%, and the kerogen type is Type I.

[0039] Step S3: Combine the organic geochemical characteristics of the source rock in step S2 with the geological data and drilling stratification data in step S1, and use PetroMod software to establish the burial history of the formation, the thermal evolution history of the source rock, the hydrocarbon generation history of the source rock, the paleo-geothermal history of the reservoir, and the paleo-stratigraphic pressure history of the reservoir, and draw the following: Figure 2 The burial history of the strata and the thermal evolution history of the source rocks shown in the figure, as well as Figure 3 The source rock hydrocarbon potential history - reservoir paleo-geothermal history - reservoir paleo-pressure history diagram is shown, and then according to Figure 3 The hydrocarbon generation history of source rocks in the hydrocarbon generation history determines the hydrocarbon generation peak of source rocks;

[0040] It can be seen that in Figure 2 The source rocks entered the low maturity stage at the end of the Early Ordovician (476 Ma), the mature stage at the beginning of the Late Ordovician (459 Ma), the high maturity stage at the end of the Early Silurian (432 Ma), the wet gas generation stage at the end of the Early Devonian (401 Ma), the dry gas generation stage at the beginning of the Late Carboniferous (314 Ma), and the hydrocarbon generation depletion stage at the end of the Middle Permian (262 Ma).

[0041] exist Figure 3In the study, the earliest hydrocarbon generation period of source rocks was the beginning of the Late Ordovician (460Ma), and the peak hydrocarbon generation period was from the Late Ordovician (451Ma) to the Early Carboniferous (342Ma). In other words, the peak hydrocarbon generation period of source rocks was from the Late Ordovician to the Carboniferous.

[0042] Step S4: Analyze reservoir rock samples to study reservoir petrological characteristics, pore and fracture development, diagenesis type, and clarify the independent or symbiotic relationship between pores and fractures and karstification.

[0043] The methods for analyzing reservoir rock samples located in the reservoir development area among the collected samples mainly include field emission scanning electron microscope observation, ordinary thin section observation, and cast thin section observation, to study the reservoir petrological characteristics, pore and fracture development, diagenesis type, and clarify the independent or symbiotic relationship between pores and fractures and karstification.

[0044] like Figure 4 As shown, the reservoir lithology is mainly composed of crystalline dolomite, granular dolomite, mud-microcrystalline dolomite, algal laminar dolomite, brecciated dolomite and other transitional dolomites. The reservoir space is mainly composed of intergranular pores, intragranular dissolved pores, intercrystalline pores and intracrystalline dissolved pores. Pores and fractures coexist and the karstification type is mainly organic acid dissolution type.

[0045] Step S5: According to the karstification situation, select reservoir rock samples to carry out dissolution experiments, determine the development period of the reservoir dissolution window according to the experimental results under different temperature and pressure conditions, and mark its range on the hydrocarbon generation potential history of source rocks-reservoir paleo-geothermal history-reservoir paleo-pressure history diagram drawn in step S3, select the common interval of paleo-geothermal and paleo-pressure where dolomite and calcite undergo a large amount of dissolution as the dissolution window and determine the period, and further determine the distribution range of the effective reservoir according to the geological data in step S1.

[0046] The study of carbonate rock dissolution mechanism is an important basis for the genetic analysis of high-quality carbonate reservoirs. According to the structural-sedimentary data in step S1 and the karstification type specified in step S4, it is determined that the main karstification of the reservoir is organic acid dissolution. Karst simulation experiments are carried out based on the reservoir rock samples in step S1. The karstification in step S4 selects 0.2% acetic acid solution (Ph≈5.0) as the dissolution liquid, and the experimental results are annotated on the hydrocarbon generation potential history of the source rock-reservoir paleogeothermal history-reservoir paleopressure history diagram drawn in step S3.

[0047] The experimental results are as follows Figure 5 As shown, calcite (Ca 2+ ) The formation pressure where a large amount of dissolution occurs is 25-35MPa, the formation temperature is 100-120℃, and dolomite (Mg 2+) The formation pressure where a large amount of dissolution occurs is 35-45MPa, and the formation temperature is 140-180°C. At the same time, when the formation pressure exceeds 45MPa and the formation temperature exceeds 180°C, the dissolution effect gradually weakens to the minimum, that is, the dissolution window is 25-45MPa and the temperature is 100-180°C. Further, according to the temperature and pressure range, the source rock hydrocarbon generation potential history-reservoir paleogeothermal history-reservoir paleopressure history diagram in step S3 is marked to determine the main period of karst development, such as Figure 3 As shown, the main karst development period is the Ordovician, which is later than the time of large-scale oil and gas generation, and the reservoir effectiveness is good. Further, according to the geological data in step S1, the distribution range of the effective reservoir is determined.

[0048] Step S6: Based on the seismic interpretation data, fault identification is performed and the fault activity period is determined, and the conductivity of the fault is further analyzed.

[0049] The conductivity of a fault is generally considered to be in an open state when the fault is active and has the conductivity, and in a closed state when the fault is inactive and has no conductivity.

[0050] As shown in Table 1, strike-slip faults were developed in the Silurian, Devonian, and Carboniferous periods. Therefore, it is believed that faults had transport capabilities in these three periods and developed fault-type transport systems.

[0051] Table 1 Statistics of fracture density and extension length at different scales and periods

[0052]

[0053]

[0054] Step S7: Based on the core observation description, the development, filling and distribution density of pores, fractures and caves are described and counted. The specific contents are shown in Table 2. The results show that the effectiveness of pores, fractures and caves is good. Combined with the symbiotic development relationship of pores and fractures defined in step S4, it is believed that the transport system developed in the reservoir is a pore-fracture type transport system. Based on the structural-sedimentary data in step S1 and the well location, a spatial comparative analysis is performed to predict the distribution of the pore-fracture type transport system.

[0055] Table 2 Statistical table of fracture characteristic parameters of reservoir core description

[0056]

[0057] Step S8: Conduct fluid inclusion fluorescence and fluid inclusion temperature measurement experiments using the reservoir rock samples in step S1, determine the oil and gas filling period and time based on the experimental results, conduct rhenium-osmium isotope dating experiments using the asphalt samples in step S1, determine the high-maturity oil and gas filling based on the principle of narrowing the time range, further quantitatively characterize the high-maturity oil and gas filling time, and mark it on the stratigraphic burial history and source rock thermal evolution history diagram drawn in S3.

[0058] In the fluorescence of fluid inclusions, liquid hydrocarbons are mainly identified by microscopic fluorescence, and gaseous hydrocarbons (methane) are mainly identified by laser Raman spectroscopy analysis. At the same time, brine fluid inclusions of the same period as the above two types of fluid inclusions are sought for temperature measurement. The temperature measurement data of brine fluid inclusions are distributed in two intervals, 100-120°C and 130-140°C. The fluorescence displays are yellow-green light (low maturity) and blue-white light (mature), respectively, indicating that it has experienced at least two oil and gas injections, namely the Late Ordovician and Early Carboniferous. The rhenium-osmium isotope dating of the reservoir asphalt shows 420-398Ma (Late Silurian to Early Carboniferous), which is consistent with the hydrocarbon generation history of the source rock proposed in step S3. Figure 2 The key moments of oil and gas accumulation are marked in the regional stratigraphic burial history, and the time range is determined to be the Late Ordovician, Devonian, and Early Carboniferous. The peak of hydrocarbon generation in the source rock in step S3 is from the Late Ordovician to the Carboniferous.

[0059] Step S9: Based on the determination of the Late Ordovician, Devonian, and Early Carboniferous as the key moments for oil and gas accumulation in step S8, the paleo-tectonic surfaces of the reservoirs in the above-mentioned periods are restored based on the seismic interpretation data. At the same time, the changes in the paleo-tectonic surfaces of the reservoirs from the Carboniferous to the present are analyzed, and the period when the paleo-tectonic surfaces of the reservoirs have changed significantly is selected. The paleo-tectonic structures of the reservoirs, the development and distribution of closures, and the changes in the morphology of the structurally controlled hydrocarbon ridges are analyzed together with the paleo-tectonic surfaces of the reservoirs at the key moments for oil and gas accumulation, and the following diagrams are drawn: Figure 6 The distribution diagram of the ancient structure traps, structural hydrocarbon ridges and flow lines during the key period of reservoir accumulation is shown in the figure, as well as the distribution diagram of the ancient structure traps, structural hydrocarbon ridges and flow lines during the key period of reservoir accumulation, as shown in the figure, Figure 7 The current structure of the reservoir, the traps, structural hydrocarbon ridges and flow lines shown in the figure are Figure 6 It can be seen that tectonic uplift occurred in the Early Carboniferous, multiple structural traps developed, and structurally controlled hydrocarbon ridges developed successively.

[0060] Step S10: Based on the premise that the pore-fracture type transport system and the fault type transport system determined in the previous step are developed and the oil and gas lateral migration start conditions are met, Figure 6 , Figure 7 The streamline method is used to analyze the direction and accumulation of oil and gas migration.

[0061] like Figure 6As shown in the figure, the streamline direction represents the migration direction of oil and gas in the transport system, the place where the streamlines converge represents the accumulation of oil and gas, and the structurally controlled hydrocarbon ridge is the main direction of oil and gas migration and accumulation.

[0062] Step S11: Based on the analysis results of oil and gas migration and accumulation in S10, the oil and gas migration and accumulation results of different periods are superimposed to draw a Figure 8 The oil and gas accumulation process diagram shown in the figure gives a specific oil and gas accumulation recovery process diagram. The results show that the oil and gas reservoirs experienced initial accumulation and were adjusted many times to form the current distribution pattern.

[0063] The above is only a preferred specific embodiment of the present invention, but the protection scope of the present invention is not limited thereto. Any changes or substitutions that can be easily thought of by a person skilled in the art within the technical scope disclosed in the embodiments of the present invention should be included in the protection scope of the present invention. Therefore, the protection scope of the present invention should be based on the protection scope of the claims.

Claims

1. A method for recovering ultra-deep carbonate oil and gas accumulation in superimposed basins, characterized in that: The following steps are involved: Step S1: Obtain geological data of the study area, conduct reservoir core observation and description, collect natural gas, crude oil, asphalt samples and reservoir rock samples in the reservoir, and collect source rock samples, wherein the geological data include structural-sedimentary data, drilling stratification data, seismic interpretation data, logging lithology data, and caprock distribution data; Step S2: Analyze and test the natural gas samples, crude oil samples and source rock samples in the reservoir respectively, and compare the test results to determine the source of oil and gas and the organic geochemical characteristics of the source rock; Step S3: combining the organic geochemical characteristics of the source rock in step S2 with the geological data and drilling stratification data in step S1, establishing the burial history of the formation, the thermal evolution history of the source rock, the hydrocarbon generation history of the source rock, the paleo-geothermal history of the reservoir, and the paleo-stratigraphic pressure history of the reservoir, and drawing a diagram of the burial history of the formation and the thermal evolution history of the source rock, as well as a diagram of the hydrocarbon generation potential history of the source rock-paleo-geothermal history of the reservoir-paleo-pressure history of the reservoir, and determining the hydrocarbon generation peak of the source rock, wherein the hydrocarbon generation peak of the source rock is the interval where the slope of the hydrocarbon generation potential curve is positive; Step S4: Analyze reservoir rock samples to study reservoir petrological characteristics, pore and fracture development, diagenesis type, and clarify the independent or symbiotic relationship between pores and fractures and karstification; Step S5: According to the karstification situation, reservoir rock samples are selected to carry out dissolution experiments, and the development period of the reservoir dissolution window is determined on the source rock hydrocarbon generation potential history-reservoir paleo-geothermal history-reservoir paleo-pressure history diagram according to the experimental results under different temperature and pressure conditions. The common interval of paleo-geothermal and paleo-pressure where dolomite and calcite undergo a large amount of dissolution is selected as the dissolution window and the period is determined. The reservoir effectiveness is determined according to the hydrocarbon generation peak of the source rock in step S3, and the distribution range of the effective reservoir is further determined according to the geological data in step S1. The method for determining the reservoir effectiveness according to the hydrocarbon generation peak of the source rock is as follows: the reservoir whose karstification development period is before or at the same time as the hydrocarbon generation peak of oil and gas is defined as an effective reservoir; Step S6: Based on the structural-sedimentary data and seismic interpretation data in step S1, fault identification and fault activity period judgment are performed, and the transport capacity of the fault is further analyzed to determine the development of the fault-type transport system at a macroscopic level; Step S7: according to the reservoir core observation description results in step S1, the development, filling and distribution density of pores, fractures and holes are determined, and combined with the independent or symbiotic relationship between pores and fractures and the development of karstification in step S4, the development of microscopic pore-type, fracture-type and pore-fracture-type conduction systems in the reservoir is determined, and combined with the structural-sedimentary data, drilling stratification data, seismic interpretation data and logging lithology data in step S1, and the development of fault-type conduction systems in step S6, the distribution of various types of conduction systems is comprehensively predicted; Step S8: using the reservoir rock sample in step S1 to carry out fluid inclusion fluorescence and fluid inclusion temperature measurement experiments, and determining the oil and gas charging period and time according to the experimental results; using the asphalt sample in step S1 to carry out rhenium-osmium isotope dating experiments, and determining the high-mature oil and gas charging on the principle of narrowing the time range, and further quantitatively characterizing the high-mature oil and gas charging time, and determining its range on the burial history of the formation and the thermal evolution history of the source rock; Step S9: Based on the oil and gas filling period and time in step S8 and the high-maturity oil and gas filling time as the key period of oil and gas accumulation, based on the seismic interpretation data in step S1, the paleostructure of the key period of oil and gas accumulation in the reservoir is restored, and the traps, structural hydrocarbon-controlling ridges and streamline distribution maps of the paleostructure in the key period of reservoir accumulation are drawn, as well as the traps, structural hydrocarbon-controlling ridges and streamline distribution maps of the current structure of the reservoir are drawn; Step S10: Based on the ancient structural surface map of the key period of reservoir accumulation and the current structural surface map of the reservoir drawn in step S9, combined with the distribution range of the effective reservoir in step S5, further analysis of oil and gas migration direction, accumulation and preservation conditions is carried out; Step S11: Draw the distribution map of ancient structural closures, structural hydrocarbon-controlling ridges and streamlines during the critical period of reservoir formation in step S10, as well as the distribution map of current structural closures, structural hydrocarbon-controlling ridges and streamlines of the reservoir, compare the oil and gas migration and accumulation characteristics of different periods, clarify the critical period of oil and gas accumulation and the current process of oil and gas migration, accumulation and adjustment, draw the oil and gas accumulation process map, and restore the entire process of oil and gas accumulation.

2. The method for recovering the ultra-deep carbonate oil and gas accumulation process in a superimposed basin according to claim 1, characterized in that: The analysis and testing method for the natural gas samples of the reservoir and the rock samples of the source rock described in step S2 is to perform carbon isotope and light hydrocarbon fingerprint analysis tests on the natural gas samples of the target reservoir; to perform chromatography and chromatography-mass spectrometry analysis tests on the crude oil samples of the target reservoir; and to perform total organic carbon content, rock pyrolysis, kerogen vitrinite reflectance, kerogen stable carbon isotope, kerogen type, chromatography, and chromatography-mass spectrometry experimental analysis on the rock samples of the source rock.

3. The method for recovering the ultra-deep carbonate oil and gas accumulation process in a superimposed basin according to claim 1, characterized in that: In step S3, PetroMod is used to establish the burial history of the formation, the thermal evolution history of the source rock, the hydrocarbon generation history of the source rock, the paleo-geothermal history of the reservoir, and the paleo-stratigraphic pressure history of the reservoir.

4. The method for recovering the ultra-deep carbonate oil and gas accumulation process in a superimposed basin according to claim 1, characterized in that: The method for restoring the ancient structure of the target reservoir in step S9 is the balanced profile method.

5. The method for recovering the ultra-deep carbonate oil and gas accumulation process in a superimposed basin according to claim 1, characterized in that: The method for analyzing the direction, accumulation and preservation conditions of oil and gas migration described in step S10 is to use the PetroMod software on the reservoir paleo-structural surface map in step S9 to analyze the direction and accumulation conditions of oil and gas migration using a mixed streamline method of microscopic Darcy flow and macroscopic fluid potential, wherein the streamlines represent the direction of oil and gas migration, and the places where the streamlines converge represent the accumulation of oil and gas.

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