Tight oil reservoir forming stage division method based on dynamic resistance coupling analysis

Abstract

The invention discloses a tight oil reservoir forming stage division method based on dynamic resistance coupling analysis. The tight oil reservoir forming stage division method comprises the following steps: step 101, paleopressure recovery; step 102, calculating ancient resistance; the method is suitable for the technical field of oil and gas geological exploration, the different reservoir forming stages in the reservoir forming period are subdivided from the angle of filling dynamics, the method can be directly used for quantitatively reflecting the reservoir forming mechanism or the essence of the reservoir forming process, and the method has the essential difference from the prior art that only the main reservoir forming period can be determined and cannot be divided more detailedly. Therefore, a new research thought and a new technical means are provided for further enhancing the mechanism understanding of the reservoir forming stage and exploration and development of tight oil.

Description

Technical Field

[0001] The invention belongs to the technical field of oil and gas geological exploration, and in particular is a method for dividing tight oil accumulation stages based on dynamic resistance coupling analysis. Background Art

[0002] Tight oil is an unconventional oil and gas resource, distributed in many oil and gas basins, and is one of the most realistic oil and gas replacement areas in my country at this stage. Due to the ultra-low porosity and permeability of tight reservoirs, most oil is non-buoyancy driven or has limited buoyancy, and the accumulation stage and corresponding accumulation process are different from conventional oil and gas.

[0003] At present, the methods or bases for dividing the accumulation stages of tight oil at home and abroad mainly include the fluid inclusion method, the relationship between the accumulation stage and reservoir densification, etc. Among them, the fluid inclusion method is a more commonly used method, which is combined with the basin simulation method to comprehensively divide the accumulation stages or stages, and often integrates geological analysis such as the hydrocarbon generation and expulsion history of source rocks and the tectonic evolution history to verify the accuracy of the accumulation period. Although this method can achieve qualitative identification and division of different accumulation stages, it does not consider the dynamic process of tight oil accumulation and cannot quantitatively reflect the accumulation mechanism of tight oil. According to the relationship between the accumulation stage and reservoir densification, some scholars divide tight oil into three accumulation processes: accumulation first and then densification, densification first and then accumulation, and accumulation while densification. However, the division of the accumulation stage is only a qualitative analysis, lacking a quantitative evaluation of the dynamic resistance coupling relationship.

[0004] In the Chinese patent application with application number CN111077586A, it is involved that a method is used to determine the main oil and gas accumulation period in a complex fault basin based on the hydrocarbon expulsion period of the main source rock and the degree of thermal evolution of the source rock in different geological periods. This invention can only determine the main accumulation period, but cannot divide it in more detail. Moreover, the division method is only based on geochemical analysis and testing of the source rock, and other factors are uncertain.

[0005] In the Chinese patent application with application number CN109425911A, it is involved that a method of determining the main reservoir-forming period is obtained by combining the microscopic spectral characteristics and temperature measurement data of inclusions with the macroscopic geological background. This invention only involves the inclusion analysis and testing method, and the division method is single, which cannot divide the reservoir-forming period in more detail, and it is only a qualitative analysis, without involving dynamic calculation.

[0006] In the Chinese patent application with application number CN104912548A, it is involved that a method for dividing the formation pressure field into three pressure environments, namely overpressure, transition and normal pressure, is established to predict the reservoir under different pressure environments, and quantitatively predict the oil content of the trap is achieved. Although the invention analyzes the reservoir from a dynamic perspective, it does not analyze the dynamic accumulation process and accumulation stage, and the physical simulation experiment of oil and gas migration and accumulation involved is costly and has harsh experimental conditions, making it difficult to promote on a large scale.

[0007] In the paper: DOI:10.3321 / j.issn:1000-0747.2000.06.004 “Accumulation Index of Lithologic Oil and Gas Reservoir Formation”, a method of defining the ratio of charging power to median pressure as the accumulation index is involved, and the relationship between the accumulation index and the oil content of the reservoir is studied. However, this method only reflects the control of power on the oil content of tight oil, and there is no analysis of the dynamic accumulation process and accumulation stage.

[0008] In the paper: DOI:10.7623 / syxb201511004 "The accumulation and formation mechanism of continuous oil and gas reservoirs - taking the upper sub-segment of the fourth segment of the Shahejie Formation in the central area of ​​the Bonan Sag as an example", the lower limit of porosity for oil and gas accumulation was derived through dynamic resistance coupling analysis. However, the empirical formula that uses 50% of the formation pressure as the charging power is difficult to generalize, and it is also inappropriate to completely replace the pressure during the accumulation period with the current formation pressure. The analysis of the accumulation process is simple and the accumulation stage is not determined.

[0009] In the paper: DOI:10.7623 / syxb201102011 "Recovering the oil and gas accumulation process by coupling the residual pressure during the accumulation period with the lower limit of the reservoir displacement pressure - Taking the Chexi sag in the Jiyang Depression as an example", the lower limit of the reservoir filling resistance during the accumulation period was calculated by coupling the dynamic resistance, and the oil and gas accumulation process was restored. However, the porosity during the reservoir accumulation period was obtained based on the current porosity and depth fitting. The porosity at the same depth often varies greatly due to various factors, resulting in large errors in the results. In addition, the resistance in this research method only considers the displacement pressure, not the median pressure, and cannot further determine the filling intensity and scale, and cannot determine the accumulation process and accumulation stage.

[0010] In summary, the existing technology cannot solve the problem of dividing different reservoir formation stages from a dynamic perspective, and it is difficult to directly use it to quantitatively reflect the reservoir formation mechanism or the essence of the reservoir formation process. Therefore, there is an urgent need for a method for dividing tight oil reservoir formation stages based on dynamic-drag coupling analysis. Summary of the invention

[0011] The purpose of the present invention is to overcome the defects of the prior art and provide a method for dividing tight oil accumulation stages based on dynamic drag coupling analysis.

[0012] To achieve the above object, the present invention adopts the following technical solutions:

[0013] The method for dividing tight oil accumulation stages based on dynamic-drag coupling analysis includes the following steps:

[0014] Step 101: Paleopressure recovery: obtaining the fluid inclusion capture pressure and the current pressure as process constraints, simulating and obtaining the pressure evolution history;

[0015] Step 102: Paleoresistance calculation: the porosity evolution history of the reservoir is restored by using the inversion backstripping method, and then the paleoresistance size and its evolution history are calculated by using the relationship formula between the current porosity and the two types of filling resistances;

[0016] Step 103: Division of reservoir formation stages: Place the evolution of charging power, displacement pressure and median pressure on the same time-pressure coordinate axis, and divide the tight oil reservoir formation stages in sequence according to the relationship between the charging power and the resistance.

[0017] Preferably, in step 101, a reservoir inclusion slice is prepared, the homogenization temperature and the gas-liquid ratio are determined, and the inclusion capture pressure is iteratively simulated by PVTsim in combination with the crude oil component content; and the pressure evolution history is simulated and obtained using PetroMod basin simulation software.

[0018] Preferably, in step 101, the uniform temperature and gas-liquid ratio information of hydrocarbon inclusions of different periods and their associated brine inclusions are determined by microscopic observation and temperature measurement.

[0019] Preferably, in step 101, the content of each component of the crude oil is obtained through crude oil composition test data.

[0020] Preferably, in step 101, iteratively simulating the inclusion capture pressure by PVTsim includes:

[0021] The hydrocarbon inclusion phase envelope, isochoric line and associated brine inclusion isochoric line are obtained through PVTsim iterative simulation. The pressure value at the intersection of the two inclusion isochoric lines is the capture pressure of the hydrocarbon inclusion.

[0022] Preferably, in step 101, using PetroMod basin simulation software to simulate and obtain the pressure evolution history includes:

[0023] The obtained fluid inclusion capture pressure and current pressure were used as process constraints, and the 1D module of PetroMod basin simulation software was used to load parameters such as formation thickness, age, lithology and heat flow to simulate and obtain the pressure evolution history.

[0024] Preferably, the step 102 further includes:

[0025] Obtain reservoir test parameters and fit the relationship formula between porosity, displacement pressure and median pressure.

[0026] Preferably, in step 102, reservoir test parameters are obtained, and the relationship formula between porosity, displacement pressure and median pressure is fitted, which specifically includes: conducting tight reservoir core porosity and high-pressure mercury injection testing to obtain parameters such as porosity, displacement pressure, median pressure, and performing correlation analysis on porosity, displacement pressure and median pressure to obtain current porosity and two types of filling resistances.

[0027] Preferably, in step 102, the two types of filling resistances include displacement pressure and median pressure.

[0028] Preferably, in step 102, based on the study of tight reservoir storage space, diagenesis and sequence, the inversion backstripping method is used to restore the reservoir porosity evolution history, and then the relationship formula between the current porosity and two types of filling resistance is used to calculate the size of the ancient resistance and its evolution history.

[0029] Preferably, in step 103, the evolution processes of the power, displacement pressure and median pressure obtained in steps 101 and 102 are placed on the same time-pressure coordinate axis to divide the tight oil accumulation stages.

[0030] Preferably, in step 103, the division of tight oil accumulation stages includes the following specific analysis process:

[0031] ① The charging power is less than the reservoir displacement pressure, and oil and gas cannot fill the reservoir during the corresponding time period;

[0032] ② The charging power begins to reach and exceed the reservoir displacement pressure but is less than the median pressure. This is the first stage of tight oil charging, and small-scale charging is carried out;

[0033] ③ The charging power reaches and exceeds the median pressure of the reservoir, which is the second stage of tight oil charging, and large-scale charging is carried out.

[0034] Preferably, in step 103, the small-scale filling is performed to an oil saturation of less than 50%.

[0035] Preferably, in step 103, the large-scale filling is performed so that the oil saturation is equal to or exceeds 50%.

[0036] In summary, due to the adoption of the above technical solution, the beneficial effects of the present invention are:

[0037] In the present invention, different accumulation stages within the accumulation period are subdivided from the perspective of filling dynamics, which can be directly used to quantitatively reflect the accumulation mechanism or the essence of the accumulation process. This is essentially different from the prior art that can only determine the main accumulation period but cannot divide it in more detail. This is helpful to further enhance the understanding of the mechanism of the accumulation stage and provide new research ideas and technical means for the exploration and development of tight oil. BRIEF DESCRIPTION OF THE DRAWINGS

[0038] Figure 1 is a flow chart of the present invention;

[0039] Figure 2 The ancient pressure map is restored by the PVTsim simulation method in the embodiment of the present invention;

[0040] Figure 3 This is a diagram showing the evolution history of tight reservoir pressure in the lower third member of the Shahejie Formation in the Linnan Sag in the embodiment of the present invention;

[0041] Figure 4 This is a relationship diagram between the reservoir porosity, displacement pressure and median pressure of the Linnan Sag in an embodiment of the present invention;

[0042] Figure 5 This is a diagram showing the evolution history of oil and gas filling resistance in the tight reservoir of the lower third member of the Shahejie Formation in the Linnan Sag in the embodiment of the present invention;

[0043] Figure 6 This is a diagram showing the dynamic-resistance coupling relationship and the reservoir-forming stage division of the Linnan Subsidence in an embodiment of the present invention. DETAILED DESCRIPTION

[0044] The following is combined with Figure 1 , further illustrating the specific implementation of the method for dividing the tight oil accumulation stages based on the dynamic resistance coupling analysis of the present invention. The method for dividing the tight oil accumulation stages based on the dynamic resistance coupling analysis of the present invention is not limited to the description of the following embodiments.

[0045] Embodiment 1:

[0046] The method of dividing tight oil accumulation stages based on dynamic drag coupling analysis, such as Figure 1 As shown, the following steps are included:

[0047] Step 101: Paleopressure recovery: obtaining the fluid inclusion capture pressure and the current pressure as process constraints, simulating and obtaining the pressure evolution history;

[0048] Step 102: Paleoresistance calculation: the porosity evolution history of the reservoir is restored by using the inversion backstripping method, and then the paleoresistance size and its evolution history are calculated by using the relationship formula between the current porosity and the two types of filling resistances;

[0049] Step 103: Division of reservoir formation stages: Place the evolution of charging power, displacement pressure and median pressure on the same time-pressure coordinate axis, and divide the tight oil reservoir formation stages in sequence according to the relationship between the charging power and the resistance.

[0050] Embodiment 2:

[0051] The method for dividing tight oil accumulation stages based on dynamic resistance coupling analysis is similar to Example 1 in other steps. Furthermore, in step 101, a reservoir inclusion thin section is prepared, the homogenization temperature and the gas-liquid ratio are determined, and the inclusion capture pressure is iteratively simulated by PVTsim in combination with the crude oil component content; and the pressure evolution history is simulated and obtained by using the PetroMod basin simulation software.

[0052] Embodiment 3:

[0053] The method for dividing tight oil accumulation stages based on dynamic drag coupling analysis is similar to Example 1 in other steps. Furthermore, in step 101, the uniform temperature and gas-liquid ratio information of hydrocarbon inclusions of different stages and their associated brine inclusions are determined by microscopic observation and temperature measurement.

[0054] Embodiment 4:

[0055] The method for dividing tight oil accumulation stages based on dynamic drag coupling analysis is similar to Example 1 in other steps. Furthermore, in step 101, the content of each component of crude oil is obtained through crude oil composition test data.

[0056] Embodiment 5:

[0057] The method for dividing tight oil accumulation stages based on dynamic drag coupling analysis is similar to that of Example 1 in other steps. Further, in step 101, the inclusion capture pressure is simulated by PVTsim iteration, including:

[0058] The hydrocarbon inclusion phase envelope, isochoric line and associated brine inclusion isochoric line are obtained through PVTsim iterative simulation. The pressure value at the intersection of the two inclusion isochoric lines is the capture pressure of the hydrocarbon inclusion.

[0059] Embodiment 6:

[0060] The method for dividing tight oil accumulation stages based on dynamic resistance coupling analysis, the other steps are similar to those in Example 1. Further, in step 101, the PetroMod basin simulation software is used to simulate and obtain the pressure evolution history, including:

[0061] The obtained fluid inclusion capture pressure and current pressure were used as process constraints, and the 1D module of PetroMod basin simulation software was used to load parameters such as formation thickness, age, lithology and heat flow to simulate and obtain the pressure evolution history.

[0062] Embodiment 7:

[0063] The method for dividing tight oil accumulation stages based on dynamic resistance coupling analysis has other steps similar to those in Example 1. Further, step 102 further includes:

[0064] Obtain reservoir test parameters and fit the relationship formula between porosity, displacement pressure and median pressure.

[0065] Embodiment 8:

[0066] The method for dividing tight oil accumulation stages based on dynamic resistance coupling analysis is similar to Example 1 in other steps. Furthermore, in step 102, reservoir test parameters are obtained, and the relationship formula between porosity, displacement pressure and median pressure is fitted, which specifically includes: conducting tight reservoir core porosity and high-pressure mercury injection testing to obtain parameters such as porosity, displacement pressure, median pressure, and performing correlation analysis on porosity, displacement pressure and median pressure to obtain current porosity and two types of filling resistance.

[0067] Embodiment 9:

[0068] The method for dividing tight oil accumulation stages based on dynamic resistance coupling analysis is similar to that of Example 1 in other steps. Furthermore, in step 102, the two types of filling resistances include displacement pressure and median pressure.

[0069] Embodiment 10:

[0070] The method for dividing tight oil accumulation stages based on dynamic resistance coupling analysis is similar to Example 1 in other steps. Furthermore, in step 102, based on the research on storage space, diagenesis and sequence of tight reservoirs, the inversion backstripping method is used to restore the reservoir porosity evolution history, and then the relationship formula between the current porosity and the two types of filling resistance is used to calculate the size of the ancient resistance and its evolution history.

[0071] Embodiment 11:

[0072] The method for dividing the tight oil accumulation stages based on dynamic-drag coupling analysis is similar to Example 1 in other steps. Furthermore, in step 103, the dynamic force, displacement pressure and median pressure evolution processes obtained in steps 101 and 102 are placed on the same time-pressure coordinate axis to divide the tight oil accumulation stages.

[0073] Embodiment 12:

[0074] The method for dividing the tight oil accumulation stages based on dynamic resistance coupling analysis has other steps similar to those in Example 1. Further, in step 103, the division of the tight oil accumulation stages includes the following specific analysis process:

[0075] ① The charging power is less than the reservoir displacement pressure, and oil and gas cannot fill the reservoir during the corresponding time period;

[0076] ② The charging power begins to reach and exceed the reservoir displacement pressure but is less than the median pressure. This is the first stage of tight oil charging, and small-scale charging is carried out;

[0077] ③ The charging power reaches and exceeds the median pressure of the reservoir, which is the second stage of tight oil charging, and large-scale charging is carried out.

[0078] Furthermore, in step 103, the small-scale filling is performed so that the oil saturation is lower than 50%.

[0079] Furthermore, in step 103, the large-scale filling is performed so that the oil saturation is equal to or greater than 50%.

[0080] Embodiment 12:

[0081] Taking the tight oil of the lower third member of the Shahejie Formation in the Linnan sag in the Jiyang Depression in the Bohai Bay Basin as an example, the method for dividing the tight oil accumulation stages based on dynamic resistance coupling analysis includes the following steps:

[0082] Step 1: Paleo Stress Recovery

[0083] Thin sections of reservoir inclusions in the lower third section of the Shahejie Formation in Well Jie 5 and Well Xia 942 were prepared. Through microscopic observation, fluorescence spectroscopy analysis, and microthermometry, the existence of two phases of hydrocarbon inclusions was confirmed. The uniform temperature and gas-liquid ratio of the two phases of hydrocarbon inclusions and their associated brine inclusions were obtained, and the content of each component of crude oil was obtained through crude oil composition test data. The above parameters were input into the PVTsim software, and the hydrocarbon inclusion phase envelope, isochoric line, and associated brine inclusion isochoric line were reconstructed through iterative simulation of the PVT Simulations module. The pressure value at the intersection of the two inclusion isochoric lines is the capture pressure of the hydrocarbon inclusion ( Figure 2 ). Through analysis, the capture pressure of hydrocarbon inclusions in Linnan Depression is 33.2Mpa.

[0084] The obtained fluid inclusion capture pressure and current pressure were used as process constraints, and the 1D module of PetroMod basin simulation software was used to load the formation thickness, age, lithology and heat flow parameters of Jie 5 well and Xia 942 well to simulate and obtain the pressure evolution history ( Figure 3 ). From the simulation of the pressure evolution history, it can be seen that the Linnan sag mainly had hydrocarbon charging pressure in the Dongying period before and after the denudation period and the Guantao-Minghuazhen period.

[0085] Step 2: Paleo resistance calculation

[0086] Based on the core porosity and high-pressure mercury injection test data of 50 groups of tight reservoirs in Linnan Sag, the correlation analysis between porosity, displacement pressure and median pressure was conducted ( Figure 4 ), and the relationship between the current porosity and two types of filling resistance (i.e., displacement pressure and median pressure) is obtained (Formula 1 and Formula 2).

[0087] Discharge pressure P c =837.53φ -2.889 (1);

[0088] Median pressure P 50 =2523.4φ -2.602 (2);

[0089] Prepare cast thin sections of reservoirs in the lower third sub-member of the Shahejie Formation in Jie 5 and Xia 942 wells, determine the diagenetic sequence based on the mineral paragenesis under a microscope and collect photos. Use Adobe Photoshop 2017 software to delineate the pores and cementation and dissolution areas at each stage in the sequence and calculate the corresponding porosity. From now on, calculate the paleo-porosity in accordance with the diagenetic sequence in sequence, and select the porosity corresponding to the key time nodes of reservoir diagenesis (43Ma, 37Ma, 24.6Ma, 14Ma, 5Ma, 0Ma) and substitute it into the fitting formula of porosity and filling resistance to calculate the resistance. Finally, connect the filling resistance at each time node in turn to restore the resistance evolution process ( Figure 5 ), and completed the evolution history of oil and gas filling resistance of the tight reservoir in the lower third member of the Shahejie Formation in the Linnan sag.

[0090] Step 3: Quantitative division of reservoir formation stages

[0091] The evolution of oil charging power, displacement pressure and median pressure of the lower Sha 3 sub-member of Well 5 and Well 942 obtained in Step 1 and Step 2 are placed on the same time-pressure coordinate axis to complete the quantitative chart of the dynamic resistance coupling relationship and the accumulation stage of Well 5 and Well 942, and the division of the tight oil accumulation stage of Linnan Sag is based on this. The tight oil accumulation stages of Well 5 and Well 942 are divided separately below.

[0092] Street 5 Well Figure 6 a):

[0093] Before 29.8 Ma, the charging power was less than the displacement pressure and no oil charging occurred.

[0094] From 29.8Ma to 29.0Ma, the charging power was greater than the displacement pressure but less than the median pressure. During this period, oil could be charged on a small scale. This stage is the first stage of the first accumulation (A1).

[0095] From 29.0Ma to 24.6Ma, the charging power was greater than the median pressure. During the corresponding period, oil could be charged on a large scale and the oil saturation in the reservoir could reach 50%. This stage is the second stage of the first phase of reservoir formation (A2).

[0096] From 24.6Ma to 14.0Ma, the strata were uplifted and the first phase of hydrocarbon accumulation ended.

[0097] From 14.0Ma to 9.6Ma, the stratum subsided again, but the charging power was less than the displacement pressure and no oil charging occurred.

[0098] From 9.6Ma to 3.5Ma, the charging power was greater than the displacement pressure but less than the median pressure. During this period, oil could be charged on a small scale. This stage is the first stage of the second phase of accumulation (B1).

[0099] From 3.5Ma to 0Ma, the charging power is greater than the median pressure. During the corresponding period, oil can be charged on a large scale and the oil saturation in the reservoir can reach 50%. This stage is the second stage of the first phase of reservoir formation (B2).

[0100] Xia 942 well ( Figure 6 b):

[0101] Before 30.7 Ma, the charging power was less than the displacement pressure and no oil charging occurred.

[0102] From 30.7Ma to 29.0Ma, the charging power was greater than the displacement pressure but less than the median pressure. During this period, oil could be charged on a small scale. This stage is the first stage of the first accumulation (A1).

[0103] From 29.0Ma to 24.6Ma, the charging power was greater than the median pressure. During the corresponding period, oil could be charged on a large scale and the oil saturation in the reservoir could reach 50%. This stage is the second stage of the first phase of reservoir formation (A2).

[0104] From 24.6Ma to 14.0Ma, the strata were uplifted and the first phase of hydrocarbon accumulation ended.

[0105] From 14.0Ma to 13.0Ma, the stratum subsided again, but the charging power was less than the displacement pressure and no oil charging occurred.

[0106] From 13.0Ma to 5.0Ma, the charging power was greater than the displacement pressure but less than the median pressure. During this period, oil could be charged on a small scale. This stage is the first stage of the second phase of accumulation (B1).

[0107] From 5.0Ma to 0Ma, the charging power is greater than the median pressure. During the corresponding period, oil can be charged on a large scale and the oil saturation in the reservoir can reach 50%. This stage is the second stage of the first phase of reservoir formation (B2).

[0108] This method of dividing tight oil accumulation stages based on dynamic-drag coupling analysis breaks through the general division of the main oil and gas accumulation period in existing technologies, and subdivides different accumulation stages within the accumulation period from the perspective of filling dynamics. It comprehensively applies the dynamic-drag coupling relationship of oil filling dynamics, displacement pressure and median pressure evolution process to quantitatively divide the tight oil accumulation stages.

[0109] The above contents are further detailed descriptions of the present invention in combination with specific preferred embodiments, and it cannot be determined that the specific implementation of the present invention is limited to these descriptions. For ordinary technicians in the technical field to which the present invention belongs, several simple deductions or substitutions can be made without departing from the concept of the present invention, which should be regarded as falling within the protection scope of the present invention.

Claims

1. A method for dividing tight oil reservoir formation stages based on dynamic-drag coupling analysis, characterized in that: The following steps are involved: Step 101: Paleopressure recovery: obtaining the fluid inclusion capture pressure and the current pressure as process constraints, simulating and obtaining the pressure evolution history; Step 102: Paleoresistance calculation: the porosity evolution history of the reservoir is restored by using the inversion backstripping method, and then the paleoresistance size and its evolution history are calculated by using the relationship formula between the current porosity and the two types of filling resistances; Step 103: Division of reservoir formation stages: Place the evolution of charging power, displacement pressure and median pressure on the same time-pressure coordinate axis, and divide the tight oil reservoir formation stages in sequence according to the relationship between the charging power and the resistance.

2. The method for dividing tight oil accumulation stages based on dynamic drag coupling analysis according to claim 1, characterized in that: In step 101, a reservoir inclusion slice is prepared, the homogenization temperature and the gas-liquid ratio are determined, and the inclusion capture pressure is simulated by PVTsim iteration in combination with the crude oil component content; and the pressure evolution history is simulated and obtained by using PetroMod basin simulation software.

3. The method for dividing tight oil accumulation stages based on dynamic drag coupling analysis according to claim 2, characterized in that: In step 101, the uniform temperature and gas-liquid ratio information of hydrocarbon inclusions of different stages and their associated brine inclusions are determined by microscopic observation and temperature measurement.

4. The method for dividing tight oil accumulation stages based on dynamic drag coupling analysis according to claim 2 is characterized in that: In step 101, the content of each component of crude oil is obtained through crude oil composition test data.

5. The method for dividing tight oil accumulation stages based on dynamic drag coupling analysis according to claim 2, characterized in that: In step 101, the inclusion capture pressure is simulated iteratively by PVTsim, including: The hydrocarbon inclusion phase envelope, isochoric line and associated brine inclusion isochoric line are obtained through PVTsim iterative simulation. The pressure value at the intersection of the two inclusion isochoric lines is the capture pressure of the hydrocarbon inclusion.

6. The method for dividing tight oil accumulation stages based on dynamic drag coupling analysis according to claim 2, characterized in that: In step 101, the pressure evolution history is simulated and obtained using the PetroMod basin simulation software, including: The obtained fluid inclusion capture pressure and current pressure were used as process constraints, and the 1D module of PetroMod basin simulation software was used to load parameters such as formation thickness, age, lithology and heat flow to simulate and obtain the pressure evolution history.

7. The method for dividing tight oil accumulation stages based on dynamic drag coupling analysis according to claim 1, characterized in that: The step 102 further includes: Obtain reservoir test parameters and fit the relationship formula between porosity, displacement pressure and median pressure.

8. The method for dividing tight oil accumulation stages based on dynamic drag coupling analysis according to claim 7, characterized in that: In the step 102, reservoir test parameters are obtained, and the relationship formula between porosity, displacement pressure and median pressure is fitted, which specifically includes: conducting tight reservoir core porosity and high-pressure mercury injection testing to obtain parameters such as porosity, displacement pressure, median pressure, and performing correlation analysis on porosity, displacement pressure and median pressure to obtain current porosity and two types of filling resistances.

9. The method for dividing tight oil accumulation stages based on dynamic drag coupling analysis according to claim 8, characterized in that: In step 102, the two types of filling resistances include displacement pressure and median pressure.

10. The method for dividing tight oil accumulation stages based on dynamic drag coupling analysis according to claim 1, characterized in that: In step 102, based on the study of tight reservoir storage space, diagenesis and sequence, the inversion backstripping method is used to restore the reservoir porosity evolution history, and then the relationship formula between the current porosity and two types of filling resistance is used to calculate the size of the ancient resistance and its evolution history.

11. The method for dividing tight oil accumulation stages based on dynamic drag coupling analysis according to claim 1, characterized in that: In step 103, the evolution processes of the power, displacement pressure and median pressure obtained in steps 101 and 102 are placed on the same time-pressure coordinate axis to divide the tight oil accumulation stages.

12. The method for dividing tight oil accumulation stages based on dynamic drag coupling analysis according to claim 2, characterized in that: In step 103, the division of tight oil accumulation stages includes the following specific analysis processes: ① The charging power is less than the reservoir displacement pressure, and oil and gas cannot fill the reservoir during the corresponding time period; ② The charging power begins to reach and exceed the reservoir displacement pressure but is less than the median pressure. This is the first stage of tight oil charging, and small-scale charging is carried out; ③ The charging power reaches and exceeds the median pressure of the reservoir, which is the second stage of tight oil charging, and large-scale charging is carried out.

13. The method for dividing tight oil accumulation stages based on dynamic drag coupling analysis according to claim 12, characterized in that: In step 103, the small-scale filling is performed with an oil saturation lower than 50%.

14. The method for dividing tight oil accumulation stages based on dynamic drag coupling analysis according to claim 12, characterized in that: In step 103, the large-scale filling is performed with an oil saturation equal to or exceeding 50%.

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