Method for representing wave range of oil and gas hydrocarbon pressurized filling based on energy conservation

Abstract

This invention discloses a method for characterizing the sweep range of hydrocarbon generation and injection pressure based on energy conservation, relating to the field of petroleum exploration and development technology. Addressing the problem that traditional methods focus on macroscopic qualitative descriptions of hydrocarbon accumulation and lack precise quantification of injection depth, this invention calculates the total hydrocarbon expulsion kinetic energy from the source rock by superimposing energy from different sources. These different sources include: undercompaction kinetic energy, hydrocarbon generation volume expansion kinetic energy, and fluid elastic energy. The invention quantifies the energy attenuation of hydrocarbons during migration from the source rock to the reservoir. Based on the total hydrocarbon expulsion kinetic energy and the energy attenuation during migration, the injection distance limit is determined.

Description

Technical Field

[0001] This invention relates to the field of oil and gas exploration and development, and more specifically, to a method for characterizing the sweep range of hydrocarbon generation pressurization and injection based on energy conservation. Background Technology

[0002] Unconventional reservoirs are characterized by low porosity, low permeability, and strong heterogeneity. The reservoir space is mainly composed of nanoscale pores, and the seepage and hydrocarbon accumulation processes are complex. Traditional theories are difficult to apply, which restricts efficient development and urgently requires targeted hydrocarbon accumulation theories and technical support.

[0003] As a cutting-edge interdisciplinary field combining petroleum geology and dynamics, hydrocarbon accumulation dynamics focuses on the balance between accumulation forces and resistance, studying the dynamic laws governing the entire hydrocarbon accumulation process and providing crucial theoretical support for unconventional oil and gas development. Its value lies in three aspects: first, accurately identifying the sources of charging power (such as hydrocarbon generation and pressurization from source rocks), clarifying the mechanisms of power loss, and determining effective reservoir charging conditions; second, revealing the mechanisms of nanoscale pore migration and charging, clarifying the role of reservoir heterogeneity in regulation, and identifying high-quality reservoirs (sweet spots); and third, guiding the optimization of development plans, providing a reference for fracturing parameter design, and improving development efficiency and recovery rate.

[0004] Current research on hydrocarbon accumulation dynamics still has shortcomings: traditional research focuses on macroscopic qualitative descriptions of hydrocarbon accumulation, and lacks precise quantitative methods for the degree of filling. Summary of the Invention

[0005] The purpose of this application is to provide a method for characterizing the sweep range of hydrocarbon generation and injection based on energy conservation, clarify the method for obtaining the total energy of source rock hydrocarbon expulsion, systematically quantify the multi-factor energy decay of the migration path, establish a scientific and operable full-process energy coupling model, realize accurate and quantitative characterization of the injection distance of unconventional oil and gas reservoirs, and solve the problems of static evaluation, insufficient accuracy and poor adaptability of existing technologies.

[0006] To solve the above-mentioned technical problems, the solution adopted in this application is as follows:

[0007] A method for characterizing the sweep range of pressurized charging for hydrocarbon generation based on energy conservation includes the following steps:

[0008] Step S100: Calculate the total hydrocarbon expulsion kinetic energy by superimposing the energy from different sources; the energy from different sources includes: undercompaction kinetic energy, hydrocarbon generation volume expansion kinetic energy, and fluid elastic energy;

[0009] Step S200: Quantify the energy attenuation of oil and gas during the migration from source rock to reservoir;

[0010] Step S300: Determine the charging distance limit based on the total hydrocarbon expulsion kinetic energy and the energy decay of the migration process.

[0011] As a specific implementation scheme, the specific implementation process of step S100 is based on the thermodynamic energy superposition principle, as follows:

[0012] By using well logging curves to obtain sediment compaction data, the contribution value of undercompacted overpressure is separated from the hydrocarbon expulsion overpressure of the source rock to obtain the undercompacted kinetic energy; combined with thermal simulation PVT experimental data, the hydrocarbon generation pressurization energy is calculated by numerical integration to obtain the hydrocarbon generation volume expansion kinetic energy; based on the rock or fluid compressibility coefficient and formation pressure, the fluid elastic energy is calculated; and by superimposing the undercompacted kinetic energy, hydrocarbon generation volume expansion kinetic energy, and fluid elastic energy, the total hydrocarbon expulsion kinetic energy is obtained.

[0013] In some specific implementation schemes, the specific process of obtaining undercompacted kinetic energy is as follows:

[0014] Step S111: Collect the sonic transit time logging curves and measured formation pressure data of the target well;

[0015] Step S112: On the sonic transit time logging curve, select a pure mudstone section and establish the sonic transit time. With depth The equation for the normal compaction trend line is: ;

[0016] In the formula, Indicates the compaction coefficient. It represents the time difference of sound waves at the Earth's surface.

[0017] Substituting different depth values ​​yields sedimentary compaction data. The compaction coefficient can be obtained through various methods, including statistical regression based on well logging data and calibration based on measured core porosity, which are existing technologies in this field and will not be elaborated upon further.

[0018] Step S113: Use the measured formation pressure as the total overpressure. Extracting under-compacted and over-compressed materials;

[0019] In this step, the overpressure from hydrocarbon source rock is caused by a combination of factors, including:

[0020] ;

[0021] ;

[0022] in, For under-compaction and over-pressure, ; For total overpressure, ; The contribution coefficient for undercompaction overpressure is dimensionless. This is the actual measured time difference of sound waves; Normal compaction trend value at the same depth; This is a regional empirical conversion factor (usually calibrated from core measurement data).

[0023] ;

[0024] in, The effective kinetic energy gained by the undercompacted fluid, i.e., the undercompacted kinetic energy. ; The seepage efficiency is dimensionless. Porosity .

[0025] It should be noted that seepage efficiency characterizes the efficiency with which undercompacted overpressure is converted into effective hydrocarbon expulsion kinetic energy by the fluid. It is obtained through core displacement experiments or mercury intrusion porosimetry combined with Darcy's flow theory. Specifically, core samples of source rocks from the target formation are collected, and steady-state displacement experiments are conducted under simulated formation conditions. The relationship between displacement pressure and fluid flow rate is recorded, and the ratio of effective permeability to absolute permeability is calculated based on Darcy's law, thus yielding the seepage efficiency. If core displacement data is unavailable, the pore throat fractal dimension can be obtained using high-pressure mercury intrusion porosimetry, and indirectly calibrated using empirical models of porosity and permeability. The methods for obtaining seepage efficiency are conventional techniques in this field and will not be described in detail here.

[0026] In some specific implementation schemes, the specific process of obtaining the kinetic energy of hydrocarbon generation volume expansion is as follows:

[0027] The kinetic energy of hydrocarbon generation due to volume expansion is the main source of high pressure, and its core is the product of the amount of oil and gas generated and the volume expansion coefficient. When kerogen is converted into oil and gas, the energy density that can drive the oil and gas to be expelled due to volume expansion is the kinetic energy of hydrocarbon generation due to volume expansion.

[0028] ;

[0029] In the formula, The kinetic energy is the volume expansion energy of hydrocarbon generation. ; For formation pressure, ; The volume increase is due to hydrocarbon generation. .

[0030] in:

[0031] ;

[0032] ;

[0033] ;

[0034] ;

[0035] ;

[0036] ;

[0037] In the formula, α is the pressure coefficient, which is dimensionless; ρ is the density of the formation water; g is the acceleration due to gravity. ; The weight of the raw oil is in kg; For organic matter abundance, ;a represents the hydrocarbon conversion rate, which is dimensionless; The density of the source rock. ; For crude oil volume, ; For crude oil density, ; For the volume of gas, ; For dissolved gas-oil ratio, ; For the volume of kerogen, ; For kerogen quality, ; For kerogen density, .

[0038] Specifically, in this invention, kerogen samples are heated under laboratory conditions through thermal simulation experiments to simulate the hydrocarbon generation process in geological history. From this experiment, the hydrocarbon generation conversion rate a as a function of temperature a(T), the product composition (oil / gas ratio) at different maturity levels, the organic matter abundance, and hydrocarbon generation kinetic parameters are obtained.

[0039] Specifically, in this invention, the high-pressure physical properties of oil and gas are measured through PVT experiments at different pressure temperatures, thereby obtaining the changes in crude oil density with pressure, the changes in dissolved gas-oil ratio with pressure, and the fluid compressibility coefficient.

[0040] Kernel quality and density are obtained by measurement, which is a conventional technique in this field.

[0041] Based on experimental data and well logging data, the kinetic energy of hydrocarbon generation volume expansion was calculated using the numerical integration method.

[0042] In some specific implementation schemes, the process of obtaining the fluid elastic properties is as follows:

[0043] Fluid elasticity serves as an auxiliary driving force in the early stages of hydrocarbon expulsion, possessing characteristics of "continuous release, adaptation to low-permeability transport, and coupling with overpressure attenuation." Therefore:

[0044] ;

[0045] In the formula, For fluid elastic properties, ; The fluid compressibility coefficient, ; For formation pressure, ; For pore volume, .

[0046] in, .

[0047] Furthermore, in step S200, the energy attenuation along the migration path is quantified based on energy conservation and fluid dynamics theory. Specifically, during the migration of oil and gas from the source rock to the reservoir, energy decreases due to increased distance and path resistance. Based on the law of energy conservation and fluid dynamics theory, the total energy attenuation decreases linearly with respect to the migration distance in a piecewise cumulative manner, expressed as:

[0048] ;

[0049] In the formula, Indicates distance from source rock The remaining energy at that location; This represents the initial energy at the source rock; It represents the straight-line distance from the source rock to a point in the reservoir, i.e., the migration path; This indicates frictional resistance per unit distance.

[0050] Frictional resistance per unit distance reflects the overall energy loss per unit distance during oil and gas migration, and consists of multiple components:

[0051] ;

[0052] ;

[0053] ;

[0054] ;

[0055] ;

[0056] In the formula, This is represented as viscous friction; Indicates capillary friction; Indicates gravitational friction; This indicates the additional frictional resistance of non-Darcy flow;

[0057] Indicates crude oil viscosity. ; Indicates the effective permeability of the reservoir. ; The oil and gas injection velocity can be obtained through basin simulation. ; This indicates the activation of the pressure gradient. ;

[0058] Indicates the coefficient of heterogeneity; This represents the average capillary force. ; Indicates the volume transported per unit. ;

[0059] , The densities of water and oil are respectively. ; It is the acceleration due to gravity. ; The inclination angle of the transport path, ;

[0060] For hydrocarbon fluid viscosity, ; The velocity of the hydrocarbon fluid, representing the distance it travels per unit time, can be obtained through a filling simulation experiment. ; Non-Darcy coefficient, ; For fluid density, .

[0061] The comprehensive unit friction expression model is as follows:

[0062] ;

[0063] Distance of the transport path Substituting into the above formula, the energy decay of the quantification transport path is calculated.

[0064] Furthermore, in step S300, when the charging stops at a certain point in the reservoir, representing the charging distance limit, the remaining energy is insufficient to overcome the capillary resistance at that point. Therefore:

[0065] ;

[0066] In the formula, Indicates remaining energy; This represents the initial total hydrocarbon expulsion kinetic energy; The unit frictional resistance represents the homogenized sand body in segment j. is the length of the j-th homogenized sand body in the hydrocarbon fluid migration path; n represents the number of homogenized sand body segments.

[0067] It should be noted that the initiation pressure gradient characterizes the minimum pressure gradient required for fluid to overcome the pore-throat interface resistance and begin flow in a low-permeability reservoir, and is determined through low-velocity non-Darcy flow experiments. Specifically, using core samples from the target reservoir, displacement experiments are conducted under simulated formation conditions using a micro-injection pump. The relationship between pressure gradient and flow velocity is recorded, and the initiation pressure gradient value is determined using a quasi-linear regression method or a capillary equilibrium method. In the absence of experimental data, regional empirical formulas can also be used. The method for obtaining the initiation pressure gradient is existing technology in this field and will not be described in detail here.

[0068] The non-Darcy coefficient is used to characterize the contribution of inertial drag to energy attenuation during high-speed fluid flow in low-permeability reservoirs, and is determined through non-Darcy flow experiments. Specifically, core samples from the target reservoir are collected, and displacement experiments are conducted at different injection rates under constant confining pressure and temperature conditions. The relationship between pressure gradient and flow velocity is recorded, and plotted. The curve was obtained by nonlinear regression fitting using the Forchheimer equation. The value can be estimated by referring to the empirical formulas given in industry standards (such as SY / T6285-2011) if experimental conditions are unavailable. The method for obtaining the non-Darcy coefficient is a prior art technique and will not be described in detail here.

[0069] The heterogeneity coefficient is obtained as follows: The heterogeneity coefficient characterizes the amplification effect of reservoir heterogeneity on capillary resistance, and is calibrated through a combination of core property statistics and capillary force experiments. ;

[0070] In the formula, This is the weighting coefficient, with a value ranging from 0 to 1; The coefficient of variation of permeability; This is the Lorentz coefficient; unless otherwise specified or core experimental data is lacking, The default value is set to 0.5. If core physical properties and capillary force experimental data are obtained, the weighting coefficients can be adjusted using the least squares method. Optimization and calibration are performed. Research on reservoir heterogeneity encompasses core aspects such as physical property distribution and fluid flow. Various existing characterization methods exist. This invention focuses on permeability differences, combining the permeability variation coefficient and the Lorentz coefficient to quantitatively characterize reservoir heterogeneity. The permeability variation coefficient accurately measures the dispersion of permeability relative to its average value, reflecting its overall distribution pattern; its acquisition method is existing technology and will not be elaborated further. The Lorentz coefficient, calculated based on full-sample permeability data, accurately characterizes the permeability distribution differences across the entire range; its acquisition method is also existing technology. Combining these two indicators overcomes the limitations of a single indicator and improves the accuracy of heterogeneity characterization; the specific steps are existing methods in this field and will not be elaborated further.

[0071] Unit transport volume is characterized as the volume of hydrocarbons expelled per unit volume of source rock, and is determined through a combination of pyrolysis experiments and hydrocarbon generation kinetics models. Specifically, core samples of the target source rock are collected, and Rock-Eval pyrolysis experiments are conducted to obtain the free hydrocarbon content. pyrolysis hydrocarbon content Based on the total organic carbon data, combined with the hydrocarbon generation conversion rate and hydrocarbon expulsion efficiency, the following formula is used for calculation:

[0072] ;

[0073] in, Hydrocarbon expulsion efficiency is determined by hydrocarbon generation kinetics simulation or geological analogy; The density of the source rock; This refers to the density of hydrocarbon fluids.

[0074] The technical solution of this application has at least the following advantages and beneficial effects:

[0075] Existing studies on hydrocarbon accumulation dynamics largely focus on qualitative descriptions of macroscopic accumulation conditions, lacking a systematic quantification of the sources of hydrocarbon expulsion (undercompaction, hydrocarbon generation expansion, and fluid elasticity) and a detailed characterization of energy attenuation along migration paths. This invention, based on the principle of thermodynamic energy superposition, integrates the kinetic energy of undercompaction, the kinetic energy of hydrocarbon generation volume expansion, and fluid elasticity into a unified total hydrocarbon expulsion kinetic energy system, achieving for the first time a quantitative superposition of hydrocarbon expulsion dynamics from source rocks. Furthermore, based on the law of conservation of energy and fluid dynamics theory, it quantifies viscous friction, capillary friction, gravitational friction, and non-Darcy flow additional friction in segments, establishing an analytical expression for migration energy attenuation. Ultimately, this achieves a quantitative determination of the charging distance, filling the gap in existing technologies where the charging range cannot be quantitatively predicted.

[0076] Furthermore, existing methods typically simplify reservoirs as homogeneous media, neglecting the nonlinear impact of heterogeneity on energy decay, leading to significant discrepancies between evaluation results and actual conditions. This invention divides the migration path into several homogenized sand body segments based on parameters such as physical properties, heterogeneity, and dip angle. The unit friction of each segment is calculated separately, and then the values ​​are accumulated segment by segment according to the actual path length, achieving a refined description of the energy decay process. Example results show that this method can accurately identify the main energy-consuming factors in different migration segments (e.g., segment 1 is dominated by capillary friction, and segment 3 is dominated by viscous friction), effectively improving the calculation accuracy of the charging distance.

[0077] Traditional "sweet spot" predictions largely rely on the superposition of static geological parameters (such as porosity, permeability, and total organic matter concentration), lacking kinetic criteria for whether hydrocarbons can be effectively injected to the target location. This invention, by balancing the total hydrocarbon expulsion kinetic energy with the cumulative energy consumption along the migration path, directly determines the effective injection distance limit, clearly answering the core exploration question of "whether hydrocarbons can reach a certain location." For example, in the embodiment, based on data from section Y of basin X, the injection distance is calculated to be over 4000m, providing quantifiable kinetic support for predicting high-quality reservoirs at distant sources and for well placement, thus reducing exploration risks.

[0078] In summary, this invention integrates theories from multiple disciplines such as petroleum geology, fluid mechanics, and thermodynamics, clarifies the theoretical derivation logic of the total energy of source rock hydrocarbon expulsion, systematically quantifies the energy decay of multiple factors along the migration path, optimizes the parameter calibration process, and establishes a scientific and operable full-process energy coupling model. This enables accurate and quantitative characterization of the charging distance of unconventional oil and gas reservoirs, solving the problems of insufficient accuracy and poor adaptability in existing static evaluation technologies. Attached Figure Description

[0079] When considered in conjunction with the accompanying drawings, the invention can be more fully and better understood by referring to the following detailed description, and the scientific and practical nature of the invention can be better illustrated. However, the accompanying drawings, which are provided to provide a further understanding of the invention and constitute a part of this invention, are used to explain the invention and do not constitute an undue limitation of the invention.

[0080] Figure 1 This is a flowchart of the present invention. Detailed Implementation

[0081] The technical solutions of the embodiments of the present invention will be clearly and completely described below with reference to the accompanying drawings. Obviously, the described embodiments are only some embodiments of the present invention, and not all embodiments. The components of the embodiments of this application described and shown in the accompanying drawings can generally be arranged and designed in various different configurations.

[0082] Therefore, the following detailed description of the embodiments of this application provided in the accompanying drawings is not intended to limit the scope of the claimed application, but merely to illustrate selected embodiments of the application. All other embodiments obtained by those skilled in the art based on the embodiments of this application without inventive effort are within the scope of protection of this application.

[0083] It should be noted that relational terms such as "first" and "second" are used merely to distinguish one entity or operation from another, and do not necessarily require or imply any such actual relationship or order between these entities or operations. Furthermore, the terms "comprising," "including," or any other variations thereof are intended to cover non-exclusive inclusion, such that a process, method, article, or apparatus that comprises a list of elements includes not only those elements but also other elements not expressly listed, or elements inherent to such process, method, article, or apparatus. Unless otherwise specified, an element defined by the phrase "comprising one..." does not exclude the presence of other identical elements in the process, method, article, or apparatus that includes the element.

[0084] like Figure 1 As shown, this invention discloses a method for characterizing the sweep range of oil and gas hydrocarbon generation pressurization and charging based on energy conservation. The overall idea is as follows: by obtaining the total hydrocarbon expulsion kinetic energy of oil and gas generation and the energy loss on the migration path, the distance that oil and gas hydrocarbon generation can migrate can be obtained, and the charging distance limit can be determined.

[0085] Example

[0086] The method for characterizing the sweep range of pressurized charging for hydrocarbon generation based on energy conservation is as follows:

[0087] Step S100: Superimpose the energy from different sources to calculate the initial total kinetic energy of hydrocarbon expulsion from the source rock; the energy from different sources includes: undercompaction kinetic energy, hydrocarbon generation volume expansion kinetic energy and fluid elastic energy.

[0088] undercompacted kinetic energy :

[0089] Based on existing data, overpressure in segment Y of basin X. Average Under-compaction overpressure contribution coefficient The value ranges from 0.2 to 0.3, with an average of 0.25; seepage efficiency. The average value is 0.42; the average porosity is... In a unit volume of source rock, the kinetic energy of hydrocarbon expulsion due to undercompaction is:

[0090] .

[0091] The kinetic energy of hydrocarbon generation volume expansion :

[0092] The organic matter abundance in segment Y of basin X is 6. Kerogen type I~II1, kerogen density is The average hydrocarbon conversion rate was 0.45; the average shale density was 2.5. The formation pressure coefficient is 1.6; the crude oil density under formation conditions is... The dissolved gas-oil ratio under formation conditions is 30.

[0093] Formation pressure ;

[0094] Raw oil quality ;

[0095] crude oil volume ;

[0096] Anger volume ;

[0097] kerogen volume ;

[0098] Volume increase due to hydrocarbon generation ;

[0099] .

[0100] Fluid elasticity :

[0101] The average compressibility coefficient of crude oil in section Y of basin X is: Other parameters are the same as above.

[0102] ;

[0103] Total kinetic energy of hydrocarbon expulsion per unit volume: .

[0104] Step S200: Quantify the energy decay of oil and gas during the migration from source rock to reservoir.

[0105] The specific implementation process of this step is as follows:

[0106] Core experiments in Basin X revealed that, based on the physical properties, heterogeneity, and dip angle of the formation along the crude oil migration path, the basin can be divided into three segments: the first segment, the second segment, and the third segment, which are homogenized sand bodies.

[0107] (1) Viscous friction :

[0108] Initiate pressure gradient It can be fitted by the basin X empirical formula:

[0109] ;

[0110] in, This is an empirical coefficient (taken as 0.01). For crude oil viscosity, take 0.8. Let mD be the penetration rate.

[0111] The flow velocity was obtained from basin simulation data. Within segment Y of basin X, the transport was low-speed within the source, and the transport velocity was... .

[0112] Section 1: ;

[0113] Section 2: ;

[0114] Section 3: ;

[0115] In the above formula, , , These represent the penetration rates of segments 1, 2, and 3, respectively. , , These represent the starting pressure gradients for segments 1, 2, and 3, respectively. This refers to the viscosity of crude oil.

[0116] (2) Capillary friction :

[0117] Unit transport volume From the pyrolysis data: heterogeneity coefficient Mean capillary force Obtained from a large amount of core data:

[0118] Section 1: ;

[0119] Section 2: ;

[0120] Section 3: ;

[0121] In the above formula, , , These represent the heterogeneity coefficients of segments 1, 2, and 3, respectively. , , These represent the average capillary forces of segments 1, 2, and 3, respectively.

[0122] (3) Gravitational friction :

[0123] Section 1: ;

[0124] Section 2: ;

[0125] Section 3: .

[0126] In the above formula, , These are the densities of water and oil, respectively. It is the acceleration due to gravity; , , These are the tilt angles of the transport paths for segments 1, 2, and 3, respectively.

[0127] (4) Non-Darcy Molecular Obstruction :

[0128] The X Basin has extremely low reservoir permeability and high hydrocarbon migration rates. In terms of magnitude, the proportion of non-Darcy flow friction in the total friction is negligible.

[0129] Step S300: Determine the charging distance limit based on the total hydrocarbon expulsion kinetic energy and energy decay during the migration process.

[0130] in Energy consumption of the first and second homogenized sand bodies

[0131]

[0132]

[0133] When the energy of the first homogenized sand body and the second homogenized sand body is not completely consumed: .

[0134] In summary, based on the principle of energy conservation, this invention quantifies the superposition effect of undercompaction kinetic energy, hydrocarbon generation volume expansion energy, and fluid elastic energy, and combines this with a multi-factor energy decay model of the migration path to clarify that the hydrocarbon expulsion energy from source rocks can effectively drive oil and gas migration to a range of 4000m. During hydrocarbon expulsion, overpressure release and energy impact easily induce fractures in low-porosity and low-permeability reservoirs, creating advantageous channels for oil and gas migration. The lower energy loss in the first migration stage lays a solid foundation for long-distance migration; as reservoir properties continuously improve (increased permeability, reduced heterogeneity), viscous friction and capillary friction significantly decrease, and with the auxiliary driving effect of buoyancy, oil and gas migration distances can exceed the 4000m limit, achieving effective charging at greater distances. This conclusion provides key dynamic support for predicting high-quality unconventional oil and gas reservoirs at distant sources and for selecting exploration and development targets, fully demonstrating the scientific and practical value of this method.

[0135] The embodiments of the present invention have now been described in detail. To avoid obscuring the concept of the invention, some details known in the art have not been described. Those skilled in the art will fully understand how to implement the technical solutions of this invention based on the above description, and the scope of the invention is defined by the appended claims.

Claims

1. A method for characterizing the sweep range of hydrocarbon generation pressurization and injection based on energy conservation, characterized in that, The total kinetic energy of hydrocarbon expulsion from source rocks is calculated by superimposing energy from different sources. Energy from different sources includes: undercompaction kinetic energy, hydrocarbon generation volume expansion kinetic energy, and fluid elastic energy; Quantify the energy attenuation of oil and gas during migration from source rocks to reservoirs; Based on the total hydrocarbon expulsion kinetic energy and energy decay during the migration process, the charging distance limit is determined. When charging stops at a certain point in the reservoir, it represents the charging distance limit, as the remaining energy is insufficient to overcome the capillary resistance at that point. Therefore: ； In the formula, Indicates remaining energy; This represents the initial total hydrocarbon expulsion kinetic energy; The total frictional resistance per unit is represented by the j-th segment of the homogenized sand body in the hydrocarbon fluid migration path. is the length of the j-th homogenized sand body in the hydrocarbon fluid migration path; n represents the number of homogenized sand body segments; The implementation process of quantifying the energy attenuation of oil and gas during migration from a hydrocarbon source rock to a reservoir is as follows: the distance of the migration path is divided into a plurality of equal segments, and the energy attenuation of each segment is calculated according to the following formula: The comprehensive unit frictional resistance is calculated by substituting the following formula, and the migration path energy attenuation is quantified. ； ； ； ； ； ； ； In the formula, Indicates distance from source rock The remaining energy at that location; This represents the initial energy at the source rock; Indicates the migration path; Indicates frictional resistance per unit distance; This is represented as viscous friction; Indicates capillary friction; Indicates gravitational friction; This indicates the additional frictional resistance of non-Darcy flow; Indicates crude oil viscosity. ; Indicates the effective permeability of the reservoir; Indicates the oil and gas injection flow rate; This indicates the activation of the pressure gradient. ; Indicates the coefficient of heterogeneity; This represents the average capillary force. ; Indicates the volume transported per unit; , These are the densities of water and oil, respectively. It is the acceleration due to gravity; The inclination angle of the transport path; Viscosity of hydrocarbon fluids; The velocity of hydrocarbon fluids; Non-Darcy coefficient; For fluid density; Indicates friction as a composite unit; The transport path is divided into segments based on the homogenized sand body, the length of each segment of homogenized sand body is obtained, and the comprehensive unit friction of the homogenized sand body is calculated.

2. The energy conservation based hydrocarbon oil and gas pressurized recharge sweep efficiency characterization method according to claim 1, wherein, The specific process for obtaining undercompacted kinetic energy is as follows: Step S111: Collect the sonic transit time logging curves and measured formation pressure data of the target well; Step S112: On the sonic transit time logging curve, select a pure mudstone section and establish the sonic transit time. With depth The equation for the normal compaction trend line is: ; In the formula, denotes the compaction factor, denotes the surface acoustic travel time; Step S113: taking the measured formation pressure as the total overpressure , extract the undercompaction overpressure; ； ； ； in, This indicates under-compression and over-compression. Total overpressure; The contribution coefficient for under-compaction overpressure; This is the actual measured time difference of sound waves; Normal compaction trend value at the same depth; For regional experience conversion coefficients; For undercompacted kinetic energy; For seepage efficiency; Porosity.

3. The energy conservation based hydrocarbon oil and gas pressurized recharge sweep efficiency characterization method according to claim 1, wherein, The specific process for obtaining the kinetic energy of hydrocarbon generation volume expansion is as follows: ； ； ； ； ； ； ； In the formula, The kinetic energy is the volume expansion kinetic energy of hydrocarbon generation. Formation pressure; For depth; The volume increase is due to hydrocarbon generation; α is the pressure coefficient. ρ is the density of the formation water; g is the acceleration due to gravity; For the quality of raw oil; denoted as organic matter abundance; 'a' represents hydrocarbon conversion rate. The density of the source rock; This represents the volume of crude oil. Density of crude oil; For the volume of gas; The dissolved gas-oil ratio; The volume of the kerogen; For kerogen quality; This represents the density of kerogen.

4. The method for characterizing the sweep range of hydrocarbon generation pressurization and charging based on energy conservation according to claim 1, characterized in that, The specific process for obtaining the fluid elastic properties is as follows: ； wherein is the fluid bulk modulus; is the fluid compressibility; is the formation pressure; is the pore volume.

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