A method for evaluating after acid fracturing of compact carbonate rocks

Abstract

The application discloses a method for evaluating a compact carbonate rock after acidification and fracturing, and comprises the following steps: step one, establishing a multi-factor interaction correlation model of gas, liquid and solid base and three phases of the compact carbonate rock reservoir; step two, generating an overall simulation mechanism; and step three, autonomous intelligent simulation. After the acidification and fracturing test evaluation experiment of the compact carbonate rock reservoir, the acidification and fracturing reconstruction effect is effectively evaluated, the reliability and pertinence of the acidification and fracturing design are stronger and stronger, better test evaluation application effects are achieved, the acidification and fracturing reconstruction conditions and reconstruction degrees of the compact carbonate rock reservoir are reflected, and the method has high practicability.

Description

Technical Field

[0001] This invention relates to the field of oil and gas field development technology, and in particular to a method for post-acid fracturing evaluation of tight carbonate rocks. Background Technology

[0002] With the continuous exploration and development of carbonate gas reservoirs, their combined share of reserves and production is increasing, currently exceeding 60%, making them the main contributor to both. The exploration and development of carbonate reservoirs primarily utilizes acid fracturing technology. Tight carbonate gas reservoirs are dense and highly heterogeneous, exhibiting varying degrees of porous, fractured, pore-filled, and cavernous reservoirs, as well as their complex combinations, in different regions. Tight carbonate reservoirs have extremely low porosity and permeability, and the non-porous media are highly dispersed and discontinuous. To effectively test and evaluate the reservoir stimulation status and degree after acid fracturing, and to specifically assess the effectiveness of acid fracturing, a post-acid fracturing evaluation technique is urgently needed to evaluate the reservoir stimulation status and degree in tight carbonate reservoirs. Therefore, finding an effective post-acid fracturing evaluation method that combines the reservoir characteristics and stimulation methods of tight carbonate gas reservoirs, and understanding and evaluating the effects of acid fracturing stimulation, is of great practical significance for accelerating the effective and rapid production of tight carbonate gas reservoirs.

[0003] CN114117791 discloses a numerical simulation method for acid fracturing in carbonate rocks, but this method only addresses the liquid-solid coupling effect. Its main shortcomings include: neglecting the influence of primary and / or secondary gas on carbonate reservoir stimulation during acid fracturing; not considering the interaction of the three phases of gas (primary gas + secondary gas), liquid (primary liquid + secondary liquid), and solid; obtaining only single permeability and solids content evaluations; lacking understanding and evaluation of equivalent fracture geometry, equivalent acid etching conductivity, equivalent permeability, and equivalent contamination coefficient; not considering the influence of the tightness of carbonate rocks on acid fracturing stimulation; the obtained parameters cannot effectively evaluate the stimulation status of acid fracturing, and cannot obtain the stimulation effect of acid fracturing on the reservoir, making acid fracturing design somewhat arbitrary; and hindering subsequent large-scale exploration and development of tight carbonate gas reservoirs. Summary of the Invention

[0004] To address the aforementioned problems, this invention provides a method for evaluating the post-acid fracturing of tight carbonate reservoirs, assessing the state and extent of fracturing after acid fracturing, and recognizing and evaluating the effectiveness of acid fracturing.

[0005] To solve the above-mentioned technical problems, the technical solution of the present invention is: a method for post-acid fracturing evaluation of tight carbonate rocks, comprising the following steps:

[0006] Step 1: Establish a multi-factor interaction model of gas, liquid, solid phases and three phases in tight carbonate reservoirs;

[0007] Step 2: Generate the overall simulation mechanism;

[0008] Step 3: Autonomous Intelligent Simulation.

[0009] Furthermore, in step one, the wellbore model involved includes the dimensions, material type, depth, and mechanical properties of the casing string, forming a hidden or explicit structural package.

[0010] Furthermore, in step one, the lithology of the reservoir model in the involved model satisfies the following partial differential equation, namely the lithological relationship equation of tight carbonate rocks: A model for the residence of changing lithological states is formed.

[0011] in:

[0012] n is the number of factors; Y i The lithology of the tight carbonate reservoir is shown in Figures i (i represents the parameter values ​​for calcite, dolomite, and mudstone, respectively); r is the position vector; F is the external disturbance factor; t l The time for mining or operation is measured in seconds (s).

[0013] Furthermore, in step one, the liquid phase of the reservoir model in the involved model satisfies the following partial differential equation, namely the liquid phase relationship equation of tight carbonate rocks: Forming a hidden structure package that can exist in a changing liquid phase state;

[0014] in:

[0015] n is the number of factors; L i Here are the liquid phase parameters of the tight carbonate reservoir (i represents the values ​​of various ion contents, pH, salinity, viscosity, density, etc.); r is the position vector; P is the pressure (MPa); T is the temperature (K); F is the external disturbance factor; t l The time for extraction or operation is measured in seconds (s).

[0016] Furthermore, in step one, the properties of the reservoir model in the involved model satisfy the following partial differential equation, namely the property relationship equation of tight carbonate rocks: An implicitly structured package that forms changing attribute states and can reside therein;

[0017] in:

[0018] n is the number of factors; R i The reservoir properties are: tight carbonate reservoir (i represents porosity, permeability, saturation, etc.); r is the position vector; P is the pressure (MPa); T is the temperature (K); F is the external disturbance factor; t l The time for mining or operation is measured in seconds (s).

[0019] Furthermore, in step one, the gas phase of the reservoir model in the involved model satisfies the following partial differential equation, namely the gas reservoir flow relationship equation: Forming a hidden structure package that exists in a changing gaseous state and can reside there;

[0020] in:

[0021] For Laplace operators; m * η is the pseudo-pressure; η is the pressure conductivity coefficient, m 2 / s;t l The time for mining or operation is measured in seconds (s).

[0022] Furthermore, in step one, the three-phase interaction model of the reservoir model in the involved model satisfies the following partial differential equation, namely, the gas-liquid-solid single-factor three-phase interaction relationship equation: To form an interaction model for a single porous medium;

[0023] in:

[0024] n is the number of factors; Y i The lithology of the tight carbonate reservoir is shown (i represents the parameter values ​​for calcite, dolomite, etc.); L i The parameters of the liquid phase in a tight carbonate reservoir are: (i represents the values ​​of various ion contents, pH, salinity, viscosity, density, etc.); Q i The values ​​represent the gas phase parameters (i represents the content of each component, including secondary components) of the tight carbonate reservoir; t l The time for mining or operation is measured in seconds (s).

[0025] Furthermore, in step one, the crack propagation model in the model involved should satisfy the following equation:

[0026] One is the equation relating fracture width to net pressure in tight carbonate rocks. This equation incorporates the medium coefficient, tightness factor, acid concentration, and gas phase, and can include secondary components. It considers both instantaneous and equivalent states.

[0027] w(r,t l )=∫G(S,r,z,D f ,L i C,Q i )σ p (t l dS instantaneous description

[0028] Equivalent description

[0029] in:

[0030] w(r,t l) is the slit width function, m; r is the position vector; t l For mining or operation time, s; G(S,r,z,D) f ) is an integral function reflecting reservoir properties and medium type; S is the medium surface area and m 2 z is the reservoir tightness factor (0.0-1.0); D f L is the dielectric constant (0.0-1.0); i Here are the liquid phase parameters of the tight carbonate reservoir (i represents the ion content, pH value, salinity, viscosity, density, etc.); C is the acid concentration, M; Q is the liquid phase parameters of the tight carbonate reservoir. i σ represents the gas phase parameters (i represents the content values ​​of each component, including secondary components) of the tight carbonate reservoir; p (t l Net pressure, MPa; symbols without an overline indicate instantaneous conditions, while symbols with an overline indicate equivalent conditions.

[0031] Simulation of crack width state changes over time, involving multiple factors and media.

[0032] Secondly, the intelligent relationship equation between fracture half-length / fracture height and lithological and property parameters in tight carbonate rocks introduces the interaction of gas, liquid / acid, and solid phases, which can contain secondary components and can be divided into two cases: instantaneous state and equivalent state.

[0033] Instantaneous description

[0034] Equivalent description

[0035] in:

[0036] L is the equivalent fracture half-length in tight carbonate rock, in meters; H is the equivalent fracture height in tight carbonate rock, in meters; r is the position vector; t l For mining or operation time, s; AI is the intelligent equation relating the fracture size (L, H) of tight carbonate rocks to reservoir lithology and properties; R i The properties of tight carbonate reservoirs are represented by i (i represents the values ​​of parameters such as porosity, permeability, and saturation); Y i The lithology of the tight carbonate reservoir is shown (i represents the parameter values ​​for calcite, dolomite, etc.); L i The parameters of the liquid phase in a tight carbonate reservoir are: (i represents the values ​​of various ion contents, pH, salinity, viscosity, density, etc.); Q i The gas phase parameters of the tight carbonate reservoir are (i represents the content values ​​of each component, including secondary components); C is the acid concentration, M; w is the equivalent fracture width of the tight carbonate rock, m; D dl For the equivalent acid-etched fracture conductivity of dense carbonate rocks, md.m; S jh / wris the equivalent geometric and / or contaminated skin coefficient; K is the equivalent matrix permeability of the tight carbonate reservoir, md, the symbol without the upper horizontal line is the instantaneous state, the symbol with the upper horizontal line is the equivalent state;

[0037] The simulation tracks and simulates the state of crack half-length / crack height, which varies with multiple factors and media and according to the development sequence.

[0038] Furthermore, in step two, multiple three-dimensional grid types are dynamically applied, a multi-dimensional system is adopted, advanced artificial intelligence algorithms are introduced, and interrelated patterns are established to form an overall simulation mechanism.

[0039] Furthermore, in step three, based on the multi-dimensional domain, effective algorithms are autonomously allocated, hierarchically optimized, and multi-point-centralized integrated to obtain the best calculation results from complex to simple, forming the optimal fitting result integrating geology and engineering, and obtaining parameters such as equivalent fracture parameters, equivalent acid etching conductivity, equivalent skin coefficient, equivalent permeability reservoir stimulation status, and reservoir stimulation degree.

[0040] The beneficial effects of this invention are as follows: After acid fracturing and testing in gas wells in tight carbonate reservoirs, the effects of acid fracturing are effectively evaluated, making the design of acid fracturing more reliable and targeted, achieving better test evaluation and application results, reflecting the status and degree of acid fracturing in tight carbonate reservoirs, and having high practicality. Detailed Implementation

[0041] The technical solution of the present invention will be clearly and completely described below. Obviously, the described embodiments are only some embodiments of the present invention, not all embodiments. Based on the embodiments of the present invention, all other embodiments obtained by those skilled in the art without creative effort are within the scope of protection of the present invention.

[0042] The present invention is described in detail below through specific embodiments, but this does not limit the scope of protection of the present invention. Unless otherwise specified, the experimental methods used in the present invention are all conventional methods, and the experimental equipment, materials, reagents, etc. used can all be obtained commercially.

[0043] Example 1

[0044] The technical approach to post-acid fracturing evaluation of tight carbonate rocks is as follows: A gas-liquid-solid interaction model and a three-phase interaction model for tight carbonate rocks are established. Advanced artificial intelligence algorithms are used to determine a multi-model correlation adaptive intelligent analysis and evaluation method after acid fracturing. This method simulates and determines the reservoir's stimulation status and degree, forming a suitable and effective technical approach for post-acid fracturing evaluation of tight carbonate rocks. This provides a means to understand and evaluate the stimulation effect of acid fracturing schemes for tight carbonate gas reservoirs.

[0045] Post-acid fracturing evaluation method for tight carbonate rocks: For acid-fracturing gas wells in tight carbonate rocks, within a multi-dimensional spatial domain, before the fracturing, attribute values ​​such as fractures, solutions / cavities, faults, reservoir lithology, tightness, original gas / liquid, porosity, permeability, and saturation are assigned to a certain area within the domain, and drilling and completion data are assigned to designated locations. Combining all production data from the start of acid fracturing after the fracturing, and based on the specific circumstances of acid fracturing injection data, downhole / wellhead pressure measurement data, and gas testing data, a multi-medium interaction model of gas, liquid, solids, and three phases in tight carbonate rocks is established. Advanced artificial intelligence algorithms are used to form an optimal trend fitting simulation mechanism for the correlation of each model. Autonomous intelligent simulation is performed to obtain parameters such as equivalent half-fracture length, equivalent fracture width, equivalent fracture height, equivalent acid etching conductivity, equivalent skin coefficient, and equivalent permeability after acid fracturing, which indicate the reservoir stimulation status and degree.

[0046] Example 2

[0047] (1) Based on the specific conditions of the target well, considering reservoir lithology, tightness, different media combination, primary gas / liquid, injected fluid, secondary gas / liquid, porosity, permeability, saturation and other properties, and combining various basic information and test information, a multi-media tight carbonate reservoir gas, liquid, solid and three-phase interaction model is formed: wellbore model, reservoir model and fracture propagation model.

[0048] Wellbore model: A wellbore model is established based on various performance parameters of the target well's casing and tubing string;

[0049] Reservoir Model: Based on the gas, liquid, and solid phase properties and corresponding descriptions of the target well reservoir, partial differential equations belonging to the following tight carbonate reservoir equations are formed;

[0050] Lithological relationship equation for dense carbonate rocks:

[0051] Liquid phase relationship equation for dense carbonate rocks:

[0052] Equation relating the properties of dense carbonate rocks:

[0053] Gas reservoir flow relationship equation:

[0054] Equation for the interaction relationship between gas, liquid, and solid phases:

[0055] in:

[0056] n is the number of factors; Y i The lithology of the tight carbonate reservoir is shown in Figures i (i represents the parameter values ​​for calcite, dolomite, and mudstone, respectively); r is the position vector; F is the external disturbance factor; tl For mining or operation time, s; L i The parameters of the liquid phase in the tight carbonate reservoir are: i = (ion content, pH value, salinity, viscosity, density, etc.); P = pressure, MPa; T = temperature, K; R = pressure. i The properties of tight carbonate reservoirs are represented by i, which are parameters such as porosity, permeability, and saturation. For Laplace operators; m * η is the pseudo-pressure; η is the pressure conductivity coefficient, m 2 / s;

[0057] Fracture propagation model: Based on the conservation of mass, energy, reaction criteria, and fracture propagation criteria of acid fracturing, fracture propagation equations and flow equations for the interaction of gas, liquid, and solid phases in tight carbonate reservoirs are established.

[0058] Local reaction relationship equation of acid rocks

[0059] Acid mass conservation equation

[0060] Acid fracturing energy balance equation

[0061] Crack propagation criterion T yl >T rx

[0062] in:

[0063] C represents the acid concentration, M; t l The extraction or action time is in seconds (s); D is the diffusion coefficient; S i Let m be the surface area of ​​the i-th medium. 2 V represents the reservoir unit volume, in meters. 3 ; y is the Laplace operator; u is the flow velocity, m / s; y is the distance from the crack perpendicular to the plane, m; q is the flow rate, m³ / s. 3 / s;C i M is the initial concentration of acid; δ is the Dirac function; T is the temperature (K); k H ρ is the thermal conductivity. ld For fluid density, kg / m³ 3 C p Specific heat capacity, J / (Kg·K); T yl Stress intensity factor, MPa.m 0.5 ;T rx The rock fracture toughness factor, MPa.m 0.5 .

[0064] The equation relating fracture width to net pressure in tight carbonate rocks incorporates a medium coefficient, tightness factor, acid concentration, and gas phase, and can include secondary components, with two scenarios: instantaneous state and equivalent state.

[0065] w(r,t l )=∫G(S,r,z,D f ,L i C,Q i )σ p (t l dS instantaneous description

[0066] Equivalent description

[0067] in:

[0068] w(r,t l ) is the slit width function, m; r is the position vector; t l For mining or operation time, s; G(S,r,z,D) f ) is an integral function reflecting reservoir properties and medium type; S is the medium surface area and m 2 z is the reservoir tightness factor (0.0-1.0); D f L is the dielectric constant (0.0-1.0); i Here are the liquid phase parameters of the tight carbonate reservoir (i represents the ion content, pH value, salinity, viscosity, density, etc.); C is the acid concentration, M; Q is the liquid phase parameters of the tight carbonate reservoir. i σ represents the gas phase parameters (i represents the content values ​​of each component, including secondary components) of the tight carbonate reservoir; p (t l Net pressure, MPa; symbols without an overline indicate instantaneous conditions, while symbols with an overline indicate equivalent conditions.

[0069] The intelligent equation relating the fracture half-length / fracture height in tight carbonate rocks to lithology, properties, and other parameters incorporates the interaction of gas, liquid / acid, and solid phases. It can contain secondary components and can be categorized into two states: instantaneous and equivalent.

[0070] Instantaneous description

[0071] Equivalent description

[0072] in:

[0073] L is the equivalent fracture half-length in tight carbonate rock, in meters; H is the equivalent fracture height in tight carbonate rock, in meters; r is the position vector; t l For mining or operation time, s; AI is the intelligent equation relating the fracture size (L, H) of tight carbonate rocks to reservoir lithology and properties; R iThe properties of tight carbonate reservoirs are represented by i (i represents the values ​​of parameters such as porosity, permeability, and saturation); Y i The lithology of the tight carbonate reservoir is shown (i represents the parameter values ​​for calcite, dolomite, etc.); L i The parameters of the liquid phase in a tight carbonate reservoir are: (i represents the values ​​of various ion contents, pH, salinity, viscosity, density, etc.); Q i The gas phase parameters of the tight carbonate reservoir are (i represents the content values ​​of each component, including secondary components); C is the acid concentration, M; w is the equivalent fracture width of the tight carbonate rock, m; D dl For the equivalent acid-etched fracture conductivity of dense carbonate rocks, md.m; S jh / wr is the equivalent geometric and / or contaminated skin coefficient; K is the equivalent matrix permeability of the tight carbonate reservoir, md, the symbol without the superscript is the instantaneous state, the symbol with the superscript is the equivalent state.

[0074] (2) Generate an overall simulation mechanism: Dynamically utilize multiple three-dimensional grid systems, adopt a multi-dimensional system, introduce advanced artificial intelligence algorithms, and build a multi-system interconnected model for each point in the simulated reservoir to form an overall simulation mechanism.

[0075] Mesh systems: tetrahedral mesh, hexahedral mesh, triangular prism mesh, pyramid mesh, and polyhedral mesh.

[0076] Multidimensional system: P n = f(x1,x2,x3,…,x) n-1 ,x n ), x1, x2, x3, ..., x n-1 ,x n Factor categories for the target reservoir.

[0077] Simulation mechanisms: Schemes employing point association mode, line association mode, local association mode, global association mode, and separate and overall smooth out-of-domain systems.

[0078] (3) Autonomous intelligent simulation: In the overall determined in-situ multidimensional spatial domain, an effective discretization method is selected, and an effective algorithm is automatically allocated through deep cognition and broad cognition from local to global. Hierarchical optimization is adopted, and the parameters within the domain are autonomously calculated using split inductive learning and deep domain learning networks. A multi-point domain self-analysis centralized integration mode is constructed, and the pruning approximates the best calculation results, forming the optimal fitting result integrating geology and engineering. The equivalent fracture parameters, equivalent acid corrosion conductivity, equivalent skin coefficient, equivalent permeability and other parameters of reservoir stimulation status and degree are obtained.

[0079] Taking a certain well as an example: Based on the wellbore models of casing, tubing, and perforation (from step (1)), a partial differential equation for the interaction model of tight carbonate rocks is established according to the gas (and / or secondary gas), liquid, solid, and three-phase characteristics of the tight carbonate reservoir, thus forming a reservoir model of the tight carbonate rock reservoir. Based on the interaction law between tight carbonate rocks and acid and the fracture propagation criterion, equations relating fracture size to corresponding parameters are established, forming a multi-factor controlled fracture propagation model.

[0080] According to step (2), using a series of grids such as tetrahedral grids, hexahedral grids, and triangular prism grids, adopting an 18-dimensional system, and using a progressive artificial intelligence recognition model, the simulated reservoir points are constructed into a four-system interconnected pattern of points, lines, local and overall, forming a separate and overall smooth out-of-domain system within the local and global ranges, generating an overall simulation mechanism.

[0081] According to step (3), within a sufficiently large multidimensional spatial domain of the reservoir, the numerical discretization method is intelligently selected to numerically discretize the space. Based on the spatial characteristics of the local area and the whole, effective algorithms are automatically allocated through two cognitive methods: depth and breadth. The system is hierarchically optimized and autonomously calculates parameters within the domain using two methods: induction and deep domain learning. A multi-point domain self-analysis and centralized integration mode is constructed. The system is autonomously and intelligently simulated and pruned to approximate the best calculation results, forming the optimal fitting result integrating geology and engineering: equivalent half-fracture length 35.52m, equivalent fracture width 4.6mm, equivalent fracture height 55m, equivalent acid erosion conductivity 1801.6md.m, equivalent permeability 595.10mD, and equivalent skin coefficient -1.69. The effect of acid fracturing was recognized and evaluated. After acid fracturing, a high-yield result of 245,000 cubic meters per day was obtained during gas testing, achieving the purpose of acid fracturing.

[0082] The embodiments described above are merely preferred embodiments of the present invention, and not all feasible embodiments of the present invention. For those skilled in the art, any obvious modifications made without departing from the principles and spirit of the present invention should be considered to be included within the scope of protection of the claims. Although the present invention has been described above with reference to embodiments, various modifications can be made and components can be replaced with equivalents without departing from the scope of the present invention. In particular, as long as there is no technical conflict, the features in the embodiments disclosed in the present invention can be combined with each other in any way. The lack of an exhaustive description of these combinations in this specification is merely for the sake of brevity and resource conservation. Therefore, the present invention is not limited to the specific embodiments disclosed herein, but includes all technical solutions falling within the scope of the claims.

Claims

1. A method for post-acid fracturing evaluation of tight carbonate rocks, characterized in that, Includes the following steps: Step 1: Establish a correlation model of the multi-factor interactions of gas, liquid, solid phases and three phases in tight carbonate reservoirs; Step 2: Generate the overall simulation mechanism; Step 3: Autonomous Intelligent Simulation.

2. The method for post-fracturing evaluation of tight carbonate rocks according to claim 1, characterized in that, In step one, the wellbore model involved includes the dimensions, material type, depth, and mechanical properties of the casing string, forming a hidden or explicit structural package.

3. The method for post-fracturing evaluation of tight carbonate rocks according to claim 1, characterized in that, In step one, the lithology of the reservoir model in the model satisfies the following partial differential equation, namely the lithological relationship equation of tight carbonate rocks: A model for the residence of changing lithological states is formed; in: n is the number of factors; Y i The lithology of the tight carbonate reservoir is shown in Figures i (i represents the parameter values ​​for calcite, dolomite, and mudstone, respectively); r is the position vector; F is the external disturbance factor; t l The time for extraction or operation is measured in seconds (s).

4. The method for post-fracturing evaluation of tight carbonate rocks according to claim 1, characterized in that, In step one, the liquid phase of the reservoir model in the aforementioned model satisfies the following partial differential equation, namely, the liquid phase relationship equation for tight carbonate rocks: Forming a hidden structure package that can exist in a changing liquid phase state; in: n is the number of factors; L i Here are the liquid phase parameters of the tight carbonate reservoir (i represents the values ​​of various ion contents, pH, salinity, viscosity, density, etc.); r is the position vector; P is the pressure (MPa); T is the temperature (K); F is the external disturbance factor; t l The time for extraction or operation is measured in seconds (s).

5. The method for post-fracturing evaluation of tight carbonate rocks according to claim 1, characterized in that, In step one, the reservoir model properties satisfy the following partial differential equation, namely the tight carbonate rock property relationship equation: An implicitly structured package that forms changing attribute states and can reside therein; in: n is the number of factors; R i The reservoir properties are: tight carbonate reservoir (i represents porosity, permeability, saturation, etc.); r is the position vector; P is the pressure (MPa); T is the temperature (K); F is the external disturbance factor; t l The time for extraction or operation is measured in seconds (s).

6. The method for post-fracturing evaluation of tight carbonate rocks according to claim 1, characterized in that, In step one, the gas phase of the reservoir model in the aforementioned model satisfies the following partial differential equation, namely the gas reservoir flow relationship equation: Forming a hidden structure package that exists in a changing gaseous state and can reside there; in: For Laplace operators; m * η is the pseudo-pressure; η is the pressure conductivity coefficient, m 2 / s;t l The time for extraction or operation is measured in seconds (s).

7. The method for post-fracturing evaluation of tight carbonate rocks according to claim 1, characterized in that, In step one, the three-phase interaction model of the reservoir model in the involved model satisfies the following partial differential equation, namely, the gas-liquid-solid single-factor three-phase interaction relationship equation: To form an interaction model for a single porous medium; in: n is the number of factors; Y i The lithology of the tight carbonate reservoir is shown (i represents the parameter values ​​for calcite, dolomite, etc.); L i The parameters of the liquid phase in a tight carbonate reservoir are: (i represents the values ​​of various ion contents, pH, salinity, viscosity, density, etc.); Q i The values ​​represent the gas phase parameters (i represents the content of each component, including secondary components) of the tight carbonate reservoir; t l The time for extraction or operation is measured in seconds (s).

8. The method for post-fracturing evaluation of tight carbonate rocks according to claim 1, characterized in that, In step one, the crack propagation model in the model involved should satisfy the following equation: One approach is to introduce the medium coefficient, tightness factor, acid concentration, and gas phase into the equation relating fracture width and net pressure in tight carbonate rocks. This equation can include secondary components and can be divided into two scenarios: instantaneous state and equivalent state. w(r,t l )=∫G(S,r,z,D f ,L i C,Q i )σ p (t l dS instantaneous description Equivalent description in: w(r,t l ) is the slit width function, m; r is the position vector; t l For mining or operation time, s; G(S,r,z,D) f ) is an integral function reflecting reservoir properties and medium type; S is the medium surface area and m 2 z is the reservoir tightness factor (0.0-1.0); D f L is the dielectric constant (0.0-1.0); i Here are the liquid phase parameters of the tight carbonate reservoir (i represents the ion content, pH value, salinity, viscosity, density, etc.); C is the acid concentration, M; Q is the liquid phase parameters of the tight carbonate reservoir. i σ represents the gas phase parameters (i represents the content values ​​of each component, including secondary components) of the tight carbonate reservoir; p (t l Net pressure, MPa; symbols without an overline indicate instantaneous conditions, while symbols with an overline indicate equivalent conditions. Simulation of crack width state changes over time, involving multiple factors and media. Secondly, the intelligent relationship equation between fracture half-length / fracture height and lithological and property parameters in tight carbonate rocks introduces the interaction of gas, liquid / acid, and solid phases, which can contain secondary components and can be divided into two cases: instantaneous state and equivalent state. Instantaneous description Equivalent description in: L is the equivalent fracture half-length in tight carbonate rock, in meters; H is the equivalent fracture height in tight carbonate rock, in meters; r is the position vector; t l For mining or operation time, s; AI is the intelligent equation relating the fracture size (L, H) of tight carbonate rocks to reservoir lithology and properties; R i The properties of tight carbonate reservoirs are represented by i (i represents the values ​​of parameters such as porosity, permeability, and saturation); Y i The lithology of the tight carbonate reservoir is shown (i represents the parameter values ​​for calcite, dolomite, etc.); L i The parameters of the liquid phase in a tight carbonate reservoir are: (i represents the values ​​of various ion contents, pH, salinity, viscosity, density, etc.); Q i The gas phase parameters of the tight carbonate reservoir are (i represents the content values ​​of each component, including secondary components); C is the acid concentration, M; w is the equivalent fracture width of the tight carbonate rock, m; D dl For the equivalent acid-etched fracture conductivity of dense carbonate rocks, md.m; S jh / wr is the equivalent geometric and / or contaminated skin coefficient; K is the equivalent matrix permeability of the tight carbonate reservoir, md, the symbol without the upper horizontal line is the instantaneous state, the symbol with the upper horizontal line is the equivalent state; The simulation tracks and simulates the state of crack half-length / crack height, which varies with multiple factors and media and according to the development sequence.

9. The method for post-fracturing evaluation of tight carbonate rocks according to claim 1, characterized in that, Step two involves dynamically utilizing various three-dimensional mesh types, adopting a multi-dimensional system, introducing advanced artificial intelligence algorithms, establishing interconnected patterns, and forming an overall simulation mechanism.

10. The method for post-fracturing evaluation of tight carbonate rocks according to claim 1, characterized in that, Step three involves autonomously allocating effective algorithms within a multi-dimensional domain, performing hierarchical optimization, and integrating multiple points into a centralized manner to obtain the best calculation results from complex to simple, forming an optimal fitting result that integrates geology and engineering, and obtaining parameters such as equivalent fracture parameters, equivalent acid etching conductivity, equivalent skin coefficient, equivalent permeability reservoir stimulation status, and reservoir stimulation degree.

Images