CN107290506B - A kind of method of quantitative assessment reservoir diagenetic evolutionary process porosity Spatio-temporal Evolution - Google Patents

Abstract

The invention provides a method for quantitatively evaluating the temporal and spatial evolution of porosity in the diagenetic evolution process of reservoirs. Including: determining the diagenetic sequence and porosity change trend of the reservoir, identifying the main diagenetic events experienced by the reservoir, and establishing the diagenetic evolution process; simulating the diagenetic evolution process in stages, determining the diagenetic evolution process, diagenetic period and diagenetic conditions; The laboratory experiment of diagenesis, testing the fluid composition, rock sample composition and pore structure before and after the experiment in each diagenetic period; completely corresponding to the experiment, carried out numerical simulation of diagenesis in different diagenetic periods, and corrected the mineral dynamics calculation parameters and specific surface area in the simulation; Extend the numerical simulation time to the actual diagenesis time of the reservoir, correct the model parameters again, and establish a quantitative simulation system for the evolution of porosity with time; simulate the evolution process of the reservoir on a regional scale, and establish a quantitative simulation system for the evolution of porosity with time and space, Realize the quantitative evaluation and prediction of porosity in space and time.

Description

A method for quantitatively evaluating the spatio-temporal evolution of porosity during reservoir diagenetic evolution

technical field

The invention relates to the field of petroleum exploration, in particular, the invention relates to a method for quantitatively evaluating the temporal and spatial evolution of porosity in the diagenetic evolution process of reservoirs.

Background technique

Oil and gas resources have increasingly become strategic resources closely related to national economy, social development and national security. Whether it is traditional conventional oil and gas with relatively mature technology or emerging unconventional resources such as shale gas and coalbed methane with great potential, they all occur in pores or fractures of reservoir rocks. If it is to be exploited effectively, the law of oil and gas accumulation must be clarified, and the physical properties such as porosity and permeability of the reservoir must be correctly evaluated.

The distribution and physical properties of oil and gas resources are mainly affected and controlled by sedimentation and diagenesis: ①Sedimentation refers to the process of sedimentation and accumulation due to changes in conditions after the material transported by the moving medium reaches a suitable place. The effect is an "innate" factor affecting the quality of the reservoir, which determines the spatial distribution and original physical properties of the reservoir; ②Diagenesis refers to the whole process from sediment deposition to rock consolidation. During the burial process, the sediment experienced different types and different intensities of diagenesis, which played an extremely important role in the formation, preservation, destruction of reservoir pores and the physical properties of the reservoir. Therefore, diagenesis is an "acquired" factor that affects the quality of the reservoir, and determines the final physical properties of the reservoir. The properties such as porosity and permeability of the current reservoir are the result of its transformation by diagenesis.

The diagenetic process is extremely complex. According to typical diagenetic events, it can be divided into several consecutive periods. Each period corresponds to different burial depth, temperature, pressure and other conditions. At the same time, there are tectonic movements, external fluid intrusion, source rocks, etc. Influenced by various factors such as generation, it also shows the characteristics of heterogeneity in space. The main diagenetic processes in the reservoir include compaction, cementation, metasomatism, crystallization, leaching, hydration, and biochemical processes. The entire diagenetic process basically takes place in an environment with water. During the long diagenetic process, a series of physical and chemical reactions will inevitably occur in the long-term contact between the complex underground aqueous solution and the surrounding rock minerals, resulting in the dissolution or precipitation of minerals, triggering Reservoir porosity changes. Therefore, it is urgent to clarify the influence of physical and chemical effects on the porosity in the reservoir under different diagenetic conditions, that is, to restore the spatiotemporal evolution of porosity in the diagenetic process, so as to accurately evaluate favorable reservoirs. The distribution of oil and gas can be used to find out the direction for oil and gas exploration and improve the production efficiency.

Regarding the study of porosity in the diagenetic process, on the one hand, the current technical scheme is based on geological data such as well points, and through theoretical analysis, petrological tests, and physical simulations, to simulate the history of sedimentary filling, burial, and heat source evolution to restore calcium The history of cementation, siliceous cementation, clay mineral cementation, feldspar mineral dissolution, etc., determine the typical diagenesis, strength and reservoir porosity changes in different periods, and determine the original pores of the reservoir based on petrological tests and other methods The increase and decrease of retained and secondary pores belong to qualitative or semi-quantitative analysis, and what is obtained is the overall curve of porosity. There is no quantitative analysis and evaluation of the evolution with time, and it cannot accurately provide a certain time or period during the diagenetic process. The specific value of porosity in a certain area.

On the other hand, there are currently a small number of literatures that study diagenesis based on geochemical theories, and use thermodynamic calculations or numerical simulation methods to evaluate the transformation of porosity by a certain diagenesis, but these studies are all limited to a single typical diagenesis, such as the Baiyun Petrification and illite petrification belong to the study of mechanism, and cannot predict the change of porosity in the actual diagenesis process. However, the actual diagenesis includes multiple diagenesis, and the process is extremely complicated. At present, there is no technical solution that can quantitatively evaluate and predict the temporal and spatial evolution of reservoir porosity during diagenesis based on comprehensive knowledge of geology, geochemistry, and computers.

Contents of the invention

The purpose of the present invention is to provide a method for quantitatively evaluating the temporal and spatial evolution of porosity in the diagenetic evolution of reservoirs; the method can accurately replicate the diagenetic evolution of reservoirs and quantitatively restore the porosity by means of combining experiments and numerical simulations evolution curve over time.

The present invention combines systematic experiments with numerical simulation techniques to establish a simulation system for the temporal and spatial evolution of porosity in the diagenetic evolution process, thereby clarifying the evolution law of reservoir porosity in the long and complex diagenetic evolution process of the reservoir, and quantitatively evaluating the reservoir porosity The evolution trend of degree over time and the distribution characteristics in space reveal the formation mechanism and spatial distribution characteristics of favorable reservoirs. This technology will point out the direction for the exploration of oil and gas resources and improve the efficiency of oil and gas recovery.

This technical solution is based on qualitative data such as petrological test and analysis, and fully utilizes geochemical numerical simulation technology to realize quantitative evaluation of porosity evolution with time and space.

In order to achieve the above object, on the one hand, the present invention provides a method for quantitatively evaluating the temporal and spatial evolution of porosity in the process of reservoir diagenetic evolution, said method comprising the following steps:

(1) Determine the diagenetic sequence and porosity change trend of the reservoir, identify the diagenetic events experienced by the reservoir, select the diagenetic events that affect the porosity (such as organic acid charging, carbon dioxide intrusion, abnormal high temperature and high pressure, etc.), delineate Multiple typical and continuous diagenetic periods (each diagenetic period has many possible diagenetic conditions, such as the rate and amount of organic acid charging, etc.), and establish one or more possible diagenetic evolution processes;

(2) Simulate the diagenetic evolution process inferred in step (1), compare the simulation results of each diagenetic evolution process with the actual diagenetic sequence and porosity change trend of the reservoir, and select the one whose simulation results are consistent with the actual data Diagenetic evolution process, then determine the diagenetic evolution process, diagenetic period and diagenetic conditions of each diagenetic period experienced by the reservoir;

(3) According to the diagenetic evolution process, diagenetic period and diagenetic conditions of each diagenetic period determined in step (2), carry out laboratory experiments of high temperature and high pressure diagenesis in different diagenetic periods, and test the fluid composition and rock composition before and after the experiment in each diagenetic period. Sample composition and pore structure;

(4) The experimental conditions in step (3) are exactly the same, and the numerical simulation of diagenesis in different diagenetic periods is carried out, the simulation results of each diagenetic period are compared with the experimental results, and the mineral dynamics calculation parameters and specific surface area in the simulation are corrected ;

(5) Extend the simulation time (5-8 days) of each diagenetic period in steps (3) and (4) to the actual diagenetic time scale of the reservoir (hundreds of thousands to millions of years), based on the (4) Perform numerical simulation of the actual diagenetic evolution process (millions of years) with the corrected simulation parameters, compare the simulation results with the reservoir diagenetic sequence and porosity change trend in step (1), and calibrate the model again parameters to establish a quantitative simulation system of porosity evolution with time;

(6) Based on the regional geological and diagenetic data, use the established quantitative simulation system of porosity evolution over time to construct a three-dimensional model to simulate the evolution process of the reservoir on the regional scale, compare with the actual data, and finally establish the porosity The quantitative simulation system of temporal and spatial evolution can realize the quantitative evaluation and prediction of porosity in space and time.

According to some specific embodiments of the present invention, wherein, step (1) is based on petrology and geochemistry, combined with rock sample thin section identification, rock sample X-ray diffraction data, fluid inclusions and maturity analysis tests, to determine the diagenetic sequence of the reservoir and porosity change trends, identify the main diagenesis experienced by the reservoir, divide typical and continuous diagenetic periods, and establish the diagenetic evolution process.

According to some specific embodiments of the present invention, wherein, step (1) is to clarify the provenance conditions and thermal evolution history of the reservoir through indoor petrological test analysis, fluid inclusion test, and isotope test, based on mineral transformation relationships and different diagenetic times According to the test data of the nodes, the diagenetic sequence and porosity change trend of the reservoir are determined, the diagenetic evolution process of the reservoir is inferred, and each possible diagenetic evolution process is generalized into several consecutive diagenetic evolution processes according to the degree of influence on the porosity. period.

According to some specific embodiments of the present invention, the step (1) is to generalize each possible diagenetic evolution process into 4-6 consecutive periods according to the degree of influence on porosity.

According to some specific embodiments of the present invention, step (1) is to delineate 4-6 typical and continuous diagenetic periods.

According to some specific embodiments of the present invention, step (1) is to establish 3-5 possible diagenetic evolution processes.

According to some specific embodiments of the present invention, the step (2) uses simulation software to simulate the diagenetic evolution process estimated in the step (1) step by step.

According to some specific embodiments of the present invention, wherein the simulation software in step (2) is multiphase flow reaction solute migration simulation software.

The multiphase flow reaction solute migration simulation software can be conventional corresponding software currently available on the market, such as TOUGHREACT, TOUCHSTONE and the like.

According to some specific embodiments of the present invention, wherein the simulation results of step (2) include one or more of rock mineral composition, mineral precipitation/dissolution tendency, and porosity.

According to some specific embodiments of the present invention, wherein, step (3) is to use the indoor diagenesis physical simulation experiment device to carry out high temperature and high pressure reaction experiments in different diagenetic periods, and test the fluid composition, rock sample composition and pore structure before and after the experiment in each period .

According to some specific embodiments of the present invention, wherein, the experimental time of each period of step (3) is 5-8 days, a total of 20-48 days.

According to some specific embodiments of the present invention, wherein, step (3) is to measure the pH value of the fluid and the concentration of typical ions in the fluid.

According to some specific embodiments of the present invention, wherein the typical ions in step (3) include K ⁺ , Ca ²⁺ , Na ⁺ , Mg ^{2 +} , Al ³⁺ , Fe (including all valence states), Cl ^- , Si ( A combination of one or more of total Si measurement) and SO ₄ ^2- .

It can be understood that, in this field, the determination of the concentration of Fe refers to the total amount of iron ions in each valence state; the determination of the concentration of Si refers to the determination of the total Si in the aqueous solution.

According to some specific embodiments of the present invention, wherein, step (3) testing rock sample composition includes carrying out following test to rock sample: 1. X-ray diffraction and spectral analysis; 2. scanning electron microscope and thin section identification; 3. casting thin section; .

According to some specific embodiments of the present invention, wherein, step (4) is based on the conditions of the indoor experiment in step (3), numerical simulations of different diagenetic periods are carried out, the simulation results are compared with the experimental results, and the simulation parameters are corrected.

According to some specific embodiments of the present invention, wherein, step (4) carries out the numerical simulation of diagenesis of different diagenetic periods, and the temperature, pressure, and time of each diagenetic period are all consistent with the conditions of corresponding diagenetic periods in step (3), and The simulation results of each diagenetic period were compared with the experimental results, and the mineral dynamics calculation parameters and specific surface area in the simulation were corrected.

According to some specific embodiments of the present invention, the simulation results of step (4) include the relative content of each mineral, the concentration of each ion and the porosity.

In summary, the present invention provides a method for quantitatively evaluating the spatiotemporal evolution of porosity during the diagenetic evolution of reservoirs. Method of the present invention has following advantage:

(1) Most previous studies on diagenesis were based on petrological testing and analysis methods, qualitatively or semi-quantitatively studying diagenetic sequences and porosity evolution. However, geochemical action plays a huge role in the diagenesis process, especially has a direct impact on reservoir porosity, and can even be said to determine the evolution process of porosity, so it is used to calculate the thermodynamics and dynamics of geochemical action Theory is extremely important. The present invention applies the geochemical numerical simulation technology to the study of the diagenetic process, and combines thermodynamic calculations, laboratory experiments, petrological test analysis and natural analogy to verify each other, not only restores the porosity evolution curve with time, but also combines the regional Geological and diagenetic characteristics within the scope, evaluate and predict the temporal and spatial evolution characteristics of porosity within the regional scope, study the evolution characteristics of porosity during diagenesis from two aspects of time domain and space domain, and thoroughly realize the evaluation and prediction of porosity during diagenesis Quantification of , there is no such research at home and abroad.

(2) The diagenetic process is extremely complex, and it is composed of multiple stages and multiple sub-processes. They influence each other and are closely related. In the past, the research on the geochemical numerical simulation of diagenesis was often limited to a single diagenesis, such as the Baiyun Petrochemical, Yili petrochemical, etc. This technical solution comprehensively considers the characteristics of porosity evolution under the joint influence of all diagenesis, which is consistent with the diagenetic process of the actual reservoir, and can provide more direct and valuable information for oil and gas exploration.

(3) The technical solution of the present invention is the first comprehensive study of various complex diagenesis using comprehensive geochemical theories, which is consistent with actual diagenesis.

(4) The technical solution of the present invention, after the preliminary generalization (the first step), increases the numerical simulation work, that is, repeatedly corrects by numerical simulation means before the indoor experiment, and determines the diagenetic process, diagenetic period and diagenetic conditions, so The indoor test is carried out again, and the success rate is extremely high. This step is critical and greatly increases the success rate of this technical solution.

Description of drawings

Fig. 1 is the process flowchart of embodiment 1;

Fig. 2 is the schematic diagram of water-rock interaction model in the diagenetic evolution process of embodiment 1;

Fig. 3 is the comparison of embodiment 1 simulation result and experimental data;

Fig. 4 is the schematic diagram of the evolution of porosity with geological time in Example 1;

Fig. 5 is a schematic diagram of spatial heterogeneity distribution of porosity and typical minerals in Example 1.

Detailed ways

The implementation process and beneficial effects of the present invention are described in detail below through specific examples, aiming to help readers better understand the essence and characteristics of the present invention, and not as a limitation to the scope of implementation of this case.

Example 1

Research Background

The northern Ordos gas field has huge oil and gas resources, and the Shihezi Formation is the main gas-producing layer. After a long and complicated geological evolution, the Shihezi Formation reservoir has undergone a series of intense diagenesis. The current average porosity is only 0.06, and the average permeability is only 1mD. It is a tight sandstone reservoir with low porosity and low permeability. The transformation of the reservoir makes the reservoir have strong heterogeneity, which leads to the problem of "low permeability, low pressure, low production and low abundance" in the exploitation of tight sandstone gas. At present, the formation mechanism of tight sandstone reservoirs in the Shihezi Formation is controversial, and the time and process of reservoir compaction are still uncertain, that is, the evolution process of porosity is unclear, resulting in low efficiency of tight sandstone gas recovery. The technique of the invention can quantitatively evaluate the evolution of porosity with time and space in the process of diagenetic evolution, clarify the mechanism of reservoir densification, and provide guidance for the exploitation of tight sandstone gas. The specific process is as follows:

1) Through a series of indoor petrological test analysis, fluid inclusion test, isotope test, etc., the diagenetic sequence and porosity change trend of Shihezi Formation reservoirs are clarified. There are four possibilities for the diagenetic evolution process of Shihezi Formation reservoirs. According to the influence degree of geochemical action on porosity, each possible diagenetic evolution process can be generalized into six consecutive typical periods (as shown in Fig. 1):

①Compaction→early shallow burial diagenesis→abnormal high temperature and high pressure→CO ₂ charging→organic acid charging→late deep burial diagenesis;

②Compaction→early shallow burial diagenesis→CO ₂ charging→abnormal high temperature and high pressure→organic acid charging→late deep burial diagenesis;

③Compaction→early shallow burial diagenesis→organic acid charging→abnormal high temperature and high pressure→CO ₂ charging→late deep burial diagenesis;

④Compaction→early shallow burial diagenesis→abnormal high temperature and high pressure→organic acid charging→CO ₂ charging→late deep burial diagenesis;

At the same time, there are many possibilities for the diagenetic conditions of each diagenetic period, such as organic acids, CO ₂ charging rate, charging amount, and charging time.

2) Using the multiphase flow reaction solute migration simulation software TOUGHREACT to simulate the four diagenetic evolution processes speculated above, each diagenetic evolution process is divided into 6 periods of simulation, and each period corresponds to a variety of diagenetic conditions (organic acid, CO ₂ charging rate, charging amount and charging time). Comparing various simulation results with the diagenetic sequence and porosity change trend of the reservoir, the main geochemical reactions experienced by the Shihezi Formation reservoir are determined, and the mineral transformation relationship is shown in equations (1)-(4). After the Shihezi Formation reservoir experienced initial compaction and early diagenetic burial, accompanied by oil and gas charging, it experienced a large amount of CO ₂ intrusion, which greatly changed the porosity. The second charging of oil and gas, the injection of organic acids, and finally experienced the late deep burial diagenetic evolution process. In short, through the numerical simulation work in this step, it is known that the diagenetic evolution process experienced by the Shihezi Formation reservoir is consistent with the second possibility speculated in step 1), while the simulation results of the other three possible diagenetic evolution processes are all consistent with the diagenetic evolution process in step 1). 1) The trends shown in the measured data are inconsistent. At the same time, through numerical simulation work, the diagenetic conditions such as temperature and pressure of each diagenetic stage are determined.

CaCO ₃ (calcite)+H ⁺ →Ca ²⁺ +HCO ₃ ^-

Feldspar minerals+H ₂ O+H ⁺ →(K ⁺ ,Na ⁺ ,Ca ²⁺ )+SiO ₂ +kaolinite

Kaolinite+K ⁺ → illite+H ₂ O+H ⁺

Smectite + K ⁺ +Al ³⁺ → illite + Na ⁺ +Ca ²⁺ +Fe ³⁺ +Mg ²⁺ +Si ⁴⁺

3) In the laboratory, the high-temperature and high-pressure reaction experiments of the six diagenetic periods were carried out with the experimental device of the diagenetic simulation system. The first period was 8 days, and the other periods were 6 days. Among them, the initial rock sample composition and fluid concentration are inversely deduced based on the petrological test results in the study area in step 1. Table 1 and Table 2 are the initial rock sample composition and fluid concentration during diagenetic evolution, respectively. The main parameters such as temperature and pressure in each stage of the experiment are taken from Step 2, as shown in Table 3.

Table 1 The relative content of each mineral in the initial rock sample preparation

The concentration of each fluid in the experiment of table 2 (mg/L)

Table 3 Experimental conditions in each stage of diagenetic evolution

Collect rock samples and water samples after the reaction of each diagenetic period, cool the water samples to room temperature, filter, measure the pH value and typical ions in the solution (K ⁺ , Ca ²⁺ , Na ⁺ , Mg ²⁺ , Al ³⁺ , Fe, Cl ^- , Si and SO ₄ ^2- ); the following tests were carried out on the rock samples: ① X-ray diffraction (XRD) and spectroscopic analysis (XRF) to test the mineral and element contents in the rock samples. ② Scanning electron microscope (SEM) and thin section identification to observe the dissolution or precipitation characteristics of minerals on the rock surface. ③Cast thin section, measure and calculate the surface porosity of the rock sample. ④ X-ray micro-CT scans the pore structure and face features of rock samples.

4) Based on the conditions of the laboratory experiment, the numerical simulation of the diagenetic evolution process (including different diagenetic periods) is carried out. The schematic diagram of the model is shown in Figure 2. The simulation results are compared with the experimental results, as shown in Figure 3, and the simulated mineral dynamics is corrected. Calculate parameters and specific surface area.

5) Extend the simulation time of each diagenetic period, and simulate the diagenetic evolution process of the actual diagenetic time scale of the reservoir, a total of 280 million years. The simulation results were compared with the measured data, the model parameters were corrected, and a quantitative simulation system of porosity evolution with time was established. The evolution curve of porosity is shown in Fig. 4. After compaction, the porosity decreased from 30% at the initial stage to 15%. The porosity remained basically unchanged during the early diagenetic period. With the charging of _CO2 gas, minerals were dissolved, The porosity increases, but after the injection is stopped, and the temperature and pressure increase, a large amount of carbonate rocks are precipitated, the porosity drops sharply below 10%, and the reservoir becomes tight, that is, with the first oil and gas charging, The intrusion of CO ₂ gas played a key role in the densification of the reservoir, and the late organic acid charging and accumulation had little effect on the porosity.

6) Based on the provenance and diagenetic data in the study area, a three-dimensional model was constructed to simulate the diagenetic evolution process of the reservoir on the regional scale. The simulation results are shown in Figure 5. The results show that the simulated results are consistent with the measured data in the area, and they all show that the overall dissolution of feldspar minerals is dominated by the transformation into illite, and the formation of anodolomite and dawsonite precipitation. However, the heterogeneity of initial minerals, porosity and permeability lead to regional heterogeneity of diagenesis, resulting in heterogeneity of final porosity, and different degrees of densification of the reservoir. From the simulated spatial distribution of porosity, favorable reservoirs can be evaluated.

The technical scheme of the present invention combines a series of experiments and simulations, and proposes a complete, scientific, and systematic method for evaluating porosity, which can establish a quantitative simulation system for porosity evolution over time and space, and not only restores porosity in the long process of diagenetic evolution The evolution curve of porosity can be realized, and the quantitative evaluation and prediction of porosity in space can be realized, which can not only find out the densification mechanism of the reservoir, but also point out the direction for the exploration of oil and gas and other resources, and improve the production efficiency.

Claims (12)

1. a kind of method of quantitative assessment reservoir diagenetic evolutionary process porosity Spatio-temporal Evolution, wherein, the described method includes such as Lower step：

(1) Diagenetic Sequence and porosity variation tendency of reservoir are determined, the diagenesis event of identification reservoir experience, chooses to porosity Influential diagenesis event, delimit multiple typical, continuous diagenesis periods, establishes a variety of possible diagenesis evolution processes；Step Suddenly (1) is to be based on petrology and geochemistry, with reference to rock sample thin section identification, rock sample X ray diffracting data, fluid inclusion and into Ripe degree analysis test, determines reservoir diagenetic sequence and porosity variation tendency, the authigenetic clay rim of identification reservoir experience, delimited Typically, in continuous diagenesis period, diagenesis evolutionary process is established；And pass through indoor petrology test analysis, fluid inclusion Test, isotope test, specify the material resource condition and thermal evolution history of reservoir, based on Mineral Transformation relation and different rock-forming time sections The test data of point, determines the Diagenetic Sequence and porosity variation tendency of reservoir, thus it is speculated that the diagenesis evolution process of reservoir, and according to To the influence degree of porosity, every kind of possible diagenesis evolution process is generalized as continuous several diagenesis periods；

(2) the diagenesis evolution process speculated respectively in simulation steps (1), by the analog result and reservoir of each diagenesis evolution process Actual Diagenetic Sequence and porosity variation tendency is contrasted, and selects the analog result therein diagenesis consistent with real data Evolutionary process, it is determined that the diagenesis condition in diagenesis evolution process, diagenesis period and each diagenesis period that reservoir is undergone；

(3) according to the diagenesis condition of identified diagenesis evolution process, diagenesis period and each diagenesis period in step (2), open The high temperature and pressure diagenesis laboratory experiment in different diagenesis periods is opened up, tests the front and rear fluid composition of each diagenesis period experiment, rock Stone sample composition and pore structure；Step (3) is to use indoor diagenesis physical simulation experiment device, carries out different diagenesis periods High-temperature high-voltage reaction experiment, test the experiment of each period front and rear fluid composition, rock sample component and pore structure；Each Period experimental period is 5-8 days, common 20-48 days；

(4) it is completely the same with the experiment condition in step (3), the diagenesis numerical simulation in different diagenesis periods is carried out, will be every The analog result in a diagenesis period is contrasted with experimental result, and correction simulates Minerals dynamics calculation parameter and compares surface Product；

(5) simulated time in each diagenesis period in step (3), (4) is extended to the actual rock-forming time scale of reservoir, base The corrected analog parameter in step (4), carries out the numerical simulation of actual diagenesis evolution process, by analog result and step (1) Diagenetic Sequence of reservoir and porosity variation tendency are contrasted in, again calibration model parameter, establish porosity with the time The quantitative simulation system of differentiation；

(6) based on the geology in regional extent and diagenesis data, the quantitative simulation system with established porosity with time-evolution System, builds threedimensional model, and the evolutionary process of reservoir in simulated domain scope, contrasts with real data, finally establish porosity with The quantitative simulation system of Spatio-temporal Evolution, realizes porosity spatially with the quantitative evaluation and prediction of time.

2. according to the method described in claim 1, wherein, step (1) is to delimit 4-6 typical, continuous diagenesis periods.

3. according to the method described in claim 1, wherein, step (1) is to establish the possible diagenesis evolution process of 3-5 kinds.

4. according to the method described in claim 1, wherein, step (1), will be every kind of possible according to the influence degree to porosity Diagenesis evolution process is generalized as continuous 4-6 diagenesis period.

5. according to the method described in claim 1, wherein, step (2) is to use simulation softward, institute in simulation by periods step (1) The diagenesis evolution process of supposition.

6. according to the method described in claim 5, wherein, step (2) described simulation softward is multiphase flow reactive solute migration mould Intend software.

7. according to the method described in claim 1, wherein, step (3), which tests the front and rear fluid composition of each diagenesis period experiment, is Measure the concentration of exemplary ion in fluid pH value and fluid.

8. according to the method described in claim 7, wherein, the exemplary ion includes K⁺、Ca²⁺、Na⁺、Mg²⁺、Al³⁺、Fe、Cl^-、 Si and SO₄ ^2-In one or more combinations；Wherein the concentration mensuration of Fe refers to the iron ion total amount of each valence state；The concentration of Si Measure refers to the measure of full Si in aqueous solution.

9. according to the method described in claim 1, wherein, step (3) test rock sample component include having carried out rock sample with Lower test：1. X-ray diffraction and spectrum analysis；2. scanning electron microscope and thin section identification；3. casting body flake；4. X-ray micron CT.

10. according to the method described in claim 1, wherein, step (4) is to be based on the condition of laboratory experiment in step (3), is carried out The numerical simulation in different diagenesis periods, analog result and experimental result are contrasted, and correct analog parameter.

11. according to the method described in claim 1, wherein, step (4) carries out the diagenesis Numerical-Mode in different diagenesis periods Intend, the temperature in each diagenesis period, pressure, diagenesis period corresponding with step (3) time it is consistent, will each into The analog result in rock period is contrasted with experimental result, correction simulation Minerals dynamics calculation parameter and specific surface area.

12. according to the method described in claim 1, wherein, the analog result of step (4) includes the relative amount of each mineral, each The concentration and porosity of ion.