CN117991351A - Method and device for determining pressure coefficient - Google Patents
Method and device for determining pressure coefficient Download PDFInfo
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- G01V1/00—Seismology; Seismic or acoustic prospecting or detecting
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Abstract
The application discloses a method and a device for determining a pressure coefficient. The method comprises the following steps: determining a relationship between effective stress and longitudinal wave velocity and shale content of the target zone based on the drilling data and logging data; determining longitudinal wave inversion speed, transverse wave inversion speed and lithologic probability body of a target area through prestack deterministic inversion and prestack geostatistical inversion based on seismic data, drilling data and logging data; determining the overburden formation pressure and the hydrostatic pressure of the target area by constructing a full-formation density body model based on the seismic data, the longitudinal wave inversion speed, the transverse wave inversion speed and the lithologic probability body of the target area; and determining the pressure coefficient of the target area based on the relation between the effective stress and the longitudinal wave speed and the clay content of the target area, the longitudinal wave inversion speed and the transverse wave inversion speed of the target area, the lithologic probability body, the overburden formation pressure and the hydrostatic pressure of the target area. The method can improve the prediction accuracy of the pressure coefficient.
Description
Technical Field
The application relates to the technical field of geophysical signal interpretation, in particular to a method and a device for determining a pressure coefficient.
Background
The pressure coefficient is an important reservoir parameter of a geological region with oil and gas, and can reflect the energy of the oil and gas fluid. The higher the pressure coefficient, the higher the hydrocarbon production of the geological region, and the stronger the continuous production capacity.
In the related art, a longitudinal wave velocity method considering lithology changes is mainly used to predict a pressure coefficient. Under the premise of considering various factors influencing the longitudinal wave speed change, the pressure coefficient is calculated by constructing a lithology model. In the construction of the lithology model, the shale content is usually represented by a shale content indicator obtained by normalizing the gamma ray intensity (GR) value, but when the shale content variation amplitude of an actual area is large, the constructed lithology model is easy to be inaccurate, and further, the prediction of the pressure coefficient is not accurate enough.
Disclosure of Invention
In view of the above, the application provides a method and a device for determining a pressure coefficient, which can solve the problem that the pressure coefficient prediction in the prior art is inaccurate, and improve the prediction accuracy of the pressure coefficient.
Specifically, the method comprises the following technical scheme:
in one aspect, an embodiment of the present application provides a method for determining a pressure coefficient, where the method includes:
Acquiring drilling data, logging data and seismic data of a sample well in a target zone at a target interval;
Determining a relationship between effective stress and longitudinal wave velocity and shale content of a target zone based on the well data and the well logging data;
Determining lithologic plane spread characteristics and vertical sand-mud proportions of a target area through prestack deterministic inversion based on the seismic data, the drilling data and the logging data;
Determining a longitudinal wave inversion speed, a transverse wave inversion speed and a lithologic probability body of the target area through pre-stack geostatistical inversion based on the seismic data, lithologic plane spread characteristics of the target area and the vertical sand-mud proportion;
Determining the overburden formation pressure and the hydrostatic pressure of the target area by constructing a full-formation density body model based on the seismic data, the longitudinal wave inversion speed, the transverse wave inversion speed and the lithology probability body of the target area;
And determining a pressure coefficient of the target area based on the relation between the effective stress of the target area and the longitudinal wave speed and the clay content, the longitudinal wave inversion speed, the transverse wave inversion speed and the lithology probability body of the target area, and the overburden formation pressure and the hydrostatic pressure of the target area.
In some embodiments, the determining the relationship between effective stress and longitudinal wave velocity and clay content of the target zone based on the drilling data and the logging data comprises:
Acquiring data of effective stress, longitudinal wave speed and clay content of a target interval and a functional relation to be fitted based on the drilling data and the logging data;
And carrying out multiple nonlinear regression fitting on the data of the effective stress, the longitudinal wave speed and the argillaceous content of the target interval based on the functional relation to be fitted to obtain the functional relation between the effective stress and the longitudinal wave speed and the argillaceous content of the target area.
In some embodiments, the seismic data comprises seismic attribute data, the well log data comprises longitudinal wave velocity, transverse wave velocity, and geological density data of the sample wells, and the well log data comprises horizon data of the sample wells; the determining lithologic plane spread characteristics and vertical sand-mud proportions of the target area through prestack deterministic inversion based on the seismic data, the drilling data and the logging data comprises:
performing prestack deterministic inversion on the seismic attribute data, the longitudinal wave velocity, the transverse wave velocity, geological density data of the sample well and horizon data of the sample well to obtain prestack deterministic inversion results;
And determining the lithologic plane spread characteristics and vertical sand-mud proportions of the target region based on the prestack deterministic inversion result and the seismic attribute data.
In some embodiments, the seismic data includes seismic attribute data; the determining, based on the seismic data, lithologic plane spread characteristics of the target area, and the vertical sand-to-mud ratio, a longitudinal wave inversion speed, a transverse wave inversion speed, and a lithologic probability body of the target area by pre-stack geostatistical inversion, includes:
And carrying out prestack geostatistical inversion on the seismic attribute data, the lithologic plane spreading characteristics and the vertical sand-mud proportion according to geostatistical parameters, and determining the longitudinal wave inversion speed, the transverse wave inversion speed and the lithologic probability body of a target area.
In some embodiments, the determining the overburden formation pressure and the hydrostatic pressure of the target region by constructing a full formation density volume model based on the seismic data, the compressional inversion speed, the shear inversion speed, and the lithologic probability volume of the target region includes:
performing depth migration processing on the seismic data to obtain depth-migrated seismic data;
constructing a depth migration velocity field model based on the depth migration seismic data;
Substituting the longitudinal wave inversion speed, the transverse wave inversion speed and the lithologic probability body of the target area into the depth migration velocity field model to obtain the longitudinal wave inversion speed, the transverse wave inversion speed and the lithologic probability body after the depth migration;
constructing the full-stratum density body model based on the longitudinal wave inversion speed, the transverse wave inversion speed and the lithologic probability body after the depth deviation;
and determining the overburden pressure and the hydrostatic pressure of the target area based on the full formation density volume model.
In some embodiments, the determining overburden pressure and hydrostatic pressure of the target area based on the full formation density volume model includes:
performing depth integration on the full formation density body to obtain the overburden formation pressure of the target area;
Substituting the density of the water into the full-stratum density body model to obtain a full-stratum density body comprising the density of the water;
And carrying out depth integration on the full stratum density body comprising the water density to obtain the hydrostatic pressure of the target area.
In some embodiments, the determining the pressure coefficient of the target zone based on the relationship between the effective stress of the target zone and the longitudinal wave velocity and the shale content, the longitudinal wave inversion velocity, the shear wave inversion velocity, and the lithology probability volume of the target zone, the overburden formation pressure and the hydrostatic pressure of the target zone includes:
Obtaining the effective stress and the effective stress coefficient of a target area based on the relation between the effective stress and the longitudinal wave speed and the argillaceous content of the target area, and the longitudinal wave inversion speed and lithology probability body of the target area;
A pressure coefficient of the target zone is determined based on overburden pressure and hydrostatic pressure of the target zone and effective stress coefficient of the target zone.
In some embodiments, the effective stress coefficient is calculated according to the following formula:
Wherein γ represents poisson's ratio, α represents the effective stress coefficient, v p represents the longitudinal wave inversion speed, and v s represents the transverse wave inversion speed.
In some embodiments, the pressure coefficient is calculated according to the following formula:
pP＝Sv-αpe
pf＝pp/(ρwgh)
Wherein p P represents the formation pore pressure, p e represents the effective stress, α represents the effective stress coefficient, S v represents the overburden formation pressure, p f represents the pressure coefficient, ρ w gh represents the hydrostatic pressure, ρ w represents the water density, h represents the burial depth of the target interval, and g represents the gravitational acceleration.
In another aspect, an embodiment of the present application provides a device for determining a pressure coefficient, where the device includes:
the data acquisition module is used for acquiring drilling data, logging data and seismic data of a sample well in a target layer section in a target area;
the relation determining module is used for determining the relation between the effective stress of the target area and the longitudinal wave speed and the clay content based on the drilling data and the logging data;
The deterministic inversion module is used for determining lithologic plane spread characteristics and vertical sand-mud proportions of a target area through prestack deterministic inversion based on the seismic data, the drilling data and the logging data;
The geostatistical inversion module is used for determining the longitudinal wave inversion speed, the transverse wave inversion speed and the lithologic probability body of the target area through prestack geostatistical inversion based on the seismic data, the lithologic plane spread characteristics of the target area and the vertical sand-mud proportion;
the pressure determining module is used for determining the overburden formation pressure and the hydrostatic pressure of the target area by constructing a full-stratum density body model based on the seismic data, the longitudinal wave inversion speed, the transverse wave inversion speed and the lithology probability body of the target area;
And the pressure coefficient determining module is used for determining the pressure coefficient of the target area based on the relation between the effective stress of the target area and the longitudinal wave speed and the clay content, the longitudinal wave inversion speed, the transverse wave inversion speed and the lithology probability body of the target area, and the overburden formation pressure and the hydrostatic pressure of the target area.
According to the method for determining the pressure coefficient, provided by the embodiment of the application, through the drilling data and the logging data of the sample well in the target layer section in the target area, the relation between the effective stress of the target area and the longitudinal wave speed and the clay content can be obtained; through seismic data, drilling data and logging data of a sample well of a target area in a target layer section, longitudinal wave inversion speed, transverse wave inversion speed and lithologic probability body of the target area can be obtained through prestack deterministic inversion and prestack geostatistical inversion; based on the seismic data, the longitudinal wave inversion speed, the transverse wave inversion speed and the lithologic probability body, the overburden stratum pressure and the hydrostatic pressure can be obtained by utilizing the constructed full stratum density body model; based on the obtained relationship between the effective stress and the longitudinal wave velocity and the clay content of the target region, the longitudinal wave inversion velocity, the transverse wave inversion velocity, the lithologic probability body, the overburden formation pressure and the hydrostatic pressure, the pressure coefficient of the target region can be determined. In the method, the lithology plane spreading characteristics and the vertical sand-mud proportion obtained by seismic data and prestack deterministic inversion are adopted to carry out prestack geostatistical inversion to determine the longitudinal wave inversion speed, the transverse wave inversion speed and lithology probability bodies, and the lithology probability bodies are combined with the relation between the effective stress and the longitudinal wave speed and the lithology content, so that the lithology probability bodies are used for representing the lithology content, the lithology content can be better constrained in the longitudinal and transverse directions, the lithology content can be accurately represented, and the prediction precision of the pressure coefficient is improved.
Drawings
In order to more clearly illustrate the technical solutions of the embodiments of the present application, the drawings required for the description of the embodiments will be briefly described below, and it is apparent that the drawings in the following description are only some embodiments of the present application, and other drawings may be obtained according to these drawings without inventive effort for a person skilled in the art.
FIG. 1 is a flowchart of a method for determining a pressure coefficient according to an embodiment of the present application;
FIG. 2 is a graph showing the fitting effect between the effective stress of the target area and the longitudinal wave velocity and the clay content in the method for determining the pressure coefficient according to the embodiment of the present application;
FIG. 3 (a) is a graph showing the effect of the velocity of the longitudinal wave inversion of the target area determined by the method for determining the pressure coefficient according to the embodiment of the present application;
FIG. 3 (b) is a graph showing the effect of the shear wave inversion speed of the target area determined by the method for determining the pressure coefficient according to the embodiment of the present application;
Fig. 3 (c) is an effect diagram of lithologic probability bodies of a target area determined in the method for determining a pressure coefficient according to an embodiment of the present application;
FIG. 4 is a flowchart of determining the overburden formation pressure and the hydrostatic pressure of a target area by constructing a full formation density body model based on seismic data, the longitudinal wave inversion speed, the transverse wave inversion speed and the lithology probability body of the target area in the method for determining the pressure coefficient provided by the embodiment of the application;
FIG. 5 is a flowchart of determining a pressure coefficient of a target area based on a relation between effective stress and longitudinal wave velocity and clay content of the target area, a longitudinal wave inversion velocity, a transverse wave inversion velocity of the target area, lithologic probability bodies, overburden formation pressure and hydrostatic pressure of the target area in a pressure coefficient determining method provided by an embodiment of the application;
Fig. 6 is a schematic structural diagram of a device for determining a pressure coefficient according to an embodiment of the present application.
Detailed Description
The following description of the embodiments of the present application will be made clearly and fully with reference to the accompanying drawings, in which it is evident that the embodiments described are some, but not all embodiments of the application. All other embodiments, which can be made by those skilled in the art based on the embodiments of the application without making any inventive effort, are intended to be within the scope of the application.
For geological areas containing oil and gas, the pressure coefficient of stratum pores is an important oil reservoir parameter, and can reflect the energy of oil and gas fluid, so that data support is provided for oil and gas exploration. The height of the pressure coefficient has direct correlation with the oil and gas yield, and the higher the pressure coefficient is, the higher the oil and gas yield of the geological region is, and the stronger the continuous production capacity is.
Currently, the determination method of the pressure coefficient mainly comprises the following three methods:
the first method is an inter-well interpolation method, which is to obtain the formation pore pressure by substituting the formation pore pressure obtained from logging data into a seismic structural model for interpolation treatment, and then calculate a pressure coefficient by using the formation pore pressure. The method has the defect that the spatial variation trend of the pore pressure of the stratum between wells cannot be controlled, and the method is only suitable for geological areas with obvious correlation between pressure coefficients and oil and gas depths and stable lithology.
The second method is a longitudinal wave velocity method, e.g., phillipphone method, which determines the formation pore pressure from the relationship between velocity bodies such as inversion velocity and layer velocity, and then calculates the pressure coefficient using the formation pore pressure. The method has the disadvantage of being only suitable for determining the pressure coefficient of a geological region with a large area, and has lower prediction accuracy on the pressure coefficient of a small region.
The third method is a longitudinal wave velocity method considering lithology changes, because the change of the longitudinal wave velocity is affected by factors such as the content of the clay, the construction movement, the lithology changes, and the like in addition to the formation pore pressure. An increase in the clay content will result in a decrease in the longitudinal wave velocity, and if lithology is not considered, the predicted pressure coefficient will be higher. In addition, the degradation effect also leads to a higher predicted pressure coefficient. The pressure coefficient is predicted by considering a longitudinal wave velocity method of lithology change, and is calculated by constructing a lithology model under the premise of considering various factors influencing the longitudinal wave velocity change. In the construction of lithology models, the shale content is often represented by a shale content indicator obtained by normalizing the GR value of logging data. The method has the defects that the method is only suitable for geological areas with slower changes of the clay content, and when the clay content of an actual area is larger in change range, the constructed lithology model is easy to be inaccurate, and then the prediction of the pressure coefficient is inaccurate.
In order to solve the problem that the pressure coefficient prediction in the prior art is not accurate enough, the embodiment of the application provides a method for determining the pressure coefficient.
Fig. 1 is a flowchart of a method for determining a pressure coefficient according to an embodiment of the present application. Referring to fig. 1, the method includes:
Step 101, obtaining drilling data, logging data and seismic data of a sample well in a target zone at a target interval.
Wherein the target area may comprise a plurality of sample wells.
In the embodiment of the application, the drilling data, the logging data and the seismic data obtained in the step refer to the drilling data, the logging data and the seismic data of each sample well in the target zone at the target interval.
The target interval is an interval in which seismic exploration is required, and the interval is an interval possibly having a hydrocarbon reservoir. By combining the drilling data, the logging data and the seismic data of the interval, the pressure coefficient of the area where the interval is located can be explored, and the energy of the oil and gas reservoir of the area can be reflected better.
It will be appreciated that drilling data may be obtained by performing a drilling operation on a sample well; logging data can be obtained by logging the sample well; seismic data may be acquired by performing a seismic survey operation on the sample wells.
Step 102, determining the relation between the effective stress of the target area and the longitudinal wave speed and the clay content based on the well drilling data and the well logging data.
And determining the relation between the effective stress of the target area and the longitudinal wave speed and the clay content by using the drilling data and the logging data, so that the effective stress of the target area can be calculated conveniently, and the pressure coefficient of the target area can be calculated.
In some embodiments, this step includes the sub-steps of:
And 1021, acquiring data of effective stress, longitudinal wave speed and clay content of the target interval and a functional relation to be fitted based on the drilling data and the logging data.
The well drilling data and the well logging data comprise data of effective stress, longitudinal wave speed and clay content of a target interval, and the functional relation to be fitted is selected so as to facilitate the subsequent fitting of the data of the effective stress, longitudinal wave speed and clay content of the target interval.
In some embodiments, the functional relation to be fitted is of the following 4 types:
pe＝A ln vp+BLi
Where p e denotes the effective stress, v p denotes the longitudinal wave velocity, L i denotes the argillaceous content, and A, B and C denote the fitting coefficients.
And step 1022, performing multiple nonlinear regression fitting on the data of the effective stress, the longitudinal wave speed and the argillaceous content of the target interval based on the functional relation to be fitted, and obtaining the functional relation between the effective stress and the longitudinal wave speed and the argillaceous content of the target area.
Coefficients in the functional relation to be fitted can be determined through multiple nonlinear regression fitting, so that the functional relation between the effective stress of the target area and the longitudinal wave speed and the argillaceous content is determined.
It will be appreciated that the relationship between the effective stress and the longitudinal wave velocity and the argillaceous content of the target region may be characterized by a functional relationship between the effective stress and the longitudinal wave velocity and the argillaceous content of the target region.
In some embodiments, the multiple nonlinear regression fitting uses the effective stress, the longitudinal wave speed and the clay content of the target interval as variables, the multiple nonlinear regression fitting is performed on the effective stress, the longitudinal wave speed and the clay content of the target interval according to a functional relation to be fitted, and the coefficient to be determined in the functional relation to be fitted is determined on the basis that the correlation coefficient is larger than a preset threshold value, so that the functional relation between the effective stress and the longitudinal wave speed and the clay content of the target area is obtained.
Based on the fitted correlation coefficient R, a functional relation between the effective stress and the longitudinal wave velocity and the clay content can be determined. The closer the correlation coefficient R is to 1, the better the fitting degree is explained.
For example, for a land shale area facing a Sichuan basin, a multiple nonlinear regression fit table may be shown in Table 1 below. The variables required to perform multiple linear regression fit for the target interval, namely effective stress, longitudinal wave velocity and clay content, are contained in table 1.
Table 1 multiple nonlinear regression fit table
Performing multiple nonlinear regression fitting through the 4 types of functional relation to be fitted to obtain a fitted functional relation and a correlation coefficient containing coefficients, wherein after comparing the correlation coefficients, the obtained functional relation between the effective stress of the target area and the longitudinal wave velocity and the argillaceous content can beFig. 2 is a graph of a fitting effect between effective stress and longitudinal wave velocity and clay content of a target area in a method for determining a pressure coefficient according to an embodiment of the present application. Referring to fig. 2, it can be seen that the correlation coefficient R is 0.8023, the correlation coefficient is larger, and the fitting degree is better.
Step 103, determining lithologic plane spread characteristics and vertical sand-mud proportion of the target area through prestack deterministic inversion based on the seismic data, the drilling data and the logging data.
And providing an inversion basis for the subsequent pre-stack geostatistical inversion by obtaining lithologic plane spreading characteristics and vertical sand-mud proportion of the determined target area.
In some embodiments, the seismic data comprises seismic attribute data, the seismic attribute data comprises amplitude attribute data and frequency attribute data, the well log data comprises longitudinal wave velocity, transverse wave velocity, and geological density data of the sample wells, and the well drilling data comprises horizon data of the sample wells.
In some embodiments, this step includes the sub-steps of:
Step 1031, performing prestack deterministic inversion on the seismic attribute data, the longitudinal wave velocity, the transverse wave velocity, the geological density data of the sample well and the horizon data of the sample well to obtain prestack deterministic inversion results.
The prestack deterministic inversion result can quantitatively reflect lithologic plane spreading characteristics and vertical sand-mud proportion.
Step 1032, determining lithologic plane spread characteristics and vertical sand-to-mud ratios of the target region based on the pre-stack deterministic inversion results and the seismic attribute data.
Because the seismic attribute data can qualitatively reflect lithologic plane spread characteristics, when the seismic attribute data is combined with a prestack deterministic inversion result, the lithologic plane spread characteristics qualitatively reflected by the seismic attribute data can be compared with the prestack deterministic inversion result, so that the lithologic plane spread characteristics and the vertical sand-mud proportion of a target area can be well determined.
Step 104, determining the longitudinal wave inversion speed, the transverse wave inversion speed and the lithologic probability body of the target area through pre-stack geostatistical inversion based on the seismic data, lithologic plane spread characteristics of the target area and the vertical sand-mud proportion.
The lithologic probability body obtained through prestack geostatistical inversion can be used for representing the clay content so as to reflect the clay content of a target area more accurately; the obtained longitudinal wave inversion speed, the transverse wave inversion speed and the lithologic probability body of the target area are convenient for the subsequent construction of a full-stratum density body model, and further are convenient for the calculation of the overburden stratum pressure and the hydrostatic pressure of the target area.
The geostatistical inversion is to integrate available prior information and actual measurement data by using bayesian discrimination to obtain probability density functions and variation functions in geostatistics capable of representing oil reservoir conditions of a target area, and calculate longitudinal wave inversion speed, transverse wave inversion speed and lithologic probability bodies of the target area by using the probability density functions and the variation functions. The lithologic plane spreading characteristics and the vertical sand-mud proportion of the target area in the step belong to priori information obtained according to prestack deterministic inversion and seismic attribute data, and the seismic data belong to actual measurement data. Therefore, the longitudinal wave inversion speed, the transverse wave inversion speed and the lithology probability body obtained through pre-stack geostatistical inversion are more in accordance with the geological rule, and the lithology probability body can reflect the clay content of the target area more accurately compared with the GR value in the related technology.
In some embodiments, the blind wells in the same target area are adopted to fully verify the pre-stack geostatistical inversion result, so that the longitudinal wave inversion speed, the transverse wave inversion speed and the reliability of lithologic probability bodies are ensured.
The method comprises the steps of carrying out logging operation on a blind well in the same target area to obtain logging data, analyzing the longitudinal wave speed, the transverse wave speed and lithology information of the blind well area from the logging data and the drilling data obtained in the drilling operation, and when errors of the longitudinal wave speed, the transverse wave speed and the lithology information of the blind well area and the obtained longitudinal wave inversion speed, the transverse wave inversion speed and the lithology probability of the target area are smaller than preset errors, indicating that the obtained longitudinal wave inversion speed, the transverse wave inversion speed and the lithology probability of the target area can reflect the longitudinal wave speed, the transverse wave speed and the lithology information of the target area, so that the reliability of the obtained longitudinal wave inversion speed, the obtained transverse wave inversion speed and the lithology probability body is ensured.
Fig. 3 (a) is an effect diagram of a longitudinal wave inversion speed of a target area determined in a method for determining a pressure coefficient according to an embodiment of the present application; FIG. 3 (b) is a graph showing the effect of the shear wave inversion speed of the target area determined by the method for determining the pressure coefficient according to the embodiment of the present application; fig. 3 (c) is an effect diagram of lithologic probability bodies of the target area determined in the method for determining a pressure coefficient according to the embodiment of the present application. Referring to fig. 3 (a) to 3 (c), it can be seen that the effects of changes in the longitudinal wave inversion profile, the transverse wave inversion profile, and the lithologic probability mass are generated from the longitudinal wave inversion speed, the transverse wave inversion speed.
In some embodiments, this step may specifically include: and carrying out prestack geostatistical inversion on the seismic attribute data, lithology plane spreading characteristics and vertical sand-mud proportion according to geostatistical parameters, and determining the longitudinal wave inversion speed, the transverse wave inversion speed and the lithology probability body of the target area.
In some embodiments, the geostatistical parameters are parameters required for pre-stack geostatistical inversion, which is an inversion framework based on bayesian theorem, by analyzing seismic attribute data, lithology plane spread characteristics, and vertical sand-to-mud ratios of the target region, probability density functions and variation functions are constructed, which are used to characterize the geostatistical parameters. And carrying out prestack geostatistical inversion on the seismic attribute data, lithology plane spreading characteristics and vertical sand-mud proportion according to geostatistical parameters, and determining the longitudinal wave inversion speed, the transverse wave inversion speed and the lithology probability body of the target area.
In some embodiments, JASON geostatistical inversion software is employed to perform pre-stack geostatistical inversion.
Step 105, determining the overburden formation pressure and the hydrostatic pressure of the target area by constructing a full-formation density body model based on the seismic data, the longitudinal wave inversion speed, the transverse wave inversion speed and the lithologic probability body of the target area.
Wherein overburden pressure refers to pressure created by the sum of the matrix mass of the overburden and the mass of the fluid (oil, gas, water) in the overburden pores. Hydrostatic pressure refers to the pressure created by water. And determining the overburden formation pressure and the hydrostatic pressure of the target area, so as to solve the formation pore pressure and the pressure coefficient.
Fig. 4 is a flowchart of determining overburden formation pressure and hydrostatic pressure of a target area by constructing a full-formation density body model based on seismic data, longitudinal wave inversion speed, transverse wave inversion speed and lithologic probability body of the target area in a method for determining pressure coefficients according to an embodiment of the present application. Referring to fig. 4, this step may specifically include the following sub-steps:
In step 1051, depth migration processing is performed on the seismic data to obtain depth-migrated seismic data.
The seismic data in the depth domain can be obtained through the depth migration, so that the seismic data are richer.
Step 1052, constructing a depth migration velocity field model based on the depth-migrated seismic data.
And constructing a depth offset speed field model, and realizing the mutual conversion of data between a time domain and a depth domain.
And 1053, substituting the longitudinal wave inversion speed, the transverse wave inversion speed and the lithologic probability body of the target area into the depth migration velocity field model to obtain the longitudinal wave inversion speed, the transverse wave inversion speed and the lithologic probability body after the depth migration.
The obtained depth-shifted longitudinal wave inversion speed, transverse wave inversion speed and lithologic probability body are data of a depth domain, so that the data of the longitudinal wave inversion speed, the transverse wave inversion speed and the lithologic probability body are more abundant.
Step 1054, constructing a full stratum density body model based on the depth-shifted longitudinal wave inversion speed, the transverse wave inversion speed and the lithologic probability body.
And by constructing the full stratum density body model, the calculation of the overburden stratum pressure and the hydrostatic pressure is convenient to follow.
In some embodiments, the construction of the full formation density volume model may be accomplished using the following three methods:
First, density averaging. And constructing a full-stratum density body model by using the average value of the shallow layer density of the target area.
Second, density curve interpolation. And determining a density curve by using the average value of the shallow layer density of the target area, and then carrying out interpolation processing to construct a whole stratum density body model.
Third, velocity method. Based on the depth migration velocity field model, a full formation density volume model is obtained by utilizing a sound wave-density conversion formula.
At step 1055, overburden and hydrostatic pressures of the target region are determined based on the full formation density volume model.
And obtaining the overburden formation pressure and the hydrostatic pressure of the target area, and preparing for the calculation of the subsequent pressure coefficient.
Based on the full formation density volume model, the manner of determining overburden formation pressure and hydrostatic pressure for the target region may be: performing depth integration on the full-stratum density body to obtain the overburden stratum pressure of the target area; substituting the density of water into a full-stratum density body model to obtain a full-stratum density body containing the density of water; and carrying out depth integration on the full stratum density body containing the density of the water to obtain the hydrostatic pressure of the target area.
Overburden pressure refers to the pressure created by the sum of the mass of the substrate of the overburden and the mass of the fluid (oil, gas, water) in the overburden pores, and thus the depth integration of the full formation density volume results in the overburden pressure of the target zone. Hydrostatic pressure refers to the pressure generated by water, and thus the hydrostatic pressure of a target zone may be obtained by deep integration of a full formation density volume comprising the density of water.
And 106, determining a pressure coefficient of the target area based on the relation between the effective stress of the target area and the longitudinal wave speed and the clay content, the longitudinal wave inversion speed, the transverse wave inversion speed and the lithology probability body of the target area, and the overburden formation pressure and the hydrostatic pressure of the target area.
The lithologic probability is utilized to represent the shale content, the longitudinal wave inversion speed, the transverse wave inversion speed and the lithologic probability of the target area are substituted into the relation between the effective stress of the target area and the longitudinal wave speed and the shale content, and the pressure coefficient of the target area can be calculated through the constraint of the overburden formation pressure and the hydrostatic pressure.
Fig. 5 is a flowchart of determining a pressure coefficient of a target area based on a relation between effective stress and longitudinal wave velocity and clay content of the target area, a longitudinal wave inversion velocity and a transverse wave inversion velocity of the target area, lithologic probability bodies, overburden formation pressure and hydrostatic pressure of the target area in the determining method of the pressure coefficient provided by the embodiment of the application. Referring to fig. 5, this step specifically includes the following sub-steps:
Step 1061, obtaining the effective stress and the effective stress coefficient of the target area based on the relation between the effective stress and the longitudinal wave velocity and the clay content of the target area, the longitudinal wave inversion velocity of the target area and the lithology probability body.
Substituting the longitudinal wave inversion speed, the transverse wave inversion speed and the lithologic probability body of the target area into a relational expression between the effective stress of the target area and the longitudinal wave speed and the clay content can calculate the effective stress, so that the effective stress coefficient is obtained.
In some embodiments, the effective stress coefficient of the target region is obtained according to the following formula:
Wherein, gamma represents poisson's ratio, alpha represents effective stress coefficient, v p represents longitudinal wave inversion speed, and v s represents transverse wave inversion speed.
Step 1062, determining a pressure coefficient of the target zone based on the overburden pressure and the hydrostatic pressure of the target zone and the effective stress coefficient of the target zone.
And calculating a pressure coefficient by overlying strata pressure, hydrostatic pressure, effective stress and effective stress coefficient constraint based on the stratum pore pressure formula and the pressure coefficient formula.
In some embodiments, the pressure coefficient is derived according to the following formula:
pP＝Sv-αpe
pf＝pp/(ρwgh)
Wherein p P represents formation pore pressure, p e represents effective stress, α represents effective stress coefficient, S v represents overburden formation pressure, p f represents pressure coefficient, ρ w gh represents hydrostatic pressure, ρ w represents water density, h represents burial depth of a target interval, i.e. depth of the ground to the target interval, and g represents gravitational acceleration.
In some embodiments, the calculated formation pore pressure is compared with the maximum principal stress and the minimum principal stress of the target region, and the formation pore pressure is ensured to be less than or equal to the minimum principal stress.
For example, for a land shale area facing a Sichuan basin, based on a real pressure coefficient actually measured in a target area of the area, comparing the pressure coefficient determined by the pressure coefficient method provided by the embodiment of the application with the pressure coefficient obtained by a longitudinal wave velocity method considering lithology variation, the pressure coefficient determined by the longitudinal wave velocity method considering lithology variation can be obtained to be 1.7, the pressure coefficient determined by the pressure coefficient method provided by the embodiment of the application is 1.4, and the pressure coefficient actually measured is 1.3. From the above pressure coefficient values, it can be seen that the prediction error of the pressure coefficient of the target area in the region is reduced from 23% to 7% by using the pressure coefficient method provided by the embodiment of the present application, and the prediction accuracy of the pressure coefficient method provided by the embodiment of the present application is higher.
It should be noted that the method can solve the problem of most areas where logging data and drilling data are relatively rich. If the logging data and the drilling data are less or no pressure coefficient exists, detailed analysis is needed by means of the data of the adjacent areas, the approximate pressure coefficient is obtained according to the compaction trend, and then the empirical correction is performed according to the lithology probability body. At the same time, attention should be paid to the fact that the relationship among longitudinal wave velocity, clay content and effective stress may be different from region to region. If the petrophysical experiment has been carried out in the region, the calculation can also be directly carried out based on the relational expression obtained by the petrophysical experiment; if no petrophysical experiments are performed in the region, the relationship between longitudinal wave velocity, clay content and effective stress can be determined according to the method provided by the application.
The method is more accurate in predicting the pressure coefficient of the geological region with the following characteristics. The geological region is characterized by a thin shale thickness, rapid sand-mud proportion change in the shale and a region with weak geological density change, such as a Sichuan basin land shale region.
According to the method for determining the pressure coefficient, provided by the embodiment of the application, the longitudinal wave inversion speed, the transverse wave inversion speed and the lithology probability body are determined by adopting the seismic data and lithology plane spreading characteristics and the vertical sand-mud proportion obtained by prestack deterministic inversion, and prestack geostatistical inversion is carried out, and the lithology probability body is used for representing the lithology content in combination with the relation between the effective stress and the longitudinal wave speed and the lithology content, so that the lithology probability body is substituted into the relation between the effective stress and the longitudinal wave speed and the lithology content, the lithology content can be better constrained in the longitudinal and transverse directions, the prediction precision of the pressure coefficient is improved, and the data support is provided for oil and gas exploration.
Fig. 6 is a schematic structural diagram of a device for determining a pressure coefficient according to an embodiment of the present application. Referring to fig. 6, the apparatus includes:
a data acquisition module 601, configured to acquire drilling data, logging data and seismic data of a sample well in a target interval in a target area;
A relationship determination module 602 for determining a relationship between effective stress and longitudinal wave velocity and clay content of the target zone based on the well log data and the well log data;
the deterministic inversion module 603 is configured to determine lithologic plane spread features and vertical sand-mud proportions of the target area through prestack deterministic inversion based on the seismic data, the drilling data and the logging data;
the geostatistical inversion module 604 is configured to determine a longitudinal wave inversion speed, a transverse wave inversion speed and a lithologic probability body of the target area through prestack geostatistical inversion based on the seismic data, lithologic plane spread characteristics of the target area and vertical sand-mud proportions;
The pressure determining module 605 is configured to determine an overburden formation pressure and a hydrostatic pressure of the target area by constructing a full formation density body model based on the seismic data, a longitudinal wave inversion speed, a transverse wave inversion speed, and a lithologic probability body of the target area;
The pressure coefficient determining module 606 is configured to determine a pressure coefficient of the target area based on a relation between an effective stress of the target area and a longitudinal wave velocity and a clay content, a longitudinal wave inversion velocity, a transverse wave inversion velocity, a lithologic probability body, an overburden formation pressure and a hydrostatic pressure of the target area.
In some embodiments, the relationship determination module 602 includes:
the acquisition unit is used for acquiring data of effective stress, longitudinal wave speed and clay content of a target interval and a functional relation to be fitted based on drilling data and logging data;
And the fitting unit is used for carrying out multiple nonlinear regression fitting on the data of the effective stress, the longitudinal wave speed and the argillaceous content of the target interval based on the functional relation to be fitted to obtain the functional relation between the effective stress and the longitudinal wave speed of the target area and the functional relation between the effective stress and the longitudinal wave speed and the argillaceous content of the target area.
In some embodiments, the seismic data comprises seismic attribute data, the well log data comprises longitudinal wave velocity, transverse wave velocity, and geological density data of the sample wells, and the well drilling data comprises horizon data of the sample wells.
In some embodiments, the deterministic inversion module 603 includes:
the deterministic inversion unit is used for carrying out prestack deterministic inversion on the seismic attribute data, the longitudinal wave speed, the transverse wave speed, the geological density data of the sample well and the horizon data of the sample well to obtain prestack deterministic inversion results;
And the characteristic determining unit is used for determining lithologic plane spreading characteristics and vertical sand-mud proportions of the target area based on the prestack deterministic inversion result and the seismic attribute data.
In some embodiments, geostatistical inversion module 604 includes:
And the geostatistical inversion unit is used for carrying out prestack geostatistical inversion on the seismic attribute data, lithologic plane spreading characteristics and vertical sand-mud proportion according to geostatistical parameters, and determining the longitudinal wave inversion speed, the transverse wave inversion speed and the lithologic probability body of the target area.
In some embodiments, the pressure determination module 605 includes:
The depth migration unit is used for carrying out depth migration processing on the seismic data to obtain the seismic data after the depth migration;
The first model building unit is used for building a depth migration velocity field model based on the seismic data after the depth migration;
The substituting unit is used for substituting the longitudinal wave inversion speed, the transverse wave inversion speed and the lithology probability body of the target area into the depth migration velocity field model to obtain the longitudinal wave inversion speed, the transverse wave inversion speed and the lithology probability body after the depth migration;
the second model building unit is used for building a full-stratum density body model based on the longitudinal wave inversion speed, the transverse wave inversion speed and the lithologic probability body after the depth deviation;
And the pressure determining unit is used for determining the overburden formation pressure and the hydrostatic pressure of the target area based on the full formation density body model.
In some embodiments, the pressure determining unit comprises:
a first determination subunit, configured to obtain an overburden formation pressure of the target area based on depth integration of the full formation density volume;
a density body calculation unit for obtaining a full-formation density body including the density of water based on substituting the density of water into the full-formation density body model;
And the second determination subunit is used for carrying out depth integration on the full stratum density body containing the density of the water to obtain the hydrostatic pressure of the target area.
In some embodiments, the pressure coefficient determination module 606 includes:
the stress calculation unit is used for obtaining the effective stress and the effective stress coefficient of the target area based on the relation between the effective stress and the longitudinal wave speed and the clay content of the target area, the longitudinal wave inversion speed of the target area and the lithology probability body;
and the pressure coefficient determining unit is used for determining the pressure coefficient of the target area based on the overburden formation pressure and the hydrostatic pressure of the target area and the effective stress coefficient of the target area.
In some embodiments, the effective stress coefficient is calculated according to the following formula:
Wherein, gamma represents poisson's ratio, alpha represents effective stress coefficient, v p represents longitudinal wave inversion speed, and v s represents transverse wave inversion speed.
In some embodiments, the pressure coefficient is calculated according to the following formula:
pP＝Sv-αpe
pf＝pp/(ρwgh)
Wherein p P represents formation pore pressure, p e represents effective stress, α represents effective stress coefficient, S v represents overburden formation pressure, p f represents pressure coefficient, ρ w gh represents hydrostatic pressure, ρ w represents water density, h represents burial depth of a target interval, i.e. depth of the ground to the target interval, and g represents gravitational acceleration.
According to the device for determining the pressure coefficient, provided by the embodiment of the application, the longitudinal wave inversion speed, the transverse wave inversion speed and the lithology probability body are determined by adopting the seismic data and lithology plane spreading characteristics and vertical sand-mud proportion obtained by prestack deterministic inversion, and are combined with the relation between the effective stress and the longitudinal wave speed and the lithology content, the lithology probability body is used for representing the lithology content, and the lithology probability body is substituted into the relation between the effective stress and the longitudinal wave speed and the lithology content, so that the lithology content can be better constrained in the longitudinal and transverse directions, and the prediction precision of the pressure coefficient is improved.
Other embodiments of the application will be apparent to those skilled in the art from consideration of the specification and practice of the application disclosed herein. This application is intended to cover any variations, uses, or adaptations of the application following, in general, the principles of the application and including such departures from the present disclosure as come within known or customary practice within the art to which the application pertains. The specification and examples are to be regarded in an illustrative manner only.
It is to be understood that the application is not limited to the precise arrangements and instrumentalities shown in the drawings, which have been described above, and that various modifications and changes may be effected without departing from the scope thereof. The scope of the application is limited only by the appended claims.
Claims (10)
1. A method of determining a pressure coefficient, the method comprising:
Acquiring drilling data, logging data and seismic data of a sample well in a target zone at a target interval;
Determining a relationship between effective stress and longitudinal wave velocity and shale content of a target zone based on the well data and the well logging data;
Determining lithologic plane spread characteristics and vertical sand-mud proportions of a target area through prestack deterministic inversion based on the seismic data, the drilling data and the logging data;
Determining a longitudinal wave inversion speed, a transverse wave inversion speed and a lithologic probability body of the target area through pre-stack geostatistical inversion based on the seismic data, lithologic plane spread characteristics of the target area and the vertical sand-mud proportion;
Determining the overburden formation pressure and the hydrostatic pressure of the target area by constructing a full-formation density body model based on the seismic data, the longitudinal wave inversion speed, the transverse wave inversion speed and the lithology probability body of the target area;
And determining a pressure coefficient of the target area based on the relation between the effective stress of the target area and the longitudinal wave speed and the clay content, the longitudinal wave inversion speed, the transverse wave inversion speed and the lithology probability body of the target area, and the overburden formation pressure and the hydrostatic pressure of the target area.
2. The method of determining a pressure coefficient according to claim 1, wherein said determining a relationship between effective stress and longitudinal wave velocity and clay content of a target zone based on said drilling data and said logging data comprises:
Acquiring data of effective stress, longitudinal wave speed and clay content of a target interval and a functional relation to be fitted based on the drilling data and the logging data;
And carrying out multiple nonlinear regression fitting on the data of the effective stress, the longitudinal wave speed and the argillaceous content of the target interval based on the functional relation to be fitted to obtain the functional relation between the effective stress and the longitudinal wave speed and the argillaceous content of the target area.
3. The method of determining a pressure coefficient of claim 1, wherein the seismic data comprises seismic attribute data, the well log data comprises longitudinal wave velocity, shear wave velocity, and geological density data of the sample well, and the well log data comprises horizon data of the sample well; the determining lithologic plane spread characteristics and vertical sand-mud proportions of the target area through prestack deterministic inversion based on the seismic data, the drilling data and the logging data comprises:
performing prestack deterministic inversion on the seismic attribute data, the longitudinal wave velocity, the transverse wave velocity, geological density data of the sample well and horizon data of the sample well to obtain prestack deterministic inversion results;
And determining the lithologic plane spread characteristics and vertical sand-mud proportions of the target region based on the prestack deterministic inversion result and the seismic attribute data.
4. The method of claim 1, wherein the seismic data comprises seismic attribute data; the determining, based on the seismic data, lithologic plane spread characteristics of the target area, and the vertical sand-to-mud ratio, a longitudinal wave inversion speed, a transverse wave inversion speed, and a lithologic probability body of the target area by pre-stack geostatistical inversion, includes:
And carrying out prestack geostatistical inversion on the seismic attribute data, the lithologic plane spreading characteristics and the vertical sand-mud proportion according to geostatistical parameters, and determining the longitudinal wave inversion speed, the transverse wave inversion speed and the lithologic probability body of a target area.
5. The method for determining the pressure coefficient according to claim 1, wherein the determining the overburden formation pressure and the hydrostatic pressure of the target area by constructing a full-formation density volume model based on the seismic data, the longitudinal wave inversion speed, the transverse wave inversion speed, and the lithologic probability volume of the target area comprises:
performing depth migration processing on the seismic data to obtain depth-migrated seismic data;
constructing a depth migration velocity field model based on the depth migration seismic data;
Substituting the longitudinal wave inversion speed, the transverse wave inversion speed and the lithologic probability body of the target area into the depth migration velocity field model to obtain the longitudinal wave inversion speed, the transverse wave inversion speed and the lithologic probability body after the depth migration;
constructing the full-stratum density body model based on the longitudinal wave inversion speed, the transverse wave inversion speed and the lithologic probability body after the depth deviation;
and determining the overburden pressure and the hydrostatic pressure of the target area based on the full formation density volume model.
6. The method of determining a pressure coefficient of claim 5, wherein determining an overburden pressure and a hydrostatic pressure of the target region based on the full formation density volume model includes:
performing depth integration on the full formation density body to obtain the overburden formation pressure of the target area;
substituting the density of the water into the full-stratum density body model to obtain a full-stratum density body containing the density of the water;
And carrying out depth integration on the full stratum density body containing the water density to obtain the hydrostatic pressure of the target area.
7. The method of determining a pressure coefficient according to claim 1, wherein the determining a pressure coefficient of the target region based on the relation between the effective stress and the longitudinal wave velocity and the argillaceous content of the target region, the longitudinal wave inversion velocity, the transverse wave inversion velocity, and the lithology probability volume of the target region, the overburden formation pressure and the hydrostatic pressure of the target region, comprises:
Obtaining the effective stress and the effective stress coefficient of a target area based on the relation between the effective stress and the longitudinal wave speed and the argillaceous content of the target area, and the longitudinal wave inversion speed and lithology probability body of the target area;
A pressure coefficient of the target zone is determined based on overburden pressure and hydrostatic pressure of the target zone and effective stress coefficient of the target zone.
8. The method of determining a pressure coefficient according to claim 7, wherein the effective stress coefficient is calculated according to the formula:
Wherein γ represents poisson's ratio, α represents the effective stress coefficient, v p represents the longitudinal wave inversion speed, and v s represents the transverse wave inversion speed.
9. The method of determining a pressure coefficient according to claim 7, wherein the pressure coefficient is calculated according to the formula:
pP＝Sv-αpe
pf＝pp/(ρwgh)
Wherein p P represents the formation pore pressure, p e represents the effective stress, α represents the effective stress coefficient, S v represents the overburden formation pressure, p f represents the pressure coefficient, ρ w gh represents the hydrostatic pressure, ρ w represents the water density, h represents the burial depth of the target interval, and g represents the gravitational acceleration.
10. A device for determining a pressure coefficient, the device comprising:
the data acquisition module is used for acquiring drilling data, logging data and seismic data of a sample well in a target layer section in a target area;
the relation determining module is used for determining the relation between the effective stress of the target area and the longitudinal wave speed and the clay content based on the drilling data and the logging data;
The deterministic inversion module is used for determining lithologic plane spread characteristics and vertical sand-mud proportions of a target area through prestack deterministic inversion based on the seismic data, the drilling data and the logging data;
The geostatistical inversion module is used for determining the longitudinal wave inversion speed, the transverse wave inversion speed and the lithologic probability body of the target area through prestack geostatistical inversion based on the seismic data, the lithologic plane spread characteristics of the target area and the vertical sand-mud proportion;
the pressure determining module is used for determining the overburden formation pressure and the hydrostatic pressure of the target area by constructing a full-stratum density body model based on the seismic data, the longitudinal wave inversion speed, the transverse wave inversion speed and the lithology probability body of the target area;
And the pressure coefficient determining module is used for determining the pressure coefficient of the target area based on the relation between the effective stress of the target area and the longitudinal wave speed and the clay content, the longitudinal wave inversion speed, the transverse wave inversion speed and the lithology probability body of the target area, and the overburden formation pressure and the hydrostatic pressure of the target area.
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