CN106546525A - The method and apparatus for setting up three-dimensional penetration rate model - Google Patents
The method and apparatus for setting up three-dimensional penetration rate model Download PDFInfo
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- 238000000034 method Methods 0.000 title claims abstract description 66
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Abstract
The embodiment of the present application provides a kind of method and apparatus for setting up three-dimensional penetration rate model, wherein, the method is comprised the following steps：Obtain the result data of target reservoir；According to the result data of target reservoir, the stress field simulation geological model of target reservoir is set up；According to the result data and target reservoir Image Logging Data of target reservoir, by stress field simulation geological model, target reservoir Stress Field Distribution data are calculated；According to target reservoir Stress Field Distribution data, target reservoir Image Logging Data and target reservoir well test data, solution obtains correcting permeability；Three-dimensional penetration rate model is set up according to correction permeability.As the program considers the impact of microcrack, and three-dimensional penetration rate model is set up according to correction permeability, therefore solve that three-dimensional penetration rate model precision present in existing modeling method is low, the technical problem that error is big, realize the technique effect of the three-dimensional penetration rate model precision for improving set up.
Description
Technical Field
The application relates to the technical field of oil reservoir development, in particular to a method and a device for establishing a three-dimensional permeability model.
Background
In the field of oil reservoir development, when a target oil reservoir is researched and analyzed, a three-dimensional permeability model about the target oil reservoir is often established according to well logging information and experimental result data of the target oil reservoir, and then specific oil reservoir engineering research and oil reservoir numerical simulation research are carried out on the target oil reservoir through the three-dimensional permeability model.
At present, the modeling method mainly adopted is generally to establish a three-dimensional permeability model related to a target oil reservoir according to the logging permeability. However, in practice, a geologic reservoir of a target reservoir often develops many micro-fractures therein, which affect the migration of fluids in the porous medium, resulting in the actual permeability of the geologic reservoir being much higher than the well-logging permeability in actual development. Therefore, the three-dimensional permeability model directly established according to the logging permeability through the existing modeling method often has the technical problems of low precision and large error. The above-mentioned technical problems with the existing modeling methods are particularly apparent when studying ultra-low permeability reservoirs.
In view of the above problems, no effective solution has been proposed.
Disclosure of Invention
The embodiment of the application provides a method and a device for establishing a three-dimensional permeability model, and aims to solve the technical problems of low model precision and large error of the existing modeling method.
The embodiment of the application provides a method for establishing a three-dimensional permeability model, which comprises the following steps:
acquiring result data of a target oil reservoir;
according to the result data of the target oil reservoir, establishing a stress field simulation geological model of the target oil reservoir;
according to the result data of the target oil reservoir and the logging information of the target oil reservoir, simulating a geological model through the stress field, and calculating to obtain the distribution data of the stress field of the target oil reservoir;
solving to obtain corrected permeability according to the target oil reservoir stress field distribution data, the logging information of the target oil reservoir and the well testing information of the target oil reservoir;
and establishing a three-dimensional permeability model of the target oil reservoir according to the corrected permeability.
In a preferred embodiment, the result data comprises: rock mechanics related parameters, stress field size and stress field horizontal maximum principal stress direction.
In a preferred embodiment, the obtaining of the result data of the target reservoir includes:
obtaining a drilling core sample of a target oil reservoir;
performing a rock triaxial stress experiment on the drilling core sample of the target oil reservoir to obtain the rock mechanics related parameters;
performing a rock acoustic emission experiment on the drilling core sample of the target oil reservoir to obtain the size of the stress field;
and obtaining the maximum main stress direction of the stress field level according to the logging information of the target oil reservoir.
In a preferred embodiment, establishing a stress field simulation geological model of the target reservoir according to the result data of the target reservoir comprises:
and according to the result data of the target oil reservoir, establishing a stress field simulation geological model of the target oil reservoir through mapping grid division.
In a preferred embodiment, solving to obtain the corrected permeability according to the target reservoir stress field distribution data, the logging data of the target reservoir and the testing data of the target reservoir includes:
calculating to obtain a crack fracture rate distribution parameter value of each measuring point in the target oil reservoir according to the stress field distribution data of the target oil reservoir;
calculating to obtain a crack density predicted value of each measuring point in the target oil reservoir according to the stress field distribution data of the target oil reservoir and the crack fracture rate distribution parameter value of each measuring point in the target oil reservoir;
dividing the target oil reservoir into a plurality of fracture development density areas according to the fracture density predicted value of each measuring point in the target oil reservoir;
and solving to obtain the corrected permeability of each measuring point in the target oil reservoir according to the logging information and the well testing information of the target oil reservoir.
In a preferred embodiment, the calculating, according to the target reservoir stress field distribution data, fracture rate distribution parameter values of each measurement point in the target reservoir includes:
calculating the fracture rate distribution parameter value of each measuring point in the target oil reservoir according to the stress field distribution data of the target oil reservoir and the following formula:
In(j)＝τn(j)/[τn](j)
It(j)＝σt(j)/[σt](j)
I(j)＝α(j)It(j)+β(j)In(j)
wherein, the [ alpha ], [ beta ]τn](j)Shear strength of rock at measurement point numbered j, C(j)Shear strength, σ, of rock when the normal stress at measurement point numbered j is zeron(j)The fracture surface shear stress at the measurement point numbered j,internal coefficient of friction, I, for measuring point numbered jn(j)Shear fracture Rate of crack, τ, for test Point numbered jn(j)Shear stress value of measurement point numbered j, It(j)Crack opening Rate, σ, for test Point numbered jt(j)The magnitude of the fracture surface tensile stress at the measurement point of number j [ sigma ]t](j)Rock tensile Strength at Point j, α(j)The ratio of open cracks at the measurement point of the number j, β(j)Shear crack ratio of measurement point numbered j, I(j)The crack fracture rate distribution parameter value at the measurement point numbered j is shown.
In a preferred embodiment, the calculating a predicted value of fracture density of each measurement point in the target reservoir according to the target reservoir stress field distribution data and the fracture rate distribution parameter value of each measurement point in the target reservoir includes:
calculating to obtain a crack density predicted value of each measuring point in the target oil reservoir according to the target oil reservoir stress field distribution data and the crack fracture rate distribution parameter value of each measuring point in the target oil reservoir and the following formula:
I(j)＜Ic,ξ(j)＝a1(j)I(j) 2+a2(j)
I(j)≥Ic,ξ(j)＝a1(j)I(j) 2+a2(j)+a3(j)(A(j)+a4(j))
wherein, I(j)The crack fracture rate distribution parameter value of the measuring point with the number j, IcIs I(j)Critical value of ξ(j)Predicted crack density at measurement point number j, a1(j)、a2(j)、a3(j)、a4(j)Is the undetermined constant of the measurement point numbered j, A(j)The energy value at the measurement point numbered j.
In a preferred embodiment, the obtaining, according to the well logging data and the well testing data of the target oil reservoir, the corrected permeability of each measuring point in the target oil reservoir by solving includes:
solving to obtain the average value of the logging permeability in each fracture development density area in the plurality of fracture development density areas according to the logging information of the target oil reservoir;
solving to obtain the well testing permeability in each fracture development density area in the plurality of fracture development density areas according to the target oil reservoir well testing data;
solving to obtain correction coefficients in each crack development density area in the plurality of crack development density areas according to the average value of the logging permeability in each crack development density area in the plurality of crack development density areas and the logging permeability value;
and solving to obtain the corrected permeability of each measuring point in the target oil reservoir according to the well logging information of the target oil reservoir and the correction coefficient in each fracture development density area in the plurality of fracture development density areas.
In a preferred embodiment, solving and obtaining an average value of the well logging permeability in each fracture development density zone of the plurality of fracture development density zones according to the well logging data of the target oil reservoir includes:
according to the logging information of the target oil reservoir, solving and obtaining the average value of the logging permeability in each fracture development density area in the plurality of fracture development density areas according to the following formula:
wherein,the average value of the well permeability in the F < th > fracture density development density region in the target oil deposit is K (phi)(j),MZ(j),Vsh(j))(j)The logging permeability of a measuring point numbered j in the ith small layer in the F-th crack density development density area is phi(j)、MZ(j)、Vsh(j)、VshPorosity, median particle size, and argillaceous content of the measuring point numbered j in the ith small layer in the F-th crack density development density area, hi(F)Is the ith small layer thickness h in the F-th crack density development density area(F)For the actual production interval thickness of the reservoir in the F-th fracture density development density region, niThe number of measuring points contained in the ith small layer in the F-th crack density development density area, N(F)The number of small layers included in the F-th fracture density development density zone.
In a preferred embodiment, solving and obtaining the well testing permeability in each fracture development density zone of the plurality of fracture development density zones according to the well testing data of the target oil reservoir includes:
according to the well testing data of the target oil reservoir, solving and obtaining the well testing permeability in each fracture development density area in the plurality of fracture development density areas according to the following formula:
wherein, KT(F)For well test permeability in the F-th fracture density development density zone in the target reservoir, Q(F)For well test yield, μ in the F-th fracture density development density zone in the target reservoir(F)Formation crude oil viscosity, r, in the density development zone for the F-th fracturee(F)For the radius of feed in the F-th fracture density development density zone, rw(F)For well radius in the F-th fracture density development density zone, Δ P(F)For the pressure difference of production in the F-th fracture density development density region, h(F)The thickness of the well testing oil deposit in the F-th fracture density development density area.
In a preferred embodiment, solving the correction coefficient in each fracture development density zone of the plurality of fracture development density zones according to the average value of the well logging permeability in each fracture development density zone of the plurality of fracture development density zones and the well logging permeability value comprises:
according to the average value and the well testing permeability value of the well logging permeability in each crack development density area in the crack development density areas, solving and obtaining the correction coefficient in each crack development density area in the crack development density areas according to the following formula:
wherein, said λ(F)Is the correction coefficient in the F-th crack density development density region, KT(F)For the test well permeability in the F-th fracture density development density zone,and the average value of the well logging permeability in the F-th fracture density development density area is shown.
In a preferred embodiment, solving the corrected permeability of each measuring point in the target reservoir according to the well logging data of the target reservoir and the correction coefficient in each fracture development density zone in the plurality of fracture development density zones comprises:
according to the logging information of the target oil reservoir and the correction coefficient in each fracture development density area in the plurality of fracture development density areas, solving and obtaining the correction permeability of each measuring point in the target oil reservoir according to the following formula:
wherein, the PERM(j)Corrected permeability, lambda, of the measurement point numbered j in the target reservoir(F)The correction coefficient is K (phi) in the F-th crack density development density area with the number of j measuring points(j),MZ(j),Vsh(j)) The log permeability for the measurement point numbered j.
Based on the same inventive concept, the embodiment of the present application further provides a device for establishing a three-dimensional permeability model, including:
the acquisition module is used for acquiring result data of the target oil reservoir;
the first establishing module is used for establishing a stress field simulation geological model of the target oil reservoir according to the result data of the target oil reservoir;
the calculation module is used for calculating to obtain target oil reservoir stress field distribution data through the stress field simulation geological model according to the result data of the target oil reservoir and the logging information of the target oil reservoir;
the correction module is used for solving and obtaining the corrected permeability of each measuring point in the target oil reservoir according to the target oil reservoir stress field distribution data, the target oil reservoir logging data and the target oil reservoir logging data;
and the second establishing module is used for establishing a three-dimensional permeability model of the target oil reservoir according to the corrected permeability of each measuring point in the target oil reservoir.
In the embodiment of the application, the influence of the micro-cracks on the permeability is considered in the process of establishing the three-dimensional permeability model, the logging permeability is corrected, and then the three-dimensional permeability model of the target oil reservoir is established according to the corrected permeability. The influence of the microcracks on the permeability is considered, so that the technical problems of low precision and large error in the existing modeling method are solved, and the purpose of improving the accuracy of the three-dimensional permeability model is achieved.
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In order to more clearly illustrate the embodiments of the present application or the technical solutions in the prior art, the drawings needed to be used in the description of the embodiments or the prior art will be briefly introduced below, it is obvious that the drawings in the following description are only some embodiments described in the present application, and for those skilled in the art, other drawings can be obtained according to the drawings without any creative effort.
FIG. 1 is a process flow diagram of a method of building a three-dimensional permeability model according to an embodiment of the present application;
FIG. 2 is a block diagram of the components of an apparatus for creating a three-dimensional permeability model according to an embodiment of the present application;
FIG. 3 is a diagram illustrating a distribution prediction of fracture crack rate distribution parameter values obtained by applying the method/apparatus for building a three-dimensional permeability model according to an embodiment of the present disclosure;
fig. 4 is a fracture density distribution prediction diagram obtained by applying the method/apparatus for establishing a three-dimensional permeability model provided in the embodiment of the present application.
Detailed Description
In order to make those skilled in the art better understand the technical solutions in the present application, the technical solutions in the embodiments of the present application will be clearly and completely described below with reference to the drawings in the embodiments of the present application, and it is obvious that the described embodiments are only a part of the embodiments of the present application, and not all of the embodiments. All other embodiments, which can be derived by a person skilled in the art from the embodiments given herein without making any creative effort, shall fall within the protection scope of the present application.
In view of existing modeling methods, it is common to build a three-dimensional permeability model of a geological reservoir of a target reservoir directly from the log permeability. The permeability of the well logging is directly adopted, and the influence of the micro-cracks developed in the reservoir on the actual permeability is not considered, so that the established three-dimensional permeability model is inaccurate, and the technical problems of low precision and large error often exist. Aiming at the root cause of the technical problems, the influence of the micro-cracks in the geological reservoir of the target oil reservoir on the permeability is considered, the logging permeability is corrected according to the well testing data, more accurate corrected permeability is obtained, and then a three-dimensional permeability model is established according to the corrected permeability. Therefore, the technical problems of poor modeling precision and large error in the existing modeling method can be solved, and the technical effect of improving the accuracy of the established three-dimensional permeability model is realized.
Based on the thought, the application provides a method for establishing a three-dimensional permeability model. Please refer to fig. 1. The method for establishing the three-dimensional permeability model provided by the application can comprise the following steps.
Step 11: and acquiring result data of the target oil reservoir.
In this embodiment, the result data may include: rock mechanics related parameters, stress field size and stress field horizontal maximum principal stress direction. Of course, besides the rock mechanics related parameters, the magnitude of the stress field and the direction of the maximum principal stress of the stress field level listed above, the result data may also include other corresponding geological data according to specific implementation conditions and actual requirements.
In a preferred embodiment, in order to obtain the result data, the target oil reservoir may be sampled, and then the corresponding result data may be obtained by performing a test on the sample. The method can be implemented according to the following steps:
s1: and obtaining a drilling core sample of the target oil reservoir.
S2: and carrying out a rock triaxial stress experiment on the drilling core sample of the target oil reservoir to obtain the rock mechanics related parameters.
S3: and carrying out a rock acoustic emission experiment on the drilling core sample of the target oil reservoir to obtain the size of the stress field.
S4: and obtaining the maximum main stress direction of the stress field level according to the logging information of the target oil reservoir.
Step 12: and establishing a stress field simulation geological model of the target oil reservoir according to the result data of the target oil reservoir.
In a preferred embodiment, in order to fully utilize the result data and establish the stress field simulation geological model, the stress field simulation geological model of the target oil deposit can be established by mapping grid division according to the result data of the target oil deposit. The mapping mesh division may specifically be mesh division according to a mesh division principle, and a three-dimensional regular mesh is established.
Step 13: and calculating to obtain target oil reservoir stress field distribution data through the stress field simulation geological model according to the result data of the target oil reservoir and the target oil reservoir logging information.
In this embodiment, the target reservoir stress field distribution data may specifically include the following data according to actual research requirements and specific implementation conditions: the shear strength of the rock at each measuring point, the shear strength of the rock when the normal stress of each measuring point is zero, the fracture surface shear stress of each measuring point, the internal friction coefficient of each measuring point, the fracture shear fracture rate of each measuring point, the shear stress value of each measuring point, the fracture tensile fracture rate of each measuring point, the fracture surface tensile stress of each measuring point, the rock tensile strength of each measuring point, the tension fracture proportion of each measuring point, the shear fracture proportion of each measuring point, the fracture rate distribution parameter value of each measuring point and the like.
In a preferred embodiment, in order to fully utilize the result data of the target oil reservoir, the logging information of the target oil reservoir and the established stress field simulation geological model, the stress field distribution data of the target oil reservoir is obtained. In specific implementation, the following steps are carried out: according to the established geological model, rock mechanical parameters (Young modulus, Poisson ratio, rock density and the like) in the obtained result data are utilized to carry out numerical simulation research on the target oil reservoir stress field by a finite element method, relevant programs of SuperSAP (Super structural analysis & design program, short for structural analysis design program) are utilized, the parameter values are selected to carry out adjustment calculation, and a target oil reservoir stress field characteristic diagram is obtained. Of course, it should be noted that the target reservoir stress characteristic map obtained here is only used to more intuitively reflect the target reservoir stress situation, and is convenient for researchers in the field to read and analyze the relevant stress data. The method and the device do not limit whether the target reservoir stress field characteristic diagram is drawn or not. During construction, whether a target oil reservoir stress field characteristic diagram is drawn or not can be flexibly selected according to specific conditions and specific requirements.
In the above embodiment, the SuperSAP used is a program software programmed according to the finite elements of the structure for calculating the stress field or the temperature field of the large-volume or large-area object. Of course, it should be noted that, in the specific implementation of the present application, the SuperSAP may be used to assist in calculating and obtaining the target reservoir stress field distribution data, and other similar software may also be used to assist in obtaining the required target reservoir stress field distribution data. The present application is not limited thereto.
Step 14: and solving to obtain the corrected permeability according to the target oil reservoir stress field distribution data, the target oil reservoir logging data and the target oil reservoir well testing data.
In a preferred embodiment, in order to fully utilize the result data of the target reservoir, the target reservoir logging data and the target reservoir stress field distribution data, the corrected permeability of each measuring point in each of the plurality of fracture development density zones in the target reservoir is obtained. The method can be specifically executed according to the following steps:
s1: and calculating to obtain a fracture rate distribution parameter value according to the target oil reservoir stress field distribution data.
S2: and calculating to obtain a fracture density predicted value according to the target oil reservoir stress field distribution data and the fracture rate distribution parameter value.
S3: and dividing the target oil reservoir into a plurality of fracture development density areas according to the fracture density predicted value.
S4: and solving to obtain the corrected permeability of each measuring point in each fracture development density area in the plurality of fracture development density areas according to the target oil reservoir logging information and the well testing information.
In a preferred embodiment, in order to calculate the fracture rate according to the target reservoir stress field distribution data, the following formula can be specifically solved to obtain the distribution parameter value of the fracture rate of each measuring point:
In(j)＝τn(j)/[τn](j)
It(j)＝σt(j)/[σt](j)
I(j)＝α(j)It(j)+β(j)In(j)
wherein [ tau ]n](j)Shear strength of rock at measurement point numbered j, C(j)Shear strength, σ, of rock when the normal stress at measurement point numbered j is zeron(j)The fracture surface shear stress at the measurement point numbered j,internal coefficient of friction, I, for measuring point numbered jn(j)The fracture shear failure rate at test point numbered j,τn(j)shear stress value of measurement point numbered j, It(j)Crack opening Rate, σ, for test Point numbered jt(j)The magnitude of the fracture surface tensile stress at the measurement point of number j [ sigma ]t](j)Rock tensile Strength at Point j, α(j)The ratio of open cracks at the measurement point of the number j, β(j)Shear crack ratio of measurement point numbered j, I(j)The crack fracture rate distribution parameter value at the measurement point numbered j is shown.
In a preferred embodiment, in order to obtain a fracture density predicted value by calculation according to target reservoir stress field distribution data and fracture rate distribution parameter values, the fracture density predicted value at each measurement point can be obtained by solving according to the following formula:
I(j)＜Ic,ξ(j)＝a1(j)I(j) 2+a2(j)
I(j)≥Ic,ξ(j)＝a1(j)I(j) 2+a2(j)+a3(j)(A(j)+a4(j))
wherein, I(j)The crack fracture rate distribution parameter value of the measuring point with the number j, IcIs I(j)Critical value of ξ(j)Predicted crack density at measurement point number j, a1(j)、a2(j)、a3(j)、a4(j)Is the undetermined constant of the measurement point numbered j, A(j)The energy value at the measurement point numbered j.
In a preferred embodiment, in order to solve and obtain the corrected permeability of each measuring point in each fracture development density zone in the plurality of fracture development density zones according to the target reservoir logging data and the well test data, the following steps may be specifically performed:
s4_ 1: and solving to obtain the average value of the logging permeability in each fracture development density area in the plurality of fracture development density areas according to the target oil deposit logging information.
S4_ 2: and solving to obtain the well testing permeability in each fracture development density area in the plurality of fracture development density areas according to the target oil reservoir well testing data.
S4_ 3: and solving to obtain a correction coefficient in each fracture development density area in the plurality of fracture development density areas according to the average value of the logging permeability in each fracture development density area in the plurality of fracture development density areas and the logging permeability value.
S4_ 4: and solving to obtain the corrected permeability of each measuring point in each fracture development density area in the plurality of fracture development density areas according to the well logging information of the target oil reservoir and the correction coefficient in each fracture development density area in the plurality of fracture development density areas.
In a preferred embodiment, in order to obtain an average value of the logging permeability in each fracture development density zone of the plurality of fracture development density zones according to the target reservoir logging information, specifically, the average value of the logging permeability in each fracture development density zone of the plurality of fracture development density zones according to the target reservoir logging information and the following formula may be obtained:
wherein,the average value of the well permeability in the F < th > fracture density development density region in the target oil deposit is K (phi)(j),MZ(j),Vsh(j))(j)The logging permeability of a measuring point numbered j in the ith small layer in the F-th crack density development density area is phi(j)、MZ(j)、Vsh(j)、VshRespectively the porosity and the median particle size of a measuring point numbered j in the ith small layer in the F-th crack density development density areaMud content, hi(F)Is the ith small layer thickness h in the F-th crack density development density area(F)For the actual production interval thickness of the reservoir in the F-th fracture density development density region, niThe number of measuring points contained in the ith small layer in the F-th crack density development density area, N(F)The number of small layers included in the F-th fracture density development density zone.
In a preferred embodiment, in order to fully utilize the target reservoir well testing data to obtain the well testing permeability in each fracture development density zone of the plurality of fracture development density zones, the well testing permeability in each fracture development density zone of the plurality of fracture development density zones may be obtained by solving according to the target reservoir well testing data and according to the following formula:
wherein, KT(F)For well test permeability in the F-th fracture density development density zone in the target reservoir, Q(F)For well test yield, μ in the F-th fracture density development density zone in the target reservoir(F)Formation crude oil viscosity, r, in the density development zone for the F-th fracturee(F)For the radius of feed in the F-th fracture density development density zone, rw(F)For well radius in the F-th fracture density development density zone, Δ P(F)For the pressure difference of production in the F-th fracture density development density region, h(F)The thickness of the well testing oil deposit in the F-th fracture density development density area.
In a preferred embodiment, in order to obtain the correction coefficient in each of the plurality of fracture development density regions according to the average value of the well logging permeability and the well testing permeability value in each of the plurality of fracture development density regions, specifically, the correction coefficient in each of the plurality of fracture development density regions may be obtained by solving according to the following formula according to the average value of the well logging permeability and the well testing permeability value in each of the plurality of fracture development density regions:
wherein, said λ(F)Is the correction coefficient in the F-th crack density development density region, KT(F)For the test well permeability in the F-th fracture density development density zone,and the average value of the well logging permeability in the F-th fracture density development density area is shown.
In a preferred embodiment, the corrected permeability of each measuring point in each fracture development density zone in the plurality of fracture development density zones is obtained according to the well logging data of the target oil reservoir and the correction coefficient in each fracture development density zone in the plurality of fracture development density zones. Specifically, according to the well logging data of the target oil reservoir and the correction coefficient in each fracture development density region in the plurality of fracture development density regions, the correction permeability of each measuring point in each fracture development density region in the plurality of fracture development density regions can be obtained by solving according to the following formula:
wherein, the PERM(j)Corrected permeability, lambda, of the measurement point numbered j in the target reservoir(F)The correction coefficient is K (phi) in the F-th crack density development density area with the number of j measuring points(j),MZ(j),Vsh(j)) The log permeability for the measurement point numbered j.
Step 15: and establishing a three-dimensional permeability model of the target oil reservoir according to the corrected permeability.
In a preferred embodiment, in order to establish the three-dimensional permeability model of the target reservoir, the three-dimensional permeability model of the target reservoir may be established by using geological modeling software and through variation function analysis according to the corrected permeability. It is worth noting that the three-dimensional permeability model obtained through establishment can show that the permeability obviously shows a spatial distribution difference along with the density of the cracks.
In the embodiment of the application, compared with the existing modeling method, the three-dimensional permeability modeling method has the advantages that the logging permeability is corrected according to the well testing data to obtain the corrected permeability, and then the three-dimensional permeability model is established according to the corrected permeability, so that the technical problems that the established three-dimensional permeability model is low in precision and large in error in the existing modeling method are solved, and the technical effect of improving the accuracy of establishing the three-dimensional permeability model is achieved.
Based on the same inventive concept, the embodiment of the present invention further provides an apparatus for establishing a three-dimensional permeability model, as described in the following embodiments. Because the principle of solving the problems by the device is similar to the method for establishing the three-dimensional permeability model, the implementation of the device can refer to the implementation of the method for establishing the three-dimensional permeability model, and repeated parts are not repeated. As used hereinafter, the term "unit" or "module" may be a combination of software and/or hardware that implements a predetermined function. Although the means described in the embodiments below are preferably implemented in software, an implementation in hardware, or a combination of software and hardware is also possible and contemplated. Referring to fig. 2, a block diagram of an apparatus for building a three-dimensional permeability model according to an embodiment of the present disclosure is shown, where the apparatus may include: the acquiring module 201, the first establishing module 202, the calculating module 203, the correcting module 204 and the second establishing module 205, and the structure will be described in detail below.
An obtaining module 201, configured to obtain result data of a target oil reservoir, where the result data includes: rock mechanics related parameters, stress field size and stress field horizontal maximum main stress direction;
the first establishing module 202 is configured to establish a stress field simulation geological model of the target oil reservoir according to the result data of the target oil reservoir;
the calculation module 203 is used for calculating to obtain target oil reservoir stress field distribution data through the stress field simulation geological model according to the result data of the target oil reservoir and the target oil reservoir logging information;
the correcting module 204 is used for solving and obtaining corrected permeability according to the target oil reservoir stress field distribution data, the target oil reservoir logging data and the target oil reservoir logging data;
and a second establishing module 205, configured to establish a three-dimensional permeability model of the target oil reservoir according to the corrected permeability.
In a specific application scenario, for example, the method/apparatus for building a three-dimensional permeability model according to the present application is used to perform an analysis and research on a target reservoir in a certain area, which may be specifically performed according to the following steps.
S1: developing stress field simulation and predicting target reservoir fracture development and distribution rule
S1-1, recording the actual well drilling rock core of the target oil reservoir, developing a rock triaxial stress experiment, and obtaining key rock mechanics related parameters (rock porosity, rock density, tensile strength, Young modulus, Poisson ratio, expansion angle, internal friction angle and cohesion); and carrying out a rock acoustic emission experiment to obtain the magnitude of the ground stress field stress.
And S1-2, analyzing the target oil reservoir logging information and obtaining the maximum main stress direction of the stress field level.
S1-3, integrating the geological research results and experimental results of the target oil reservoir, and establishing a three-dimensional regular grid by adopting mapping grid division, thereby establishing a geological model for simulating the stress field of the target oil reservoir.
And S1-4, according to the established geological model, carrying out numerical simulation research on the stress field of the target oil reservoir by using the obtained rock mechanical parameters (Young modulus, Poisson ratio, rock density and the like) by adopting a finite element method, and selecting the parameter values to adjust and calculate by using a SuperSAP related program to obtain a characteristic diagram of the stress field of the target oil reservoir.
S1-5, calculating crack breaking rate distribution parameter value
Calculating fracture rate distribution parameter values of different drilling cores one by using the formula 1, and compiling a fracture rate distribution parameter value distribution prediction chart by using an established geological model and a random modeling method of geological modeling software. Referring specifically to fig. 3, the black dots and numbers indicate the different well locations.
Total fracture split distribution parameter value: i isGeneral assembly＝αIt+βIn
In the formula: a. beta is the ratio of open cracks to shear cracks observed and counted by the rock core.
Fracture shear fracture rate: i isn＝τn/[τn]
In the formula: tau isnIs the shear stress value, in units: MPa; [ tau ] ton]Shear strength of rock, unit: MPa.
In the formula: c is cohesive force, and is the shear strength of the rock when the normal stress is zero, and the unit is as follows: MPa;internal friction angle, unit: (iv) DEG;the internal friction coefficient.
Fracture tensile failure rate: i ist＝σt/[σt]
In the formula: sigmatThe fracture surface tensile stress is the magnitude; [ sigma ]t]Rock tensile strength.
S1-6, calculating and predicting the crack density
Predicting the crack density of the target area according to a binary method prediction crack density method (formula 2), and making a crack density distribution prediction map according to the crack density, which can be specifically referred to as fig. 4.
I＜Ic,β＝a1I2+a2
I＞Ic,β＝a1I2+a2+a3(A+a4)
Wherein β is the predicted value of crack density, I is the fracture value, a1，a2，a3，a4Four undetermined constants; i iscA critical value for the rupture value I; a is the energy value.
S2: developing dynamic analysis of oil reservoir to obtain dynamic permeability of target oil reservoir
Analyzing dynamic monitoring data of the target oil reservoir, particularly well testing data, carrying out well testing analysis on the well testing data of each well by utilizing the seepage mechanics theory (formula 3), and explaining the dynamic permeability of each well of the target oil reservoir.
In the formula: kTIs the dynamic permeability of the oil reservoir, unit: mum of2(ii) a Q is the well production, unit: cm3(iv)/s (underground value); μ is the formation crude oil viscosity in units: mPa.s; r iseFor the feed radius, the unit: cm; r iswIs the well radius, in units: cm; Δ P is the differential production pressure, in units: MPa, h is reservoir thickness, unit: cm.
S3: establishing a corresponding relation between the well testing permeability and the well logging permeability
And according to the established corresponding relation between different fracture development density areas and well testing positions, establishing the corresponding relation between different well testing permeabilities and well logging permeabilities according to the different fracture development density areas, and further obtaining a well testing permeability correction model. The specific process is as follows:
s-1, calculating the permeability of the actual production interval of the oil reservoir by using an average value method of the logging permeability
In the formula:the average value of the well testing permeability of the actual production interval of the oil reservoir is as follows, unit: mum of2；K(φ,MZ,Vsh) Logging permeability for the ith sub-layer jth sample point, in units: mum of2；φ、Mz、VshThe porosity, the median particle size and the argillaceous content of the ith sampling point of the ith small layer are respectively; h isiIs ith minor layer thickness, unit: m; h is the thickness of the actual production interval of the oil reservoir, unit: m; n is1Logging permeability points contained in the ith sublayer; n is2The pressure measurement layer section comprises a small number of layers.
S3-2, introducing a correction coefficient lambda in order to establish a correction model of the well testing permeability and the well logging permeability, and establishing corresponding relations between different well testing permeabilities and different well logging permeabilities.
And S3-3, establishing a correction model of the logging permeability by using different correction coefficients for different crack density development areas by using the correction coefficient lambda.
Specifically, referring to table 1, table 1 shows the correction coefficient between the dynamic permeability and the logging permeability obtained by the above method. As can be seen from the table, the dynamic permeability is very different from the logging permeability. Wherein, the difference between the two can reach 47 times at the maximum, 6 times at the minimum, and generally varies between 10-25 times.
TABLE 1 dynamic correction coefficient for well logging interpretation permeability
Note: in the table, the volume coefficient of the crude oil was calculated to be 1.112, and the viscosity of the crude oil was calculated to be 6.7 mPas.
The permeability of the oil reservoir dynamic test can reflect the seepage characteristics of the oil reservoir and is closer to the real permeability of the oil reservoir. When the logging permeability is corrected by the production dynamic permeability, a logging Permeability (PERM) dynamic correction model can be established, namely:
PERM＝λ×K(φ,Mz,Vsh)
s4: and establishing a permeability three-dimensional model by using the corrected logging permeability.
According to the corrected permeability, geological modeling software is utilized, a three-dimensional permeability model of the target oil reservoir is established through variation function analysis, and spatial distribution differences can be obviously shown along with the density of the cracks in the three-dimensional permeability model. By means of specific implementation, the following two main points can be presented:
1. in areas with high local crack density, the permeability is also high, which mainly means that the cracks make great contribution to the permeability;
2. the permeability of the reservoir in the area with low fracture density is low, the reservoir is mainly influenced by the permeability of the matrix, and the local permeability is low due to few fractures.
The effect on permeability caused by the crack density is very consistent with the actual development of the region. In the blocks with large fracture density, the yield in the initial development stage is better, and the flooding in the later development stage is very serious, because the permeability of the blocks is higher, the fluid can smoothly flow into a shaft along the fractures, but because of the existence of a large number of fractures, the injected water can easily enter along the fractures, so that the phenomena of quick water breakthrough of the oil well and serious flooding in the later development stage are caused. In the low permeability area with low crack development density, although the oil well liquid production is low, the water content rising speed is relatively slow, and the phenomenon of water injection plunging is not obvious. This not only fully accounts for the correctness of the created fracture model. It is also shown that the influence of the fracture on the local permeability of the ultra-low permeability reservoir can be very obvious. Therefore, the method or the device for establishing the three-dimensional permeability model can accurately establish the reservoir permeability model and provide reliable basis for oil reservoir development.
Compared with the existing modeling method, the method and the device for establishing the three-dimensional permeability model provided by the embodiment of the application firstly obtain the result data of the target oil reservoir, establish the geological model for simulating the stress field of the target oil reservoir according to the result data, and obtain the parameter data through the geological model for simulating the stress field of the target oil reservoir; considering the influence of the micro-cracks in the reservoir on the actual permeability, correcting the logging permeability according to the parameter data and the well testing data to obtain the corrected permeability; and establishing a three-dimensional permeability model according to the corrected permeability. According to the method, the three-dimensional permeability model is established according to the corrected permeability, so that the technical problems of low precision and large error existing in the existing establishment of the three-dimensional permeability model according to the logging permeability are solved, and the technical effect of improving the accuracy of establishing the three-dimensional permeability model is realized; in addition, the correction coefficients in different crack density development areas are respectively calculated, and the well logging permeability in the different crack density development areas is corrected in a targeted mode according to the correction coefficients of the different crack density development areas, so that the accuracy of building a three-dimensional permeability model is further improved.
Although the present application provides method steps as described in an embodiment or flowchart, more or fewer steps may be included based on conventional or non-inventive means. The order of steps recited in the embodiments is merely one manner of performing the steps in a multitude of orders and does not represent the only order of execution. When an apparatus or client product in practice executes, it may execute sequentially or in parallel (e.g., in a parallel processor or multithreaded processing environment, or even in a distributed data processing environment) according to the embodiments or methods shown in the figures. The terms "comprises," "comprising," or any other variation thereof, are intended to cover a non-exclusive inclusion, such that a process, method, article, or apparatus that comprises a list of elements does not include only those elements but may include other elements not expressly listed or inherent to such process, method, article, or apparatus. Without further limitation, the presence of additional identical or equivalent elements in a process, method, article, or apparatus that comprises the recited elements is not excluded.
The devices or modules and the like explained in the above embodiments may be specifically implemented by a computer chip or an entity, or implemented by a product with certain functions. For convenience of description, the above devices are described as being divided into various modules by functions, and are described separately. Of course, in implementing the present application, the functions of each module may be implemented in one or more pieces of software and/or hardware, or a module that implements the same function may be implemented by a combination of a plurality of sub-modules, and the like. The above-described apparatus embodiments are merely illustrative, and for example, the division of the modules is merely a logical division, and other divisions may be realized in practice, for example, a plurality of modules or components may be combined or integrated into another system, or some features may be omitted, or not executed.
Those skilled in the art will also appreciate that, in addition to implementing the controller as pure computer readable program code, the same functionality can be implemented by logically programming method steps such that the controller is in the form of logic gates, switches, application specific integrated circuits, programmable logic controllers, embedded microcontrollers and the like. Such a controller may therefore be considered as a hardware component, and the means included therein for performing the various functions may also be considered as a structure within the hardware component. Or even means for performing the functions may be regarded as being both a software module for performing the method and a structure within a hardware component.
The application may be described in the general context of computer-executable instructions, such as program modules, being executed by a computer. Generally, program modules include routines, programs, objects, components, data structures, classes, etc. that perform particular tasks or implement particular abstract data types. The application may also be practiced in distributed computing environments where tasks are performed by remote processing devices that are linked through a communications network. In a distributed computing environment, program modules may be located in both local and remote computer storage media including memory storage devices.
The embodiments in the present specification are described in a progressive manner, and the same or similar parts among the embodiments are referred to each other, and each embodiment focuses on the differences from the other embodiments. The application is operational with numerous general purpose or special purpose computing system environments or configurations. For example: personal computers, server computers, hand-held or portable devices, tablet-type devices, multiprocessor systems, microprocessor-based systems, set top boxes, programmable electronic devices, network PCs, minicomputers, mainframe computers, distributed computing environments that include any of the above systems or devices, and the like.
While the present application has been described with examples, those of ordinary skill in the art will appreciate that there are numerous variations and permutations of the present application without departing from the spirit of the application, and it is intended that the appended claims encompass such variations and permutations without departing from the present application.
Claims (13)
1. A method of building a three-dimensional permeability model, comprising:
acquiring result data of a target oil reservoir;
according to the result data of the target oil reservoir, establishing a stress field simulation geological model of the target oil reservoir;
according to the result data of the target oil reservoir and the logging information of the target oil reservoir, simulating a geological model through the stress field, and calculating to obtain the distribution data of the stress field of the target oil reservoir;
solving to obtain corrected permeability according to the target oil reservoir stress field distribution data, the logging information of the target oil reservoir and the well testing information of the target oil reservoir;
and establishing a three-dimensional permeability model of the target oil reservoir according to the corrected permeability.
2. The method of claim 1, wherein the result data comprises: rock mechanics related parameters, stress field size and stress field horizontal maximum principal stress direction.
3. The method of claim 2, wherein obtaining result data for the target reservoir comprises:
obtaining a drilling core sample of a target oil reservoir;
performing a rock triaxial stress experiment on the drilling core sample of the target oil reservoir to obtain the rock mechanics related parameters;
performing a rock acoustic emission experiment on the drilling core sample of the target oil reservoir to obtain the size of the stress field;
and obtaining the maximum main stress direction of the stress field level according to the logging information of the target oil reservoir.
4. The method of claim 2, wherein building a stress field simulation geological model of the target reservoir from the result data of the target reservoir comprises:
and according to the result data of the target oil reservoir, establishing a stress field simulation geological model of the target oil reservoir through mapping grid division.
5. The method of claim 2, wherein solving for corrected permeability according to the target reservoir stress field distribution data, the log data of the target reservoir and the test data of the target reservoir comprises:
calculating to obtain a crack fracture rate distribution parameter value of each measuring point in the target oil reservoir according to the stress field distribution data of the target oil reservoir;
calculating to obtain a crack density predicted value of each measuring point in the target oil reservoir according to the stress field distribution data of the target oil reservoir and the crack fracture rate distribution parameter value of each measuring point in the target oil reservoir;
dividing the target oil reservoir into a plurality of fracture development density areas according to the fracture density predicted value of each measuring point in the target oil reservoir;
and solving to obtain the corrected permeability of each measuring point in the target oil reservoir according to the logging information of the target oil reservoir and the well testing information of the target oil reservoir.
6. The method of claim 5, wherein the step of calculating fracture rate distribution parameter values of each measuring point in the target reservoir according to the target reservoir stress field distribution data comprises:
calculating the fracture rate distribution parameter value of each measuring point in the target oil reservoir according to the stress field distribution data of the target oil reservoir and the following formula:
In(j)＝τn(j)/[τn](j)
It(j)＝σt(j)/[σt](j)
I(j)＝α(j)It(j)+β(j)In(j)
wherein [ tau ]n](j)Shear strength of rock at measurement point numbered j, C(j)Shear strength, σ, of rock when the normal stress at measurement point numbered j is zeron(j)The fracture surface shear stress at the measurement point numbered j,internal coefficient of friction, I, for measuring point numbered jn(j)Crack shear fracture at test point numbered jRate, τn(j)Shear stress value of measurement point numbered j, It(j)Crack opening Rate, σ, for test Point numbered jt(j)The magnitude of the fracture surface tensile stress at the measurement point of number j [ sigma ]t](j)Rock tensile Strength at Point j, α(j)The ratio of open cracks at the measurement point of the number j, β(j)Shear crack ratio of measurement point numbered j, I(j)The crack fracture rate distribution parameter value at the measurement point numbered j is shown.
7. The method of claim 5, wherein the step of calculating a predicted fracture density value of each measuring point in the target reservoir according to the target reservoir stress field distribution data and the fracture rate distribution parameter value of each measuring point in the target reservoir comprises:
calculating to obtain a crack density predicted value of each measuring point in the target oil reservoir according to the target oil reservoir stress field distribution data and the crack fracture rate distribution parameter value of each measuring point in the target oil reservoir and the following formula:
I(j)＜Ic,ξ(j)＝a1(j)I(j) 2+a2(j)
I(j)≥Ic,ξ(j)＝a1(j)I(j) 2+a2(j)+a3(j)(A(j)+a4(j))
wherein, I(j)The crack fracture rate distribution parameter value of the measuring point with the number j, IcIs I(j)Critical value of ξ(j)Predicted crack density at measurement point number j, a1(j)、a2(j)、a3(j)、a4(j)Is the undetermined constant of the measurement point numbered j, A(j)The energy value at the measurement point numbered j.
8. The method of claim 5, wherein solving for the corrected permeability of each measurement point in the target reservoir according to the well logging data of the target reservoir and the well testing data of the target reservoir comprises:
solving to obtain the average value of the logging permeability in each fracture development density area in the plurality of fracture development density areas according to the logging information of the target oil reservoir;
solving to obtain the well testing permeability in each fracture development density area in the plurality of fracture development density areas according to the target oil reservoir well testing data;
solving to obtain correction coefficients in each crack development density area in the plurality of crack development density areas according to the average value of the logging permeability in each crack development density area in the plurality of crack development density areas and the logging permeability value;
and solving to obtain the corrected permeability of each measuring point in the target oil reservoir according to the well logging information of the target oil reservoir and the correction coefficient in each fracture development density area in the plurality of fracture development density areas.
9. The method of claim 8, wherein solving for an average of the log permeabilities in each of the plurality of fracture development density zones based on the log data of the target reservoir comprises:
according to the logging information of the target oil reservoir, solving and obtaining the average value of the logging permeability in each fracture development density area in the plurality of fracture development density areas according to the following formula:
wherein,the average value of the well permeability in the F < th > fracture density development density region in the target oil deposit is K (phi)(j),MZ(j),Vsh(j))(j)The logging permeability of a measuring point numbered j in the ith small layer in the F-th crack density development density area is phi(j)、MZ(j)、Vsh(j)、VshPorosity, median particle size, and argillaceous content of the measuring point numbered j in the ith small layer in the F-th crack density development density area, hi(F)Is the ith small layer thickness h in the F-th crack density development density area(F)For the actual production interval thickness of the reservoir in the F-th fracture density development density region, niThe number of measuring points contained in the ith small layer in the F-th crack density development density area, N(F)The number of small layers included in the F-th fracture density development density zone.
10. The method of claim 8, wherein solving for the well test permeability in each of the plurality of fracture development density zones according to the well test data of the target reservoir comprises:
according to the well testing data of the target oil reservoir, solving and obtaining the well testing permeability in each fracture development density area in the plurality of fracture development density areas according to the following formula:
wherein, KT(F)For well test permeability in the F-th fracture density development density zone in the target reservoir, Q(F)For well test yield, μ in the F-th fracture density development density zone in the target reservoir(F)Formation crude oil viscosity, r, in the density development zone for the F-th fracturee(F)For the radius of feed in the F-th fracture density development density zone, rw(F)For well radius in the F-th fracture density development density zone, Δ P(F)For the pressure difference of production in the F-th fracture density development density region, h(F)The thickness of the well testing oil deposit in the F-th fracture density development density area.
11. The method of claim 8, wherein solving for the correction factor in each of the plurality of fracture development density zones based on the average of the log permeability and the test permeability value in each of the plurality of fracture development density zones comprises:
according to the average value and the well testing permeability value of the well logging permeability in each crack development density area in the crack development density areas, solving and obtaining the correction coefficient in each crack development density area in the crack development density areas according to the following formula:
wherein, said λ(F)Is the correction coefficient in the F-th crack density development density region, KT(F)For the test well permeability in the F-th fracture density development density zone,and the average value of the well logging permeability in the F-th fracture density development density area is shown.
12. The method of claim 8, wherein solving for the corrected permeability of each of the plurality of sites in the target reservoir based on the well log data of the target reservoir and the correction coefficients in each of the plurality of fracture development density zones comprises:
according to the logging information of the target oil reservoir and the correction coefficient in each fracture development density area in the plurality of fracture development density areas, solving and obtaining the correction permeability of each measuring point in the target oil reservoir according to the following formula:
wherein, the PERM(j)Corrected permeability, lambda, of the measurement point numbered j in the target reservoir(F)The correction coefficient is K (phi) in the F-th crack density development density area with the number of j measuring points(j),MZ(j),Vsh(j)) The log permeability for the measurement point numbered j.
13. An apparatus for creating a three-dimensional permeability model, comprising:
the acquisition module is used for acquiring result data of the target oil reservoir;
the first establishing module is used for establishing a stress field simulation geological model of the target oil reservoir according to the result data of the target oil reservoir;
the calculation module is used for calculating to obtain target oil reservoir stress field distribution data through the stress field simulation geological model according to the result data of the target oil reservoir and the logging information of the target oil reservoir;
the correction module is used for solving and obtaining the corrected permeability of each measuring point in the target oil reservoir according to the target oil reservoir stress field distribution data, the target oil reservoir logging data and the target oil reservoir logging data;
and the second establishing module is used for establishing a three-dimensional permeability model of the target oil reservoir according to the corrected permeability of each measuring point in the target oil reservoir.
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