CN108957581B - Method for analyzing shale stratum rock physical anisotropy - Google Patents
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Abstract
The invention discloses a method for analyzing shale stratum rock physical anisotropy, which comprises the following steps: collecting shale formation mineral content, kerogen content, pore fluid content, and pore structure, the mineral content comprising content of directionally arranged clays, non-directionally arranged clays, and skeletal minerals; calculating the equivalent elastic modulus of the skeleton mineral; calculating the equivalent elastic modulus of the mixed minerals of the skeleton mineral and the non-directionally arranged clay; calculating the equivalent elastic modulus of the dry rock; calculating the equivalent elastic modulus of the mixed fluid; calculating the equivalent elastic modulus of the saturated rock; calculating the equivalent elastic modulus of the anisotropic medium of the shale stratum; the longitudinal and transverse wave velocities in the horizontal and vertical directions are calculated, as well as the anisotropy parameters. The method can analyze the rock physical anisotropy of the shale stratum; compared with the prior art, the method has the advantages of simple process, accurate result and low implementation difficulty.
Description
Technical Field
The invention relates to the field of geological exploration, in particular to a method for analyzing shale stratum rock physical anisotropy.
Background
In the process of developing and utilizing geological resources, in order to confirm the development value of geological resource points and make development plans, the real and detailed rock physical characteristics of the geological resource points need to be acquired.
However, due to the invisibility of the formation rock, the skilled person usually describes the petrophysical properties of the actual geological resource point indirectly by interpreting experimental measurements or well logs. Or further, the experimental determination or the well logging data interpretation is further analyzed, and the rock physical characteristics of the actual geological resource point are predicted by using the analysis result. Therefore, before the development and utilization of geological resources, it is necessary to analyze experimental measurement or well-logging data interpretation to obtain an analysis result as detailed and accurate as possible. The analysis result aiming at experimental determination or well logging data interpretation can directly influence the finally obtained rock physical characteristic description of the geological resource point.
Disclosure of Invention
The invention provides a method for analyzing rock physical anisotropy of a shale stratum, which comprises the following steps:
(1) collecting shale formation mineral content, kerogen content, pore fluid content and pore structure which are determined by experiments or explained by logging data, wherein the mineral content comprises the content of directionally arranged clay, non-directionally arranged clay and skeleton minerals;
(2) calculating the equivalent elastic modulus of the skeleton mineral;
(3) calculating the equivalent elastic modulus of the mixed minerals of the skeleton mineral and the non-directionally arranged clay;
(4) calculating an equivalent elastic modulus of the dry rock based on the equivalent elastic modulus of the mixed minerals and the pore structure;
(5) calculating an equivalent elastic modulus of a mixed fluid based on the pore fluid content and the kerogen content, the mixed fluid comprising oil, gas, water, and kerogen;
(6) calculating an equivalent elastic modulus of saturated rock based on the equivalent elastic modulus of the mixed fluid and the equivalent elastic modulus of the dry rock;
(7) calculating an equivalent elastic modulus of the anisotropic medium of the shale formation based on the clay content of the directional arrangement and the equivalent elastic modulus of the saturated rock in combination with the anisotropy caused by the directional arrangement of the clay mineral particles;
(8) and calculating the longitudinal and transverse wave speeds in the horizontal and vertical directions and the anisotropy parameters based on the equivalent elastic modulus of the shale formation anisotropic medium.
In one embodiment, the content of the directionally arranged clay, the content of the non-directionally arranged clay, and the pore structure in the step (1) are determined by an electron microscope scanning method.
In one embodiment, the equivalent elastic modulus of the skeletal mineral is calculated in step (2) using a VRH model.
In one embodiment, the equivalent elastic modulus of the mixed minerals is calculated by using a DEM model in the step (3).
In one embodiment, the equivalent modulus of elasticity of the dry rock is calculated in step (4) using an SCA model.
In one embodiment, the pore structure includes four pore types of spherical pores, coin pores, disk pores, and needle pores, and aspect ratio parameters thereof.
In one embodiment, a Wood model is used to calculate the equivalent elastic modulus of the mixed fluid in step (5).
In one embodiment, the equivalent elastic modulus of the saturated rock is calculated in step (6) using a Gassmann model.
In one embodiment, anisotropy caused by the directional arrangement of clay mineral particles is calculated using a Backus average model in the step (7).
In one embodiment, the equivalent elastic modulus of the dry rock is calculated in step (4) by using a DEM or K-T model.
The method can analyze the rock physical anisotropy of the shale stratum; compared with the prior art, the method has the advantages of simple process, accurate result and low implementation difficulty.
Additional features and advantages of the invention will be set forth in the description which follows. Also, some of the features and advantages of the invention will be apparent from the description, or may be learned by practice of the invention. The objectives and some of the advantages of the invention may be realized and attained by the process particularly pointed out in the written description and claims hereof as well as the appended drawings.
Drawings
The accompanying drawings, which are included to provide a further understanding of the invention and are incorporated in and constitute a part of this specification, illustrate embodiments of the invention and together with the description serve to explain the principles of the invention and not to limit the invention. In the drawings:
FIG. 1 is a prior art shale petrophysical modeling flow diagram;
FIG. 2 is a modeling flow diagram according to an embodiment of the invention;
FIG. 3 is a flow diagram of method steps according to one embodiment of the invention;
FIG. 4 is a diagram illustrating the results of the anisotropic interpretation of the rock mechanics of the shale formation according to an embodiment of the present invention.
Detailed Description
The following detailed description will be provided for the embodiments of the present invention with reference to the accompanying drawings and examples, so that the practitioner of the present invention can fully understand how to apply the technical means to solve the technical problems, achieve the technical effects, and implement the present invention according to the implementation procedures. It should be noted that, as long as there is no conflict, the embodiments and the features of the embodiments of the present invention may be combined with each other, and the technical solutions formed are within the scope of the present invention.
In the process of developing and utilizing geological resources, in order to confirm the development value of geological resource points and make development plans, the real and detailed rock physical characteristics of the geological resource points need to be acquired.
However, due to the invisibility of the formation rock, the skilled person usually describes the petrophysical properties of the actual geological resource point indirectly by interpreting experimental measurements or well logs. Or further, the experimental determination or the well logging data interpretation is further analyzed, and the rock physical characteristics of the actual geological resource point are predicted by using the analysis result. Therefore, before the development and utilization of geological resources, it is necessary to analyze experimental measurement or well-logging data interpretation to obtain an analysis result as detailed and accurate as possible. The analysis result aiming at experimental determination or well logging data interpretation can directly influence the finally obtained rock physical characteristic description of the geological resource point.
The invention provides a method for analyzing shale stratum rock physical anisotropy.
The input and output parameters of the anisotropic (VTI) petrophysical model are usually a stiffness matrix C or a compliance matrix S (S ═ C)-1) The stiffness matrix contains 5 independent elastic parameters (C)11、C13、C33、C55And C66)：
By extracting elastic parameters in the matrix, the method can be used for calculating the longitudinal and transverse wave speeds in different directions
Wherein, VPRepresenting P-waves or longitudinal waves, VSHRepresenting SV waves or shear waves.
Further, five elastic anisotropy moduli C describing the properties of VTI media11、C13、C33、C55And C66Can be recombined into five other parameters, i.e. P-wave and SV-wave velocities V perpendicular to the isotropic planeP0、VSV0And three dimensionless Thomsen anisotropy parameters, γ.
Thomsen anisotropy parameters, γ, are expressed as:
the parameter is longitudinal wave anisotropy and is a parameter for measuring the strength of quasi-longitudinal wave anisotropy; gamma is transverse wave anisotropy, and is a parameter for measuring quasi-transverse wave anisotropy or transverse wave splitting strength; the coefficient of variation of the longitudinal wave indicates how fast the anisotropy of the longitudinal wave changes in the vertical direction. When the isotropy limit is taken, γ tends to zero. The vast majority of actual rocks in the data presented by Thomsen exhibit weak anisotropy, i.e., gamma < < 1.
According to the method, according to the mineral components, the pore structures and the fluid properties of the shale stratum, the minerals which are randomly distributed in the stratum, have different arrangement modes and different pore structures are gradually added into the rock matrix by adopting a rock physical response model, and the equivalent elastic modulus of the shale stratum is gradually calculated by utilizing various equivalent medium rock physical models. Therefore, longitudinal wave velocity and transverse wave velocity of different shale formations and anisotropic property parameters thereof can be conveniently calculated, and further the shale formation rock physical anisotropy can be analyzed. The method can analyze the rock physical anisotropy of the shale stratum; compared with the prior art, the method has the advantages of simple process, accurate result and low implementation difficulty.
In the prior art, in order to predict the equivalent elastic modulus of a mixture of a rock skeleton and a pore composition by using a theoretical method, the following general knowledge is required: (1) the volume content of the parts constituting the rock skeleton; (2) the modulus of elasticity of each rock skeleton component; (3) the geometry of the porosity between the rock skeletons.
Aiming at Barnett shale, a relatively comprehensive rock physical modeling process is provided in the prior art. In the process, an SCA model or a DEM model is used for calculating the equivalent elastic modulus of a mixture of clay and bound water, a KT model is used for calculating the equivalent elastic modulus of a mixture of kerogen and related fluid, the fluid comprises three types of oil, gas and water, and the equivalent elastic modulus after mixing is obtained by using a Wood equation. Secondly, the isotropic material consisting of randomly distributed mineral particles and pore fluid is acquired by SCA or DEM model. Finally, the VTI anisotropy caused by the directional alignment of clay minerals with the kerogen particles was taken into account using the Backus mean model. The modeling idea is mainly characterized in that the clay minerals and the organic substance kerogen are divided into two parts, wherein one part is randomly distributed, and the other part is directionally arranged. The clay and kerogen distributed randomly and other minerals such as quartz, calcite and dolomite as well as various pores distributed randomly such as spherical pores, interparticle pores and cracks form an isotropic rock skeleton. On this basis, the rock can be idealized as a transverse anisotropic medium (VTI) with a vertical axis of symmetry based on the horizontally oriented arrangement of clay mineral and kerogen particles. The existing organic shale petrophysical modeling flow is shown in fig. 1.
According to the invention, a rock physical response model is adopted according to mineral components, directional and non-directional clay contents, pore structures and fluid properties of the shale formation, and a shale formation longitudinal and transverse wave velocity and rock physical anisotropy simulation flow is established, as shown in figure 2. Shale formations contain primarily rock skeletons (sandstone, carbonate, pyrite, etc.), clays, kerogen, and fluids. The rock skeleton and the clay which is not directionally arranged form dry rock. The dry rock has pores, and the kerogen and other fluids (oil, gas, water) of the shale formation are added to the dry rock, assuming the kerogen is part of the pores, and the dry rock becomes saturated rock after the kerogen and other fluids are added. The anisotropy of saturated rocks can be analyzed in combination with the anisotropy caused by the directional arrangement of clay mineral particles.
The detailed flow of a method according to an embodiment of the invention is described in detail below based on the accompanying drawings, the steps shown in the flow chart of which can be executed in a computer system containing instructions such as a set of computer executable instructions. Although a logical order of steps is illustrated in the flowcharts, in some cases, the steps illustrated or described may be performed in an order different than presented herein.
As shown in FIG. 3, in one embodiment, the steps of the present invention include:
(1) collecting experimentally determined or well-log data interpreted shale formation mineral content, kerogen content, pore fluid content and pore structure, said mineral content comprising oriented clay, non-oriented clay and skeletal mineral content (S110);
(2) calculating an equivalent elastic modulus of the skeleton mineral (S120);
(3) calculating an equivalent elastic modulus of a mixed mineral of the skeletal mineral and the non-directionally arranged clay (S130);
(4) calculating an equivalent elastic modulus of the dry rock based on the equivalent elastic modulus of the mixed minerals and the pore structure (S140);
(5) an equivalent elastic modulus of the mixed fluid is calculated based on the pore fluid content and the kerogen content (S150), and specifically, the mixed fluid includes oil, gas, water, and kerogen. (ii) a
(6) Calculating an equivalent elastic modulus of saturated rock based on the equivalent elastic modulus of the mixed fluid and the equivalent elastic modulus of the dry rock (S160);
(7) combining anisotropy caused by the directional arrangement of clay mineral particles (S171), calculating an equivalent elastic modulus of the shale formation anisotropic medium based on the content of the directionally arranged clay and the equivalent elastic modulus of the saturated rock (S170);
(8) the velocity of the longitudinal and transverse waves in the horizontal and vertical directions and the anisotropy parameter are calculated based on the equivalent elastic modulus of the anisotropic medium of the shale formation (S180).
Further, in one embodiment, in step S120, the equivalent elastic modulus of the skeletal mineral is calculated by using the VRH model.
Further, in one embodiment, in step S130, the DEM model is used to calculate the equivalent elastic modulus of the framework minerals and the mixed minerals of the non-directionally arranged clay.
Further, in one embodiment, in step S140, the SCA model is used to calculate the equivalent elastic modulus of the dry rock.
Further, in one embodiment, in step S150, a Wood model is used to calculate the equivalent elastic modulus of the mixed fluid.
Further, in one embodiment, in step S160, the equivalent elastic modulus of the saturated rock is calculated by using a Gassmann model.
Further, in one embodiment, in step S170, anisotropy caused by the directional arrangement of clay mineral particles is calculated using a Backus average model.
In one embodiment, in step S180, the Thomsen anisotropic parameters, γ, of the shale formation are calculated according to the equivalent elastic modulus of the VTI anisotropic medium of the shale formation (equivalent elastic parameters in the VTI medium stiffness matrix).
Further, in one embodiment, the content of the directionally arranged clay, the content of the non-directionally arranged clay, and the pore structure are determined by a scanning electron microscope method in step S110. .
Further, in one embodiment, the pore structure includes a pore type and a corresponding pore aspect ratio. Specifically, in one embodiment, the pore structure includes four types of pores, spherical, coin, disk and needle, and their aspect ratio parameters. The actual pore structure of the shale bed is obtained in step S110 and the specific type of pore type and its aspect ratio parameters are substituted in step S140 to calculate the equivalent elastic modulus of the dry rock.
Further, in an embodiment, in step S140, a petrophysical model other than the SCA model may also be used for the calculation. Specifically, in one embodiment, the equivalent elastic modulus of the dry rock is calculated in step S140 using a DEM or K-T model.
In summary, in an embodiment of the present invention, the analysis process for the petrophysical properties of the shale formation is as follows:
(1) collecting the contents of minerals such as shale stratum directionally arranged clay, randomly distributed clay, sandstone, carbonate, pyrite and the like and the contents of kerogen and pore fluid in the stratum, which are determined by experiments or explained by logging data;
(2) calculating equivalent elastic modulus of skeleton minerals such as sandstone, carbonate, pyrite and the like by using a VRH model;
(3) calculating the equivalent elastic modulus of the mixed minerals of the framework minerals and the non-directionally arranged clay by using a DEM model;
(4) calculating the equivalent elastic modulus of the dry rock by using an SCA, DEM or K-T model in consideration of different pore structures (spherical, coin-shaped, disc-shaped and needle-shaped pore types and aspect ratio parameters thereof) of the dry rock;
(5) calculating the equivalent elastic modulus of the mixed fluid of oil, gas, water and kerogen in the stratum by using a Wood model;
(6) adding mixed fluid (oil, gas, water and kerogen) of a shale stratum into dry rock, wherein the dry rock becomes saturated rock, and obtaining the equivalent elastic modulus of the saturated rock by using a Gassmann model;
(7) because directionally arranged clay will cause anisotropy of the shale formation, VTI anisotropy caused by the directional arrangement of clay mineral particles is considered by a Backus average model, so that the equivalent elastic modulus of the VTI anisotropic medium of the shale formation is calculated;
(8) calculating longitudinal and transverse wave speeds in the horizontal direction and the vertical direction according to the equivalent elastic modulus of the VTI anisotropic medium of the shale stratum (equivalent elastic parameters in a VTI medium rigidity matrix);
(8) from the elastic parameters of the VTI medium properties, the Thomsen anisotropy parameters, γ, of the shale formation are calculated.
In an application scenario, as shown in fig. 4, the mineral content and pore fluid of the shale formation are interpreted by using the results of element logging and conventional logging of a certain shale gas well, and the horizontal and vertical young modulus, poisson ratio, longitudinal and transverse wave time difference and the anisotropy coefficient of the shale formation are simulated by using the SCA model and the coin-shaped pore structure. The graph shows the anisotropy of the longitudinal wave, which is a parameter for measuring the strength of the anisotropy of the quasi-longitudinal wave, and the anisotropy of the longitudinal wave is strong when the shale interval is between 0.5 and 0.8; gamma is transverse wave anisotropy and is a parameter for measuring quasi-transverse wave anisotropy or transverse wave splitting strength, and the transverse wave anisotropy is very strong when the gamma is between 0.8 and 1.0 in the shale layer section; the coefficient of variation of the longitudinal wave represents the degree of the anisotropy change of the longitudinal wave in the vertical direction, and the anisotropy of the longitudinal wave in the vertical direction is smaller when the shale interval is less than 0.
Although the embodiments of the present invention have been described above, the above description is only for the convenience of understanding the present invention, and is not intended to limit the present invention. There are various other embodiments of the method of the present invention. Various corresponding changes or modifications may be made by those skilled in the art without departing from the spirit of the invention, and these corresponding changes or modifications are intended to fall within the scope of the appended claims.
Claims (9)
1. A method of analyzing petrophysical anisotropy of a shale formation, the method comprising:
(1) collecting experimentally determined or well-log data interpreted shale formation mineral content, kerogen content, pore fluid content and pore structure, the mineral content comprising content of directionally arranged clay, non-directionally arranged clay and skeletal minerals, the skeletal minerals including sandstone, carbonate and pyrite;
(2) calculating the equivalent elastic modulus of the skeleton mineral;
(3) calculating the equivalent elastic modulus of the mixed minerals of the skeleton mineral and the non-directionally arranged clay;
(4) calculating an equivalent elastic modulus of the dry rock based on the equivalent elastic modulus of the mixed mineral and the pore structure, the pore structure including four pore types of spherical pores, coin-shaped pores, disc-shaped pores and needle-shaped pores and aspect ratio parameters thereof;
(5) calculating an equivalent elastic modulus of a mixed fluid based on the pore fluid content and the kerogen content, the mixed fluid comprising oil, gas, water, and kerogen;
(6) calculating an equivalent elastic modulus of saturated rock based on the equivalent elastic modulus of the mixed fluid and the equivalent elastic modulus of the dry rock;
(7) calculating an equivalent elastic modulus of the anisotropic medium of the shale formation based on the clay content of the directional arrangement and the equivalent elastic modulus of the saturated rock in combination with the anisotropy caused by the directional arrangement of the clay mineral particles;
(8) and calculating the longitudinal and transverse wave speeds in the horizontal and vertical directions and the anisotropy parameters based on the equivalent elastic modulus of the shale formation anisotropic medium.
2. The method according to claim 1, wherein the oriented clay, the non-oriented clay content and the pore structure in step (1) are determined by an electron microscope scanning method.
3. The method of claim 1, wherein the equivalent modulus of elasticity of the skeletal mineral is calculated in step (2) using a VRH model.
4. The method of claim 1, wherein the equivalent elastic modulus of the blended mineral is calculated in step (3) using a DEM model.
5. The method according to claim 1, characterized in that in step (4) the equivalent modulus of elasticity of the dry rock is calculated with an SCA model.
6. The method according to claim 1, wherein a Wood model is used to calculate the equivalent modulus of elasticity of the mixed fluid in step (5).
7. The method according to claim 1, characterized in that in step (6) the equivalent elastic modulus of the saturated rock is calculated using a Gassmann model.
8. The method according to claim 1, wherein anisotropy caused by the directional arrangement of clay mineral particles is calculated in the step (7) using a Backus average model.
9. The method according to claim 1, characterized in that in step (4) the equivalent elastic modulus of the dry rock is calculated using DEM or K-T model.
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| WO2022198363A1 (en) * | 2021-03-22 | 2022-09-29 | 中国石油大学(华东) | Method and device for predicting elastic parameters of shale reservoir, and storage medium |
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| A shale rock physics model for analysis of brittleness index, mineralogy and porosity in the Barnett Shale;Zhiqi Guo 等;《JOURNAL OF GEOPHYSICS AND ENGINEERING》;20130219;第1-10页 * |
| 基于页岩岩石物理等效模型的地应力预测方法研究;张广智 等;《地球物理学报》;20150630;第58卷(第6期);第2112-2122 * |
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