CN112630019B - Shale brittleness index determination method and device and readable storage medium - Google Patents
Shale brittleness index determination method and device and readable storage medium Download PDFInfo
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Abstract
The disclosure provides a method, a device and a readable storage medium for determining a shale brittleness index, wherein the method comprises the following steps: acquiring the transverse wave time difference and the longitudinal wave time difference of a first stratum core of a target horizon; calculating the dynamic Young modulus and the dynamic Poisson ratio of the first stratum core; determining a first theoretical relationship between the dynamic Young's modulus and the static Young's modulus, and determining a second theoretical relationship between the dynamic Poisson's ratio and the static Poisson's ratio; and determining a third theoretical relationship of the transverse wave time difference and the longitudinal wave time difference in the shale brittleness index determination, wherein the third theoretical relationship is used for determining the shale brittleness index of the block corresponding to the target horizon. And determining a third theoretical relationship through the transverse wave time difference, the longitudinal wave time difference, the dynamic and static Young modulus and the Poisson ratio, wherein the third theoretical relationship is used for directly determining the shale brittleness index of the target layer corresponding to the research block, so that a large number of mechanical experiments are avoided, and the determination process of the shale brittleness index is relatively convenient.
Description
Technical Field
The disclosure relates to the technical field of shale fracturing evaluation, in particular to a method and a device for determining a shale brittleness index and a readable storage medium.
Background
The quality of the shale crushability determines the oil and gas production capacity of the shale, the shale brittleness index is an important index for evaluating the shale crushability, and the accuracy of the shale brittleness index directly influences the result of evaluating the shale crushability.
In the related technology, the shale brittleness index determination method is based on the compressive strength, tensile strength and other strength parameters of shale, coring is carried out after the shale brittleness index of a specific well target stratum in a specific research block is determined, a mechanical experiment is carried out by using a taken stratum core, and then the shale brittleness index is calculated on the basis of the experiment.
In the related art, a large number of mechanical experiments are required to be carried out when the shale brittleness index is determined, the determination method of the shale brittleness index is complicated, and the determination process efficiency is low.
Disclosure of Invention
The invention provides a method and a device for determining a shale brittleness index and a readable storage medium, which can solve the problems that a large number of mechanical experiments need to be carried out when the shale brittleness index is determined, the method for determining the shale brittleness index is relatively complicated, and the efficiency of the determination process is low. The method comprises the following steps:
in one aspect, a method for determining a shale brittleness index is provided, and the method includes:
acquiring the transverse wave time difference and the longitudinal wave time difference of a first stratum core of a target horizon;
calculating the dynamic Young modulus and the dynamic Poisson ratio of the first stratum core according to the transverse wave time difference and the longitudinal wave time difference;
obtaining the static Young modulus and the static Poisson ratio of the first stratum core;
determining a first theoretical relationship between the dynamic Young's modulus and the static Young's modulus, and determining a second theoretical relationship between the dynamic Poisson's ratio and the static Poisson's ratio;
determining a calculation mode of calculating the shale brittleness index by at least two shale brittleness index calculation methods and then averaging, wherein the at least two shale brittleness index calculation methods are calculated by the static Young modulus and the static Poisson ratio;
and determining a third theoretical relationship of the transverse wave time difference and the longitudinal wave time difference in the determination of the shale brittleness index according to the calculation mode, the first theoretical relationship and the second theoretical relationship, wherein the third theoretical relationship is used for determining the shale brittleness index of the block corresponding to the target horizon.
Optionally, the obtaining of the static young's modulus and the static poisson's ratio of the first formation core comprises:
receiving the static Young modulus and the static Poisson ratio sent by experimental equipment, wherein the static Young modulus and the static Poisson ratio are experimental data obtained by the experimental equipment through a compression experiment;
or the like, or, alternatively,
and receiving stress and strain data of the first formation core, which are sent by experimental equipment, wherein the stress and strain data are experimental data obtained by the experimental equipment through the compression experiment, and obtaining a static Young modulus and a static Poisson ratio according to the stress and strain data.
Optionally, said determining a first theoretical relationship between said dynamic young's modulus and said static young's modulus comprises:
sampling the target layer for n times, and acquiring n dynamic Young's moduli and n static Young's moduli for n shales obtained by the n times of sampling, wherein n is a positive integer;
establishing a first linear relationship corresponding to the n dynamic Young's moduli and the n static Young's moduli, and determining the first linear relationship as the first theoretical relationship.
Optionally, the determining a second theoretical relationship between the dynamic poisson's ratio and the static poisson's ratio comprises:
sampling the target horizon n times, and acquiring n dynamic Poisson ratios and n static Poisson ratios for n shales obtained by the n times of sampling, wherein n is a positive integer;
establishing a second linear relationship corresponding to the n dynamic poisson ratios and the n static poisson ratios, and determining the second linear relationship as the second theoretical relationship.
Optionally, the determining a calculation mode for calculating the static young's modulus and the static poisson ratio to the shale brittleness index includes:
obtaining m shale brittleness index calculation modes, wherein each calculation mode in the m shale brittleness index calculation modes has an application relation to the static Young modulus and the static Poisson ratio in the calculation process, and m is a positive integer;
calculating the shale brittleness index of the first formation core by combining the m shale brittleness index calculation modes to obtain m shale brittleness index calculation results;
determining k results with the highest accuracy from the m shale brittleness index calculation results, wherein k is more than 0 and less than or equal to m;
and determining a calculation mode when the static Young modulus and the static Poisson ratio calculate the shale brittleness index according to k shale brittleness index calculation modes corresponding to the k results with the highest accuracy.
Optionally, the determining, according to the k shale brittleness indexes corresponding to the k results with the highest accuracy, a calculation mode when the static young modulus and the static poisson ratio are calculated with respect to the shale brittleness index includes:
and taking the ratio of the sum of the k shale brittleness index calculation modes to k as a calculation mode when the static Young modulus and the static Poisson ratio are used for calculating the shale brittleness index.
Optionally, after determining a third theoretical relationship when determining the shale brittleness index of the shear wave time difference and the longitudinal wave time difference according to the calculation manner, the first theoretical relationship, and the second theoretical relationship, the method further includes:
acquiring the transverse wave time difference and the longitudinal wave time difference of a second stratum core of the target horizon;
and substituting the transverse wave time difference and the longitudinal wave time difference of the second stratum core into the third theoretical relationship to obtain the shale brittleness index of the second stratum core.
In another aspect, an apparatus for determining a shale brittleness index is provided, the apparatus comprising:
the acquisition module is used for acquiring the transverse wave time difference and the longitudinal wave time difference of the first stratum core of the target horizon;
the determining module is used for calculating the dynamic Young modulus and the dynamic Poisson ratio of the first stratum core according to the transverse wave time difference and the longitudinal wave time difference;
the acquisition module is further used for acquiring the static Young modulus and the static Poisson ratio of the first formation core;
the determining module is further configured to determine a first theoretical relationship between the dynamic young's modulus and the static young's modulus, and determine a second theoretical relationship between the dynamic poisson's ratio and the static poisson's ratio;
the determining module is further configured to determine a calculation mode of calculating the shale brittleness index by at least two shale brittleness index calculation methods and then averaging the shale brittleness index, where the at least two shale brittleness index calculation methods are calculated by the static young's modulus and the static poisson's ratio;
the determining module is further configured to determine a third theoretical relationship of the transverse wave time difference and the longitudinal wave time difference in determining the shale brittleness index according to the calculating mode, the first theoretical relationship and the second theoretical relationship, where the third theoretical relationship is used to determine the shale brittleness index of the block corresponding to the target horizon.
Optionally, the obtaining module is further configured to:
receiving a static Young modulus and a static Poisson ratio which are sent by experimental equipment, wherein the static Young modulus and the static Poisson ratio are experimental data obtained by the experimental equipment through a compression experiment;
or the like, or, alternatively,
and receiving stress and strain data of the first formation core sent by the experimental equipment, wherein the stress and strain data are experimental data obtained by the experimental equipment through a compression experiment, and obtaining the static Young modulus and the static Poisson ratio according to the stress and strain data.
Optionally, the determining module is further configured to:
sampling a target layer for n times, and acquiring n dynamic Young's moduli and n static Young's moduli aiming at n shales obtained by the n times of sampling, wherein n is a positive integer;
establishing a first linear relationship corresponding to the n dynamic Young's moduli and the n static Young's moduli, and determining the first linear relationship as a first theoretical relationship.
Optionally, the determining module is further configured to sample the target horizon n times, and obtain n dynamic poisson ratios and n static poisson ratios for n shales obtained through the n-time sampling, where n is a positive integer;
optionally, the determining module is further configured to establish a second linear relationship corresponding to the n dynamic poisson ratios and the n static poisson ratios, and determine the second linear relationship as a second theoretical relationship.
Optionally, the obtaining module is further configured to obtain m shale brittleness index calculation manners, each calculation manner of the m shale brittleness index calculation manners has an application relation to a static young's modulus and a static poisson ratio in a calculation process, and m is a positive integer; calculating the shale brittleness index of the first stratum core by combining m shale brittleness index calculation modes to obtain m shale brittleness index calculation results; determining k results with the highest accuracy from the m shale brittleness index calculation results, wherein k is more than 0 and less than or equal to m; and determining a calculation mode when the static Young modulus and the static Poisson ratio are used for calculating the shale brittleness index according to k shale brittleness index calculation modes corresponding to k results with the highest accuracy.
Optionally, the determining module is further configured to use a ratio between the sum of the k shale brittleness index calculation manners and k as a calculation manner when the static young modulus and the static poisson ratio are used for calculating the shale brittleness index.
Optionally, the determining module is further configured to obtain a shear wave time difference and a longitudinal wave time difference of a second formation core of the target horizon; and substituting the transverse wave time difference and the longitudinal wave time difference of the second stratum core into a third theoretical relationship to obtain the shale brittleness index of the second stratum core.
In another aspect, a computer-readable storage medium is provided, having stored therein at least one instruction, at least one program, a set of codes, or a set of instructions, which is loaded and executed by a processor to implement the method of determining a shale brittleness index as provided in the embodiments of the present disclosure above.
The beneficial effect that technical scheme that this disclosure embodiment provided brought includes at least:
the method comprises the steps of determining a first theoretical relationship between static and dynamic Young modulus and a second theoretical relationship between static and dynamic Poisson ratio, taking the static and dynamic Young modulus and the static and dynamic Poisson ratio as a bridge, obtaining a third theoretical relationship between a shale brittleness index of a stratum of a target layer position of a research block and transverse wave time difference and longitudinal wave time difference, and directly determining the shale brittleness index according to the third theoretical relationship when determining the shale brittleness index of the same layer positions of other wells of the research block, so that a large number of mechanical experiments are avoided, the workload is greatly reduced, the cost is greatly reduced, the determination process of the shale brittleness index is easy to realize and is convenient.
Drawings
Fig. 1 is a flow chart illustrating a method for determining a shale brittleness index according to an exemplary embodiment of the present disclosure;
FIG. 2 illustrates a linear relationship between dynamic Young's modulus and static Young's modulus;
FIG. 3 is a graph illustrating a linear relationship between a dynamic Poisson's ratio and a static Poisson's ratio;
FIG. 4 is a flow chart illustrating a method for determining a shale brittleness index according to an exemplary embodiment of the present disclosure;
fig. 5 is a block diagram illustrating a structure of a device for determining a shale brittleness index according to an exemplary embodiment of the present disclosure.
Detailed Description
Reference will now be made in detail to the exemplary embodiments, examples of which are illustrated in the accompanying drawings. The implementations described in the exemplary embodiments below are not intended to represent all implementations consistent with the present disclosure. Rather, they are merely examples of methods consistent with certain aspects of the disclosure, as detailed in the appended claims.
Before describing the embodiments in detail, some specific terms are explained:
the shale fracturing evaluation refers to the evaluation of the capability of the shale to generate cracks under high pressure; the core is also called a core sample and is a substance test block taken out from the stratum for testing; the shale brittleness index is an index representing the brittleness size of shale; the compressive strength refers to the maximum load which can be borne on a unit area when the test piece is pressed to be damaged; the sound wave time difference comprises a transverse wave time difference and a longitudinal wave time difference, wherein the transverse wave time difference refers to a time difference for receiving transverse waves, and the longitudinal wave time difference refers to a time difference for receiving longitudinal waves; young's modulus is a physical quantity that describes the ability of a solid material to resist deformation; the poisson ratio is the ratio of the absolute value of the transverse strain and the longitudinal strain of the test piece; stress refers to the internal force per unit area within an object; the strain refers to the local relative deformation of an object under the action of factors such as external force and a non-uniform temperature field.
Fig. 1 is a flowchart illustrating a method for determining a shale brittleness index according to an exemplary embodiment of the present disclosure, the method including:
Optionally, the transverse wave time difference and the longitudinal wave time difference of the first formation core at the target layer can be obtained by directly querying records of the transverse wave time difference and the longitudinal wave time difference of the target layer, schematically, the transverse wave time difference and the longitudinal wave time difference of the formation core at the target layer are stored in the terminal, and the records are directly obtained to obtain the transverse wave time difference and the longitudinal wave time difference of the formation core at the target layer; and can also be obtained by carrying out the acoustic moveout test.
And 102, calculating the dynamic Young modulus and the dynamic Poisson's ratio of the first stratum core according to the transverse wave time difference and the longitudinal wave time difference.
Alternatively, when calculating the dynamic young's modulus, the following formula one may be adopted:
the formula I is as follows:
alternatively, in calculating the dynamic poisson's ratio, the following formula two may be adopted:
the formula II is as follows:
wherein: e d Is the dynamic Young's modulus; mu.s d Is the dynamic poisson's ratio; Δ t s The unit is the stratum transverse wave time difference is mu s/ft; Δ t p The unit is the longitudinal wave time difference of the stratum and is mus/ft; rho is the volume density of stratum rock and has the unit of g/cm 3 。
Optionally, the static young's modulus and the static poisson ratio of the first formation core may be obtained by querying a data record of the static young's modulus and the static poisson ratio of the target layer; or may be obtained by performing a compression experiment, wherein when the static young's modulus and the static poisson's ratio are obtained by performing the compression experiment, the obtaining method includes:
1. processing the rock core into an experimental standard rock sample, wherein the size of the rock sample is phi a x [ (2-2.25) x a ] mm, the value of a can be 25, 50 and 38, and the number of the rock samples is more than or equal to 5;
2. and (5) performing a compression experiment to obtain the static Young modulus and the static Poisson ratio of each rock sample.
Alternatively, the first theoretical relationship is obtained by performing linear fitting on the dynamic young's modulus and the static young's modulus, and as shown in fig. 2, performing parametric regression on the dynamic young's modulus and the static young's modulus, and fitting to obtain the first theoretical relationship between the dynamic young's modulus and the static young's modulus.
Optionally, the second theoretical relationship is obtained by performing linear fitting on the dynamic poisson's ratio and the static poisson's ratio, as shown in fig. 3, performing parametric regression on the dynamic poisson's ratio and the static poisson's ratio, and fitting to obtain the second theoretical relationship between the dynamic poisson's ratio and the static poisson's ratio.
It should be noted that the above-mentioned manner of determining the first theoretical relationship and the second theoretical relationship through linear fitting may also be implemented as other fitting manners instead, which is not limited by the embodiment of the present disclosure.
And 105, determining a calculation mode of calculating the shale brittleness index by at least two shale brittleness index calculation methods and then averaging, wherein the at least two shale brittleness index calculation methods are calculated by the static Young modulus and the static Poisson ratio.
Optionally, screening k calculation methods which have the highest coincidence degree and are applied with static Young modulus and static Poisson ratio from the disclosed shale brittleness index calculation methods; and taking the ratio of the sum of the k shale brittleness index calculation methods to k as a calculation mode when the static Young modulus and the static Poisson ratio are used for calculating the shale brittleness index.
And 106, determining a third theoretical relationship of the transverse wave time difference and the longitudinal wave time difference in the determination of the shale brittleness index according to the calculation mode, the first theoretical relationship and the second theoretical relationship, wherein the third theoretical relationship is used for determining the shale brittleness index of the block corresponding to the target horizon.
Optionally, the first theoretical relationship is a corresponding relationship between the dynamic young's modulus and the static young's modulus, and the second theoretical relationship is a corresponding relationship between the dynamic poisson's ratio and the static poisson's ratio, where it can be known by referring to step 102 that the dynamic young's modulus and the dynamic poisson's ratio are determined according to the transverse wave time difference and the longitudinal wave time difference, so that the static young's modulus and the static poisson's ratio can be calculated through the transverse wave time difference and the longitudinal wave time difference, and then the shale brittleness index of the target horizon can be calculated by applying the result of step 105, that is, a third theoretical relationship between the transverse wave time difference, the longitudinal wave time difference and the shale brittleness index is determined.
Optionally, when the third theoretical relationship is determined, the above steps may also be repeated to obtain multiple groups of shale shear wave time differences, longitudinal wave time differences, and shale brittleness indexes corresponding to the multiple groups of shale shear wave time differences, and the third theoretical relationship between the logging acoustic wave time differences and the shale brittleness indexes is obtained according to the multiple groups of data.
Optionally, for shales in the same layer of other cored wells in the research area, the shale brittleness index can be directly determined according to the third theoretical relationship and by applying the acoustic wave time difference.
To sum up, in the technical scheme provided by the embodiment of the present disclosure, a third theoretical relationship of the transverse wave time difference and the longitudinal wave time difference when determining the shale brittleness index is determined by obtaining the transverse wave time difference, the longitudinal wave time difference, the static young modulus, the static poisson ratio, the dynamic young modulus and the dynamic poisson ratio of the first formation core at the target layer of the research block, and the third theoretical relationship is used for determining the shale brittleness index of the target layer corresponding to the research block, so that a large number of mechanical experiments are avoided, the workload is greatly reduced, the cost is greatly reduced, the determination process of the shale brittleness index is simple and easy to operate, and the determination process is easy to implement, relatively convenient and fast, and has strong practicability.
Fig. 4 is a flowchart illustrating a method for determining a shale brittleness index according to an exemplary embodiment of the present disclosure, the method including:
Optionally, the transverse wave time difference and the longitudinal wave time difference of the first formation core at the target horizon can be obtained by directly querying the records of the transverse wave time difference and the longitudinal wave time difference of the target horizon; and can also be obtained by carrying out the acoustic moveout test.
When the transverse wave time difference and the longitudinal wave time difference are obtained by carrying out the sound wave time difference test, the method comprises any one of the following three conditions:
firstly, directly testing the sound wave time difference to obtain transverse wave time difference and longitudinal wave time difference;
secondly, obtaining transverse wave time differences through sound wave tests, and determining and obtaining longitudinal wave time differences according to conversion coefficients between transverse wave time differences and longitudinal wave time differences;
thirdly, longitudinal wave time difference is obtained through sound wave testing, and transverse wave time difference is determined and obtained according to conversion coefficients between transverse wave time difference and longitudinal wave time difference.
Alternatively, when the transverse wave time difference and the longitudinal wave time difference are obtained from the conversion coefficient after determining one of them, the determination of the conversion coefficient is realized by: the core is machined into a standard size cube, such as: the core was processed into a cube of 60 × 60 × 60mm, and the acoustic moveout was measured with shear and longitudinal waves from three different directions to obtain three sets of data: Δ t s1 、Δt p1 ；Δt s2 、Δt p2 ；Δt s3 、Δt p3 Alternatively, the three different directions may be directions perpendicular to different planes of the cube and perpendicular to each other.
Obtaining the volume density of the core, wherein the volume density is the mass of the material in unit volume under the state of containing solid volume, opening and closed pore, and the test method of the volume density comprises the steps of firstly measuring the volume of the core by using a drainage method, then drying the core to measure the mass of the core, and then taking the ratio of the mass and the volume of the core as the volume density of the core; or directly reading the volume density of the rock core by using a rock density tester.
And (3) respectively substituting the three groups of data into the following formula three by using the volume density of the rock core:
the formula III is as follows:
in the formula: x, Y and Z are the time difference conversion coefficient of the formation sound wave, the unit is mus/ft; Δ t p The unit is the longitudinal wave time difference of the stratum and is mus/ft; Δ t s The unit is the stratum transverse wave time difference is mu s/ft; rho is the volume density of the rock core and is expressed in g/cm 3 。
And substituting the three groups of data into the third formula to construct an equation set and solve the acoustic wave time difference conversion coefficient of the target horizon of the research block.
Optionally, after the transverse wave time difference or the longitudinal wave time difference of other cores in the same phase in the research block is obtained, the longitudinal wave time difference can be directly calculated according to the transverse wave time difference or the longitudinal wave time difference by applying the third formula.
Optionally, please refer to the above formula one and formula two for the calculation of the dynamic young's modulus and the dynamic poisson's ratio, which is not described herein again.
And step 403, receiving the static young modulus and the static poisson ratio sent by the experimental equipment, wherein the static young modulus and the static poisson ratio are experimental data obtained by the experimental equipment through a compression experiment.
Alternatively, the experimental procedure for this compression experiment is as follows:
processing the rock core into an experimental standard rock sample, wherein the size of the standard rock sample is phi a x [ (2-2.25) x a ] mm, the value of a can be 25, 50 and 38, and the number of the standard rock samples is more than or equal to 5;
and (3) acquiring the static Young modulus and the static Poisson ratio of the standard rock sample through experimental equipment.
Alternatively, the experimental equipment for performing the above-mentioned compression experiment may be a uniaxial testing machine, a triaxial testing machine, a true triaxial apparatus.
Optionally, the uniaxial compressive strength and the full stress-strain curve of each rock sample can be obtained through a compression experiment, and the brittleness of the rock sample can be observed.
Alternatively, the experimental procedure for this compression experiment is as follows:
processing the rock core into a standard rock sample for experiment, wherein the size of the standard rock sample is determined according to the requirements of experimental equipment; and acquiring stress and strain data of the standard rock sample through experimental equipment, and calculating according to the stress and strain data to obtain the static Young modulus and the static Poisson ratio.
Alternatively, the experimental device for performing the above-described compression experiment may be any one of a uniaxial testing machine, a triaxial testing machine, and a true triaxial apparatus.
Optionally, the uniaxial compressive strength and the full stress-strain curve of each rock sample can be obtained through a compression experiment, and the brittleness of the rock sample can be observed.
It should be noted that step 403 and step 404 may be executed simultaneously, or only one of them may be executed.
The n dynamic young's moduli and the n dynamic poisson ratios may be obtained by the methods shown in the above steps 401 and 402, and the n static young's moduli and the n static poisson ratios may be obtained by the methods shown in the above steps 403 and 404.
Alternatively, the method of determining the first linear relationship may be a parametric regression of the n dynamic young's moduli and the n static young's moduli: and establishing a coordinate system by taking the dynamic Young modulus of the shale and the static Young modulus of the shale as two coordinate axes, and making a linear relation graph of the dynamic Young modulus of the shale and the static Young modulus of the shale to obtain a mathematical expression of the static Young modulus and the dynamic Young modulus.
Optionally, the coordinate system may be established by taking a shale dynamic young modulus as an abscissa and a shale static young modulus as an ordinate, and establishing a planar rectangular coordinate system; or a plane rectangular coordinate system can be established by taking the static Young modulus of the shale as an abscissa and the dynamic Young modulus of the shale as an ordinate.
Alternatively, the method of determining the second linear relationship may be to perform parametric regression on the n dynamic poisson ratios and the n static poisson ratios: and establishing a coordinate system by taking the shale dynamic Poisson ratio and the shale static Poisson ratio as two coordinate axes, and making a linear relation graph of the shale dynamic Poisson ratio and the shale static Poisson ratio to obtain mathematical expressions of the static Poisson ratio and the dynamic Poisson ratio.
Optionally, the coordinate system may be established by taking a shale dynamic poisson's ratio as a horizontal coordinate and taking a shale static poisson's ratio as a vertical coordinate, and establishing a planar rectangular coordinate system; or a plane rectangular coordinate system can be established by taking the static Poisson's ratio of the shale as a horizontal coordinate and taking the dynamic Poisson's ratio of the shale as a vertical coordinate.
Optionally, when determining the calculation mode, first obtaining m shale brittleness index calculation modes, where each calculation mode in the m shale brittleness index calculation modes has an application relation to a static young modulus and a static poisson ratio in a calculation process, and m is a positive integer, and optionally, the m shale brittleness index calculation modes are m selected from currently disclosed shale brittleness index calculation modes; calculating the shale brittleness index of the first stratum core by combining m shale brittleness index calculation modes to obtain m shale brittleness index calculation results; and determining k results with the highest accuracy from the m shale brittleness index calculation results, wherein k is more than 0 and less than or equal to m.
Alternatively, the method of determining the k most accurate results may be: and (3) comparing the computed results of the m shale brittleness indexes with the brittleness intensity of the rock sample obtained through the compression experiment observation in the step (402), and screening k shale brittleness index computing modes which have the highest degree of conformity with the compression experiment observation result from the m shale brittleness index computing modes. For example, in one possible embodiment, if the core is strongly brittle as observed through the compression experiment in step 402, k shale brittleness index calculation results with strong brittleness are selected from the m shale brittleness index calculation methods as k most accurate results.
And determining a calculation mode when the static Young modulus and the static Poisson ratio are used for calculating the shale brittleness index according to k shale brittleness index calculation modes corresponding to k results with the highest accuracy.
Optionally, the ratio of the sum of k shale brittleness index calculation modes to k is used as a calculation mode when the static young modulus and the static poisson ratio are used for calculating the shale brittleness index. Schematically, taking k =2 as an example, the above calculation method may be as follows:
the formula four is as follows:
wherein: b is a shale comprehensive shale brittleness index; b Eμ The shale brittleness index is calculated by applying a calculation mode of static Young modulus and static Poisson ratio; b μE The shale brittleness index is calculated by another calculation mode which applies the static Young modulus and the static Poisson ratio.
The calculation method of the m shale brittleness indexes can comprise the following formula five and formula six:
optionally, a shale brittleness index calculation formula using the static young's modulus and the static poisson ratio is five:
the formula five is as follows:
alternatively, another shale brittleness index calculation formula using static young's modulus and static poisson's ratio is six:
the formula six:
wherein: b 1 The shale brittleness index is calculated by a shale brittleness index calculation method applying the static Young modulus and the static Poisson ratio; e is the static Young's modulus; e min The minimum value of the static Young modulus in each experimental rock sample; e max The maximum value of the static Young modulus in each experimental rock sample; v. of max The maximum value of the static Poisson ratio in each experimental rock sample; b is 2 The shale brittleness index is calculated by another brittleness calculation method applying the static Young modulus and the static Poisson ratio.
And 408, determining a third theoretical relationship of the transverse wave time difference and the longitudinal wave time difference in determining the shale brittleness index according to the calculation mode, the first theoretical relationship and the second theoretical relationship, wherein the third theoretical relationship is used for determining the shale brittleness index of the block corresponding to the target horizon.
Optionally, repeating the steps 401 to 405 for g coring wells in the research block to obtain corresponding data of shale brittleness indexes and sonic time differences of g target horizons, wherein g is a positive integer.
Optionally, performing parameter regression on the shale brittleness indexes of the g coring well target layers and the corresponding data of the acoustic time difference to obtain a third theoretical relationship between the shale brittleness indexes of the target layers of the research block and the acoustic time difference.
And 409, obtaining the acoustic time difference of the shale at the target layer positions of other coring wells, and obtaining shale brittleness indexes of the target layer positions of other coring wells by applying a third theoretical relationship.
The method for performing parameter regression on the corresponding data of the shale brittleness index and the acoustic wave time difference can perform unitary regression on the transverse wave time difference or the longitudinal wave time difference and the shale brittleness index; or performing multiple regression on the shear wave time difference, the longitudinal wave time difference and the shale brittleness index.
The unitary regression mode of the transverse wave time difference or the longitudinal wave time difference and the shale brittleness index can be as follows: establishing a coordinate system by taking the shale transverse wave time difference or longitudinal wave time difference and the shale brittleness index as two coordinate axes, and making a relational graph of the shale brittleness index of the target layer and the shale acoustic wave time difference; and fitting a theoretical relation between the shale acoustic wave time difference and the shale brittleness index of the target horizon according to the relational graph.
Optionally, the coordinate system may be established by establishing a planar rectangular coordinate system with the shale transverse wave time difference as a horizontal coordinate and the shale brittleness index of the target horizon as a vertical coordinate; a plane rectangular coordinate system can be established by taking the shale longitudinal wave time difference as a horizontal coordinate and the shale brittleness index of the target horizon as a vertical coordinate; a planar rectangular coordinate system can be established by taking the shale brittleness index of the target horizon as a horizontal coordinate and the shale transverse wave time difference as a vertical coordinate; or establishing a plane rectangular coordinate system by taking the shale brittleness index of the target horizon as a horizontal coordinate and the shale longitudinal wave time difference as a vertical coordinate.
To sum up, in the technical scheme provided by the embodiment of the disclosure, the static young modulus and the static poisson ratio are used as a third theoretical relationship between the shale brittleness index and the acoustic time difference for determining the target level of the research block by the bridge, and the acoustic time difference data can be directly utilized to obtain the shale brittleness index of the target level of a certain coring well of the research block according to the third theoretical relationship, so that the problems that a large number of mechanical experiments are carried out, the workload and the working cost are greatly reduced, the operation is simple and easy, the implementation is easy, the practicability is strong, various indexes are applied, and the problem that the result is inaccurate due to too single index applied when the shale brittleness index is determined are solved.
Fig. 5 is a block diagram of a device for determining a shale brittleness index according to an exemplary embodiment of the present disclosure, and as shown in fig. 5, the device includes an obtaining module 501 and a determining module 502. Wherein:
an obtaining module 501, configured to obtain a transverse wave time difference and a longitudinal wave time difference of a first formation core of a target horizon.
A determining module 502, configured to calculate a dynamic young's modulus and a dynamic poisson's ratio of the first formation core according to the shear wave time difference and the longitudinal wave time difference.
The obtaining module 501 is configured to obtain a static young's modulus and a static poisson's ratio of the first formation core.
The determining module 502 is further configured to determine a first theoretical relationship between the dynamic young's modulus and the static young's modulus, and determine a second theoretical relationship between the dynamic poisson's ratio and the static poisson's ratio.
The determining module 502 is further configured to determine a calculation mode of calculating the shale brittleness index by at least two shale brittleness index calculation methods and then taking an average value, where the at least two shale brittleness index calculation methods calculate by a static young's modulus and a static poisson ratio;
the determining module 502 is further configured to determine, according to the calculation manner, the first theoretical relationship and the second theoretical relationship, a third theoretical relationship of the transverse wave time difference and the longitudinal wave time difference in determining the shale brittleness index, where the third theoretical relationship is used to determine the shale brittleness index of the block corresponding to the target horizon.
In an optional embodiment, the obtaining module 501 is further configured to receive a static young's modulus and a static poisson ratio sent by the experimental apparatus, where the static young's modulus and the static poisson ratio are experimental data obtained by the experimental apparatus through a compression experiment;
or the like, or, alternatively,
the obtaining module 501 is further configured to receive stress and strain data of the first formation core sent by the experimental device, where the stress and strain data are experimental data obtained by the experimental device through a compression experiment, and a static young's modulus and a static poisson ratio are obtained according to the stress and strain data.
In an optional embodiment, the determining module 502 is further configured to sample the target horizon n times, and obtain n dynamic young's moduli and n static young's moduli for n shales obtained through the n-time sampling, where n is a positive integer.
The determining module 502 is further configured to establish a first linear relationship corresponding to the n dynamic young's moduli and the n static young's moduli, and determine the first linear relationship as a first theoretical relationship.
In an optional embodiment, the determining module 502 is further configured to sample the target horizon n times, and obtain n dynamic poisson ratios and n static poisson ratios for n shales obtained through the n sampling times, where n is a positive integer.
The determining module 502 is further configured to establish a second linear relationship corresponding to the n dynamic poisson ratios and the n static poisson ratios, and determine the second linear relationship as a second theoretical relationship.
In an optional embodiment, the obtaining module 501 is further configured to obtain m shale brittleness index calculation manners, where each calculation manner of the m shale brittleness index calculation manners has an application relationship to a static young's modulus and a static poisson's ratio in a calculation process, and m is a positive integer; calculating the shale brittleness index of the first stratum core by combining m shale brittleness index calculation modes to obtain m shale brittleness index calculation results; determining k results with the highest accuracy from the m shale brittleness index calculation results, wherein k is more than 0 and less than or equal to m; and determining a calculation mode when the static Young modulus and the static Poisson ratio are calculated according to k shale brittleness indexes corresponding to k results with highest accuracy.
In an optional embodiment, the determining module 502 is further configured to use a ratio of the sum of the k shale brittleness index calculation manners to k as a calculation manner when the static young's modulus and the static poisson ratio are calculated for the shale brittleness index.
In an alternative embodiment, the determining module 502 is further configured to obtain a shear wave moveout and a longitudinal wave moveout of a second formation core of the target horizon; and substituting the transverse wave time difference and the longitudinal wave time difference of the second stratum core into a third theoretical relationship to obtain the shale brittleness index of the second stratum core.
To sum up, the shale brittleness index determination apparatus provided in the embodiment of the present disclosure obtains a third theoretical relationship between the shale brittleness index of the stratum at the target layer position of the research block and the acoustic wave time difference by using the static young modulus and the static poisson's ratio as a bridge, and when determining the shale brittleness index of the same layer position of other wells of the research block, the shale brittleness index can be directly determined according to the third theoretical relationship, so that the workload is greatly reduced, the determination process of the shale brittleness index is relatively convenient, and the problem that the calculation result is not accurate enough due to the fact that the calculation method is too single can be avoided by applying multiple evaluation parameters to perform comprehensive evaluation.
An exemplary embodiment of the present disclosure further provides a computer-readable storage medium, in which at least one instruction, at least one program, a code set, or a set of instructions is stored, and the at least one instruction, the at least one program, the code set, or the set of instructions is loaded and executed by a processor to implement the shale brittleness index determination method provided in the above-mentioned method embodiments. For example, the computer-readable storage medium may be a Read-Only Memory (ROM), a Random Access Memory (RAM), a Compact Disc Read-Only Memory (CD-ROM), a magnetic tape, a floppy disk, an optical data storage device, and the like.
Other embodiments of the disclosure will be apparent to those skilled in the art from consideration of the specification and practice of the disclosure disclosed herein. This disclosure is intended to cover any variations, uses, or adaptations of the disclosure following, in general, the principles of the disclosure and including such departures from the present disclosure as come within known or customary practice within the art to which the disclosure pertains. It is intended that the specification and examples be considered as exemplary only, with a true scope and spirit of the disclosure being indicated by the following claims.
It will be understood that the present disclosure is not limited to the precise arrangements described above and shown in the drawings and that various modifications and changes may be made without departing from the scope thereof. The scope of the present disclosure is limited only by the appended claims.
Claims (9)
1. A method for determining a shale brittleness index, the method comprising:
acquiring the transverse wave time difference and the longitudinal wave time difference of a first stratum core of a target horizon;
calculating the dynamic Young modulus and the dynamic Poisson ratio of the first stratum core according to the transverse wave time difference and the longitudinal wave time difference;
obtaining the static Young modulus and the static Poisson ratio of the first stratum core;
determining a first theoretical relationship between the dynamic Young's modulus and the static Young's modulus, and determining a second theoretical relationship between the dynamic Poisson's ratio and the static Poisson's ratio;
obtaining m shale brittleness index calculation modes, wherein each calculation mode in the m shale brittleness index calculation modes has an application relation to the static Young modulus and the static Poisson ratio in the calculation process, and m is a positive integer;
calculating the shale brittleness index of the first formation core by combining the m shale brittleness index calculation modes to obtain m shale brittleness index calculation results;
determining k results with the highest coincidence degree from the m shale brittleness index calculation results, wherein k is more than 1 and less than or equal to m;
determining a calculation mode when the static Young modulus and the static Poisson ratio are used for calculating the shale brittleness index according to k shale brittleness index calculation modes corresponding to the k results with the highest conformity degrees, wherein the m shale brittleness index calculation modes are calculated according to the static Young modulus and the static Poisson ratio;
and determining a third theoretical relationship of the transverse wave time difference and the longitudinal wave time difference in determining the shale brittleness index according to the calculation mode, the first theoretical relationship and the second theoretical relationship, wherein the third theoretical relationship is used for determining the shale brittleness index of the block corresponding to the target horizon.
2. The method of claim 1, wherein the obtaining the static young's modulus and the static poisson's ratio of the first formation core comprises:
receiving the static Young modulus and the static Poisson ratio sent by experimental equipment, wherein the static Young modulus and the static Poisson ratio are experimental data obtained by the experimental equipment through a compression experiment;
or the like, or a combination thereof,
and receiving stress and strain data of the first formation core, which are sent by experimental equipment, wherein the stress and strain data are experimental data obtained by the experimental equipment through a compression experiment, and the static Young modulus and the static Poisson ratio are obtained according to the stress and strain data.
3. The method of claim 1, wherein determining the first theoretical relationship between the dynamic young's modulus and the static young's modulus comprises:
sampling the target layer for n times, and acquiring n dynamic Young's moduli and n static Young's moduli for n shales obtained by the n times of sampling, wherein n is a positive integer;
establishing a first linear relationship corresponding to the n dynamic Young's moduli and the n static Young's moduli, and determining the first linear relationship as the first theoretical relationship.
4. The method of claim 1, wherein said determining a second theoretical relationship between said dynamic poisson's ratio and said static poisson's ratio comprises:
sampling the target horizon n times, and acquiring n dynamic Poisson ratios and n static Poisson ratios for n shales obtained by the n times of sampling, wherein n is a positive integer;
establishing a second linear relationship corresponding to the n dynamic poisson ratios and the n static poisson ratios, and determining the second linear relationship as the second theoretical relationship.
5. The method according to claim 1, wherein the determining the calculation mode for calculating the static young's modulus and the static poisson ratio for the shale brittleness index according to the k shale brittleness index calculation modes corresponding to the k results with the highest degree of conformity comprises:
and taking the ratio of the sum of the k shale brittleness index calculation modes to k as a calculation mode when the static Young modulus and the static Poisson ratio are used for calculating the shale brittleness index.
6. The method according to any one of claims 1 to 3, wherein said determining said shear wave moveout and said longitudinal wave moveout based on said calculation, said first theoretical relationship and said second theoretical relationship after determining a third theoretical relationship in said determining said shale brittleness index further comprises:
acquiring the transverse wave time difference and the longitudinal wave time difference of a second stratum core of the target horizon;
and substituting the transverse wave time difference and the longitudinal wave time difference of the second stratum core into the third theoretical relationship to obtain the shale brittleness index of the second stratum core.
7. An apparatus for determining a shale brittleness index, the apparatus comprising:
the acquisition module is used for acquiring the transverse wave time difference and the longitudinal wave time difference of the first stratum core of the target horizon;
the determining module is used for calculating the dynamic Young modulus and the dynamic Poisson ratio of the first stratum core according to the transverse wave time difference and the longitudinal wave time difference;
the acquisition module is further used for acquiring the static Young modulus and the static Poisson ratio of the first formation core;
the determining module is further configured to determine a first theoretical relationship between the dynamic young's modulus and the static young's modulus, and determine a second theoretical relationship between the dynamic poisson's ratio and the static poisson's ratio;
the determining module is further configured to obtain m shale brittleness index calculation modes, each calculation mode of the m shale brittleness index calculation modes has an application relation to the static young modulus and the static poisson ratio in a calculation process, and m is a positive integer; calculating the shale brittleness index of the first formation core by combining the m shale brittleness index calculation modes to obtain m shale brittleness index calculation results; determining k results with the highest coincidence degree from the m shale brittleness index calculation results, wherein k is more than 1 and less than or equal to m; determining a calculation mode when the static Young modulus and the static Poisson ratio are used for calculating the shale brittleness index according to k shale brittleness index calculation modes corresponding to the k results with the highest conformity degrees, wherein the m shale brittleness index calculation modes are calculated according to the static Young modulus and the static Poisson ratio;
the determining module is further configured to determine a third theoretical relationship of the transverse wave time difference and the longitudinal wave time difference in determining the shale brittleness index according to the calculating mode, the first theoretical relationship and the second theoretical relationship, where the third theoretical relationship is used to determine the shale brittleness index of the block corresponding to the target horizon.
8. The apparatus of claim 7, wherein the obtaining module is further configured to receive the static young's modulus and the static poisson ratio sent by an experimental device, where the static young's modulus and the static poisson ratio are experimental data obtained by the experimental device through a compression experiment;
or the like, or, alternatively,
the acquisition module is further configured to receive stress and strain data of the first formation core, which are sent by an experimental device, where the stress and strain data are obtained by the experimental device through a compression experiment, and the static young modulus and the static poisson ratio are obtained according to the stress and strain data.
9. A computer readable storage medium having stored therein at least one instruction, at least one program, a set of codes, or a set of instructions, which is loaded and executed by a processor to carry out a method of determining a shale brittleness index according to any one of claims 1 to 6.
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