Shale oil and gas reservoir elastic parameter generation method and device

Abstract

The present invention provides a method and device for generating elastic parameters of shale oil and gas reservoirs, and relates to the technical field of petroleum exploration. The method comprises: obtaining target measurement parameters, organic matter adsorption performance parameters and organic matter physical form parameters of shale oil and gas reservoirs; generating organic elastic property parameters considering the coupling of fluid adsorption performance and pore pressure according to the organic matter adsorption performance parameters and the organic matter physical form parameters; generating inorganic elastic stiffness coefficients according to target measurement parameters; generating coupled shale oil and gas reservoir elastic property parameters according to the organic elastic property parameters and the inorganic elastic stiffness coefficients; generating shale oil and gas reservoir elastic parameters according to the coupled shale oil and gas reservoir elastic property parameters. The present invention takes into account the influence of the coupling of adsorption performance and pore pressure on elastic characteristics, and therefore, the obtained elastic parameters can be used to improve the accuracy of the prediction results of quantitative seismic interpretation of shale oil and gas reservoirs based on seismic and well logging data.

Description

Technical Field

[0001] The present invention relates to the technical field of petroleum exploration, and in particular to a method and a device for generating elastic parameters of shale oil and gas reservoirs. Background Art

[0002] At present, the existing seismic rock physics models of shale oil and gas reservoirs are mainly based on different equivalent medium theories to characterize the influence of total organic carbon content (TOC), porosity, pore structure, organic matter occurrence form, etc. on seismic elastic parameters. The seismic elastic parameters obtained by the existing models make the prediction results of quantitative seismic interpretation of shale oil and gas reservoirs based on seismic and logging data differ greatly from the actual physical conditions. Summary of the invention

[0003] The present invention provides a method and device for generating elastic parameters of shale oil and gas reservoirs. The scheme takes into account the influence of adsorption performance and pore pressure coupling on elastic characteristics. Therefore, the obtained elastic parameters can be used to improve the accuracy of prediction results of quantitative seismic interpretation of shale oil and gas reservoirs based on seismic and logging data.

[0004] In a first aspect, an embodiment of the present invention provides a method for generating elastic parameters of a shale oil and gas reservoir, the method comprising: obtaining target measurement parameters, organic matter adsorption performance parameters and organic matter physical form parameters of a shale oil and gas reservoir; generating organic elastic property parameters that consider the coupling of fluid adsorption performance and pore pressure according to the organic matter adsorption performance parameters and the organic matter physical form parameters; generating an inorganic elastic stiffness coefficient according to the target measurement parameters; generating coupled shale oil and gas reservoir elastic property parameters according to the organic elastic property parameters and the inorganic elastic stiffness coefficient; generating shale oil and gas reservoir elastic parameters according to the coupled shale oil and gas reservoir elastic property parameters.

[0005] In a second aspect, an embodiment of the present invention further provides a shale oil and gas reservoir elastic parameter generation device, the device comprising: an acquisition module, used to acquire target measurement parameters, organic matter adsorption performance parameters and organic matter physical form parameters of the shale oil and gas reservoir; an organic module, used to generate organic elastic property parameters considering the coupling of fluid adsorption performance and pore pressure according to the organic matter adsorption performance parameters and the organic matter physical form parameters; an inorganic module, used to generate inorganic elastic stiffness coefficients according to the target measurement parameters; a synthesis module, used to generate coupled shale oil and gas reservoir elastic property parameters according to the organic elastic property parameters and the inorganic elastic stiffness coefficients; and a calculation module, used to generate shale oil and gas reservoir elastic parameters according to the coupled shale oil and gas reservoir elastic property parameters.

[0006] In a third aspect, an embodiment of the present invention further provides a computer device, comprising a memory, a processor, and a computer program stored in the memory and executable on the processor, wherein the processor implements the above-mentioned method for generating elastic parameters of shale oil and gas reservoirs when executing the computer program.

[0007] In a fourth aspect, an embodiment of the present invention further provides a computer-readable storage medium, wherein the computer-readable storage medium stores a computer program for executing the above-mentioned method for generating elastic parameters of shale oil and gas reservoirs.

[0008] The embodiments of the present invention bring the following beneficial effects: the embodiments of the present invention provide a shale oil and gas reservoir elastic parameter generation scheme, which obtains the target measurement parameters, organic matter adsorption performance parameters and organic matter physical form parameters of the shale oil and gas reservoir; generates organic elastic property parameters that consider the coupling of fluid adsorption performance and pore pressure according to the organic matter adsorption performance parameters and the organic matter physical form parameters; generates inorganic elastic stiffness coefficients according to the target measurement parameters; generates coupled shale oil and gas reservoir elastic property parameters according to the organic elastic property parameters and the inorganic elastic stiffness coefficient; generates shale oil and gas reservoir elastic parameters according to the coupled shale oil and gas reservoir elastic property parameters. The embodiments of the present invention take into account the influence of the coupling of adsorption performance and pore pressure on the elastic characteristics, so the obtained elastic parameters can be used to improve the accuracy of the prediction results of quantitative seismic interpretation of shale oil and gas reservoirs based on seismic and logging data.

[0009] Other features and advantages of the present invention will be described in the following description, and partly become apparent from the description, or understood by practicing the present invention. The purpose and other advantages of the present invention are realized and obtained by the structures particularly pointed out in the description, claims and drawings.

[0010] In order to make the above-mentioned objects, features and advantages of the present invention more obvious and easy to understand, preferred embodiments are given below and described in detail with reference to the accompanying drawings. BRIEF DESCRIPTION OF THE DRAWINGS

[0011] In order to more clearly illustrate the specific implementation methods of the present invention or the technical solutions in the prior art, the drawings required for use in the specific implementation methods or the description of the prior art will be briefly introduced below. Obviously, the drawings described below are some implementation methods of the present invention. For ordinary technicians in this field, other drawings can be obtained based on these drawings without paying creative work.

[0012] Figure 1 A flow chart of a method for generating elastic parameters of shale oil and gas reservoirs provided in an embodiment of the present invention;

[0013] Figure 2A workflow diagram for rock physics modeling of shale oil and gas reservoirs taking into account the adsorption effect provided in an embodiment of the present invention;

[0014] Figure 3 A schematic diagram of a shale oil reservoir pore pressure-total porosity seismic rock physics template provided by an embodiment of the present invention;

[0015] Figure 4 A structural block diagram of a shale oil and gas reservoir elastic parameter generation device provided in an embodiment of the present invention;

[0016] Figure 5 A structural block diagram of a computer device provided in an embodiment of the present invention. DETAILED DESCRIPTION

[0017] In order to make the purpose, technical solution and advantages of the embodiments of the present invention clearer, the technical solution of the present invention will be clearly and completely described below in conjunction with the accompanying drawings. Obviously, the described embodiments are part of the embodiments of the present invention, not all of the embodiments. Based on the embodiments of the present invention, all other embodiments obtained by ordinary technicians in this field without creative work are within the scope of protection of the present invention.

[0018] At present, shale oil and gas reservoirs have a large number of organic micro-nano and pores, and a large amount of shale oil and gas in the reservoir is adsorbed on the surface of organic matter (a small amount is adsorbed on inorganic minerals), of which adsorbed gas accounts for 20%-85% of the total gas volume. The adsorption process of organic shale is closely related to pore pressure. Generally speaking, the higher the pore pressure, the greater the adsorption amount. Therefore, it is particularly important to explore the elastic response of the coupling of adsorption performance and pore pressure.

[0019] On the one hand, using elastic characteristics to evaluate the contribution of adsorbed oil and gas to overall reserves is an effective supplement to the existing technology of using geophysical response characteristics to evaluate the degree of oil and gas enrichment; on the other hand, the current commonly used prediction of pore pressure in shale oil and gas reservoirs based on well logging and seismic elastic characteristics basically ignores the effect of coupling between adsorption performance and pore pressure on elastic properties. Seismic prediction of shale oil and gas faces great challenges, and the prediction of the occurrence state of oil and gas in organic matter and the amount of adsorbed oil and gas is even more difficult.

[0020] Existing shale oil and gas seismic rock physics models do not consider the effect of adsorption performance and pore pressure coupling on seismic elastic characteristics. This makes the quantitative seismic interpretation of shale oil and gas reservoirs based on seismic and logging data lack consideration of the effect of adsorption, making the prediction results different from the actual physical conditions.

[0021] Based on this, the embodiment of the present invention provides a method and device for generating elastic parameters of shale oil and gas reservoirs, which can simultaneously characterize the influence of adsorbed oil and gas on elastic characteristics under different pore pressure conditions, effectively improve the estimation accuracy of adsorbed oil and gas, and form effective technical support for pore pressure prediction. This solution is of great significance for shale oil and gas reservoir rock physics modeling technology that considers the coupling of organic pore adsorption performance and pore pressure, and also has important guiding significance for pore pressure prediction using geophysical response characteristics.

[0022] This method introduces the surface effect into the classical solid-liquid two-phase medium elastic mechanics (under the framework of Biot-Gassmann theory), and combines the Gibbs adsorption formula, Langmuir adsorption model, and Shuttleworth formula of surface interface mechanics to propose a calculation formula for the elastic modulus of porous media with adsorption properties. This equation can effectively describe the influence of different fluids on the elastic characteristics of rocks with different adsorption properties under different pore pressures. Combining this equation with the seismic rock physics modeling method of organic shale, it is possible to quantitatively evaluate the influence of the coupling of adsorption performance and pore pressure on the elastic characteristics of shale oil and gas reservoirs.

[0023] To facilitate understanding of this embodiment, a method for generating elastic parameters of a shale oil and gas reservoir disclosed in an embodiment of the present invention is first introduced in detail.

[0024] The embodiment of the present invention provides a method for generating elastic parameters of shale oil and gas reservoirs, see Figure 1 A flow chart of a method for generating elastic parameters of shale oil and gas reservoirs is shown, the method comprising the following steps:

[0025] Step S102, obtaining target measurement parameters, organic matter adsorption performance parameters and organic matter physical form parameters of the shale oil and gas reservoir.

[0026] In an embodiment of the present invention, for a specific shale oil and gas reservoir, the main physical parameters affecting the adsorption performance and elastic characteristics of the organic shale are extracted, mainly including target measurement parameters, organic adsorption performance parameters and organic physical form parameters.

[0027] Based on the adsorption experiment of organic shale, physical parameters characterizing the adsorption performance of organic matter are extracted. These parameters mainly include the maximum adsorption amount of gas per unit surface area and the equilibrium coefficient when the adsorption reaches the saturated state; based on scanning electron microscopy and CT (Computed Tomography) analysis, the relevant parameters characterizing the physical form of organic matter are determined, mainly including the aspect ratio of the organic phase, the radius of organic pores, the aspect ratio of organic pores to inorganic pores, and the relative percentage of solid asphalt and kerogen; based on XRD (Diffraction of X-Rays) mineral analysis, geochemical analysis, and porosity measurement, the content of inorganic minerals, organic carbon content, inorganic porosity, organic porosity, etc. are determined to obtain the target measurement parameters.

[0028] For example, see Table 1, which shows the petrophysical parameters required for shale oil reservoir modeling considering the adsorption effect.

[0029]

[0030]

[0031] Table 1

[0032] Step S104, generating organic elastic property parameters considering the coupling of fluid adsorption performance and pore pressure according to the organic matter adsorption performance parameters and the organic matter physical form parameters.

[0033] In an embodiment of the present invention, after obtaining the organic matter adsorption performance parameters and the organic matter physical form parameters, the parameters can be used to calculate the paper fluid adsorption performance and the organic matter physical form, and then obtain the organic elastic property parameters considering the coupling of fluid adsorption performance and pore pressure.

[0034] Step S106, generating an inorganic elastic stiffness coefficient according to the target measurement parameter.

[0035] In the embodiment of the present invention, the composition of the inorganic phase of shale generally includes a clay portion containing bound water and a non-clay portion. The non-clay portion includes silicate minerals, carbonate minerals and inorganic pores containing free water.

[0036] The equivalent elastic properties of silicate minerals, carbonate minerals and inorganic pores containing free water are calculated according to the target measurement parameters to obtain the inorganic elastic stiffness coefficient.

[0037] Step S108, generating coupled shale oil and gas reservoir elastic property parameters according to the organic elastic property parameters and the inorganic elastic stiffness coefficients.

[0038] In the embodiment of the present invention, the organic elastic property parameters and the inorganic elastic stiffness coefficients are coupled to obtain the elastic property parameters of the shale oil and gas reservoir coupled with the organic phase and the inorganic phase.

[0039] Step S110, generating shale oil and gas reservoir elastic parameters according to the coupled shale oil and gas reservoir elastic property parameters.

[0040] In the embodiment of the present invention, the elastic characteristics of the shale oil and gas reservoir taking into account the coupling of adsorption performance and pore pressure, that is, the stiffness coefficient of the entire shale, are obtained. For example, it can be expressed in a matrix as follows:

[0041]

[0042] in, Then the density of the entire shale is obtained by taking the weighted average of the volume fractions of each phase, combined with the following formula: and In the formula, ρ represents density, V s (0) and V p (0) represents velocity, and the longitudinal wave velocity and transverse wave velocity of the shale oil and gas reservoir can be further calculated to obtain the elastic parameters of the shale oil and gas reservoir.

[0043] It should be noted that the elastic parameters of shale oil and gas reservoirs can be expressed as the ratio of longitudinal and transverse wave velocities or longitudinal wave impedance, which can be set according to actual needs and are not specifically limited in the embodiments of the present invention.

[0044] The embodiment of the present invention provides a shale oil and gas reservoir elastic parameter generation scheme, which obtains the target measurement parameters, organic matter adsorption performance parameters and organic matter physical form parameters of the shale oil and gas reservoir; generates organic elastic property parameters that consider the coupling of fluid adsorption performance and pore pressure according to the organic matter adsorption performance parameters and the organic matter physical form parameters; generates inorganic elastic stiffness coefficients according to the target measurement parameters; generates coupled shale oil and gas reservoir elastic property parameters according to the organic elastic property parameters and the inorganic elastic stiffness coefficient; generates shale oil and gas reservoir elastic parameters according to the coupled shale oil and gas reservoir elastic property parameters. The embodiment of the present invention takes into account the influence of the coupling of adsorption performance and pore pressure on the elastic characteristics, so the obtained elastic parameters can be used to improve the accuracy of the prediction results of quantitative seismic interpretation of shale oil and gas reservoirs based on seismic and well logging data.

[0045] In one embodiment, generating organic elastic property parameters considering the coupling of fluid adsorption performance and pore pressure according to organic matter adsorption performance parameters and organic matter physical form parameters can be performed according to the following steps:

[0046] The elastic modulus of porous organic matter without fluid is calculated based on organic matter adsorption performance parameters and organic matter physical form parameters; the elastic modulus of porous organic matter without fluid, organic matter adsorption performance parameters and organic matter physical form parameters are used to generate organic elastic property parameters that consider the coupling of fluid adsorption performance and pore pressure.

[0047] In the embodiment of the present invention, the elastic modulus of porous organic matter without fluid is first calculated. The isotropic DEM (Digital Elevation Model) can be used to calculate the bulk modulus of organic matter containing organic pores, that is, solid organic matter (kerogen or asphalt) is used as the base, leaving pore positions but not filled with fluid. Then, the elastic properties of the organic phase considering the coupling of fluid adsorption performance and pore pressure are calculated. After obtaining the bulk modulus of porous organic matter without fluid, the influence of adsorption performance on the elastic properties of organic matter is further considered, including the bulk modulus of the organic phase part affected by adsorption and pore pressure coupling. After calculation, the organic elastic property parameters considering the coupling of fluid adsorption performance and pore pressure are obtained.

[0048] In one embodiment, the elastic modulus of porous organic matter without fluid is calculated according to the organic matter adsorption performance parameter and the organic matter physical form parameter using the following formula:

[0049]

[0050] Where y represents the volume percentage of organic pores in the entire porous organic matter, K * (y) represents the bulk modulus of porous organic matter without fluid corresponding to the y value, μ * (y) represents the shear modulus of porous organic matter without fluid corresponding to the value of y, and the initial condition is K * (0) = K1, μ * (0) = μ1, K2 represents the bulk modulus of the fluid inclusion, μ2 represents the shear modulus of the fluid inclusion, and P and Q are geometric factors.

[0051] In the embodiment of the present invention, K2 and μ2 represent the bulk modulus and shear modulus of the fluid inclusions, respectively, and can be set to 0. P and Q are geometric factors. They are related to the aspect ratio of each phase. The superscript *2 of P and Q indicates that these factors are for the effective modulus K of the fluid included in the background medium of phase 2 solid organic matter (kerogen or asphalt). * and μ *

[0052] In one embodiment, the elastic modulus of porous organic matter without fluid, the organic matter adsorption performance parameter and the organic matter physical form parameter are used to generate the organic elastic property parameter considering the coupling of fluid adsorption performance and pore pressure using the following formula:

[0053]

[0054]

[0055] Among them, K adsorb represents the organic elastic property parameter considering the coupling of fluid adsorption performance and pore pressure, K represents the elastic modulus of porous organic matter without fluid, b is the Biot coefficient, is the Biot modulus, K s is the bulk modulus of the organic part of cheese or asphalt, K f represents the bulk modulus of the fluid, φ0 represents the porosity, p is the pore pressure, R I is the pore radius, is the surface stress of the medium in vacuum, R is the ideal gas constant, T is the absolute temperature, is the maximum adsorption amount of gas per unit surface area, B CO2 is the equilibrium coefficient when the adsorption reaches saturation state.

[0056] In the embodiment of the present invention, K may be the bulk modulus of porous organic matter without fluid effect, that is, the above K * (y) value. It should be noted that when kerogen adsorption s is the bulk modulus of kerogen, when asphalt is adsorbed, K s is the bulk modulus of asphalt.

[0057] In one embodiment, generating an inorganic elastic stiffness coefficient according to a target measurement parameter may be performed according to the following steps:

[0058] The comprehensive elastic modulus of silicate minerals and carbonate minerals is calculated according to the target measurement parameters; the equivalent modulus of the non-clay part is determined according to the inorganic pore parameter and the comprehensive elastic modulus; the inorganic elastic stiffness coefficient is calculated according to the equivalent modulus of the non-clay part and the target measurement parameters.

[0059] In the embodiment of the present invention, the non-clay part includes silicate minerals (quartz and feldspar), carbonate minerals (calcite and dolomite) and inorganic pores. Then, the comprehensive results of silicate minerals and carbonate minerals are calculated using Hill average, and then the inorganic phase is constructed by integrating clay and non-clay. The anisotropic SCA model is used to integrate the clay part and the non-clay part to obtain the equivalent elastic modulus of the inorganic phase part of the shale oil and gas reservoir, which is used as the inorganic elastic stiffness coefficient to complete the construction of the equivalent elastic properties of the inorganic phase part.

[0060] In one embodiment, the comprehensive elastic modulus of silicate minerals and carbonate minerals is calculated according to the target measurement parameters according to the following formula: Among them, M VRHRepresents the comprehensive elastic modulus of silicate minerals and carbonate minerals, f i represents the volume fraction of the i-th phase, M i represents the elastic modulus of the ith phase.

[0061] In the embodiment of the present invention, M i It can be the bulk modulus or the shear modulus. According to the above formula, when N is 2, the calculation can be performed according to the following steps:

[0062] Elastic modulus of silicate minerals: M1 = f1 × M feldspar +(1-f1)×M quartz ;

[0063] Elastic modulus of carbonate minerals: M2 = f2 × M calcite +(1-f2)×M dolomite ;

[0064] in,

[0065] The comprehensive results obtained according to Hill average are as follows:

[0066] M V =(f feldspar +f quartz )M1+(f calcite +f dolomite )M2

[0067]

[0068] Among them, f feldspare 、f quartz 、f calcite 、f dolomite Represent the volume fractions of feldspar, quartz, calcite and dolomite respectively; M feldspare 、M quartz 、M calcite 、M dolomite represents the corresponding elastic modulus, and M can be either the bulk modulus or the shear modulus.

[0069] In one embodiment, the equivalent modulus of the non-clay part is determined according to the inorganic pore parameter and the comprehensive elastic modulus according to the following formula: Where i represents the i-th material, x i represents the volume content of the ith material, represents the equivalent bulk modulus of the non-clay part, It represents the equivalent shear modulus of the non-clay part. P and Q are geometric factors related to the aspect ratio of each phase. The superscript *i of P and Q means that this geometric factor is for the self-compatible equivalent modulus. and The inclusion material i in the background medium, K i represents the bulk modulus of the non-clay part, μ i Represents the shear modulus of the non-clay part.

[0070] In the embodiment of the present invention, after the comprehensive elastic modulus of silicate minerals and carbonate minerals is calculated, the inorganic pores are added using the SCA model to obtain the equivalent elastic modulus of the non-clay part.

[0071] In one embodiment, the inorganic elastic stiffness coefficient is calculated according to the equivalent modulus of the non-clay part and the target measurement parameter according to the following formula: Among them, C sca represents the inorganic elastic stiffness coefficient, I is the unit tensor, v n Indicates the volume percentage of clay and non-clay parts, C n is the stiffness matrix of the n-th phase material, which is converted from the equivalent modulus of the non-clay part, and the tensor G is the Eshelby tensor.

[0072] In an embodiment of the present invention, the value of N can be 2. When n is 1, it can correspond to the calculation of parameters related to the clay part. When n is 2, it can correspond to the calculation of parameters related to the non-clay part. The above formula is used to comprehensively calculate the clay part and the non-clay part to obtain the inorganic elastic stiffness coefficient.

[0073] The formula of the anisotropic SCA model is as follows:

[0074]

[0075] The clay part is given a modulus setting based on the VTI anisotropy assumption (Sayers et al., 2013): c 11 =44.9GPa,c 33 =24.2Gpa,c 44 =3.7Gpa; c 66 =11.6Gpa,c 13 =18.1GPa c 12 =c 11 -2×c 66 ;

[0076]

[0077] The equivalent elastic modulus of the non-clay part is or Its formula is as follows:

[0078] in

[0079]

[0080]

[0081]

[0082] Here, v n (n=1,2…N) represents the volume percentage of each component, C n The stiffness coefficients representing the various components are given by the equivalent modulus of the non-clay part and Convert to C SCA Represents the hybrid stiffness coefficient of the self-consistent overall inorganic phase part, which is a second-order tensor. It is a fourth-order tensor that uses Green's function to characterize the geometry of inclusion compounds.

[0083] In one embodiment, generating coupled shale oil and gas reservoir elastic property parameters according to organic elastic property parameters and inorganic elastic stiffness coefficients may be performed according to the following steps:

[0084] The elastic flexibility coefficient is generated according to the organic elastic property parameters and the inorganic elastic stiffness coefficient; and the coupled shale oil and gas reservoir elastic property parameters are generated according to the elastic flexibility coefficient.

[0085] In the embodiment of the present invention, the anisotropic SCA model is used to fill the kerogen containing organic pores into the inorganic skeleton to obtain a solid background replaced by a solid. The specific calculation can also refer to the formula: The aspect ratio of the inclusions is consistent with that of porous kerogen. Since solid asphalt does not play a skeletal supporting role in rocks, the anisotropic SCA model is used to fill the empty pores with an elastic modulus of 0 into the solid replacement background to obtain the elastic stiffness coefficient of organic shale without asphalt. The aspect ratio of the empty pores is consistent with that of organic pore asphalt, and the volume of the empty pores is the same as that of organic pore asphalt. Anisotropic Gassmann solid replacement is used to characterize the effect of filling with organic pore asphalt on the elastic parameters of the overall shale oil and gas reservoir. The solid replacement formula of anisotropic media can be expressed by the flexibility coefficient.

[0086] In one embodiment, the coupled shale oil and gas reservoir elastic property parameters are generated according to the elastic compliance coefficient according to the following formula: in, represents the elastic compliance coefficient, Represents the coupled shale oil and gas reservoir elastic property parameters, represents the effective flexibility tensor of the mineral, β fl represents the compressibility of pore fluid, β0 represents the compressibility of mineral, and φ represents the porosity.

[0087] In the embodiment of the present invention, the solid replacement formula of the anisotropic medium can be expressed by the flexibility coefficient. The flexibility tensor is obtained by the inverse matrix of the elastic stiffness coefficient. The fourth-order tensor of the stiffness coefficient is required. The conversion relationship is shown in Table 2 below:

[0088] ij(kl) I(J) 11 1 22 2 33 3 23,32 4 13,31 5 12,21 6

[0089] Table 2

[0090]

[0091]

[0092] are the effective elastic stiffness coefficients of dry rock (in the above formula, C SCA The fourth-order tensor of the mineral effective elastic stiffness coefficient (in the above formula ), They are the effective flexibility tensor of rock with fillings, the effective flexibility tensor of dry rock, the effective flexibility tensor of minerals, and the flexibility tensor is the inverse matrix of the stiffness coefficient; K fl is the elastic modulus of the fluid, K0 is the bulk modulus of the solid background, β fl , β0 are the compressibility of pore fluid and mineral, respectively K fl and the reciprocal of K0. This is the final elastic property of shale oil and gas that reflects the inorganic and organic coupling parts. The inverse conversion of the flexibility matrix into a stiffness matrix can obtain the longitudinal and transverse wave velocities of the shale oil and gas reservoir.

[0093] The embodiment of the present invention constructs a seismic rock physics template that considers the coupling of adsorption performance and pore pressure, selects shale oil and gas reservoir pore pressure and reservoir physical parameters (such as porosity) as variables, thereby obtaining shale P-wave impedance and P-wave velocity ratio corresponding to different organic pore pressures and reservoir physical parameters, and then the seismic rock physics template can be used for quantitative seismic interpretation of well logging and seismic elastic data. Figure 3 The schematic diagram of the pore pressure-total porosity seismic rock physics template of shale oil reservoirs shown in the figure shows that with the increase of pore pressure, the longitudinal wave impedance and the aspect ratio velocity ratio show a downward trend. This is mainly due to the increase of pore pressure and the enhanced adsorption effect of shale oil reservoirs, which leads to the reduction of the surface energy of organic pores in shale oil. As the porosity increases, the influence of pore pressure on elastic properties also gradually increases. This is mainly because with the increase of organic porosity, its adsorption effect shows an increasing trend, so the coupling effect of pore pressure and adsorption performance shows an increasing trend.

[0094] The embodiment of the present invention provides a method and device for generating elastic parameters of shale oil and gas reservoirs, see Figure 2 The workflow diagram of rock physical modeling of shale oil and gas reservoirs taking into account the adsorption effect is shown. The elastic parameters of shale oil and gas reservoirs obtained by this method take into account the adsorption performance of organic pores and pore pressure, and can quantitatively characterize the influence of the adsorption performance of different fluids under different physical conditions on the elastic properties of shale oil and gas reservoirs, thereby providing a new technical means for predicting oil and gas richness, characterizing reservoir physical parameters and predicting pore pressure based on logging and seismic data.

[0095] The present invention also provides a shale oil and gas reservoir elastic parameter generation device, as described in the following embodiments. Since the principle of the device to solve the problem is similar to the shale oil and gas reservoir elastic parameter generation method, the implementation of the device can refer to the implementation of the shale oil and gas reservoir elastic parameter generation method, and the repeated parts will not be repeated. Figure 4 The structural block diagram of the shale oil and gas reservoir elastic parameter generation device shown in the figure includes:

[0096] An acquisition module 71 is used to acquire target measurement parameters, organic matter adsorption performance parameters and organic matter physical form parameters of shale oil and gas reservoirs; an organic module 72 is used to generate organic elastic property parameters that consider the coupling of fluid adsorption performance and pore pressure based on the organic matter adsorption performance parameters and the organic matter physical form parameters; an inorganic module 73 is used to generate inorganic elastic stiffness coefficients based on the target measurement parameters; a synthesis module 74 is used to generate coupled shale oil and gas reservoir elastic property parameters based on the organic elastic property parameters and the inorganic elastic stiffness coefficients; a calculation module 75 is used to generate shale oil and gas reservoir elastic parameters based on the coupled shale oil and gas reservoir elastic property parameters.

[0097] In one embodiment, the organic module is specifically used to: calculate the elastic modulus of porous organic matter without fluid based on organic matter adsorption performance parameters and organic matter physical form parameters; use the elastic modulus of porous organic matter without fluid, organic matter adsorption performance parameters and organic matter physical form parameters to generate organic elastic property parameters that take into account the coupling of fluid adsorption performance and pore pressure.

[0098] In one embodiment, the organic module is specifically used to calculate the elastic modulus of porous organic matter without fluid according to the organic matter adsorption performance parameter and the organic matter physical form parameter using the following formula: Where y represents the volume percentage of organic pores in the entire porous organic matter, K * (y) represents the bulk modulus of porous organic matter without fluid corresponding to the y value, μ * (y) represents the shear modulus of porous organic matter without fluid corresponding to the value of y, and the initial condition is K * (0) = K1, μ *(0) = μ1, K2 represents the bulk modulus of the fluid inclusion, μ2 represents the shear modulus of the fluid inclusion, and P and Q are geometric factors.

[0099] In one embodiment, the organic module is specifically used to generate organic elastic property parameters that consider the coupling of fluid adsorption performance and pore pressure using the following formula using the elastic modulus of porous organic matter without fluid, organic adsorption performance parameters and organic physical form parameters: Among them, K adsorb represents the organic elastic property parameter considering the coupling of fluid adsorption performance and pore pressure, K represents the elastic modulus of porous organic matter without fluid, b is the Biot coefficient, is the Biot modulus, K s is the bulk modulus of the organic part of cheese or asphalt, K f represents the bulk modulus of the fluid, φ0 represents the porosity, p is the pore pressure, R I is the pore radius, is the surface stress of the medium in vacuum, R is the ideal gas constant, T is the absolute temperature, is the maximum adsorption amount of gas per unit surface area, B CO2 is the equilibrium coefficient when the adsorption reaches saturation state.

[0100] In one embodiment, the inorganic module is specifically used to: calculate the comprehensive elastic modulus of silicate minerals and carbonate minerals according to the target measurement parameters; determine the equivalent modulus of the non-clay part according to the inorganic pore parameters and the comprehensive elastic modulus; calculate the inorganic elastic stiffness coefficient according to the equivalent modulus of the non-clay part and the target measurement parameters.

[0101] In one embodiment, the inorganic module is specifically used to calculate the comprehensive elastic modulus of silicate minerals and carbonate minerals according to the target measurement parameters according to the following formula: Among them, M VRH Represents the comprehensive elastic modulus of silicate minerals and carbonate minerals, f i represents the volume fraction of the i-th phase, M i represents the elastic modulus of the ith phase.

[0102] In one embodiment, the inorganic module is specifically used to determine the equivalent modulus of the non-clay part according to the inorganic pore parameter and the comprehensive elastic modulus according to the following formula: Where i represents the i-th material, x i represents the volume content of the ith material, represents the equivalent bulk modulus of the non-clay part, It represents the equivalent shear modulus of the non-clay part. P and Q are geometric factors related to the aspect ratio of each phase. The superscript *i of P and Q means that this geometric factor is for the self-compatible equivalent modulus. and The inclusion material i in the background medium, K i represents the bulk modulus of the non-clay part, μ i represents the shear modulus of the non-clay part

[0103] In one embodiment, the inorganic module is specifically used to calculate the inorganic elastic stiffness coefficient according to the equivalent modulus of the non-clay part and the target measurement parameter according to the following formula: Among them, C sca represents the inorganic elastic stiffness coefficient, I is the unit tensor, v n Indicates the volume percentage of clay and non-clay parts, C n is the stiffness matrix of the n-th phase material, which is converted from the equivalent modulus of the non-clay part, and the tensor G is the Eshelby tensor.

[0104] In one embodiment, the synthesis module is specifically used to: generate an elastic compliance coefficient according to organic elastic property parameters and inorganic elastic stiffness coefficients; and generate coupled shale oil and gas reservoir elastic property parameters according to the elastic compliance coefficients.

[0105] In one embodiment, the synthesis module is specifically used to generate coupled shale oil and gas reservoir elastic property parameters according to the elastic compliance coefficient according to the following formula: in, represents the elastic compliance coefficient, Represents the coupled shale oil and gas reservoir elastic property parameters, represents the effective flexibility tensor of the mineral, β fl represents the compressibility of pore fluid, β0 represents the compressibility of mineral, and φ represents the porosity.

[0106] The embodiment of the present invention also provides a computer device, see Figure 5 The computer device structure schematic block diagram shown includes a memory 81, a processor 82, and a computer program stored in the memory and executable on the processor. When the processor executes the computer program, the steps of any one of the above-mentioned methods for generating elastic parameters of shale oil and gas reservoirs are implemented.

[0107] Those skilled in the art can clearly understand that, for the convenience and brevity of description, the specific working process of the computer device described above can refer to the corresponding process in the aforementioned method embodiment, and will not be repeated here.

[0108] An embodiment of the present invention further provides a computer-readable storage medium, which stores a computer program for executing any of the above-mentioned methods for generating elastic parameters of shale oil and gas reservoirs.

[0109] Those skilled in the art will appreciate that embodiments of the present invention may be provided as methods, systems, or computer program products. Therefore, the present invention may take the form of a complete hardware embodiment, a complete software embodiment, or an embodiment combining software and hardware. Moreover, the present invention may take the form of a computer program product implemented on one or more computer-usable storage media (including but not limited to disk storage, CD-ROM, optical storage, etc.) containing computer-usable program code.

[0110] The present invention is described with reference to flowcharts and / or block diagrams of methods, devices (systems), and computer program products according to embodiments of the present invention. It should be understood that each process and / or block in the flowchart and / or block diagram, as well as the combination of processes and / or blocks in the flowchart and / or block diagram, can be implemented by computer program instructions. These computer program instructions can be provided to a processor of a general-purpose computer, a special-purpose computer, an embedded processor, or other programmable data processing device to produce a machine, so that the instructions executed by the processor of the computer or other programmable data processing device generate instructions for implementing the processes in the flowchart and / or block diagram. Figure 1 A process or multiple processes and / or boxes Figure 1 A device that provides the functions specified in a block or multiple blocks.

[0111] These computer program instructions may also be stored in a computer readable memory capable of directing a computer or other programmable data processing device to operate in a specific manner, so that the instructions stored in the computer readable memory produce an article of manufacture including an instruction device, which implements the process Figure 1 A process or multiple processes and / or boxes Figure 1 A function specified in one or more boxes.

[0112] These computer program instructions can also be loaded onto a computer or other programmable data processing device so that a series of operating steps are executed on the computer or other programmable device to produce a computer-implemented process, thereby providing instructions for implementing the process. Figure 1 A process or multiple processes and / or boxes Figure 1 The steps for the functions specified in one or more boxes.

[0113] Finally, it should be noted that the above-described embodiments are only specific implementations of the present invention, which are used to illustrate the technical solutions of the present invention, rather than to limit them. The protection scope of the present invention is not limited thereto. Although the present invention is described in detail with reference to the above-described embodiments, ordinary technicians in the field should understand that any technician familiar with the technical field can still modify the technical solutions recorded in the above-described embodiments within the technical scope disclosed by the present invention, or can easily think of changes, or make equivalent replacements for some of the technical features therein; and these modifications, changes or replacements do not make the essence of the corresponding technical solutions deviate from the spirit and scope of the technical solutions of the embodiments of the present invention, and should be included in the protection scope of the present invention. Therefore, the protection scope of the present invention shall be subject to the protection scope of the claims.

Claims

1. A method for generating elastic parameters of shale oil and gas reservoirs, characterized in that: include: Obtain target measurement parameters, organic matter adsorption performance parameters and organic matter physical form parameters of shale oil and gas reservoirs; Generating organic elastic property parameters considering the coupling of fluid adsorption performance and pore pressure according to the organic matter adsorption performance parameters and the organic matter physical form parameters; generating an inorganic elastic stiffness coefficient according to the target measurement parameter; generating coupled shale oil and gas reservoir elastic property parameters according to the organic elastic property parameters and the inorganic elastic stiffness coefficient; Generating shale oil and gas reservoir elasticity parameters according to the coupled shale oil and gas reservoir elasticity property parameters; Generating organic elastic property parameters considering the coupling of fluid adsorption performance and pore pressure according to the organic matter adsorption performance parameters and the organic matter physical form parameters includes: Calculating the elastic modulus of porous organic matter without fluid according to the organic matter adsorption performance parameter and the organic matter physical form parameter; Generate organic elastic property parameters that consider the coupling of fluid adsorption performance and pore pressure by using the elastic modulus of the porous organic matter without fluid, the organic matter adsorption performance parameter and the organic matter physical form parameter; The elastic modulus of the porous organic matter without fluid, the organic matter adsorption performance parameter and the organic matter physical form parameter are used to generate the organic elastic property parameter considering the coupling of fluid adsorption performance and pore pressure using the following formula: Among them, K adsorb represents the organic elastic property parameter considering the coupling of fluid adsorption performance and pore pressure, K represents the elastic modulus of porous organic matter without fluid, b is the Biot coefficient, is the Biot modulus, K s is the bulk modulus of the organic part of cheese or asphalt, K f represents the bulk modulus of the fluid, φ0 represents the porosity, p is the pore pressure, R I is the pore radius, is the surface stress of the medium in vacuum, R is the ideal gas constant, T is the absolute temperature, is the maximum adsorption amount of gas per unit surface area, B CO2 is the equilibrium coefficient when the adsorption reaches saturation state.

2. The method according to claim 1, characterized in that The method comprises calculating the elastic modulus of the porous organic matter without fluid according to the organic matter adsorption performance parameter and the organic matter physical form parameter using the following formula: Where y represents the volume percentage of organic pores in the entire porous organic matter, K * (y) represents the bulk modulus of porous organic matter without fluid corresponding to the y value, μ * (y) represents the shear modulus of porous organic matter without fluid corresponding to the value of y, and the initial condition is K * (0) = K1, μ * (0) = μ1, K2 represents the bulk modulus of the fluid inclusion, μ2 represents the shear modulus of the fluid inclusion, P and Q are geometric factors; the superscript *2 of P and Q represents the effective modulus K of the fluid inclusion in the solid organic background medium of phase 2 * and μ * .

3. The method according to claim 1, characterized in that Generating an inorganic elastic stiffness coefficient according to the target measurement parameter includes: Calculating the comprehensive elastic modulus of silicate minerals and carbonate minerals according to the target measurement parameters; Determining the equivalent modulus of the non-clay part according to the inorganic pore parameter and the comprehensive elastic modulus; The inorganic elastic stiffness coefficient is calculated according to the equivalent modulus of the non-clay part and the target measurement parameter.

4. The method according to claim 3, characterized in that The method includes calculating the comprehensive elastic modulus of silicate minerals and carbonate minerals according to the target measurement parameters according to the following formula: Among them, M VRH Represents the comprehensive elastic modulus of silicate minerals and carbonate minerals, f i represents the volume fraction of the i-th phase, M i represents the elastic modulus of the i-th phase.

5. The method according to claim 3, characterized in that: The method includes determining the equivalent modulus of the non-clay part according to the inorganic pore parameter and the comprehensive elastic modulus according to the following formula: Where i represents the i-th material, x i represents the volume content of the ith material, represents the equivalent bulk modulus of the non-clay part, It represents the equivalent shear modulus of the non-clay part. P and Q are geometric factors related to the aspect ratio of each phase. The superscript *i of P and Q means that this geometric factor is for the self-compatible equivalent modulus. and The inclusion material i in the background medium, K i represents the bulk modulus of the non-clay part, μ i Represents the shear modulus of the non-clay part.

6. The method according to claim 3, characterized in that The method includes calculating the inorganic elastic stiffness coefficient according to the equivalent modulus of the non-clay part and the target measurement parameter according to the following formula: Among them, C sca represents the inorganic elastic stiffness coefficient, I is the unit tensor, v n Indicates the volume percentage of clay and non-clay parts, C n is the stiffness matrix of the n-phase material, which is converted from the equivalent modulus of the non-clay part, and the tensor G is the Eshelby tensor; is a fourth-order tensor that uses Green's function to characterize the geometry of the inclusion compound; Represent the fourth-order tensor The index arrangements are in the form of ijkl, ikjl, and jkil, which are used to describe the tensor characteristics under different index arrangements.

7. The method according to claim 1, characterized in that Generate coupled shale oil and gas reservoir elastic property parameters according to the organic elastic property parameters and the inorganic elastic stiffness coefficient, including: generating an elastic compliance coefficient according to the organic elastic property parameter and the inorganic elastic stiffness coefficient; The coupled shale oil and gas reservoir elastic property parameters are generated according to the elastic flexibility coefficient.

8. The method according to claim 7, characterized in that The method includes generating coupled shale oil and gas reservoir elastic property parameters according to the elastic flexibility coefficient according to the following formula: in, and They represent the index arrangement of the elastic flexibility tensor in the form of ijkl, ijaa, klaa and ααββ respectively; Represents the coupled shale oil and gas reservoir elastic property parameters, as well as They represent the index arrangement of the mineral effective flexibility tensor as jiaa, klaa and ααββ, β fl represents the compressibility of pore fluid, β0 represents the compressibility of mineral, and φ represents the porosity.

9. A shale oil and gas reservoir elastic parameter generation device, characterized in that: include: An acquisition module is used to obtain target measurement parameters, organic matter adsorption performance parameters and organic matter physical form parameters of shale oil and gas reservoirs; An organic module, used for generating organic elastic property parameters considering the coupling of fluid adsorption performance and pore pressure according to the organic matter adsorption performance parameters and the organic matter physical form parameters; An inorganic module, used for generating an inorganic elastic stiffness coefficient according to the target measurement parameter; A synthesis module, used for generating coupled shale oil and gas reservoir elastic property parameters according to the organic elastic property parameters and the inorganic elastic stiffness coefficient; A calculation module, used for generating shale oil and gas reservoir elastic parameters according to the coupled shale oil and gas reservoir elastic property parameters; The organic module is specifically used for: Calculating the elastic modulus of porous organic matter without fluid according to the organic matter adsorption performance parameter and the organic matter physical form parameter; Generate organic elastic property parameters that consider the coupling of fluid adsorption performance and pore pressure by using the elastic modulus of the porous organic matter without fluid, the organic matter adsorption performance parameter and the organic matter physical form parameter; The organic module is specifically used to generate organic elastic property parameters that consider the coupling of fluid adsorption performance and pore pressure by using the elastic modulus of the porous organic matter without fluid, the organic matter adsorption performance parameter and the organic matter physical form parameter using the following formula: Among them, K adsorb represents the organic elastic property parameter considering the coupling of fluid adsorption performance and pore pressure, K represents the elastic modulus of porous organic matter without fluid, b is the Biot coefficient, is the Biot modulus, K s is the bulk modulus of the organic part of cheese or asphalt, K f represents the bulk modulus of the fluid, φ0 represents the porosity, p is the pore pressure, R I is the pore radius, is the surface stress of the medium in vacuum, R is the ideal gas constant, T is the absolute temperature, is the maximum adsorption amount of gas per unit surface area, B C02 is the equilibrium coefficient when the adsorption reaches saturation state.

10. The device according to claim 9, characterized in that The organic module is specifically used to calculate the elastic modulus of porous organic matter without fluid according to the organic matter adsorption performance parameter and the organic matter physical form parameter using the following formula: Where y represents the volume percentage of organic pores in the entire porous organic matter, K * (y) represents the bulk modulus of porous organic matter without fluid corresponding to the y value, μ * (y) represents the shear modulus of porous organic matter without fluid corresponding to the value of y, and the initial condition is K * (0) = K1, μ * (0) = μ1, K2 represents the bulk modulus of the fluid inclusion, μ2 represents the shear modulus of the fluid inclusion, and P and Q are geometric factors.

11. The device according to claim 9, characterized in that The inorganic module is specifically used for: Calculating the comprehensive elastic modulus of silicate minerals and carbonate minerals according to the target measurement parameters; Determining the equivalent modulus of the non-clay part according to the inorganic pore parameter and the comprehensive elastic modulus; The inorganic elastic stiffness coefficient is calculated according to the equivalent modulus of the non-clay part and the target measurement parameter.

12. The device according to claim 11, characterized in that The inorganic module is specifically used to calculate the comprehensive elastic modulus of silicate minerals and carbonate minerals according to the target measurement parameters according to the following formula: Among them, M VRH Represents the comprehensive elastic modulus of silicate minerals and carbonate minerals, f i represents the volume fraction of the i-th phase, M i represents the elastic modulus of the i-th phase.

13. The device according to claim 11, characterized in that The inorganic module is specifically used to determine the equivalent modulus of the non-clay part according to the inorganic pore parameter and the comprehensive elastic modulus according to the following formula: Where i represents the i-th material, x i represents the volume content of the ith material, represents the equivalent bulk modulus of the non-clay part, It represents the equivalent shear modulus of the non-clay part. P and Q are geometric factors related to the aspect ratio of each phase. The superscript *i of P and Q means that this geometric factor is for the self-compatible equivalent modulus. and The inclusion material i in the background medium, K i represents the bulk modulus of the non-clay part, μ i Represents the shear modulus of the non-clay part.

14. The device according to claim 11, characterized in that The inorganic module is specifically used to calculate the inorganic elastic stiffness coefficient according to the equivalent modulus of the non-clay part and the target measurement parameter according to the following formula: Among them, C sca represents the inorganic elastic stiffness coefficient, I is the unit tensor, v n Indicates the volume percentage of clay and non-clay parts, C n is the stiffness matrix of the n-phase material, which is converted from the equivalent modulus of the non-clay part, and the tensor G is the Eshelby tensor; is a fourth-order tensor that uses Green's function to characterize the geometry of the inclusion compound; Represent the fourth-order tensor The index arrangements are in the form of ijkl, ikjl, and jkil, which are used to describe the tensor characteristics under different index arrangements.

15. The device according to claim 9, characterized in that The synthesis module is specifically used for: generating an elastic compliance coefficient according to the organic elastic property parameter and the inorganic elastic stiffness coefficient; The coupled shale oil and gas reservoir elastic property parameters are generated according to the elastic flexibility coefficient.

16. The device according to claim 15, characterized in that The synthesis module is specifically used to generate coupled shale oil and gas reservoir elastic property parameters according to the elastic flexibility coefficient according to the following formula: in, and They represent the index arrangement of the elastic flexibility tensor in the form of ijkl, ijaa, klaa and ααββ respectively; Represents the coupled shale oil and gas reservoir elastic property parameters, as well as They represent the index arrangement of the mineral effective flexibility tensor as ijaa, klaa and ααββ, β fl represents the compressibility of pore fluid, β0 represents the compressibility of mineral, and φ represents the porosity.

17. A computer device comprising a memory, a processor, and a computer program stored in the memory and executable on the processor, characterized in that: When the processor executes the computer program, the method for generating elastic parameters of shale oil and gas reservoirs as claimed in any one of claims 1 to 8 is implemented.

18. A computer-readable storage medium, characterized in that: The computer-readable storage medium stores a computer program for executing the method for generating elastic parameters of shale oil and gas reservoirs as described in any one of claims 1 to 8.

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