CN109597964B - Theoretical reservoir seepage parameter value determining method, system, equipment and readable medium - Google Patents
Theoretical reservoir seepage parameter value determining method, system, equipment and readable medium Download PDFInfo
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Abstract
The invention provides a theoretical reservoir seepage parameter value determining method, a theoretical reservoir seepage parameter value determining system, theoretical reservoir seepage parameter value determining equipment and a theoretical reservoir seepage parameter value determining readable medium. The method comprises the following steps: solving theoretical seismic traces corresponding to all possible reservoir seepage parameter combinations in the target stratum; performing difference processing on the actual seismic channel and each theoretical seismic channel to obtain a difference section corresponding to each theoretical seismic channel; and obtaining a zero-value channel from the difference profile, wherein the reservoir seepage parameter corresponding to the zero-value channel is a determined theoretical reservoir seepage parameter value. The method can find the determined theoretical oil reservoir seepage parameter value at one time through the computer, does not need repeated tests for a plurality of rounds, saves time compared with an iteration method, has uniform standard and smaller error, and can be cited in a large scale.
Description
Technical Field
The invention relates to the technical field of oil reservoir permeation, in particular to a theoretical oil reservoir seepage parameter value determining method, system, equipment and readable medium.
Background
In the petroleum exploitation process, the oil reservoir seepage parameters (mainly including porosity, permeability, saturation and the like) change at any moment, which inevitably leads to the change of the oil reservoir speed and density, namely the change of wave impedance, and thus the change of the seismic phase.
At present, the industry commonly utilizes an iterative convolution method to establish the relation between oil reservoir seepage parameters and earthquakes: the method comprises the steps of setting initial oil reservoir seepage parameters, converting the oil reservoir seepage parameters into geophysical parameters such as speed, density and the like by utilizing theories such as solving equations, obtaining corresponding theoretical seismic channels by convolution with seismic wavelets, analyzing and comparing the theoretical seismic channels with actual data, and modifying the oil reservoir seepage parameters until the difference between the theoretical seismic channels and the actual data is within an acceptable range if the difference is large.
Because repeated tests are needed, the iterative convolution method is time-consuming and labor-consuming, and because the uniform and effective standard is lacking in the process of modifying the oil reservoir seepage parameters, the difference between the seismic trace obtained after the oil reservoir seepage parameters are modified and the actual data is larger, and the iterative convolution method cannot be applied on a large scale.
Disclosure of Invention
In order to solve the problem that the conventional method cannot be applied on a large scale due to time and labor consumption and lack of unified and effective modification standards in the conventional method for determining the permeability parameters of the oil reservoir, the invention provides a theoretical oil reservoir permeability parameter value determining method, a theoretical oil reservoir permeability parameter value determining system, theoretical oil reservoir permeability parameter value determining equipment and a theoretical oil reservoir permeability parameter value determining method and a theoretical oil reservoir permeability parameter value determining device.
In certain embodiments, a method of determining theoretical reservoir seepage parameter values comprises:
solving theoretical seismic traces corresponding to all possible reservoir seepage parameter combinations in the target stratum;
performing difference processing on the actual seismic channel and each theoretical seismic channel to obtain a difference section corresponding to each theoretical seismic channel;
and obtaining a zero-value channel from the difference profile, wherein the reservoir seepage parameter corresponding to the zero-value channel is a determined theoretical reservoir seepage parameter value.
In certain embodiments, a theoretical reservoir seepage parameter value determination system comprises:
the theoretical seismic channel calculating module calculates theoretical seismic channels corresponding to all possible reservoir seepage parameter combinations in the target stratum;
the difference processing module is used for performing difference processing on the actual seismic channel and each theoretical seismic channel to obtain a difference section corresponding to each theoretical seismic channel;
and the acquisition module acquires a zero-value channel from the difference profile, wherein the oil reservoir seepage parameter corresponding to the zero-value channel is a determined theoretical oil reservoir seepage parameter value.
In certain embodiments, a computer device includes a memory, a processor, and a computer program stored on the memory and executable on the processor, which when executed implements the steps of theoretical reservoir seepage parameter value determination as described above.
In certain embodiments, a computer readable storage medium has stored thereon a computer program which when executed by a processor performs the steps of theoretical reservoir seepage parameter value determination as described above.
The invention has the beneficial effects that:
the method, the system, the equipment and the readable medium for determining the theoretical oil reservoir seepage parameter value provided by the invention are characterized in that the corresponding theoretical seismic channels are obtained through combining all oil reservoir seepage parameters, and the difference treatment is carried out, so that the difference section corresponding to each possible combination is obtained, and a zero value channel is searched, wherein the oil reservoir seepage parameter corresponding to the zero value channel is the determined theoretical oil reservoir seepage parameter value.
Drawings
In order to more clearly illustrate the embodiments of the invention or the technical solutions in the prior art, the drawings that are required in the embodiments or the description of the prior art will be briefly described, it being obvious that the drawings in the following description are only some embodiments of the invention, and that other drawings may be obtained according to these drawings without inventive effort for a person skilled in the art.
Fig. 1 shows a flow chart of a method for determining a theoretical reservoir seepage parameter value in an embodiment of the invention.
Fig. 2 shows a specific flow diagram of step S1 of fig. 1.
Fig. 3 shows a specific flowchart of step S11 in fig. 2.
FIG. 4 shows velocity profiles for the combined transformation of different reservoir seepage parameters in an embodiment of the present invention.
Fig. 5 shows a demonstration of a theoretical seismic trace in an embodiment of the invention.
FIG. 6 is a diagram illustrating a process of forming a difference profile for a difference between a theoretical seismic trace and an actual seismic trace in an embodiment of the invention.
Fig. 7 shows a schematic representation of a difference profile of an embodiment of the invention.
Fig. 8 shows a schematic structural diagram of a theoretical reservoir seepage parameter value determining system in an embodiment of the invention.
Fig. 9 shows a specific structural diagram of the theoretical seismic trace finding module 101 in fig. 8.
Fig. 10 is a schematic diagram showing a specific configuration of the reservoir wave impedance determination unit 111 in fig. 9.
Fig. 11 shows a schematic structural diagram of a computer device suitable for use in implementing embodiments of the present application.
Detailed Description
The following description of the embodiments of the present invention will be made clearly and completely with reference to the accompanying drawings, in which it is apparent that the embodiments described are only some embodiments of the present invention, but not all embodiments. All other embodiments, which can be made by those skilled in the art based on the embodiments of the invention without making any inventive effort, are intended to be within the scope of the invention.
At present, the industry commonly utilizes an iterative convolution method to establish the relation between oil reservoir seepage parameters and earthquakes: the method comprises the steps of setting initial oil reservoir seepage parameters, converting the oil reservoir seepage parameters into geophysical parameters such as speed, density and the like by utilizing theories such as solving equations, obtaining corresponding theoretical seismic channels by convolution with seismic wavelets, analyzing and comparing the theoretical seismic channels with actual data, and modifying the oil reservoir seepage parameters until the difference between the theoretical seismic channels and the actual data is within an acceptable range if the difference is large.
Because repeated tests are needed, the iterative convolution method is time-consuming and labor-consuming, and because the uniform and effective standard is lacking in the process of modifying the oil reservoir seepage parameters, the difference between the seismic trace obtained after the oil reservoir seepage parameters are modified and the actual data is larger, and the iterative convolution method cannot be applied on a large scale.
In view of this, the present invention provides a theoretical reservoir seepage parameter value determination method, system, device, readable medium.
Fig. 1 shows a flow chart of a theoretical reservoir seepage parameter value determining method in an embodiment of the invention, which includes:
s1, solving theoretical seismic traces corresponding to all possible reservoir seepage parameter combinations in the target stratum.
S2, performing difference processing on the actual seismic channels and each theoretical seismic channel to obtain a difference section corresponding to each theoretical seismic channel;
and S3, obtaining a zero-value channel from the difference section, wherein the oil reservoir seepage parameter corresponding to the zero-value channel is a determined theoretical oil reservoir seepage parameter value.
According to the theoretical oil reservoir seepage parameter value determining method provided by the invention, through solving the corresponding theoretical seismic traces for all oil reservoir seepage parameter combinations and performing difference processing, the difference profile corresponding to each possible combination is obtained, so that the zero value trace in the theoretical seismic traces is found, and the oil reservoir seepage parameter corresponding to the zero value trace is the determined theoretical oil reservoir seepage parameter value.
Specifically, the reservoir seepage parameters include: porosity, permeability, and saturation.
In some embodiments, the reservoir permeability parameters are porosity, permeability, and saturation in a rock formation (the target formation in this embodiment). It is assumed that a general range can be obtained from prior rock analysis, for example, a porosity of 5-30%, a permeability of 10-17% and a saturation of 70-90%.
Splitting the above range into a plurality of combinations according to a preset interval, for example, the preset interval of each parameter is 1%, and then the range of the porosity can be split into: 5%, 6%, 7% to 30%. And vice versa for permeability and saturation. Then as an example one of the possible combinations is: (porosity 5%, permeability 10%, saturation 70%).
Of course, the preset interval may be set as needed, and the preset interval of each parameter may be the same or different.
In some embodiments, as shown in connection with fig. 2, step S1 specifically includes:
and S11, obtaining the oil reservoir wave impedance corresponding to each oil reservoir seepage parameter combination according to all possible oil reservoir seepage parameter combinations in the target stratum.
Specifically, the equation may be calculated, and in one embodiment, as shown in fig. 3, step S11 specifically includes:
and S111, converting all possible combinations of oil reservoir seepage parameters into wave velocity of longitudinal waves and pore fluid medium rock density.
Specifically, the equation may be calculated.
The equation is calculated as:
wherein Vp is longitudinal wave velocity, ρ, K, M and μ are density, bulk modulus, plane wave modulus and shear modulus, ρ, respectively, of the pore fluid medium rock d 、ρ m And ρ f The density of the fluid in the rock matrix, rock matrix and pores, respectively.
From the above equations, it can be appreciated that the density of the pore fluid medium rock is determined from the density of the rock matrix, rock matrix and the fluid in the pores; the wave velocity of the longitudinal wave converted by all possible combinations of reservoir seepage parameters is obtained according to the density, the bulk modulus, the plane wave modulus and the shear modulus of the pore fluid medium rock, and the invention is not repeated.
In one embodiment, the target formation is a geologic model of only two layers: the first layer is mudstone, the speed and density are all known constants, and the second layer is sandstone of an aqueous oil-water mixture. FIG. 4 is a velocity profile of a transformation using a solution equation based on different reservoir seepage parameter combinations.
And S112, obtaining the oil reservoir wave impedance value by integrating the longitudinal wave velocity and the pore fluid medium rock density of each group of combinations.
The ratio of the pressure acting on an area to the flow of particles vertically through the area per unit time (i.e. area times particle vibration velocity) as the seismic wave propagates through the medium has the meaning of a resistance, called wave impedance, which is equal to the product of the medium density p and the wave velocity V.
S12, obtaining the reflection coefficient of each reservoir wave impedance.
S13, carrying out convolution on the seismic wavelets and each reflection coefficient to obtain theoretical seismic channels corresponding to each combination.
FIG. 5 is a theoretical seismic trace obtained by convolution. FIG. 6 is a demonstration of a difference profile formed by making differences between a theoretical seismic trace and an actual seismic trace. Fig. 7 is a resulting difference profile, from which it can be seen that zero-valued traces are uniform lines in the difference profile.
Since each possible combination is calculated by means of traversal, there must be zero-valued traces. And the oil reservoir seepage parameter corresponding to the zero-value channel is the target parameter value.
The invention further provides a theoretical reservoir seepage parameter value determining system, which is shown in combination with fig. 8 and comprises:
the theoretical seismic trace calculation module 101 calculates theoretical seismic traces corresponding to all possible reservoir seepage parameter combinations in the target stratum;
the difference processing module 102 performs difference processing on the actual seismic trace and each theoretical seismic trace to obtain a difference section corresponding to each theoretical seismic trace
And an obtaining module 103, obtaining a zero-value channel from the difference profile, wherein the reservoir seepage parameter corresponding to the zero-value channel is a determined theoretical reservoir seepage parameter value.
Specifically, the reservoir seepage parameters include: porosity, permeability, and saturation.
In some embodiments, the reservoir permeability parameters are porosity, permeability, and saturation in a rock formation (the target formation in this embodiment). It is assumed that a general range can be obtained from prior rock analysis, for example, a porosity of 5-30%, a permeability of 10-17% and a saturation of 70-90%.
Splitting the above range into a plurality of combinations according to a preset interval, for example, the preset interval of each parameter is 1%, and then the range of the porosity can be split into: 5%, 6%, 7% to 30%. And vice versa for permeability and saturation. Then as an example one of the possible combinations is: (porosity 5%, permeability 10%, saturation 70%).
Of course, the preset interval may be set as needed, and the preset interval of each parameter may be the same or different.
In some embodiments, in conjunction with fig. 9, the theoretical seismic trace calculation module 101 includes:
the reservoir wave impedance obtaining unit 111 obtains the reservoir wave impedance corresponding to each reservoir seepage parameter combination according to all possible reservoir seepage parameter combinations in the target stratum;
a reflection coefficient calculation unit 112 that calculates a reflection coefficient for each reservoir wave impedance;
and a convolution processing unit 113 for obtaining theoretical seismic traces corresponding to each reservoir seepage parameter combination by convolving the seismic wavelet and each reflection coefficient.
Further, as can be seen from fig. 10, the reservoir wave impedance obtaining unit 111 includes:
a conversion unit 121 for converting all possible combinations of reservoir seepage parameters into wave velocity of longitudinal waves and pore fluid medium rock density;
the product unit 122 obtains the reservoir wave impedance value by integrating the longitudinal wave velocity and the pore fluid medium rock density of each group.
In one embodiment, the wave velocity of the longitudinal wave and the pore fluid medium rock density may be determined by solving an equation.
The equation is calculated as:
wherein Vp is longitudinal wave velocity, ρ, K, M and μ are density, bulk modulus, plane wave modulus and shear modulus, ρ, respectively, of the pore fluid medium rock d 、ρ m And ρ f The density of the fluid in the rock matrix, rock matrix and pores, respectively.
From the above equation, it can be unambiguously determined that the conversion unit comprises:
a density calculating unit for calculating the density of the pore fluid medium rock according to the densities of the rock framework, the rock matrix and the fluid in the pores;
and the longitudinal wave velocity obtaining unit is used for obtaining the wave velocity of the longitudinal wave converted by the possible combination of all the oil reservoir seepage parameters according to the density, the bulk modulus, the plane wave modulus and the shear modulus of the pore fluid medium rock.
In one embodiment, the target formation is a geologic model of only two layers: the first layer is mudstone, the speed and density are all known constants, and the second layer is sandstone of an aqueous oil-water mixture. FIG. 4 is a velocity profile of a transformation using a solution equation based on different reservoir seepage parameters.
FIG. 5 is a theoretical seismic trace obtained by convolution. FIG. 6 is a demonstration of a difference profile formed by making differences between a theoretical seismic trace and an actual seismic trace. Fig. 7 is a resulting difference profile, from which it can be seen that zero-valued traces are uniform lines in the difference profile.
Since each possible combination is calculated by means of traversal, there must be zero-valued traces. And the oil reservoir seepage parameter corresponding to the zero-value channel is the target parameter value.
Obviously, the theoretical oil reservoir seepage parameter value determining system provided by the invention can find the determined theoretical oil reservoir seepage parameter value through a computer at one time, does not need repeated tests for a plurality of times, saves time compared with an iteration method, has uniform standard and smaller error, and can be cited on a large scale.
Referring now to FIG. 11, there is illustrated a schematic diagram of a computer device 600 suitable for use in implementing embodiments of the present application.
As shown in fig. 11, the computer apparatus 600 includes a Central Processing Unit (CPU) 601, which can perform various appropriate works and processes according to a program stored in a Read Only Memory (ROM) 602 or a program loaded from a storage section 608 into a Random Access Memory (RAM)) 603. In the RAM603, various programs and data required for the operation of the system 600 are also stored. The CPU601, ROM602, and RAM603 are connected to each other through a bus 604. An input/output (I/O) interface 605 is also connected to bus 604.
The following components are connected to the I/O interface 605: an input portion 606 including a keyboard, mouse, etc.; an output portion 607 including a Cathode Ray Tube (CRT), a Liquid Crystal Display (LCD), and the like, a speaker, and the like; a storage section 608 including a hard disk and the like; and a communication section 609 including a network interface card such as a LAN card, a modem, or the like. The communication section 609 performs communication processing via a network such as the internet. The drive 610 is also connected to the I/O interface 606 as needed. Removable media 611 such as a magnetic disk, an optical disk, a magneto-optical disk, a semiconductor memory, or the like is mounted on drive 610 as needed, so that a computer program read therefrom is mounted as needed as storage section 608.
In particular, according to embodiments of the present invention, the processes described above with reference to flowcharts may be implemented as computer software programs. For example, embodiments of the present invention include a computer program product comprising a computer program tangibly embodied on a machine-readable medium, the computer program comprising program code for performing the method shown in the flowchart. In such an embodiment, the computer program may be downloaded and installed from a network through the communication portion 609, and/or installed from the removable medium 611.
Computer readable media, including both non-transitory and non-transitory, removable and non-removable media, may implement information storage by any method or technology. The information may be computer readable instructions, data structures, modules of a program, or other data. Examples of storage media for a computer include, but are not limited to, phase change memory (PRAM), static Random Access Memory (SRAM), dynamic Random Access Memory (DRAM), other types of Random Access Memory (RAM), read Only Memory (ROM), electrically Erasable Programmable Read Only Memory (EEPROM), flash memory or other memory technology, compact disc read only memory (CD-ROM), digital Versatile Discs (DVD) or other optical storage, magnetic cassettes, magnetic tape magnetic disk storage or other magnetic storage devices, or any other non-transmission medium, which can be used to store information that can be accessed by a computing device. Computer-readable media, as defined herein, does not include transitory computer-readable media (transmission media), such as modulated data signals and carrier waves.
For convenience of description, the above devices are described as being functionally divided into various units, respectively. Of course, the functions of each element may be implemented in one or more software and/or hardware elements when implemented in the present application.
The present invention is described with reference to flowchart illustrations and/or block diagrams of methods, apparatus (systems) and computer program products according to embodiments of the invention. It will be understood that each flow and/or block of the flowchart illustrations and/or block diagrams, and combinations of flows and/or blocks in the flowchart illustrations and/or block diagrams, can be implemented by computer program instructions. These computer program instructions may be provided to a processor of a general purpose computer, special purpose computer, embedded processor, or other programmable data processing apparatus to produce a machine, such that the instructions, which execute via the processor of the computer or other programmable data processing apparatus, create means for implementing the functions specified in the flowchart flow or flows and/or block diagram block or blocks.
These computer program instructions may also be stored in a computer-readable memory that can direct a computer or other programmable data processing apparatus to function in a particular manner, such that the instructions stored in the computer-readable memory produce an article of manufacture including instruction means which implement the function specified in the flowchart flow or flows and/or block diagram block or blocks.
These computer program instructions may also be loaded onto a computer or other programmable data processing apparatus to cause a series of operational steps to be performed on the computer or other programmable apparatus to produce a computer implemented process such that the instructions which execute on the computer or other programmable apparatus provide steps for implementing the functions specified in the flowchart flow or flows and/or block diagram block or blocks.
It should also be noted that the terms "comprises," "comprising," or any other variation thereof, are intended to cover a non-exclusive inclusion, such that a process, method, article, or apparatus that comprises a list of elements does not include only those elements but may include other elements not expressly listed or inherent to such process, method, article, or apparatus. Without further limitation, an element defined by the phrase "comprising one … …" does not exclude the presence of other like elements in a process, method, article or apparatus that comprises the element.
It will be appreciated by those skilled in the art that embodiments of the present application may be provided as a method, system, or computer program product. Accordingly, the present application may take the form of an entirely hardware embodiment, an entirely software embodiment or an embodiment combining software and hardware aspects. Furthermore, the present application may take the form of a computer program product embodied on one or more computer-usable storage media (including, but not limited to, disk storage, CD-ROM, optical storage, and the like) having computer-usable program code embodied therein.
The application may be described in the general context of computer-executable instructions, such as program modules, being executed by a computer. Generally, program modules include routines, programs, objects, components, data structures, etc. that perform particular tasks or implement particular abstract data types. The application may also be practiced in distributed computing environments where tasks are performed by remote processing devices that are linked through a communications network. In a distributed computing environment, program modules may be located in both local and remote computer storage media including memory storage devices.
In this specification, each embodiment is described in a progressive manner, and identical and similar parts of each embodiment are all referred to each other, and each embodiment mainly describes differences from other embodiments. In particular, for system embodiments, since they are substantially similar to method embodiments, the description is relatively simple, as relevant to see a section of the description of method embodiments.
The foregoing is merely exemplary of the present application and is not intended to limit the present application. Various modifications and changes may be made to the present application by those skilled in the art. Any modifications, equivalent substitutions, improvements, etc. which are within the spirit and principles of the present application are intended to be included within the scope of the claims of the present application.
Claims (8)
1. The method for determining the theoretical reservoir seepage parameter value is characterized by comprising the following steps of:
solving theoretical seismic traces corresponding to all possible reservoir seepage parameter combinations in the target stratum;
performing difference processing on the actual seismic channel and each theoretical seismic channel to obtain a difference section corresponding to each theoretical seismic channel;
obtaining a zero-value channel from the difference profile, wherein the reservoir seepage parameter corresponding to the zero-value channel is a determined theoretical reservoir seepage parameter value;
the method for obtaining the theoretical seismic traces corresponding to all possible reservoir seepage parameter combinations in the target stratum comprises the following steps:
according to all possible oil reservoir seepage parameter combinations in the target stratum, obtaining oil reservoir wave impedance corresponding to each oil reservoir seepage parameter combination;
obtaining the reflection coefficient of each reservoir wave impedance;
carrying out convolution on the seismic wavelet and each reflection coefficient to obtain a theoretical seismic channel corresponding to each reservoir seepage parameter combination;
according to all possible reservoir seepage parameter combinations in the target stratum, obtaining the reservoir wave impedance corresponding to each reservoir seepage parameter combination, wherein the method comprises the following steps:
converting all possible combinations of reservoir seepage parameters into wave velocity of longitudinal waves and pore fluid medium rock density;
solving by solving an equation, wherein the solving equation is as follows:
wherein Vp is longitudinal wave velocity, ρ, K, M and μ are density, bulk modulus, plane wave modulus and shear modulus, ρ, respectively, of the pore fluid medium rock d 、ρ m And ρ f The density of the fluid in the rock matrix, rock matrix and pores, respectively;
and obtaining the oil reservoir wave impedance value by integrating the longitudinal wave velocity and the pore fluid medium rock density of each group of combinations.
2. The method of claim 1, wherein the reservoir permeability parameters include porosity, permeability, and saturation.
3. The method of claim 1, wherein converting all possible combinations of reservoir seepage parameters into wave velocity and pore fluid medium rock density for longitudinal waves comprises:
solving the density of the pore fluid medium rock according to the densities of the rock framework, the rock matrix and the fluid in the pores;
and (3) solving the wave velocity of the longitudinal waves converted by the possible combination of all the oil reservoir seepage parameters according to the density, the bulk modulus, the plane wave modulus and the shear modulus of the pore fluid medium rock.
4. A theoretical reservoir seepage parameter value determination system, comprising:
the theoretical seismic channel calculating module calculates theoretical seismic channels corresponding to all possible reservoir seepage parameter combinations in the target stratum;
the difference processing module is used for performing difference processing on the actual seismic channel and each theoretical seismic channel to obtain a difference section corresponding to each theoretical seismic channel;
the acquisition module acquires a zero-value channel from the difference profile, wherein the oil reservoir seepage parameter corresponding to the zero-value channel is a determined theoretical oil reservoir seepage parameter value;
the theoretical seismic trace solving module comprises:
the oil reservoir wave impedance obtaining unit obtains the oil reservoir wave impedance corresponding to each oil reservoir seepage parameter combination according to all possible oil reservoir seepage parameter combinations in the target stratum;
a reflection coefficient calculation unit for calculating the reflection coefficient of each reservoir wave impedance;
the convolution processing unit is used for carrying out convolution on the seismic wavelet and each reflection coefficient to obtain a theoretical seismic channel corresponding to each reservoir seepage parameter combination;
the oil reservoir wave impedance obtaining unit comprises:
the conversion unit converts all possible combinations of oil reservoir seepage parameters into wave speed of longitudinal waves and pore fluid medium rock density;
solving by solving an equation, wherein the solving equation is as follows:
wherein Vp is longitudinal wave velocity, ρ, K, M and μ are density, bulk modulus, plane wave modulus and shear modulus, ρ, respectively, of the pore fluid medium rock d 、ρ m And ρ f The density of the fluid in the rock matrix, rock matrix and pores, respectively;
and the product unit is used for obtaining the oil reservoir wave impedance value by integrating the longitudinal wave velocity and the pore fluid medium rock density of each group of combinations.
5. The system of claim 4, wherein the reservoir seepage parameters include porosity, permeability, and saturation.
6. The system of claim 4, wherein the conversion unit comprises:
a density calculating unit for calculating the density of the pore fluid medium rock according to the densities of the rock framework, the rock matrix and the fluid in the pores;
and the longitudinal wave velocity obtaining unit is used for obtaining the wave velocity of the longitudinal wave converted by the possible combination of all the oil reservoir seepage parameters according to the density, the bulk modulus, the plane wave modulus and the shear modulus of the pore fluid medium rock.
7. A computer device comprising a memory, a processor and a computer program stored on the memory and executable on the processor, wherein the processor performs the steps of determining the theoretical reservoir seepage parameter value of any one of claims 1 to 3 when the program is executed.
8. A computer readable storage medium having stored thereon a computer program, characterized in that the computer program when executed by a processor realizes the step of determining the theoretical reservoir seepage parameter value of any one of claims 1 to 3.
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