CN112684498A - Reservoir fracture prediction method and system based on wide-azimuth seismic data - Google Patents
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Abstract
The invention provides a reservoir fracture prediction method and system based on wide azimuth seismic data, wherein the method comprises the following steps: carrying out azimuth dividing processing on the wide azimuth seismic data of the target reservoir to obtain azimuth dynamic correction speeds of the azimuth dividing angles, and carrying out inversion on the azimuth dynamic correction speeds of the azimuth dividing angles through the characteristic that the seismic wave speed changes along with the azimuth to obtain fracture azimuth information of each sampling point on each reflecting surface of the target reservoir; carrying out seismic wave amplitude variation along with the azimuth angle characteristic inversion on the corresponding relation between the crack azimuth and the longitudinal wave medium reflection coefficient of each sampling point and the isotropic characteristic of each sampling point to obtain isotropic characteristic information of each sampling point; and predicting the reservoir fracture development zone according to the fracture azimuth information and the isotropic characteristic information of all sampling points of the target reservoir.
Description
Technical Field
The invention relates to the technical field of geophysical exploration, in particular to a reservoir fracture prediction method and system based on wide-azimuth seismic data.
Background
Fractured reservoirs are one of the most important hydrocarbon reservoirs. In the face of increasing difficulty of conventional oil and gas resource exploration, unconventional, compact and concealed oil and gas reservoirs are becoming key points of exploration, so that fractured oil and gas reservoirs become important fields for increasing reserves and increasing yields of oil and gas in the world at present. In the aspects of reservoir prediction and oil and gas development, fractures play a vital role, the fractures increase the storage space and improve the matrix permeability and the void connectivity of a reservoir, and therefore the reservoir fracture prediction becomes a key technology in exploration and development.
With the popularization of high-density and wide-azimuth seismic acquisition technology, the seismic anisotropy analysis technology plays an increasingly important role, and the fracture prediction technology based on the HTI (horizontal Transverse Isotropy) anisotropy theory is a powerful tool for reservoir prediction. Specifically, there is often an obvious influence of azimuthal anisotropy in a fractured reservoir, which is mainly manifested as azimuthal amplitude difference, azimuthal velocity difference, azimuthal reflection waveform difference and phase difference. A crack prediction method based on wide azimuth longitudinal wave seismic data azimuth anisotropy information is a method for detecting cracks by mainly utilizing the characteristic that seismic longitudinal waves have obvious azimuth anisotropy.
Research on crack prediction by using longitudinal wave seismic data mainly focuses on seismic forward modeling, attribute analysis, Velocity and azimuth anisotropic analysis (VVAZ (seismic wave Velocity with azimuth angle change characteristic)) and Amplitude and azimuth anisotropic analysis (AVAZ (Amplitude variation with azimuth angle change characteristic)). By utilizing a velocity and azimuth anisotropy (VVAZ) analysis technology, the oil and gas content of a fractured reservoir can be predicted by picking dynamic correction velocity and travel time information of different azimuths and performing anomaly comparison analysis, but the fracture density prediction has the defect of insufficient spatial resolution due to low sensitivity of azimuth anisotropy characteristic change of seismic wave velocity, and only fracture distribution can be qualitatively detected.
Disclosure of Invention
The invention aims to provide a reservoir fracture prediction method based on wide-azimuth seismic data, which is used for performing VVAZ and AVAZ joint inversion, fully utilizing azimuth anisotropy change of seismic wave velocity and amplitude information and predicting reservoir fracture information quantitatively and more accurately. It is another object of the present invention to provide a reservoir fracture prediction system based on wide-azimuth seismic data. It is a further object of this invention to provide such a computer apparatus. It is a further object of this invention to provide such a readable medium.
In order to achieve the above object, the present invention discloses a reservoir fracture prediction method based on wide azimuth seismic data, including:
carrying out azimuth dividing processing on the wide azimuth seismic data of the target reservoir to obtain azimuth dynamic correction speeds of the azimuth dividing angles, and carrying out inversion on the azimuth dynamic correction speeds of the azimuth dividing angles through the characteristic that the seismic wave speed changes along with the azimuth to obtain fracture azimuth information of each sampling point on each reflecting surface of the target reservoir;
carrying out seismic wave amplitude variation along with the azimuth angle characteristic inversion on the corresponding relation between the crack azimuth and the longitudinal wave medium reflection coefficient of each sampling point and the isotropic characteristic of each sampling point to obtain isotropic characteristic information of each sampling point;
and predicting the reservoir fracture development zone according to the fracture azimuth information and the isotropic characteristic information of all sampling points of the target reservoir.
Preferably, the obtaining of the azimuth dynamic correction speed of the sub-azimuth by performing the sub-azimuth processing on the target reservoir wide-azimuth seismic data specifically includes:
carrying out azimuth-dividing amplitude-preserving fidelity processing on the wide-azimuth seismic data to obtain azimuth-dividing prestack time migration gather data;
and performing dynamic correction speed analysis on the prestack time migration gather data of the sub-azimuth angle to obtain the azimuth dynamic correction speed of the sub-azimuth angle.
Preferably, the sub-azimuth amplitude-preserving fidelity processing comprises observation system loading, static correction, noise attenuation, earth surface consistency amplitude compensation, earth surface consistency deconvolution, residual static correction, sub-azimuth dynamic correction velocity analysis and sub-azimuth pre-stack time migration.
Preferably, the method further comprises:
and simplifying a Ruger longitudinal wave HTI medium reflection coefficient formula in advance according to the crack orientation to obtain the corresponding relation between the longitudinal wave reflection coefficient and the isotropic characteristics of each sampling point.
Preferably, the isotropic features include an isotropic intercept, an isotropic gradient and an anisotropic gradient.
Preferably, the obtaining of the isotropic characteristic information of each sampling point by performing seismic wave amplitude variation along with the azimuth angle characteristic inversion on the corresponding relationship between the fracture azimuth and the longitudinal wave medium reflection coefficient of each sampling point and the isotropic characteristic of each sampling point specifically includes:
establishing a target function according to the corresponding relation of all the directions;
and solving the target function by a calculation method of least square solution based on the crack azimuth information and the longitudinal wave reflection coefficient to obtain isotropic characteristic information of each sampling point.
The invention also discloses a reservoir fracture prediction system based on the wide azimuth seismic data, which comprises the following steps:
the velocity inversion unit is used for carrying out azimuth dividing processing on the wide-azimuth seismic data of the target reservoir to obtain azimuth dynamic correction velocities of the azimuth dividing angles, and carrying out inversion on the azimuth dynamic correction velocities of the azimuth dividing angles through the characteristic that the seismic wave velocity changes along with the azimuth to obtain fracture azimuth information of each sampling point on each reflecting surface of the target reservoir;
the amplitude inversion unit is used for performing characteristic inversion of the change of the seismic wave amplitude along with the azimuth angle to the corresponding relation between the crack orientation and the longitudinal wave medium reflection coefficient of each sampling point and the isotropic characteristics of each sampling point to obtain isotropic characteristic information of each sampling point;
and the fracture prediction unit is used for predicting the reservoir fracture development zone according to the fracture azimuth information and the isotropic characteristic information of all sampling points of the target reservoir.
Preferably, the velocity inversion unit is specifically configured to perform azimuth-dividing amplitude-preserving fidelity processing on the wide-azimuth seismic data to obtain azimuth-dividing prestack time migration gather data, and perform dynamic correction velocity analysis on the azimuth-dividing prestack time migration gather data to obtain azimuth dynamic correction velocities of the azimuth.
Preferably, the velocity inversion unit is specifically configured to perform observation system loading, static correction, noise attenuation, earth surface consistency amplitude compensation, earth surface consistency deconvolution, residual static correction, sub-azimuth dynamic correction velocity analysis, and sub-azimuth pre-stack time migration on the wide-azimuth seismic data to obtain the sub-azimuth pre-stack time migration gather data.
Preferably, the amplitude inversion unit is further configured to simplify a Ruger longitudinal wave HTI medium reflection coefficient formula in advance according to the fracture azimuth, so as to obtain a corresponding relationship between a longitudinal wave reflection coefficient and isotropic features of each sampling point.
Preferably, the isotropic features include an isotropic intercept, an isotropic gradient and an anisotropic gradient.
Preferably, the amplitude inversion unit is specifically configured to establish an objective function according to the corresponding relationship of all azimuths, and solve the objective function by a calculation method of a least square solution based on the fracture azimuth information and the longitudinal wave reflection coefficient to obtain isotropic characteristic information of each sampling point.
The invention also discloses a computer device comprising a memory, a processor and a computer program stored on the memory and executable on the processor,
the processor, when executing the program, implements the method as described above.
The invention also discloses a computer-readable medium, having stored thereon a computer program,
which when executed by a processor implements the method as described above.
According to the reservoir fracture prediction method based on the VVAZ and AVAZ joint inversion of the wide-azimuth seismic data, the anisotropic information of the velocity and the amplitude azimuth of the wide-azimuth seismic data is fully utilized to perform fracture prediction, the defects of insufficient spatial resolution, low inversion accuracy and the like in the fracture prediction by singly utilizing the anisotropic information of the velocity or the amplitude azimuth are reduced, the reservoir fracture information can be predicted quantitatively more accurately, the identification capability of a fractured reservoir is enhanced, and the reliability of the fracture prediction result is improved.
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In order to more clearly illustrate the embodiments of the present invention or the technical solutions in the prior art, the drawings used in the description of the embodiments or the prior art will be briefly described below, it is obvious that the drawings in the following description are only some embodiments of the present invention, and for those skilled in the art, other drawings can be obtained according to the drawings without creative efforts.
FIG. 1 illustrates one of the flow charts of one embodiment of a method for reservoir fracture prediction based on wide-azimuth seismic data of the present invention;
FIG. 2 illustrates a second flow chart of an embodiment of a method for reservoir fracture prediction based on wide-azimuth seismic data in accordance with the present invention;
FIG. 3 is a third flow chart of an embodiment of a method for reservoir fracture prediction based on wide-azimuth seismic data according to the present invention;
FIG. 4 is a fourth flowchart illustrating a method for reservoir fracture prediction based on wide-azimuth seismic data according to an embodiment of the present invention;
FIG. 5 is a block diagram illustrating one embodiment of a wide azimuth seismic data based reservoir fracture prediction system of the present invention;
FIG. 6 illustrates a schematic block diagram of a computer device suitable for use in implementing embodiments of the present invention.
Detailed Description
The technical solutions in the embodiments of the present invention will be clearly and completely described below with reference to the drawings in the embodiments of the present invention, and it is obvious that the described embodiments are only a part of the embodiments of the present invention, and not all of the embodiments. All other embodiments, which can be derived by a person skilled in the art from the embodiments given herein without making any creative effort, shall fall within the protection scope of the present invention.
According to one aspect of the invention, the present embodiments disclose a method for reservoir fracture prediction based on wide-azimuth seismic data. As shown in fig. 1, in this embodiment, the method includes:
s100: and carrying out azimuth dividing processing on the wide azimuth seismic data of the target reservoir to obtain azimuth dynamic correction speeds of the azimuth dividing angles, and carrying out inversion on the azimuth dynamic correction speeds of the azimuth dividing angles through the characteristic that the seismic wave speed changes along with the azimuth to obtain fracture azimuth information of each sampling point on each reflecting surface of the target reservoir.
S200: and performing seismic wave amplitude variation along with the azimuth angle characteristic inversion on the corresponding relation between the crack azimuth and the longitudinal wave medium reflection coefficient of each sampling point and the isotropic characteristic of each sampling point to obtain the isotropic characteristic information of each sampling point.
S300: and predicting the reservoir fracture development zone according to the fracture azimuth information and the isotropic characteristic information of all sampling points of the target reservoir.
According to the reservoir fracture prediction method based on the VVAZ and AVAZ joint inversion of the wide-azimuth seismic data, the anisotropic information of the velocity and the amplitude azimuth of the wide-azimuth seismic data is fully utilized to perform fracture prediction, the defects of insufficient spatial resolution, low inversion accuracy and the like in the fracture prediction by singly utilizing the anisotropic information of the velocity or the amplitude azimuth are reduced, the reservoir fracture information can be predicted quantitatively more accurately, the identification capability of a fractured reservoir is enhanced, and the reliability of the fracture prediction result is improved.
In a preferred embodiment, as shown in fig. 2, the obtaining of the azimuthing dynamic correction speed of the sub-azimuth by performing the sub-azimuth processing on the wide-azimuth seismic data in S100 specifically includes:
s110: and carrying out azimuth-dividing amplitude-preserving fidelity processing on the wide-azimuth seismic data to obtain azimuth-dividing prestack time migration gather data. The method comprises the steps of carrying out three-dimensional wide azimuth seismic exploration and acquisition through a conventional technology known in the art to obtain original wide azimuth seismic data suitable for wide azimuth processing, and then carrying out azimuth-dividing amplitude-preserving fidelity processing on the acquired three-dimensional wide azimuth seismic data to obtain azimuth-dividing pre-stack time migration gather data capable of carrying out reservoir fracture azimuth and fracture density inversion.
When the azimuth-dividing fidelity processing is performed on the wide-azimuth seismic data, the wide-azimuth seismic data can be divided into a plurality of azimuths according to the azimuth dividing principle so as to perform the fidelity processing on the wide-azimuth seismic data of the divided azimuth. In an optional embodiment, the azimuth dividing principle may be: in the range of 0 to 180 degrees of azimuth angle, more than 4 azimuth angle sectors are divided at equal intervals. For the azimuth angle within the range of 180-360 degrees, according to the symmetry principle, the azimuth angle within the range of 180-360 degrees and the azimuth angle of 0-180 degrees are symmetrically divided, and the two symmetrical azimuth angles are classified into the sectors of the corresponding azimuth angle within the range of 0-180 degrees. For example, when the number of azimuth sectors divided in the 0 to 180 degree azimuth range is N equal to 6, the corresponding azimuth sector division manner is: sector 1 [0-30 degrees, 180-210 degrees ]; sector 2 [30-60 degrees, 210-240 degrees ]; sector 3 [60-90 degrees, 240-270 degrees ]; sector 4 [90-120 degrees, 270-300 degrees ]; sector 5 [ [ 120-; sector 6 [ [ 150-.
In a preferred embodiment, the sub-azimuth amplitude-preserving fidelity processing includes at least one of observation system loading, static correction, noise attenuation, earth surface consistency amplitude compensation, earth surface consistency deconvolution, residual static correction, sub-azimuth dynamic correction velocity analysis, and sub-azimuth pre-stack time migration processing, and the pre-stack time migration gather data may be obtained.
S120: and performing dynamic correction (NMO) speed analysis on the prestack time migration gather data of the sub-azimuth angle to obtain the azimuth dynamic correction speed of the sub-azimuth angle.
Specifically, for an azimuthally anisotropic medium, the following equation can be used for the dynamic correction:
wherein T is the total two-way travel time T0For a zero offset two-way journey, x is the offset, VNMO(φ) is the azimuthal moment correction velocity, which can be expressed as a function of the borehole azimuth φ. Phi is the azimuth angle of the shot detection obtained by actual observation. Phi is a0The azimuth angle of the dynamic correction speed of the fast wave is equivalent to the actual crack development azimuth angle. VfastAnd VslowThe dynamic correction speeds are fast and slow waves respectively. W11，W12And W22The coefficient is an elliptical anisotropy coefficient related to the dynamic correction speed and the azimuth angle of the fast wave and the slow wave, and the fast wave and the slow wave are in a 90-degree orthogonal relation.
Further, the azimuth motion is corrected for the speedPerforming VVAZ inversion to obtain the actual crack development azimuth phi of each sampling point on each underground reflecting surface0Comprises the following steps:
in a preferred embodiment, as shown in fig. 3, the method further comprises:
s000: and simplifying a Ruger longitudinal wave HTI medium reflection coefficient formula in advance according to the crack orientation to obtain the corresponding relation between the longitudinal wave reflection coefficient and the isotropic characteristics of each sampling point. Wherein the longitudinal wave reflection coefficient can be obtained in advance by the conventional technology in the field.
Wherein the isotropic features include at least an isotropic intercept, an isotropic gradient, and an anisotropic gradient. According to the invention, by adopting a joint inversion method combining VVAZ and AVAZ, crack parameter information such as crack orientation, isotropic intercept, isotropic gradient and anisotropic gradient can be obtained by inversion at the same time. The fracture azimuth and anisotropic gradient information can effectively indicate the development degree of reservoir fractures, meanwhile, the isotropic intercept and isotropic gradient information obtained by inversion can effectively indicate the gas-water change characteristics of the reservoir, and the popularization and application value of the method is improved.
In a preferred embodiment, Ruger et al (1998) after an in-depth study of the theory of seismic wave propagation in HTI media, proposed an equation for longitudinal reflection coefficient as a function of angle of incidence and observed azimuth under weak anisotropy assumptions. For the seismic reflection data with the short and medium offset distances, the corresponding relation obtained by simplifying the Ruger longitudinal wave HTI medium reflection coefficient formula according to the crack azimuth can be approximately expressed as follows:
R(φ,i)＝A+Biso sin2 i+Bani cos2(φ-φ0)sin2 i
wherein R (phi, i) is a longitudinal wave reflection coefficient varying with an incident angle and a shot-inspection azimuth, A represents an isotropic intercept, BisoDenotes an isotropic gradient, BaniDenotes the anisotropic gradient, i is the angle of incidence, phi isActual observation of the azimuth angle of shot inspection, phi0The actual fracture growth azimuth is shown. According to the theoretical model of anisotropy proposed by Hudson (1981), the gradient of anisotropy BaniCan be expressed as fracture development density.
In a preferred embodiment, as shown in fig. 4, the S200 may specifically include:
s210: and establishing an objective function according to the corresponding relation of all the orientations.
Specifically, in a specific embodiment, the established objective function J may be:
where m denotes the current sector number, m is 1,2,3, …, N is the total number of azimuth sectors, R (phi)mI) is the actual longitudinal wave reflection coefficient which changes along with the incident angle and the shot detection azimuth in the current sector, i is the shot detection incident angle obtained by actual observation in the current sector, phimFor the azimuth angle of shot detection, phi, actually observed in the current sector0The actual fracture growth azimuth is shown. A represents the isotropic intercept, BisoDenotes an isotropic gradient, BaniThe anisotropy gradient is indicated. When the objective function value J reaches the minimum value, the elastic parameter value A, B of the reservoir can be obtained by inversion solvingisoAnd Bani。
S220: and solving the target function by a calculation method of least square solution based on the crack azimuth information and the longitudinal wave reflection coefficient to obtain isotropic characteristic information of each sampling point.
In order to minimize J, a calculation method based on a least square solution is adopted, and the following equation system is solved:
the solution of the equation set is calculated to obtain the isotropic intercept A and the isotropic gradient BisoAnd an anisotropic gradient BaniA value of (1), wherein the anisotropy gradient BaniThe crack development density can be effectively indicated.
For all the provided pre-stack time migration gather data of the sub-azimuth angles of the subsurface reflection surface elements, fracture azimuth information and isotropic characteristic information are solved for each sampling point in the time window range of the target reservoir, and then the fracture development azimuth angle phi of the seismic data volume target reservoir of the whole three-dimensional work area can be obtained0And crack development Density Bani. Specifically, to achieve the purpose of predicting the fractures of the target reservoir section, inversion calculation needs to be performed on all sampling points within the time window range of the target reservoir, and then, fractured reservoir prediction and identification can be performed according to the fracture azimuth and the fracture density inversion result of the target reservoir in the whole seismic work area.
Wherein, the target reservoir time window range refers to the time range of the target reservoir, and the fracture prediction time window [ T ] is selected according to the time range of the target reservoira,Tb]. Predicting a time window [ T ] for target reservoirs of different depositional characteristicsa,Tb]With different value ranges. For example, reservoir fracture prediction for shallow clastic sedimentary reservoir Fujiahe group, [ T [ [ T ]a,Tb]Respectively representing the reflection time of the top and bottom reflection interfaces of the beard family river group; as another example, for the prediction of reservoir fractures in the Longwanggao group of the deep carbonate sedimentary reservoir, [ T ] Ta,Tb]Respectively representing the reflection time of the top and bottom reflection interfaces of the Longwang temple group.
Each sampling point position on each underground reflection surface element can be any imaging point position in azimuth pre-stack time migration gather data, can also be an imaging point range in a period of time window, and can also be all imaging point ranges of all three-dimensional work area data volumes. The technical scheme is suitable for inversion of the data volume of the time migration channel set before the azimuth stacking in any time window range and any plane range in the three-dimensional work area, and the selection of the specific inversion time window is determined according to the geological position of the target reservoir stratum of the specific earthquake work area.
In a preferred embodiment, in S300, the theory of the change rule of the longitudinal wave reflection coefficient and the dynamic correction speed with the observation azimuth angle is based on an anisotropic theory, that is, seismic waves have different propagation characteristics when propagating in the direction parallel to or perpendicular to the fracture in the anisotropic medium. When the ray plane is parallel to the crack growth zone direction, the longitudinal wave reflection amplitude is maximum, and the dynamic correction speed is fastest, and when the ray plane is vertical to the crack growth zone direction, the longitudinal wave reflection amplitude is minimum, and the dynamic correction speed is slowest; in other directions, the longitudinal wave reflection amplitude and the dynamic correction speed are between the two, and the change characteristic is similar to a sine-cosine curve with a period of 180 degrees, so that the reservoir fracture development zone prediction can be carried out according to the fracture azimuth information and the isotropic characteristic information.
Based on the same principle, the embodiment also discloses a reservoir fracture prediction system based on the wide azimuth seismic data. As shown in fig. 5, in the present embodiment, the system includes a velocity inversion unit 11, an amplitude inversion unit 12, and a fracture prediction unit 13.
The velocity inversion unit 11 is configured to perform azimuth dividing processing on the target reservoir wide azimuth seismic data to obtain azimuth dynamic correction velocities of the azimuth dividing angle, and perform inversion on the azimuth dynamic correction velocities of the azimuth dividing angle through the characteristic that the seismic wave velocity changes along with the azimuth to obtain fracture azimuth information of each sampling point on each reflecting surface of the target reservoir.
The amplitude inversion unit 12 is configured to perform characteristic inversion of the change of the seismic wave amplitude along with the azimuth angle to obtain isotropic characteristic information of each sampling point according to the corresponding relationship between the fracture azimuth and the longitudinal wave medium reflection coefficient of each sampling point and the isotropic characteristic of each sampling point.
The fracture prediction unit 13 is configured to perform reservoir fracture development zone prediction according to the fracture azimuth information and the isotropic feature information of all sampling points of the target reservoir.
In a preferred embodiment, the velocity inversion unit 11 is specifically configured to perform azimuth-dividing amplitude-preserving fidelity processing on the wide-azimuth seismic data to obtain azimuth-dividing prestack time migration gather data, and perform dynamic correction velocity analysis on the azimuth-dividing prestack time migration gather data to obtain azimuth dynamic correction velocities of the azimuth.
In a preferred embodiment, the velocity inversion unit 11 is specifically configured to perform observation system loading, static correction, noise attenuation, amplitude compensation of surface consistency, surface consistency deconvolution, residual static correction, sub-azimuth dynamic correction velocity analysis, and sub-azimuth pre-stack time migration on the wide-azimuth seismic data to obtain sub-azimuth pre-stack time migration gather data.
In a preferred embodiment, the amplitude inversion unit 12 is further configured to simplify a Ruger longitudinal wave HTI medium reflection coefficient formula in advance according to the fracture azimuth, so as to obtain a corresponding relationship between a longitudinal wave reflection coefficient and an isotropic feature of each sampling point.
In a preferred embodiment, the isotropic features include an isotropic intercept, an isotropic gradient, and an anisotropic gradient.
In a preferred embodiment, the amplitude inversion unit 12 is specifically configured to establish an objective function according to the corresponding relationship of all azimuths, and solve the objective function by a least square solution calculation method based on the fracture azimuth information and the longitudinal wave reflection coefficient to obtain isotropic characteristic information of each sampling point.
Since the principle of the system for solving the problem is similar to the above method, the implementation of the system can refer to the implementation of the method, and the detailed description is omitted here.
The systems, devices, modules or units illustrated in the above embodiments may be implemented by a computer chip or an entity, or by a product with certain functions. A typical implementation device is a computer device, which may be, for example, a personal computer, a laptop computer, a cellular telephone, a camera phone, a smart phone, a personal digital assistant, a media player, a navigation device, an email device, a game console, a tablet computer, a wearable device, or a combination of any of these devices.
In a typical example, the computer device specifically comprises a memory, a processor and a computer program stored on the memory and executable on the processor, which when executed by the processor implements the method as described above.
Referring now to FIG. 6, shown is a schematic diagram of a computer device 600 suitable for use in implementing embodiments of the present application.
As shown in fig. 6, 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 necessary for the operation of the system 600 are also stored. The CPU601, ROM602, and RAM603 are connected to each other via 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, a mouse, and the like; an output section 607 including a Cathode Ray Tube (CRT), a liquid crystal feedback (LCD), and the like, and 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 driver 610 is also connected to the I/O interface 605 as needed. A removable medium 611 such as a magnetic disk, an optical disk, a magneto-optical disk, a semiconductor memory, or the like is mounted on the drive 610 as necessary, so that a computer program read out therefrom is mounted as necessary on the storage section 608.
In particular, according to an embodiment of the present invention, the processes described above with reference to the flowcharts may be implemented as computer software programs. For example, embodiments of the 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 illustrated in the flow chart. In such an embodiment, the computer program may be downloaded and installed from a network through the communication section 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 computer storage media 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 that can be used to store information that can be accessed by a computing device. As defined herein, a computer readable medium does not include a transitory computer readable medium such as a modulated data signal and a carrier wave.
For convenience of description, the above devices are described as being divided into various units by function, and are described separately. Of course, the functionality of the units may be implemented in one or more software and/or hardware when implementing 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 flow diagrams and/or block diagrams, and combinations of flows and/or blocks in the flow diagrams 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 an … …" does not exclude the presence of other like elements in a process, method, article, or apparatus that comprises the element.
As will be appreciated by one skilled in the art, 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.
The embodiments in the present specification are described in a progressive manner, and the same and similar parts among the embodiments are referred to each other, and each embodiment focuses on the differences from the other embodiments. In particular, for the system embodiment, since it is substantially similar to the method embodiment, the description is simple, and for the relevant points, reference may be made to the partial description of the method embodiment.
The above description is only an example of the present application and is not intended to limit the present application. Various modifications and changes may occur to those skilled in the art. Any modification, equivalent replacement, improvement, etc. made within the spirit and principle of the present application should be included in the scope of the claims of the present application.
Claims (14)
1. A reservoir fracture prediction method based on wide azimuth seismic data is characterized by comprising the following steps:
carrying out azimuth dividing processing on the wide azimuth seismic data of the target reservoir to obtain azimuth dynamic correction speeds of the azimuth dividing angles, and carrying out inversion on the azimuth dynamic correction speeds of the azimuth dividing angles through the characteristic that the seismic wave speed changes along with the azimuth to obtain fracture azimuth information of each sampling point on each reflecting surface of the target reservoir;
carrying out seismic wave amplitude variation along with the azimuth angle characteristic inversion on the corresponding relation between the crack azimuth and the longitudinal wave medium reflection coefficient of each sampling point and the isotropic characteristic of each sampling point to obtain isotropic characteristic information of each sampling point;
and predicting the reservoir fracture development zone according to the fracture azimuth information and the isotropic characteristic information of all sampling points of the target reservoir.
2. The reservoir fracture prediction method of claim 1, wherein the obtaining of the azimuth dynamics correction speed of the sub-azimuth by performing the sub-azimuth processing on the target reservoir wide-azimuth seismic data specifically comprises:
carrying out azimuth-dividing amplitude-preserving fidelity processing on the wide-azimuth seismic data to obtain azimuth-dividing prestack time migration gather data;
and performing dynamic correction speed analysis on the prestack time migration gather data of the sub-azimuth angle to obtain the azimuth dynamic correction speed of the sub-azimuth angle.
3. A reservoir fracture prediction method as defined in claim 2, wherein the sub-azimuth amplitude preserving fidelity process comprises observation system loading, static correction, noise attenuation, surface conformance amplitude compensation, surface conformance deconvolution, residual static correction, sub-azimuth dynamic correction velocity analysis, and sub-azimuth pre-stack time migration.
4. A reservoir fracture prediction method as defined in claim 1, further comprising:
and simplifying a Ruger longitudinal wave HTI medium reflection coefficient formula in advance according to the crack orientation to obtain the corresponding relation between the longitudinal wave reflection coefficient and the isotropic characteristics of each sampling point.
5. A reservoir fracture prediction method as defined in claim 1 or 4, wherein the isotropic features comprise isotropic intercept, isotropic gradient and anisotropic gradient.
6. The reservoir fracture prediction method according to claim 1, wherein the obtaining of the isotropic feature information of each sampling point by performing seismic wave amplitude variation with azimuth angle feature inversion on the corresponding relationship between the fracture azimuth and the longitudinal wave medium reflection coefficient of each sampling point and the isotropic feature of each sampling point specifically comprises:
establishing a target function according to the corresponding relation of all the directions;
and solving the target function by a calculation method of least square solution based on the crack azimuth information and the longitudinal wave reflection coefficient to obtain isotropic characteristic information of each sampling point.
7. A system for reservoir fracture prediction based on wide-azimuth seismic data, comprising:
the velocity inversion unit is used for carrying out azimuth dividing processing on the wide-azimuth seismic data of the target reservoir to obtain azimuth dynamic correction velocities of the azimuth dividing angles, and carrying out inversion on the azimuth dynamic correction velocities of the azimuth dividing angles through the characteristic that the seismic wave velocity changes along with the azimuth to obtain fracture azimuth information of each sampling point on each reflecting surface of the target reservoir;
the amplitude inversion unit is used for performing characteristic inversion of the change of the seismic wave amplitude along with the azimuth angle to the corresponding relation between the crack orientation and the longitudinal wave medium reflection coefficient of each sampling point and the isotropic characteristics of each sampling point to obtain isotropic characteristic information of each sampling point;
and the fracture prediction unit is used for predicting the reservoir fracture development zone according to the fracture azimuth information and the isotropic characteristic information of all sampling points of the target reservoir.
8. The reservoir fracture prediction system of claim 7, wherein the velocity inversion unit is specifically configured to perform azimuth-splitting amplitude-preserving fidelity processing on the wide-azimuth seismic data to obtain azimuth-splitting prestack time migration gather data, and perform dynamic correction velocity analysis on the azimuth-splitting prestack time migration gather data to obtain azimuth dynamic correction velocities of the azimuth.
9. The reservoir fracture prediction system of claim 8, wherein the velocity inversion unit is specifically configured to perform observation system loading, static correction, noise attenuation, surface consistency amplitude compensation, surface consistency deconvolution, residual static correction, sub-azimuth dynamic correction velocity analysis, and sub-azimuth pre-stack time migration on the wide-azimuth seismic data to obtain sub-azimuth pre-stack time migration gather data.
10. The reservoir fracture prediction system of claim 7, wherein the amplitude inversion unit is further configured to simplify a Ruger longitudinal wave HTI medium reflection coefficient formula in advance according to fracture azimuth to obtain a corresponding relationship between a longitudinal wave reflection coefficient and isotropic characteristics of each sampling point.
11. A reservoir fracture prediction system as claimed in claim 7 or 10, wherein the isotropic features comprise isotropic intercept, isotropic gradient and anisotropic gradient.
12. The reservoir fracture prediction system according to claim 7, wherein the amplitude inversion unit is specifically configured to establish an objective function according to the correspondence of all azimuths, and solve the objective function by a least square solution calculation method based on the fracture azimuth information and the longitudinal wave reflection coefficient to obtain isotropic feature information of each sampling point.
13. A computer device comprising a memory, a processor, and a computer program stored on the memory and executable on the processor,
the processor, when executing the program, implements the method of any of claims 1-6.
14. A computer-readable medium, having stored thereon a computer program,
the program when executed by a processor implementing the method according to any one of claims 1-6.
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