CN111610563B - A method and device for identifying multiple waves - Google Patents

Abstract

The present invention provides a method and device for identifying multiple waves. The method includes: acquiring time horizon data and well logging data of the seismic work area; determining the wave impedance body of the seismic work area according to the time horizon data and well logging data; The acoustic impedance volume is converted into primary wave reflectivity; based on the primary wave reflectivity and logging data, the primary wave seismic record and the full wave seismic record are synthesized by forward modeling; according to the primary wave seismic record and the full wave seismic record, different The multiple interference area of the interference level. The present invention can predict the overall development degree and distribution of multiple waves in the entire seismic work area, which is used to analyze the characteristics of potential multiple waves, and is applied in multiple wave suppression processing, so as to realize the optimization of multiple wave suppression processing parameters, to a certain extent In addition, it reduces the uncertainty of suppressing multiple waves; it can also be used to evaluate the quality of seismic data and divide unreliable areas of seismic data, thereby reducing the multi-solution of reservoir prediction and reducing the risk of well location deployment.

Description

A method and device for identifying multiple waves

technical field

The invention belongs to the technical field of petroleum exploration and development, in particular to a method and device for identifying multiple waves.

Background technique

In oil exploration, seismic waves propagate through underground rock formations, and when encountering strong reflection interfaces, strong energy reflection waves are generated. When the reflected wave travels back upwards and encounters a good strong reflection interface, it is reflected again and propagates downwards, thus forming multiple waves back and forth. Therefore, under normal circumstances, multiple waves exist to varying degrees in various exploration areas in my country, especially in the Sichuan Basin, Tarim Basin, and Ordos Basin, where the structure is gentle and there are many strong reflection interfaces, and the multiple wave interference is more serious. This type of multiple wave has the same amplitude as the deep primary wave, and the dynamic correction time difference is small. It interferes with the deep primary wave and is difficult to identify, which affects the reliability of seismic interpretation research such as seismic data migration quality, seismic attribute extraction, and inversion.

Due to the complex causes of multiple waves, it is difficult to identify and suppress them in the process of seismic data processing, which will cause distortion of effective wave reflection energy, make reservoir prediction results wrong, and bring great risks to oil and gas exploration and development. Therefore, it is necessary to Identify its distribution.

In current seismic processing and interpretation, multiples are usually identified on the velocity spectrum, stacked section, and seismic prestack gathers based on the velocity and periodicity of the multiples: in the prestack stage, there are low-velocity energy clusters and CMP gathers in the velocity spectrum. Insufficient dynamic correction occurs on the upper surface, and the pull-down phenomenon occurs with the increase of offset, and the deep layer and the shallow layer have similar travel periods; Identify multiple waves; when the inclination angle of the subterranean reflection interface is small, if there is another group of reflection events below the strong reflection interface that is consistent with its shape and whose appearance time is less than 2 times, it can be judged that this group of events is multiple Reflected waves; for inclined formations, the inclination angle of the secondary reflected waves on the stacked section is about twice that of the primary reflected waves.

However, in the prior art, it is only possible to identify multiple waves on a single observation point (a pre-stack seismic gather or a seismic velocity spectrum) and an observation line (stacked seismic section), and it is impossible to obtain the The overall development degree and distribution on the plane of the work area. Due to the rapid change of the underground structure and stratum thickness, the multiple waves also have strong heterogeneity on the plane. The results of a single point and a single line obviously cannot represent the situation of the entire seismic work area, and cannot meet the requirements of multiple wave identification and suppression. The need for performance evaluation.

Contents of the invention

The embodiment of the present invention provides a method for identifying multiple waves, using the reflectivity forward modeling method to obtain the energy distribution of multiple waves in a certain geological layer on the plane, and the results can be used to guide the processing personnel to reasonably suppress the presence of multiple waves in seismic data. The multiple waves can also be used by interpreters to evaluate the quality of seismic data, evaluate the reliability of reservoir prediction results, and reduce the risk of well deployment in development and exploration. The method includes:

Obtain the time horizon data and logging data of the seismic work area;

Determine the wave impedance volume of the seismic work area according to the time horizon data and logging data;

Convert wave impedance volume to primary wave reflectivity;

Based on the primary wave reflectivity and logging data, forward synthetic primary wave seismic records and full wave seismic records;

According to primary wave seismic records and full wave seismic records, multiple wave interference areas with different interference levels are determined from the seismic work area.

The embodiment of the present invention also provides a device for identifying multiple waves, including:

The data acquisition module is used to acquire the time horizon data and logging data of the seismic work area;

The acoustic impedance volume determination module is used to determine the acoustic impedance volume of the seismic work area according to the time horizon data and well logging data;

The primary wave reflectivity conversion module is used to convert the wave impedance body into the primary wave reflectivity;

The forward modeling synthesis module is used for forward modeling and synthesizing primary wave seismic records and full wave seismic records according to the primary wave reflectivity and logging data;

The multiple wave interference area determination module is used to determine multiple wave interference areas of different interference levels from the seismic work area according to the primary wave seismic records and the full wave seismic records.

An embodiment of the present invention also provides a computer device, including a memory, a processor, and a computer program stored on the memory and operable on the processor, when the processor executes the computer program, the above-mentioned method for identifying multiple waves is realized .

An embodiment of the present invention also provides a computer-readable storage medium, where the computer-readable storage medium stores a computer program for implementing the above-mentioned method for identifying multiple waves.

The embodiment of the present invention provides a method and device for identifying multiple waves. By establishing an acoustic impedance volume, the reflectivity forward modeling method is used to forward synthesize primary wave seismic records and full-wave seismic records; through the full-wave seismic records The energy distribution of the multiple waves in a certain geological layer on the plane is obtained by analyzing the primary wave seismic records. Compared with the identification method of multiple wave single point and single line in the prior art, the embodiment of the present invention can multiple times for the entire seismic work area. It is used to predict the overall development degree and distribution of multiple waves, which is used to analyze the characteristics of potential multiple waves, and is applied in multiple wave suppression processing, so as to realize the optimization of multiple wave suppression processing parameters, and to a certain extent reduce the inconsistency of suppressing multiple waves. Certainty; the embodiment of the present invention can also evaluate the quality of seismic data according to the multiple interference areas of different interference levels, and divide the unreliable areas of seismic data, thereby reducing the ambiguity of reservoir prediction and reducing the deployment of well locations risks of.

Description of drawings

In order to more clearly illustrate the technical solutions in the embodiments of the present invention or the prior art, the following will briefly introduce the drawings that need to be used in the description of the embodiments or the prior art. Obviously, the accompanying drawings in the following description are only These are some embodiments of the present invention. Those skilled in the art can also obtain other drawings based on these drawings without creative work. In the attached picture:

FIG. 1 is a schematic diagram of a method for identifying multiples according to an embodiment of the present invention.

Fig. 2 is a schematic diagram showing the results displayed on a certain seismic survey line by an acoustic impedance body established by an application example of a method for identifying multiples according to an embodiment of the present invention.

Fig. 3 is a seismic section view of a primary wave seismic record of an application example of a method for identifying multiples according to an embodiment of the present invention.

Fig. 4 is a flow chart of determining the total wave reflectivity of a method for identifying multiple waves according to an embodiment of the present invention.

Fig. 5 is a seismic section view of a full-wave seismic record of an application example of a method for identifying multiple waves according to an embodiment of the present invention.

Fig. 6 is a multiple wave seismogram at the same location in an application example of a method for identifying multiple waves according to an embodiment of the present invention.

FIG. 7 is a SNR attribute slice diagram obtained by an application example of a method for identifying multiples according to an embodiment of the present invention.

FIG. 8 is a schematic diagram of an apparatus for identifying multiple waves according to an embodiment of the present invention.

Detailed ways

In order to make the purpose, technical solutions and advantages of the embodiments of the present invention more clear, the embodiments of the present invention will be further described in detail below in conjunction with the accompanying drawings. Here, the exemplary embodiments and descriptions of the present invention are used to explain the present invention, but not to limit the present invention.

The embodiment of the present invention provides a method for identifying multiple waves, using the reflectivity forward modeling method to obtain the energy distribution of multiple waves in a certain geological layer on the plane, and the results can be used to guide the processing personnel to reasonably suppress the presence of multiple waves in seismic data. The multiple waves can also be used for interpreters to evaluate the quality of seismic data, to evaluate the reliability of reservoir prediction results, and to reduce the risk of well location deployment in development and exploration, as shown in Figure 1. A method for identifying multiple waves in an embodiment of the present invention As shown in the schematic diagram of , the method includes:

Step 101, obtaining time horizon data and logging data of the seismic work area;

Step 102, according to the time horizon data and logging data, determine the wave impedance volume of the seismic work area;

Step 103, converting the wave impedance volume into primary wave reflectivity;

Step 104, according to the reflectivity of the primary wave and the logging data, forward modeling synthesizes the primary wave seismic record and the full wave seismic record;

Step 105, according to the primary wave seismic records and the full wave seismic records, multiple wave interference areas of different interference levels are determined from the seismic work area.

The embodiment of the present invention can predict the overall development degree and distribution of multiples in the entire seismic work area, which is used to analyze the characteristics of potential multiples, and is applied in the processing of multiples suppression, thereby realizing the optimization of processing parameters for multiples suppression. To a certain extent, the uncertainty of suppressing multiple waves is reduced; the embodiment of the present invention can also evaluate the quality of seismic data according to the divided multiple wave interference areas of different interference levels, and divide the unreliable areas of seismic data, thereby reducing the storage capacity. The multi-solution of layer prediction reduces the risk of well location deployment.

When implementing the multiple wave identification method, it is first necessary to obtain the time horizon data and logging data of the seismic work area; then determine the acoustic impedance volume of the seismic work area according to the time horizon data and well logging data; converted into primary wave reflectivity; then based on the primary wave reflectivity and logging data, forward synthetic primary wave seismic records and full wave seismic records; finally, based on the forward modeling synthetic primary wave seismic records and full wave seismic records, the Determine the multiple wave interference areas with different interference levels in the work area.

The embodiment of the present invention provides an application example of using the multiple wave identification method: in the deep Sinian Deng 4 member in a 3D seismic work area in the central Sichuan Basin, a high-yield and enriched carbonate rock karst gas reservoir was discovered. Drilling in the central Sichuan area has revealed that there are multiple reflection interfaces in the middle and shallow layers above the deep Dengying Formation; the Sichuan Basin is dominated by sandstone and mudstone strata deposited in marine-terrestrial interactions from the Late Triassic to the Cenozoic, and from the Sinian to the Middle Triassic. The superimposed carbonate rock strata were deposited on marine carbonate rock platforms; the lithology transition from sandy mudstone to carbonate rock strata formed a good wave impedance reflection interface in the region; due to the large number of strong reflection There are certain changes in the structure, which lead to complex multiple wave interference under the strong reflection interface, especially in the Dengying Formation; these interlayer multiple waves have many sources and complex causes, and the difference between the velocity and the velocity of the primary wave is small. Therefore, it is difficult to effectively distinguish and identify primary effective waves and multiple waves in seismic data, which brings great troubles to seismic processing, and it is difficult to obtain seismic result data with high signal-to-noise ratio; therefore, the present invention can be applied in this seismic work area. The method of identifying multiple waves provided by the example realizes the effective identification of multiple waves.

When specifically implementing the time horizon data and logging data of the seismic work area, in one embodiment, the well logging data can include wave impedance curves; according to the time horizon data and well logging data, determine the wave impedance volume of the seismic work area, specifically It may include: taking the time horizon data as constraints, and using the inverse distance interpolation algorithm to perform three-dimensional space interpolation on the wave impedance curve to determine the wave impedance volume.

寒武系筇竹寺组

震旦系灯三段(Z₂d3)和灯影组(Z₂d)等底界的10个时间层位数据。In the application example of the embodiment of the present invention, the time horizon data of the seismic work area are obtained from oil fields, geophysical service companies, etc., including the Upper Triassic Xujiahe (T ₃ x1), Lower Triassic Fei 4 Member (T ₁ f4), Upper Permian Changxing Formation (P ₂ ch), Longtan Formation (P ₂ l), Lower Permian Liangshan Formation (P ₁ l), Ordovician (O), Cambrian Longwangmiao Formation

Cambrian Qiongzhusi Formation

Data of 10 time horizons of the lower boundary of the third member of the Dengying Formation (Z ₂ d3) and the Dengying Formation (Z ₂ d) of the Sinian system.

After obtaining the time horizon data and logging data of the seismic work area, use the seismic inversion interpretation software to establish the initial model module, and use the time horizon as a constraint to perform spatial interpolation on the wave impedance curve to create a wave impedance volume. To: import the time horizon data of the seismic work area obtained above into the Earth Model modeling module of Jason software, and the wave impedance curve in the joint logging data, under the constraints of the above 10 time horizon data, use inverse distance interpolation Algorithm, perform three-dimensional space interpolation on the wave impedance curve, and establish the wave impedance volume. Fig. 2 is a schematic diagram of the results displayed on a certain seismic survey line by an acoustic impedance volume established by an application example of a method for identifying multiples according to an embodiment of the present invention. Fig. 2 also shows the aforementioned time horizon data at the same time.

After the wave impedance body is established, the wave impedance body is converted into the primary wave reflectivity; during specific implementation, in one embodiment, the wave impedance body can be converted into the primary wave reflectivity in the following manner:

Among them, r is the reflectivity of the primary wave; PI is the wave impedance body; i is the serial number of the reflectivity sampling point.

The above-mentioned expression for converting the wave impedance body into the primary wave reflectivity is an example, and those skilled in the art can understand that the above formula can also be deformed in a certain form and other parameters or data can be added according to the needs during implementation. , or provide other specific formulas, these variations should fall within the protection scope of the present invention.

After converting the acoustic impedance volume into the primary wave reflectivity, in one embodiment, the reflectivity forward modeling method can be used to forward synthesize primary wave seismic records and full-wave seismic data according to the primary wave reflectivity and logging data. Recorded, well log data may include seismic wavelets. Wherein, the forward modeling and synthesizing the primary seismic records according to the primary reflectivity and logging data may include: performing convolution calculation on the primary reflectivity and the seismic wavelet, and forward synthesizing the primary seismic records. In specific implementation, the forward modeling of synthetic primary seismic records can be carried out in the following manner:

Among them, Sy is the seismic record of the primary wave; w is the seismic wavelet; r is the reflectivity of the primary wave; i is the serial number of the reflectivity sampling point; N is the length of the seismic wavelet; j is the serial number of the seismic wavelet sampling point.

The expression of the above-mentioned forward modeling synthetic primary wave seismic record is an example, and those skilled in the art can understand that the above formula can also be deformed in a certain form and add other parameters or data according to the needs during implementation, or provide Other specific formulas and these variation examples should all fall within the protection scope of the present invention.

Z₂d3等3个界面强反射界面清晰。In the application example of the embodiment of the present invention, the main frequency for analyzing the actual seismic data is 32 Hz, so the 32 Hz Lake wavelet is selected as the seismic wavelet for forward modeling. Fig. 3 is a seismic section view of a primary wave seismic record of an application example of a method for identifying multiples according to an embodiment of the present invention. It can be seen from Fig. 3 that the seismic profile of the primary wave seismic record obtained by the convolution of the primary wave reflectivity and the 32Hz Reckon wavelet shows that the seismic reflection of the theoretical primary wave has good lateral continuity, and the vertical strength contrast is obvious.

The three interfaces such as Z ₂ d3 have clear strong reflection interfaces.

After forward modeling and synthesizing the primary wave seismic records, then forward modeling and synthesizing the full wave seismic records; in one embodiment, according to the primary wave reflectivity and logging data, forward modeling and synthesizing the full wave seismic records may include: rate, determine the full-wave reflectivity, perform convolution calculation on the full-wave reflectivity and seismic wavelet, and synthesize full-wave seismic records by forward modeling. When determining the full-wave reflectivity according to the primary-wave reflectivity in specific implementation, the primary-wave reflectivity (r) and its number of sampling points (M) can be input, and the determination of the full-wave reflectance of a method for identifying multiple waves according to the embodiment of the present invention in FIG. 4 As shown in the flow chart of wave reflectivity, the total wave reflectivity (r') is calculated as:

First, set the starting point time to 0 by i=0, dw ₀ =1, and the initial downgoing wave energy to 1, and set up=0, j=i to set the initial upgoing wave energy to 0, and then according to dw _j+1 = -r _j *up+(1-r _j )*dw _j calculates the downgoing reflected wave at time j, and calculates the upgoing reflected wave at time j according to up=r _j *dw _j +(1+r _j )*up, and then from time i to 0 Loop iteratively until j<0, then set the initial downgoing wave energy to 0 through dw ₀ =0, i=i+1, get the reflected wave energy at time i through r' _i =up, and then proceed from time 0 to M cycle iterates until i>M-1, and finally outputs r' to obtain the full-wave reflectivity.

Among them, r is the reflectivity of the primary wave; M is the number of sampling points of the reflectivity of the primary wave; r' is the reflectivity of the total wave; up is the upward wave; dw is the traveling wave.

In the process of calculating the full-wave reflectivity above, the formulas and expressions involved are examples, and those skilled in the art can understand that the above formulas and expressions can also be modified in a certain form and added other Parameters or data, or provide other specific formulas, these variations should fall within the protection scope of the present invention.

After determining the full-wave reflectivity, the synthetic full-wave seismic record is forward modeled. In one embodiment, when implementing forward modeling and synthesizing full-wave seismic records, the full-wave reflectivity and seismic wavelets are convoluted to perform forward modeling and synthesizing full-wave seismic records; further, the forward modeling and synthesis can be performed as follows Full-wave seismic records:

Among them, Sy' is the full-wave seismic record; w is the seismic wavelet; r' is the full-wave reflectivity; i is the reflectivity sampling point number; N is the seismic wavelet length, and j is the seismic wavelet sampling point number.

The expression of the above-mentioned forward synthetic full-wave seismic record is an example, and those skilled in the art can understand that the above-mentioned formula can also be deformed in a certain form and add other parameters or data according to the needs during implementation, or provide Other specific formulas and these variation examples should all fall within the protection scope of the present invention.

Z₂d3等3个界面强反射均明显受到不同程度的减弱，Z₂d3反射整体变得不易识别，图5地震剖面图左侧的

强反射严重被屏蔽变为弱反射；通过对比图5和图3的正演合成地震剖面图，可以清晰地看出多次波在深层灯影组的发育程度和对地震反射振幅的影响程度。In the aforementioned application example of the present invention, similar to the forward modeling and synthesis of a seismic wave record, the same 32Hz Reich wavelet is selected as the seismic wavelet, and is convoluted with the full-wave reflectivity to obtain a full-wave seismic record. Figure 5 is a graph of the present invention Embodiment A full-wave seismic record seismic profile of an application example of a method for identifying multiple waves, as seen in Figure 5, the full-wave seismic record seismic profile obtained by full-wave reflectivity and 32Hz Reckont wavelet convolution, considering After the down-going reflection, the seismic section includes multiple reflections in addition to the primary reflection. Compared with the primary-wave synthetic seismic section, the overall signal-to-noise ratio of the full-wave synthetic seismic section decreases and the continuity becomes poor; affected by the interference of multiple waves, the deep layer

The strong reflections at the three interfaces such as Z ₂ d3 are obviously weakened to varying degrees, and the overall reflection of Z ₂ d3 becomes difficult to identify. The left side of the seismic section in Figure 5

Strong reflections were severely shielded and turned into weak reflections; by comparing the forward modeling seismic profiles in Figure 5 and Figure 3, we can clearly see the degree of development of multiple waves in the deep Dengying Formation and the degree of influence on seismic reflection amplitude.

After the primary and full-wave seismic records are synthesized by forward modeling, the multiple-wave interference areas of different interference levels are determined from the seismic work area according to the primary-wave seismic records and the full-wave seismic records; in one embodiment, the specific implementation is based on When primary wave seismic records and full wave seismic records are used to determine multiple wave interference areas of different interference levels from the seismic work area, it may include: determining multiple wave seismic records based on primary wave seismic records and full wave seismic records; Seismic records and multiple seismic records, determine the SNR attribute slice; determine the multiple wave interference area with different interference levels from the seismic work area according to the SNR attribute slice.

Wherein, according to the primary wave seismic record and the full wave seismic record, determining the multiple wave seismic record may include: subtracting the full wave seismic record from the primary wave seismic record to obtain the multiple wave seismic record; , the multiple seismic records can be determined as follows:

ΔSy=Sy'-Sy

Among them: ΔSy is the multiple wave seismic record; Sy' is the full wave seismic record; Sy is the primary wave seismic record.

The above-mentioned expressions for determining multiple seismic records are examples, and those skilled in the art can understand that the above-mentioned formulas can also be modified in a certain form and added with other parameters or data according to needs, or other parameters can be provided. The specific formulas, these variations all should fall within the scope of protection of the present invention.

至震旦系灯三段(Z2d3)之间的灯四段气藏上，并且横向上强度也有所差异，会对地震储层预测结果造成较大的影响。Fig. 6 is a multiple wave seismogram at the same position in an application example of a method for identifying multiple waves in an embodiment of the present invention. As shown in Fig. 6, it can be seen more clearly that multiple wave energy is in different time horizons The energy has changed, especially the strong energy multiples mainly appear in the Cambrian Qiongzhusi Formation

To the Deng 4 member gas reservoir between the Sinian Deng 3 member (Z2d3), and the strength is also different in the lateral direction, which will have a greater impact on the seismic reservoir prediction results.

After determining the multiple seismic records, determine the SNR attribute slice according to the primary seismic records and the multiple seismic records; in one embodiment, when determining the SNR attribute slice in specific implementation, it may include: Seismic records (Sy) extract attribute values along time horizons to obtain primary wave attribute slices (At); for multiple seismic records (ΔSy) to extract attribute values along time horizons, multiple wave along layer attribute slices ( ΔAt); determine the signal-to-noise ratio attribute slice (SN) according to the primary wave along-layer attribute slice (At) and the multiple wave along-layer attribute slice (ΔAt). Further, when extracting attribute values, those skilled in the art can understand that any one or more of the following calculation methods can be used, including: root mean square value calculation, maximum value calculation, positive value average Calculation, trough average calculation, amplitude absolute value calculation, energy calculation and other conventional seismic attribute calculations.

After determining the slice of the primary wave along the layer attribute and the slice of the multiple wave along the layer attribute, then determine the slice of the SNR attribute; in one implementation, when determining the slice of the SNR attribute, it may include: The ratio of the attribute slice (At) to the multiple wave along-layer attribute slice (ΔAt) is determined as the signal-to-noise ratio attribute slice (SN).

After determining the SNR attribute slice, according to the SNR attribute slice, determine the multiple wave interference area with different interference levels from the seismic work area; when determining the multiple wave interference area with different interference levels in the seismic work area , in one embodiment, determining the multiple wave interference areas of different interference levels from the seismic work area may include:

The multiple wave interference area where the value of the SNR attribute slice is greater than 2 is determined as the multiple wave interference area of the first interference level in the seismic work area;

The multiple wave interference area with the value of the signal-to-noise ratio attribute slice greater than 1 and less than 2 is determined as the multiple wave interference area of the second interference level in the seismic work area;

The multiple wave interference area where the value of the SNR attribute slice is less than 1 is determined as the third interference level multiple wave interference area in the seismic work area;

Wherein, the first interference level is smaller than the second interference level, and the second interference level is smaller than the third interference level.

Among the divided multiple wave interference areas of different interference levels, the seismic data quality of the multiple wave interference area of the first interference level is high, and the seismic reflection can effectively reflect the characteristics of the reservoir; the multiple wave interference area of the second interference level The reliability of the seismic data in the interference area is general, the interference wave is close to the energy of the effective wave, and the use of earthquakes to predict the reservoir has strong multi-solution; the energy of the interference wave in the interference area of the third interference level is stronger than that of the effective wave. Reflection can no longer effectively reflect the characteristics of the reservoir.

至震旦系灯三段(Z2d3)两个时间层位之间的数据进行振幅均方根属性提取计算，最终获取了如图7所示的灯四段信噪比属性切片。如图7所示，在该三维地震工区，多次波干扰在空间上分布很不均匀，在主力含气层灯四段附近，强干扰主要位于工区北部，南部多次波干扰相对较弱，因此，在北部地区依靠地震进行井位部署具有较强的风险。In the application example of the embodiment of the present invention, FIG. 7 is a SNR attribute slice diagram obtained by an application example of a method for identifying multiples in the embodiment of the present invention. In FIG. 7 , the multiples of the first interference level The interference area is divided into Type I multiple wave weak interference area, which indicates that the quality of seismic data is high and the seismic reflection can effectively reflect the characteristics of the reservoir; the second interference level multiple wave interference area is divided into Type II multiple wave medium In the interference area, the reliability of seismic data is average, the interference wave is close to the effective wave energy, and the seismic prediction of reservoir has strong multi-solution; the third interference level multiple wave interference area is classified as III strong multiple wave interference area, indicating that the energy of the interference wave is stronger than that of the effective wave. At this time, the seismic reflection cannot effectively reflect the characteristics of the reservoir. Since in the application example of the embodiment of the present invention, the fourth member of the Sinian system is the main gas reservoir, therefore, for the Cambrian Qiongzhusi Formation

The data between the two time horizons of the third member of the Sinian system (Z2d3) were extracted and calculated for the root mean square attribute of the amplitude, and finally the SNR attribute slice of the fourth member of the Dengeng as shown in Figure 7 was obtained. As shown in Fig. 7, in the 3D seismic work area, the multiple wave interference is very unevenly distributed in space. Near the main gas-bearing layer Deng 4, the strong interference is mainly located in the north of the work area, and the multiple wave interference is relatively weak in the south. Therefore, relying on earthquakes for well deployment in the northern region has a strong risk.

An embodiment of the present invention also provides a computer device, including a memory, a processor, and a computer program stored on the memory and operable on the processor, when the processor executes the computer program, the above-mentioned method for identifying multiple waves is realized .

An embodiment of the present invention also provides a computer-readable storage medium, where the computer-readable storage medium stores a computer program for implementing the above-mentioned method for identifying multiple waves.

Embodiments of the present invention also provide a device for identifying multiple waves, as described in the following embodiments. Since the problem-solving principle of the device is similar to a method for identifying multiples, the implementation of the device can refer to the implementation of a method for identifying multiples, and the repetition will not be repeated.

Fig. 8 is a schematic diagram of a device for identifying multiple waves according to an embodiment of the present invention. As shown in Fig. 8, the device may include:

The data acquisition module 801 is used to acquire the time horizon data and logging data of the seismic work area;

The acoustic impedance volume determination module 802 is used to determine the acoustic impedance volume of the seismic work area according to the time horizon data and well logging data;

The primary wave reflectivity conversion module 803 is used to convert the wave impedance volume into the primary wave reflectivity;

The forward modeling synthesis module 804 is used for forward modeling and synthesizing primary wave seismic records and full wave seismic records according to the primary wave reflectivity and logging data;

The multiple wave interference area determination module 805 is used to determine multiple wave interference areas of different interference levels from the seismic work area according to the primary wave seismic records and the full wave seismic records.

In one embodiment, the logging data acquired by the data acquisition module includes wave impedance curves;

The acoustic impedance volume determination module determines the acoustic impedance volume of the seismic work area according to the time horizon data and logging data, including:

Constrained by the time horizon data, the wave impedance curve is interpolated in three dimensions by using the inverse distance interpolation algorithm to determine the wave impedance volume.

In one embodiment, the primary wave reflectivity conversion module converts the wave impedance body into the primary wave reflectivity as follows:

Among them, r is the reflectivity of the primary wave; PI is the wave impedance body; i is the serial number of the reflectivity sampling point.

In one embodiment, the logging data acquired by the data acquisition module includes seismic wavelets;

The forward modeling synthesis module performs forward modeling and synthesis of primary wave seismic records according to the primary wave reflectivity and logging data, including:

The primary wave reflectivity and seismic wavelet are convolved and calculated, and the primary wave seismic records are synthesized by forward modeling.

In one embodiment, the logging data acquired by the data acquisition module includes seismic wavelets;

The forward synthesis module performs forward synthesis of full-wave seismic records based on primary wave reflectivity and logging data, including:

Determine the total wave reflectivity according to the primary wave reflectivity;

The full-wave reflectivity and seismic wavelet are convolved and calculated, and the full-wave seismic records are synthesized by forward modeling.

In one embodiment, the multiple wave interference area determination module determines multiple wave interference areas of different interference levels from the seismic work area according to the primary wave seismic records and the full wave seismic records, including:

According to the primary wave seismic record and the full wave seismic record, determine the multiple wave seismic record;

Determine the SNR attribute slice based on primary seismic records and multiple seismic records;

According to the SNR attribute slice, multiple wave interference areas with different interference levels are determined from the seismic work area.

In one embodiment, the multiple wave interference area determination module determines the multiple wave seismic records according to the primary wave seismic records and the full wave seismic records, including:

The primary seismic record is subtracted from the full seismic record to obtain the multiple seismic record.

In one embodiment, the multiple wave interference area determination module determines the SNR attribute slice according to the primary wave seismic record and the multiple wave seismic record, including:

Extract the attribute value along the time horizon from the primary wave seismic record, and obtain the primary wave along the layer attribute slice;

Extract attribute values along the time horizon for multiple seismic records, and obtain attribute slices of multiple waves along the layer;

The SNR attribute slice is determined according to the primary wave along-layer attribute slice and the multiple wave along-layer attribute slice.

In one embodiment, the multiple wave interference area determination module determines the SNR attribute slice according to the primary wave along the layer attribute slice and the multiple wave along the layer attribute slice, including:

The ratio of the primary wave along the layer attribute slice to the multiple wave along the layer attribute slice is determined as the signal-to-noise ratio attribute slice.

In one embodiment, the multiple wave interference area determination module determines multiple wave interference areas of different interference levels from the seismic work area according to the signal-to-noise ratio attribute slice, including:

The multiple wave interference area where the value of the SNR attribute slice is greater than 2 is determined as the multiple wave interference area of the first interference level in the seismic work area;

The multiple wave interference area with the value of the signal-to-noise ratio attribute slice greater than 1 and less than 2 is determined as the multiple wave interference area of the second interference level in the seismic work area;

The multiple wave interference area where the value of the SNR attribute slice is less than 1 is determined as the third interference level multiple wave interference area in the seismic work area;

Wherein, the first interference level is smaller than the second interference level, and the second interference level is smaller than the third interference level.

To sum up, the embodiment of the present invention provides a method and device for identifying multiple waves. By establishing an acoustic impedance volume, the reflectivity forward modeling method is used to forward synthesize primary wave seismic records and full-wave seismic records; Seismic records and primary wave seismic records are analyzed to obtain the energy distribution of multiple waves in a certain geological layer on the plane. Compared with the identification method of multiple wave single point and single line in the prior art, the embodiment of the present invention can identify the entire seismic work area. The overall development degree and distribution of multiple waves are predicted, used to analyze potential multiple wave characteristics, and applied in multiple wave suppression processing, so as to realize the optimization of multiple wave suppression processing parameters and reduce the suppression of multiple waves to a certain extent. Uncertainty; the embodiment of the present invention can also evaluate the quality of seismic data according to the divided multiple interference areas of different interference levels, and divide the unreliable areas of seismic data, thereby reducing the ambiguity of reservoir prediction and reducing the number of wells. Bit deployment risk. The embodiment of the present invention only needs time horizon data, logging data and conventional inversion software, and does not need seismic processing software and processing personnel to participate, so the realization process is simple and efficient. The embodiment of the present invention can obtain the signal-to-noise ratio plane distribution of each geological layer, which can be directly applied to well location deployment, and has strong practicability.

Those skilled in the art should understand that the embodiments of the present invention may be provided as methods, systems, or computer program products. Accordingly, the present invention can take the form of an entirely hardware embodiment, an entirely software embodiment, or an embodiment combining software and hardware aspects. Furthermore, the present invention 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, etc.) having computer-usable program code embodied therein.

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 should be understood that each procedure and/or block in the flowchart and/or block diagram, and a combination of procedures and/or blocks in the flowchart and/or block diagram can be realized by computer program instructions. These computer program instructions may be provided to a general purpose computer, special purpose computer, embedded processor, or processor of other programmable data processing equipment to produce a machine such that the instructions executed by the processor of the computer or other programmable data processing equipment produce a An apparatus for realizing the functions specified in one or more procedures of the flowchart and/or one or more blocks of the block diagram.

These computer program instructions may also be stored in a computer-readable memory capable of directing a computer or other programmable data processing apparatus to operate in a specific manner, such that the instructions stored in the computer-readable memory produce an article of manufacture comprising instruction means, the instructions The device realizes the function specified in one or more procedures of the flowchart and/or one or more blocks of the block diagram.

These computer program instructions can also be loaded onto a computer or other programmable data processing device, causing a series of operational steps to be performed on the computer or other programmable device to produce a computer-implemented process, thereby The instructions provide steps for implementing the functions specified in the flow chart or blocks of the flowchart and/or the block or blocks of the block diagrams.

The specific embodiments described above have further described the purpose, technical solutions and beneficial effects of the present invention in detail. It should be understood that the above descriptions are only specific embodiments of the present invention and are not intended to limit the scope of the present invention. Protection scope, within the spirit and principles of the present invention, any modification, equivalent replacement, improvement, etc., shall be included in the protection scope of the present invention.

Claims (20)

1. A method for identifying multiple waves, comprising: Obtain the time horizon data and logging data of the seismic work area; Determine the wave impedance volume of the seismic work area according to the time horizon data and logging data; Convert wave impedance volume to primary wave reflectivity; Based on the primary wave reflectivity and logging data, forward synthetic primary wave seismic records and full wave seismic records; According to primary wave seismic records and full wave seismic records, multiple wave interference areas with different interference levels are determined from the seismic work area; Among them, according to primary wave seismic records and full wave seismic records, multiple wave interference areas with different interference levels are determined from the seismic work area, including: According to the primary wave seismic record and the full wave seismic record, determine the multiple wave seismic record; Determine the SNR attribute slice based on primary seismic records and multiple seismic records; According to the SNR attribute slice, multiple wave interference areas with different interference levels are determined from the seismic work area. 2. The method of claim 1, wherein the well logging data comprises a wave impedance curve; According to the time horizon data and logging data, determine the wave impedance volume of the seismic work area, including: Constrained by the time horizon data, the wave impedance curve is interpolated in three dimensions by using the inverse distance interpolation algorithm to determine the wave impedance volume. 3. The method according to claim 1, characterized in that, the wave impedance body is converted into primary wave reflectivity as follows:

Among them, r is the reflectivity of the primary wave; PI is the wave impedance body; i is the serial number of the reflectivity sampling point. 4. The method of claim 1, wherein the well logging data comprises seismic wavelets; Based on primary reflectivity and logging data, forward synthetic primary seismic records include: The primary wave reflectivity and seismic wavelet are convolved and calculated, and the primary wave seismic records are synthesized by forward modeling. 5. The method of claim 1, wherein the well logging data comprises seismic wavelets; Based on the primary wave reflectivity and logging data, forward synthetic full-wave seismic records, including: Determine the total wave reflectivity according to the primary wave reflectivity; The full-wave reflectivity and seismic wavelet are convolved and calculated, and the full-wave seismic records are synthesized by forward modeling. 6. The method according to claim 1, wherein, according to the primary seismic record and the full seismic record, determining the multiple seismic record comprises: The primary seismic record is subtracted from the full seismic record to obtain the multiple seismic record. 7. The method according to claim 1, wherein, according to the primary wave seismic record and the multiple wave seismic record, determining the SNR attribute slice comprises: Extract the attribute value along the time horizon from the primary wave seismic record, and obtain the primary wave along the layer attribute slice; Extract attribute values along the time horizon for multiple seismic records, and obtain attribute slices of multiple waves along the layer; The SNR attribute slice is determined according to the primary wave along-layer attribute slice and the multiple wave along-layer attribute slice. 8. The method according to claim 7, wherein, according to the primary wave along the layer attribute slice and the multiple wave along the layer attribute slice, determine the signal-to-noise ratio attribute slice, comprising: The ratio of the primary wave along the layer attribute slice to the multiple wave along the layer attribute slice is determined as the signal-to-noise ratio attribute slice. 9. The method according to claim 1, characterized in that, according to the SNR attribute slice, the multiple wave interference area of different interference levels is determined from the seismic work area, including: The multiple wave interference area where the value of the SNR attribute slice is greater than 2 is determined as the multiple wave interference area of the first interference level in the seismic work area; The multiple wave interference area with the value of the signal-to-noise ratio attribute slice greater than 1 and less than 2 is determined as the multiple wave interference area of the second interference level in the seismic work area; The multiple wave interference area where the value of the SNR attribute slice is less than 1 is determined as the third interference level multiple wave interference area in the seismic work area; Wherein, the first interference level is smaller than the second interference level, and the second interference level is smaller than the third interference level. 10. A device for identifying multiple waves, comprising: The data acquisition module is used to acquire the time horizon data and logging data of the seismic work area; The acoustic impedance volume determination module is used to determine the acoustic impedance volume of the seismic work area according to the time horizon data and well logging data; The primary wave reflectivity conversion module is used to convert the wave impedance body into the primary wave reflectivity; The forward modeling synthesis module is used for forward modeling and synthesizing primary wave seismic records and full wave seismic records according to the primary wave reflectivity and logging data; The multiple wave interference area determination module is used to determine multiple wave interference areas of different interference levels from the seismic work area according to the primary wave seismic records and the full wave seismic records; Among them, the multiple wave interference area determination module determines the multiple wave interference areas of different interference levels from the seismic work area according to the primary wave seismic records and the full wave seismic records, including: According to the primary wave seismic record and the full wave seismic record, determine the multiple wave seismic record; Determine the SNR attribute slice based on primary seismic records and multiple seismic records; According to the SNR attribute slice, multiple wave interference areas with different interference levels are determined from the seismic work area. 11. The device according to claim 10, characterized in that, the logging data obtained by the data acquisition module comprises wave impedance curves; The acoustic impedance volume determination module determines the acoustic impedance volume of the seismic work area according to the time horizon data and logging data, including: Constrained by the time horizon data, the wave impedance curve is interpolated in three dimensions by using the inverse distance interpolation algorithm to determine the wave impedance volume. 12. The device according to claim 10, wherein the primary wave reflectivity conversion module converts the wave impedance body into primary wave reflectivity as follows:

Among them, r is the reflectivity of the primary wave; PI is the wave impedance body; i is the serial number of the reflectivity sampling point. 13. The device according to claim 10, wherein the logging data obtained by the data acquisition module comprises seismic wavelets; The forward modeling synthesis module performs forward modeling and synthesis of primary wave seismic records according to the primary wave reflectivity and logging data, including: The primary wave reflectivity and seismic wavelet are convolved and calculated, and the primary wave seismic records are synthesized by forward modeling. 14. The device according to claim 10, wherein the logging data obtained by the data acquisition module comprises seismic wavelets; The forward synthesis module performs forward synthesis of full-wave seismic records based on primary wave reflectivity and logging data, including: Determine the total wave reflectivity according to the primary wave reflectivity; The full-wave reflectivity and seismic wavelet are convolved and calculated, and the full-wave seismic records are synthesized by forward modeling. 15. The device according to claim 10, wherein the multiple wave interference area determination module determines the multiple wave seismic records according to the primary wave seismic records and the full wave seismic records, including: The primary seismic record is subtracted from the full seismic record to obtain the multiple seismic record. 16. The device according to claim 10, wherein the multiple wave interference area determination module determines the SNR attribute slice according to the primary wave seismic record and the multiple wave seismic record, comprising: Extract the attribute value along the time horizon from the primary wave seismic record, and obtain the primary wave along the layer attribute slice; Extract attribute values along the time horizon for multiple seismic records, and obtain attribute slices of multiple waves along the layer; The SNR attribute slice is determined according to the primary wave along-layer attribute slice and the multiple wave along-layer attribute slice. 17. The device according to claim 16, wherein the multiple wave interference area determination module determines the SNR attribute slice according to the primary wave along the layer attribute slice and the multiple wave along the layer attribute slice, comprising: The ratio of the primary wave along the layer attribute slice and the multiple wave along the layer attribute slice is determined as the signal-to-noise ratio attribute slice. 18. The device according to claim 10, wherein the multiple wave interference area determination module determines the multiple wave interference area of different interference levels from the seismic work area according to the signal-to-noise ratio attribute slice, including: The multiple wave interference area where the value of the SNR attribute slice is greater than 2 is determined as the multiple wave interference area of the first interference level in the seismic work area; The multiple wave interference area with the value of the signal-to-noise ratio attribute slice greater than 1 and less than 2 is determined as the multiple wave interference area of the second interference level in the seismic work area; The multiple wave interference area where the value of the SNR attribute slice is less than 1 is determined as the third interference level multiple wave interference area in the seismic work area; Wherein, the first interference level is smaller than the second interference level, and the second interference level is smaller than the third interference level. 19. A computer device, comprising a memory, a processor, and a computer program stored on the memory and operable on the processor, when the processor executes the computer program, the recognition described in any one of claims 1 to 9 is realized multiple wave method. 20. A computer-readable storage medium storing a computer program for implementing the method for identifying multiple waves according to any one of claims 1 to 9.

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