CN114624772A - Well-seismic calibration method, device, equipment and storage medium for sonic-free curve well - Google Patents

Abstract

The application provides a well seismic calibration method, a well seismic calibration device, well seismic calibration equipment and a storage medium for a silent wave curve well. In the method, a first acoustic time difference curve of an adjacent well of a silent wave curve well to be calibrated and a reference curve of the silent wave curve well are obtained. And establishing a response relation equation between the reference curve and the first sound wave time difference curve, and performing multivariate linear fitting processing to obtain a second sound wave time difference curve of the silent wave curve well. And finally, carrying out well seismic calibration on the silent wave curve well according to the second sound wave time difference curve. According to the technical scheme, the well seismic calibration of the silent wave curve well is realized by acquiring the first acoustic time difference curve of the reference curve and the adjacent well and performing multivariate linear fitting processing, and the well seismic calibration efficiency is improved.

Description

Well-seismic calibration method, device, equipment and storage medium for non-acoustic curve wells

technical field

The present application relates to the technical field of well logging, and in particular, to a well seismic calibration method, device, equipment and storage medium for a non-acoustic curve well.

Background technique

Acoustic logging data records the propagation time of acoustic waves in the formation, and reflects the pore characteristics and wave impedance characteristics of the formation, which is in good agreement with seismic data in reflecting the real properties of the formation. The seismic data has the characteristics of wide range and good continuity in the lateral direction, which can track and predict the formation laterally, and has a high vertical resolution. Therefore, the acoustic logging data and the seismic data next to the well are combined and applied to seismic exploration. become a necessary and commonly used technical means.

In the process of well-seismic calibration, it is often encountered that the acoustic curve is missing, and the well is usually abandoned in the well-seismic calibration and reservoir inversion at this time. With the development of logging technology, the common solution to this situation is through the method of petrophysical modeling.

However, in the prior art, this modeling method requires a lot of basic data such as core analysis, pressure-volume-temperature analysis (PVT), volume composition, water saturation, porosity, etc., and Both the economic cost and the time cost are high. If these data are lacking, this method will not be suitable for solving the well-seismic calibration problem of the well with the silent time difference curve.

SUMMARY OF THE INVENTION

The present application provides a well-seismic calibration method, device, equipment and storage medium for a well without an acoustic wave curve, which is used to solve the problem that the well-seismic calibration cannot be performed for a well without an acoustic time difference curve and lacking necessary basic data.

In a first aspect, an embodiment of the present application provides a well-seismic calibration method for a non-acoustic curve well, including:

Acquiring a first sonic time difference curve of an adjacent well of a non-acoustic curve well to be calibrated, where the distance between the adjacent well and the non-acoustic curve well is less than a preset value and has the same characteristics;

obtaining the reference curve of the silent curve well;

establishing a response relationship equation between the reference curve and the first sonic time difference curve, and performing multivariate linear fitting processing to obtain a second sonic time difference curve of the non-acoustic curve well;

According to the second sonic time difference curve, the well-seismic calibration is performed on the well without the sonic curve.

In a possible design of the first aspect, the acquiring the first acoustic transit time curve of the adjacent well of the non-acoustic curve well to be calibrated includes:

According to the characteristics of the silent curve well, a logging well whose distance from the silent curve well is less than the preset distance and has the same characteristics is selected as the offset well;

selecting a sample interval from the well intervals in the offset well that meet the preset wellbore conditions, and the sample interval ranges from 2 meters to 10 meters;

The first acoustic transit time curve is determined according to a plurality of sample points obtained from the sample slice.

In this possible design, the method further includes:

A plurality of sample points are obtained from the sample interval, the number of the plurality of sample points ranges from 20 to 80, and the types of lithology and fluidity of the plurality of sample points are the same as those of the silent wave Some sections of the curve well have similar data.

Optionally, the deposition environment and the degree of compaction of the non-acoustic curve well and the adjacent well are the same.

Optionally, the reference curve is a natural gamma curve or/and a deep resistivity curve.

Optionally, the response relationship equation is: DT=a*GR+b*DEN+c*lg(RD)+N;

Among them, DT stands for acoustic transit time, GR stands for natural gamma, DEN stands for density, RD stands for deep resistivity, and a, b, c, and N are fitting constants, respectively.

In another possible design of the first aspect, the method further includes:

Obtaining the degree of difference between the well-seismic calibration result performed by using the second acoustic wave time difference curve and the measured seismic waveform;

If the degree of difference is greater than the preset threshold, reselect sample points from the adjacent wells to obtain a new first acoustic wave time difference curve;

The fitting process is performed according to the new first acoustic wave time difference curve and the reference curve to obtain a new second acoustic wave time difference curve.

In a second aspect, the present application provides a well-seismic calibration device for a non-acoustic curve well, comprising: an acquisition module and a processing module;

The processing module is used to obtain the first sonic time difference curve of the adjacent well of the non-acoustic curve well to be calibrated, the distance between the adjacent well and the non-acoustic curve well is less than a preset value, and the characteristics are the same;

the acquisition module, configured to acquire the reference curve of the soundless curve well;

The processing module is further configured to establish a response relationship equation between the reference curve and the first sonic time difference curve, and perform multivariate linear fitting processing to obtain the second sonic time difference curve of the non-acoustic curve well ;

The processing module is further configured to perform well-seismic calibration on the well without the acoustic wave curve according to the second acoustic wave time difference curve.

In a possible design of the second aspect, the processing module, configured to obtain the first acoustic transit time curve of the adjacent well of the non-acoustic curve well to be calibrated, includes:

According to the characteristics of the silent curve well, a logging well whose distance from the silent curve well is less than the preset distance and has the same characteristics is selected as the offset well;

selecting a sample interval from the well intervals in the offset well that meet the preset wellbore conditions, and the sample interval ranges from 2 meters to 10 meters;

The first acoustic transit time curve is determined according to a plurality of sample points obtained from the sample slice.

In this possible design, the processing module further includes acquiring a plurality of sample points from the sample layer, the number of the plurality of sample points ranges from 20 to 80, and the plurality of samples The types of lithology and fluidity of the points are similar to the data of some sections of the silent curve well.

Optionally, the deposition environment and the degree of compaction of the non-acoustic curve well and the adjacent well are the same.

Optionally, the reference curve is a natural gamma curve or/and a deep resistivity curve.

Optionally, the response relationship equation is: DT=a*GR+b*DEN+c*lg(RD)+N;

Among them, DT stands for acoustic transit time, GR stands for natural gamma, DEN stands for density, RD stands for deep resistivity, and a, b, c, and N are fitting constants, respectively.

In another possible design of the second aspect, the processing module is further configured to:

Obtaining the degree of difference between the well-seismic calibration result performed by using the second acoustic wave time difference curve and the measured seismic waveform;

If the degree of difference is greater than the preset threshold, reselect sample points from the adjacent wells to obtain a new first acoustic wave time difference curve;

The fitting process is performed according to the new first acoustic wave time difference curve and the reference curve to obtain a new second acoustic wave time difference curve.

In a third aspect, an embodiment of the present application provides a computer device, including: a processor, a memory, and a transceiver;

the memory for storing computer program instructions executable on the processor;

The processor, when executing the computer program instructions, implements the methods provided by the first aspect and possible designs described above.

In a fourth aspect, embodiments of the present application may provide a computer-readable storage medium, where computer-executable instructions are stored in the computer-readable storage medium, and when the computer-executable instructions are executed by a processor, are used to implement the first aspect and methods provided by each possible design.

In a fifth aspect, an embodiment of the present application provides a program for executing the method according to the first aspect when the program is executed by a processor.

In a sixth aspect, embodiments of the present application provide a computer program product, including program instructions, where the program instructions are used to implement the method described in the first aspect.

The well-seismic calibration method, device, device, and storage medium for a non-acoustic curve well provided by the embodiments of the present application are obtained by acquiring the first acoustic time difference curve of the adjacent well of the non-acoustic curve well to be calibrated, and the benchmark of the non-acoustic curve well curve. A response relationship equation is established between the reference curve and the first acoustic time difference curve, and multivariate linear fitting is performed to obtain the second acoustic time difference curve of the well without acoustic wave curve. Finally, according to the second sonic time difference curve, the well seismic calibration is carried out for the well without sonic curve. In this technical scheme, by obtaining the reference curve and the first acoustic time difference curve of the adjacent well, and performing multivariate linear fitting processing, the well seismic calibration of the well without the acoustic wave curve is realized, and the efficiency of the well seismic calibration is improved.

Description of drawings

1 is a flow chart of Embodiment 1 of a well-seismic calibration method for a non-acoustic curve well provided by an embodiment of the present application;

2 is a flow chart of Embodiment 2 of the well-seismic calibration method for a non-acoustic curve well provided by an embodiment of the present application;

3 is a flowchart of Embodiment 3 of the well-seismic calibration method for a non-acoustic curve well provided by an embodiment of the present application;

Fig. 4 is the general flow chart of the well-seismic calibration method of the non-acoustic curve well provided by the embodiment of the present application;

5 is a schematic structural diagram of a well seismic calibration device for a non-acoustic curve well provided in an embodiment of the present application;

FIG. 6 is a schematic structural diagram of a computer device provided by an embodiment of the present application.

Detailed ways

In order to make the purposes, technical solutions and advantages of the embodiments of the present application clearer, the technical solutions in the embodiments of the present application will be described clearly and completely below with reference to the drawings in the embodiments of the present application. Obviously, the described embodiments It is a part of the embodiments of the present application, but not all of the embodiments. Based on the embodiments in the present application, all other embodiments obtained by those of ordinary skill in the art without creative work fall within the protection scope of the present application.

Before introducing the embodiments of the present application, the background technology of the present application will be explained first:

Well-seismic calibration is a bridge connecting logging and seismic information, and fine seismic calibration is the basis and premise of horizon interpretation and reservoir description. The main factors that affect the results of well seismic markers are: logging data, seismic data, wavelets and other factors.

Inaccurate well-seismic calibration results may lead to reservoir structural depth errors, inaccurate reservoir predictions, and shifts in reservoir knowledge. In the well-seismic calibration, the commonly used method is to solve the well-seismic calibration problem of the non-acoustic transit time curve well through the rock physics modeling method. Specifically, the core analysis, pressure-volume-temperature analysis (Pressure-Volume-Temperature, PVT) , volume composition, water saturation, porosity and other basic data to carry out petrophysical modeling. However, the economic cost and time cost of this method are high. If these data are lacking, this method will not be suitable for solving the well-seismic calibration problem of the wells with non-acoustic transit time curve. In addition, this method is dependent on the seismic interpretation experience of technicians, resulting in strong subjectivity of analysis results.

Sw等参数，建立体积模型，根据工区储层、流体类型选择合适的岩石物理模型、测试调整各类参数，到最终正演出缺失的声波曲线，整个过程基本在2-3天以上；第三、传统采用岩石物理建模的方法，对于没有录取岩心、PVT等基础资料的单井，就无法进行井震标定，并且在储层反演中，也只能放弃该井。Specifically, when the sound wave curve is missing, taking Tarim Oilfield as an example, first, the well depth of Tarim Oilfield is usually 5000-7000 meters, taking 1 tube core + PVT + core analysis, the cost is about 1 million; second, petrophysical modeling Due to the numerous parameters and the lengthy process, the Vclay,

Sw and other parameters, establish a volume model, select an appropriate petrophysical model according to the reservoir and fluid type in the work area, test and adjust various parameters, and finally perform the missing sound wave curve, the whole process basically takes more than 2-3 days; third, The traditional petrophysical modeling method cannot perform well-seismic calibration for a single well without basic data such as core and PVT, and in the reservoir inversion, the well can only be abandoned.

In view of the above-mentioned technical problems, the inventive concept of the present application is as follows: due to the lack of necessary basic data, an adjacent well with the same characteristics can be found in the vicinity of the non-acoustic curve well that needs to perform well seismic calibration, and then the characteristics of the adjacent well can be analyzed, combined with According to the characteristics of the non-acoustic curve wells that need to be calibrated by well-seismic, and establishing a certain relationship, the accurate well-seismic calibration of the non-acoustic curve wells can be made.

Hereinafter, the technical solutions of the present application will be described in detail through specific embodiments.

It should be noted that the following specific embodiments may be combined with each other, and the same or similar concepts or processes may not be repeated in some embodiments.

FIG. 1 is a flowchart of Embodiment 1 of a well-seismic calibration method for a non-acoustic curve well provided by an embodiment of the present application. As shown in Figure 1, the well seismic calibration method may include the following steps:

Step 11: Acquire the first acoustic time difference curve of the adjacent well of the non-acoustic curve well to be calibrated.

In this step, when it is necessary to perform well-seismic calibration for the non-acoustic curve well to be calibrated (that is, the well without sonic time difference logging), it is necessary to find other adjacent wells (that is, adjacent wells), and process the adjacent wells , to obtain the acoustic transit time curve of the adjacent well (ie, the first acoustic transit time curve).

Optionally, the distance between the offset well and the silent curve well is less than a preset value and has the same characteristics.

Specifically, in order to make the geological conditions and other factors between the offset well and the silent curve well as close as possible to reduce the error of well seismic calibration, the distance from the offset well to the silent curve well needs to be smaller than the preset value. The value can be an artificially specified distance value.

Optionally, the characteristics of the offset well and the silent curve well may be the same: the deposition environment and the degree of compaction are the same.

Step 12, obtaining the reference curve of the silent curve well.

The reference curve may be a natural gamma curve or/and a deep resistivity curve. Mainly because the natural gamma curve and the deep resistivity curve are the two curves that are less affected by wellbore conditions in the process of oil exploration.

Optionally, the natural gamma curve is a reference curve obtained by the natural gamma logging technology. Based on the geophysical detection method, the physical properties such as electrical conductivity, heat transfer, acoustics, and radioactivity of different well sections in the well measured without sound wave curve can be understood. , to determine the relationship between the lithology, physical properties, oil and gas properties, salt-bearing brine salinity and geophysical properties of rock formations.

Specifically, the radioactive isotopes of uranium, thorium and their decay products and potassium contained in natural rocks can cause natural radioactivity in the formation. These radioactive elements emit radiation without any external excitation. These radioactive elements emit alpha, beta, and gamma rays during decay. Alpha particles and beta particles have poor penetrating ability and cannot be used for well logging; while gamma rays are high-energy electromagnetic waves with strong penetrating ability, which can be detected during drilling. Therefore, the natural gamma measurement while drilling system can reflect the lithology of the formation by measuring the natural gamma change of the formation.

Optionally, the deep resistivity curve is a reference curve obtained by deep resistivity sounding (resistivity sounding, electrical sounding method). Optionally, the resistivity of oil and water is very different, and the same reservoir has higher resistivity when it contains oil than when it contains water.

Step 13 , establishing a response relationship equation between the reference curve and the first sonic time difference curve, and performing multivariate linear fitting processing to obtain a second sonic time difference curve of a well without an acoustic wave curve.

In this step, based on the first sonic time difference curve and the reference curve obtained in steps 11 and 12, a response relationship equation is established, and multivariate linear fitting is performed to obtain the sonic time difference curve of the non-acoustic curve well, that is, the second acoustic wave Time difference curve.

In a possible implementation, in order to perform well-seismic calibration more accurately, a density curve can be added to the reference curve to participate in the multivariate linear fitting process, that is, the response relationship equation can be: DT=a*GR+b *DEN+c*lg(RD)+N.

Among them, DT stands for acoustic transit time, GR stands for natural gamma, DEN stands for density, RD stands for deep resistivity, and a, b, c, and N are fitting constants, respectively.

Optionally, the density curve irradiates the formation with gamma rays emitted by a gamma source, and measures the formation bulk density according to the Compton effect, which is greatly affected by borehole collapse. Horse curve correction, so after the correction, it can be used as a reference curve to participate in the fitting process of the acoustic time difference curve at the same time as the natural gamma curve or/and the deep resistivity curve.

Step 14 , according to the second sonic time difference curve, perform well seismic calibration for the well without sonic curve.

In this step, according to the second acoustic wave time difference curve obtained by the multivariate linear fitting process, the well seismic calibration is performed on the well without the acoustic wave curve to be calibrated.

In the well-seismic calibration method for a sonic curve well provided by the embodiment of the present application, by obtaining the first sonic time difference curve of the adjacent well of the sonic curve well to be calibrated and the reference curve of the sonic curve well, the reference curve and the first acoustic curve are obtained. The response relationship equation is established between the wave time difference curves, and multivariate linear fitting is performed to obtain the second acoustic wave time difference curve of the well without acoustic wave curve. Finally, according to the second sonic time difference curve, the well seismic calibration is carried out for the well without sonic curve. In this technical scheme, by performing multivariate linear fitting processing on the reference curve of the non-acoustic curve well to be calibrated and the first acoustic time difference curve of the adjacent well, the well seismic calibration of the non-acoustic curve well is realized, and the wellbore is improved. Efficiency of vibration calibration.

On the basis of the foregoing embodiment, FIG. 2 is a flowchart of Embodiment 2 of the well seismic calibration method for a non-acoustic curve well provided by the embodiment of the present application. As shown in Figure 2, the above step 11 can be implemented by the following steps:

Step 21 , according to the characteristics of the silent curve well, select the logging well whose distance from the silent curve well is less than the preset distance and has the same characteristics as the offset well.

In this step, for the selection of offset wells, the characteristics of the non-acoustic curve wells should be used as a reference, and the logging wells with the same characteristics (ie, the same depositional environment and the same degree of compaction) should be selected. In addition to the same characteristics, in order to ensure that the geological conditions and other factors are as close as possible, the distance between the selected offset well and the silent curve well should be smaller than the preset distance.

Optionally, when an offset well is actually selected, according to different stages of exploration and development, the preset distance may be several hundred meters, or several tens of kilometers, or even greater.

Step 22: Select a sample interval from the well intervals in the offset well that satisfy the preset wellbore condition.

In this step, a sample interval is selected from the well intervals in the offset wells that meet the preset wellbore conditions, and the range of the well interval is a distance of ±50m longitudinally from the sample interval. Wherein, the range of the sample interval may be 2 meters to 10 meters.

Optionally, the preset wellbore condition may be that the acoustic transit time curve in the well section is not distorted.

Step 23: Determine a first acoustic wave time difference curve according to a plurality of sample points obtained from the sample slice.

In this step, a plurality of sample points are obtained from the sample layers determined in the above steps, and according to these sample points, a first acoustic wave time difference curve is determined.

Among them, the number of multiple sample points ranges from 20 to 80, and the types of lithology and fluidity of the multiple sample points are similar to the data of part of the well section of the soundless curve well.

Optionally, in order to further ensure the accuracy of the well-seismic calibration, if the number of sample points is less than 20 or more than 80, the fitting data will be inaccurate and the calibration result will be affected.

In the well-seismic calibration method for a sonic curve well provided by the embodiment of the present application, according to the characteristics of the silent curve well, a logging well whose distance from the silent curve well is less than a preset distance and has the same characteristics is selected as an offset well, and the offset wells satisfy the requirements from the offset well. A sample interval is selected from a well interval with preset wellbore conditions, and a first acoustic time difference curve is determined according to a plurality of sample points obtained from the sample interval. In this technical solution, by selecting multiple sample points in the offset well, a more accurate determination of the first acoustic time difference curve is realized, which provides a reliable basis for subsequent well-seismic calibration.

FIG. 3 is a flowchart of Embodiment 3 of the well-seismic calibration method for a non-acoustic curve well provided by the embodiment of the present application. As shown in Figure 3, the well seismic calibration method may further include the following steps:

Step 31: Obtain the degree of difference between the well-seismic calibration result using the second acoustic wave time difference curve and the seismic waveform obtained by actual measurement.

In this step, after the well-seismic calibration result is obtained by using the second acoustic wave transit time curve to obtain the well-seismic calibration result, it is judged whether the well-seismic calibration result is accurate.

In a possible implementation, the measured seismic waveforms are compared with the well-seismic calibration results to determine the degree of difference between the seismic waveforms and the well-seismic calibration results.

Step 32: If the degree of difference is greater than the preset threshold, re-select sample points from the adjacent wells to obtain a new first acoustic wave time difference curve.

In this step, a preset threshold is set for comparing the degree of difference between the seismic waveform and the well-seismic calibration result in the above steps. If the difference is greater than the preset threshold, the well-seismic calibration result is considered to be inaccurate.

Optionally, the reason why the degree of difference is greater than the preset threshold may be that the selection of sample points does not conform to the well section of the silent curve well. For the sound wave time difference curve, repeat step 11 above.

Optionally, if the degree of difference is not greater than the preset threshold, it is considered that the seismic waveform and the well-seismic calibration result have a high degree of conformity, that is, the well-seismic calibration result using the second acoustic wave time difference curve is accurate.

Step 33: Perform fitting processing according to the new first acoustic wave time difference curve and the reference curve to obtain a new second acoustic wave time difference curve.

In this step, after the new first acoustic wave time difference curve is acquired, referring to the above-mentioned step 13, a fitting process is performed with the reference curve to obtain a new second acoustic wave time difference curve.

In a possible implementation, the well-seismic calibration result is determined according to the new second acoustic wave time difference curve, and the operation of step 31 is repeated until the degree of difference between the seismic waveform and the well-seismic calibration result is not greater than a preset threshold, then it is considered that the The well-seismic calibration results are accurate.

The well-seismic calibration method for a sonic curve well provided by the embodiment of the present application obtains the degree of difference between the well-seismic calibration result using the second sonic time difference curve and the measured seismic waveform. If the degree of difference is greater than the preset threshold, re-select sample points from the adjacent wells, obtain a new first acoustic time difference curve, and perform fitting processing with the reference curve based on the new first acoustic time difference curve to obtain a new first acoustic time difference curve. Two sound wave time difference curve. In this technical solution, the degree of difference between the well-seismic calibration result and the seismic waveform determined by the second sonic time difference curve is used to verify the accuracy of the well-seismic calibration result. If it is not accurate, the first sonic time difference curve can be re-determined to avoid The possible errors in the selection of sample points in the determination process are eliminated, and the accuracy of the well-seismic calibration results is further improved.

On the basis of the above-mentioned embodiment, FIG. 4 is a general flow chart of the well-seismic calibration method of the non-acoustic curve well provided by the embodiment of the present application. As shown in Figure 4, the method includes the following steps:

Step 1. Obtain multiple sample points of the offset well.

Step 2: Obtain the reference curve of the silent curve well.

The third step is to establish the response relationship equation.

Step 4, multivariate linear fitting processing to obtain the second acoustic wave time difference curve.

Step 5: Perform well-seismic calibration for the silent wave curve well.

Step 6: Determine that the degree of difference between the well-seismic calibration result and the measured seismic waveform is less than a preset threshold, if yes, perform Step 7; if not, perform Step 1 again.

Step 7, end.

In the well-seismic calibration method for a non-acoustic curve well provided by the embodiment of the present application, a response relationship equation is established according to multiple sample points of an adjacent well and a reference curve of a non-acoustic curve well, and a second acoustic time difference is obtained through multivariate linear fitting processing. Curve, according to the second acoustic wave time difference curve, the well-seismic calibration is carried out. Finally, by determining the degree of difference between the well-seismic calibration results and the measured seismic waveforms, the accuracy of the well-seismic calibration results is determined. This technical solution realizes the well-seismic calibration of the curve-free wells and improves the well-seismic calibration. s efficiency.

FIG. 5 is a schematic structural diagram of a well-seismic calibration device for a non-acoustic curve well provided in an embodiment of the present application. As shown in FIG. 5 , the well-seismic calibration device includes: an acquisition module 51 and a processing module 52 .

The processing module 52 is configured to acquire the first acoustic time difference curve of the adjacent well of the non-acoustic curve well to be calibrated, the distance between the adjacent well and the non-acoustic curve well is less than a preset value, and the characteristics are the same;

an acquisition module 51, configured to acquire a reference curve of a soundless curve well;

The processing module 52 is further configured to establish a response relationship equation between the reference curve and the first acoustic wave time difference curve, and perform multivariate linear fitting processing to obtain a second acoustic wave time difference curve of a well without an acoustic wave curve;

The processing module 52 is further configured to perform well-seismic calibration for a well without an acoustic wave curve according to the second acoustic wave time difference curve.

In a possible design of the embodiment of the present application, the processing module 52 is configured to obtain the first acoustic time difference curve of the adjacent well of the non-acoustic curve well to be calibrated, including:

According to the characteristics of the silent curve wells, the logging wells whose distance from the silent curve wells are less than the preset distance and have the same characteristics are selected as offset wells;

The sample interval is selected from the well intervals in the offset well that meet the preset wellbore conditions, and the range of the sample interval is 2 meters to 10 meters;

A first acoustic wave transit time curve is determined according to a plurality of sample points obtained from the sample slice.

In this possible design, the processing module 52 further includes acquiring a plurality of sample points from the sample interval, the number of the plurality of sample points ranges from 20 to 80, and the lithology and fluidity of the plurality of sample points are The type is similar to the data of some sections of the silent curve well.

Optionally, the depositional environment and the degree of compaction are the same for the silent curve well and the offset well.

Optionally, the reference curve is a natural gamma curve or/and a deep resistivity curve.

Optionally, the response relation equation is: DT=a*GR+b*DEN+c*lg(RD)+N;

Among them, DT stands for acoustic transit time, GR stands for natural gamma, DEN stands for density, RD stands for deep resistivity, and a, b, c, and N are fitting constants, respectively.

In another possible design of the embodiment of the present application, the processing module 52 is further configured to:

Obtain the degree of difference between the well-seismic calibration result using the second acoustic wave time difference curve and the measured seismic waveform;

If the difference degree is greater than the preset threshold, re-select sample points from the offset wells to obtain a new first acoustic wave time difference curve;

The fitting process is performed according to the new first acoustic wave time difference curve and the reference curve to obtain a new second acoustic wave time difference curve.

The well-seismic calibration device for a non-acoustic curve well provided by the embodiment of the present application can be used to execute the well-seismic calibration method for a non-acoustic curve well in the above-mentioned embodiment, and its realization principle and technical effect are similar, and are not repeated here.

It should be noted that it should be understood that the division of each module of the above apparatus is only a division of logical functions, and in actual implementation, all or part of it may be integrated into a physical entity, or may be physically separated. And these modules can all be implemented in the form of software calling through processing elements; they can also all be implemented in hardware; some modules can also be implemented in the form of calling software through processing elements, and some modules can be implemented in hardware. For example, the determination module may be a separately established processing element, or may be integrated into a certain chip of the above-mentioned device to be implemented, in addition, it may also be stored in the memory of the above-mentioned device in the form of program code, and a certain processing element of the above-mentioned device may Call and execute the function of the above determined module. The implementation of other modules is similar. In addition, all or part of these modules can be integrated together, and can also be implemented independently. The processing element here may be an integrated circuit with signal processing capability. In the implementation process, each step of the above-mentioned method or each of the above-mentioned modules can be completed by an integrated logic circuit of hardware in the processor element or an instruction in the form of software.

FIG. 6 is a schematic structural diagram of a computer device provided by an embodiment of the present application. As shown in FIG. 6 , the computer device may include: a processor 61 , a memory 62 , and a transceiver 63 .

The processor 61 executes the computer-executed instructions stored in the memory 62, so that the processor 61 executes the solutions in the foregoing embodiments. The processor 61 can be a general-purpose processor, including a central processing unit CPU, a network processor (NP), etc.; it can also be a digital signal processor DSP, an application-specific integrated circuit ASIC, a field programmable gate array FPGA or other programmable logic devices, discrete gate or transistor logic devices, discrete hardware components.

The transceiver 63 is used to communicate with other devices. Optionally, in terms of hardware implementation, the obtaining module 51 in the embodiment shown in FIG. 5 above corresponds to the transceiver 63 in this embodiment, and the transceiver 63 constitutes a communication interface.

Optionally, the above-mentioned components of the computer equipment may be connected through a system bus.

The computer equipment provided in the embodiments of the present application can be used to execute the solutions in the foregoing embodiments, and the implementation principles and technical effects thereof are similar, and details are not described herein again.

The embodiment of the present application further provides a chip for running instructions, and the chip is used to execute the solution in the above-mentioned embodiment.

Embodiments of the present application further provide a computer-readable storage medium, where computer instructions are stored in the computer-readable storage medium, and when the computer instructions are executed on a computer, the computer can execute the solutions of the foregoing embodiments.

Embodiments of the present application further provide a computer program product, where the computer program product includes a computer program, which is stored in a computer-readable storage medium, at least one processor can read the computer program from the computer-readable storage medium, and at least one processor The solutions in the above-described embodiments can be implemented when a computer program is executed.

Finally, it should be noted that the above embodiments are only used to illustrate the technical solutions of the present application, but not to limit them; although the present application has been described in detail with reference to the foregoing embodiments, those of ordinary skill in the art should understand that: The technical solutions described in the foregoing embodiments can still be modified, or some or all of the technical features thereof can be equivalently replaced; and these modifications or replacements do not make the essence of the corresponding technical solutions deviate from the technical solutions of the embodiments of the present application. scope.

Claims (10)

1. A well-seismic calibration method for a silent wave curve well is characterized by comprising the following steps:

acquiring a first acoustic time difference curve of an adjacent well of a silent wave curve well to be calibrated, wherein the distance between the adjacent well and the silent wave curve well is smaller than a preset value, and the characteristics are the same;

acquiring a reference curve of the sonic-free curve well;

establishing a response relation equation between the reference curve and the first sound wave time difference curve, and performing multivariate linear fitting processing to obtain a second sound wave time difference curve of the silent wave curve well;

and carrying out well seismic calibration on the sonic-free curve well according to the second sound wave time difference curve.

2. The method of claim 1, wherein said obtaining a first sonic moveout profile of an adjacent well to a silent curve well to be calibrated comprises:

selecting a logging with the distance from the silent wave curve well being smaller than the preset distance and consistent in characteristics as the adjacent well according to the characteristics of the silent wave curve well;

selecting a sample interval from the well sections meeting the preset well bore conditions in the adjacent wells, wherein the range of the sample interval is 2-10 meters;

determining the first acoustic moveout curve from a plurality of sample points taken from the sample interval.

3. The method of claim 2, further comprising:

obtaining a plurality of sample points from the sample interval, wherein the number of the plurality of sample points ranges from 20 to 80, and the lithology and the fluidity of the plurality of sample points are similar to the partial well interval data of the silent wave curve well.

4. The method of any one of claims 1 to 3, wherein the deposition environment and compaction level of the anechoic curve well and the adjacent well are the same.

5. The method according to any one of claims 1 to 3, wherein the reference curve is a natural gamma curve or/and a deep resistivity curve.

6. The method of any one of claims 1 to 3, wherein the response relation equation is: DT ═ a × GR + b × DEN + c × lg (rd) + N;

where DT denotes acoustic moveout, GR denotes natural gamma, DEN denotes density, RD denotes deep resistivity, and a, b, c, and N are fitting constants, respectively.

7. The method according to any one of claims 1 to 3, further comprising:

acquiring the difference degree between the well seismic calibration result carried out by adopting the second sound wave time difference curve and the seismic waveform obtained by actual measurement;

if the difference degree is larger than a preset threshold value, selecting a sample point from the adjacent well again to obtain a new first acoustic time difference curve;

and fitting the new first sound wave time difference curve and the reference curve to obtain a new second sound wave time difference curve.

8. A well shake calibration device of a silent wave curve well is characterized by comprising: the device comprises an acquisition module and a processing module;

the processing module is used for acquiring a first acoustic time difference curve of an adjacent well of a silent wave curve well to be calibrated, wherein the distance between the adjacent well and the silent wave curve well is smaller than a preset value, and the characteristics of the adjacent well and the silent wave curve well are the same;

the acquisition module is used for acquiring a reference curve of the silent wave curve well;

the processing module is further configured to establish a response relation equation between the reference curve and the first acoustic time difference curve, and perform multivariate linear fitting processing to obtain a second acoustic time difference curve of the silent wave curve well;

and the processing module is also used for carrying out well seismic calibration on the sonic-free curve well according to the second sound wave time difference curve.

9. A computer device, comprising: a processor, a memory, and a transceiver;

the memory for storing computer program instructions executable on the processor;

the processor, when executing the computer program instructions, implements the method of any of claims 1-7 above.

10. A computer-readable storage medium having computer-executable instructions stored thereon, which when executed by a processor, perform the method of any one of claims 1-7.

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