Time matching method and device for ground seismic longitudinal wave converted wave data

Abstract

The invention relates to a time matching method and device for ground seismic longitudinal wave converted wave data. The method comprises the following steps: acquiring vertical seismic profile data, ground seismic longitudinal wave data and ground seismic converted wave data; according to the vertical seismic profile data, solving a longitudinal wave layer velocity curve and a transverse wave layer velocity curve at the well point position; processing the vertical seismic profile data, and separating vertical seismic longitudinal wave data and vertical seismic converted wave data; and carrying out seismic inversion, analysis and calculation on the longitudinal and transverse wave interval velocity curves, the vertical seismic longitudinal wave data and the vertical seismic converted wave data to obtain a relation formula of the longitudinal wave velocity and the transverse wave velocity. Combining the longitudinal wave layer velocity curve of the well point position with the ground seismic longitudinal wave velocity data obtained by inversion of the ground seismic longitudinal wave data, and further calculating the ground seismic transverse wave velocity; and finally, according to the ground seismic longitudinal wave speed, the ground seismic transverse wave speed and the ground seismic converted wave data, converting the converted wave into longitudinal wave two-way travel time.

Description

Technical Field

[0001] The present invention relates to the technical field of seismic exploration, and particularly relates to a method and device for time matching of surface seismic longitudinal wave converted wave data. Background Art

[0002] Multi-wave seismic exploration can obtain various types of wave field information such as longitudinal waves, transverse waves, and converted waves, and has unique advantages such as multi-wave joint imaging, multi-wave joint calibration, multi-wave joint inversion, and multi-attribute fusion. It has good application prospects in analyzing reservoir lithology (referring to the characteristics of reservoir rock types, mineral compositions, structures, physical properties, etc.) and hydrocarbon-bearing prediction. However, because there are differences in the propagation speeds of longitudinal waves and transverse waves, the propagation time of transverse waves is longer than that of the corresponding longitudinal waves. In addition to the difference in propagation time, there are also differences in the reflection coefficient magnitudes and polarities of longitudinal wave reflections and transverse wave reflections. Therefore, there are also differences in the dynamic characteristics of longitudinal and transverse wave fields. Therefore, to give full play to the advantages of multi-wave seismic exploration technology, it is first necessary to solve the problem of matching multi-wave seismic data. The time matching of longitudinal wave converted wave data is an important link in the interpretation of multi-wave seismic exploration.

[0003] At present, the time matching method for surface seismic longitudinal wave converted wave data is mainly based on horizon matching. By manually interpreting the longitudinal wave and converted wave seismic exploration data respectively, tracking out the corresponding horizons respectively, and then using the interpreted corresponding horizons of longitudinal waves and converted waves for control, a time shift volume for matching longitudinal waves and converted waves is generated. The time shift volume is applied to the longitudinal wave and converted wave data to achieve the time matching of longitudinal wave and converted wave data, that is, unified to the two-way travel time of longitudinal waves or the two-way travel time of converted waves. Generally, the converted wave data is transformed from its time domain to the corresponding two-way travel time of longitudinal waves, laying a foundation for the next step of joint interpretation of longitudinal waves and converted waves. This matching method highly depends on manual interpretation experience, there is not enough control between horizons, it is easy to generate waveform distortion, and has great uncertainty. Especially in the case of data with unclear horizon reflection characteristics, high-precision matching cannot be achieved.

[0004] Therefore, how to propose a method that can improve the time matching accuracy of multi-wave seismic data has become an urgent technical problem to be solved at present. Summary of the Invention

[0005] In view of this, the present invention aims to solve the problem of relatively low time matching accuracy between longitudinal wave and converted wave data, thereby reducing the time matching difficulty between longitudinal waves and converted waves, and improving the time matching accuracy and matching efficiency between longitudinal waves and converted waves.

[0006] Specifically, the present invention is realized through the following technical solutions:

[0007] According to a first aspect of the present invention, there is provided a method for time matching of surface seismic longitudinal wave converted wave data, including: acquiring vertical seismic profile data, surface seismic longitudinal wave data, and surface seismic converted wave data; obtaining the longitudinal wave layer velocity curve and the shear wave layer velocity curve at the well point position according to the vertical seismic profile data; performing data processing on the vertical seismic profile data to obtain vertical seismic longitudinal wave data and vertical seismic converted wave data; performing seismic inversion on the longitudinal wave layer velocity curve, the shear wave layer velocity curve, the vertical seismic longitudinal wave data, and the vertical seismic converted wave data to obtain the vertical seismic longitudinal wave velocity and the vertical seismic shear wave velocity; analyzing the vertical seismic longitudinal wave velocity and the vertical seismic shear wave velocity to obtain the relationship between the longitudinal wave velocity and the shear wave velocity; inversely obtaining the surface seismic longitudinal wave velocity according to the longitudinal wave layer velocity curve and the surface seismic longitudinal wave data; converting the surface seismic longitudinal wave velocity according to the relationship to obtain the surface seismic shear wave velocity; constructing a well-to-surface integrated spatio-temporal variable longitudinal and shear wave velocity ratio field according to the surface seismic longitudinal wave velocity and the surface seismic shear wave velocity; determining the two-way travel time of the corresponding surface seismic longitudinal wave data according to the well-to-surface integrated spatio-temporal variable longitudinal and shear wave velocity ratio field and the two-way travel time of the surface seismic converted wave data, and obtaining the surface seismic converted wave data transformed to the two-way travel time of the longitudinal wave.

[0008] Optionally, the step of obtaining the longitudinal wave layer velocity curve and the shear wave layer velocity curve at the well point position according to the vertical seismic profile data includes: performing wave field analysis on the vertical seismic profile data, and performing longitudinal wave first arrival picking and shear wave first arrival picking, and calculating to obtain the longitudinal wave layer velocity and the shear wave layer velocity at the well point position; obtaining the longitudinal wave layer velocity curve and the shear wave layer velocity curve according to the longitudinal wave layer velocity and the shear wave layer velocity.

[0009] Optionally, the step of performing data processing on the vertical seismic profile data to obtain vertical seismic longitudinal wave data and vertical seismic converted wave data includes: performing wave field separation and imaging processing on the vertical seismic profile data to obtain vertical seismic longitudinal wave data and vertical seismic converted wave data.

[0010] Optionally, the step of performing seismic inversion on the longitudinal wave layer velocity curve, the shear wave layer velocity curve, the vertical seismic longitudinal wave data, and the vertical seismic converted wave data to obtain the vertical seismic longitudinal wave velocity and the vertical seismic shear wave velocity includes: performing synthetic record calibration and horizon interpretation processing on the vertical seismic longitudinal wave data and the vertical seismic converted wave data according to the longitudinal wave layer velocity curve and the shear wave layer velocity curve, and obtaining the vertical seismic longitudinal wave velocity and the vertical seismic shear wave velocity through seismic inversion.

[0011] Optionally, the relationship between the longitudinal wave velocity and the shear wave velocity is:

[0012] V S = 0.58V P - 149;

[0013] wherein, VS Denoted as the shear wave velocity, with the unit of m / s, V p Denoted as the compressional wave velocity, with the unit of m / s.

[0014] Optionally, the steps of inverting the surface seismic compressional wave velocity based on the compressional wave interval velocity curve and surface seismic compressional wave data include: performing synthetic seismogram calibration on the surface seismic compressional wave data according to the compressional wave interval velocity curve, and performing horizon interpretation processing, and obtaining the surface seismic compressional wave velocity through seismic inversion.

[0015] Optionally, the steps of converting the surface seismic compressional wave velocity to the surface seismic shear wave velocity according to the relational expression include: performing amplitude processing on the surface seismic compressional wave velocity according to the relational expression between the compressional wave velocity and the shear wave velocity to obtain the surface seismic shear wave velocity.

[0016] Optionally, the steps of constructing a well - to - surface integrated spatio - temporal variable P - to - S wave velocity ratio field based on the surface seismic compressional wave velocity and the surface seismic shear wave velocity include: calculating the division of the surface seismic compressional wave velocity and the surface seismic shear wave velocity to obtain the P - to - S wave velocity ratio of the surface seismic waves; performing spatial processing and temporal processing on the P - to - S wave velocity ratio of the surface seismic waves to construct a well - to - surface integrated spatio - temporal variable P - to - S wave velocity ratio field.

[0017] Optionally, the calculation formula for determining the two - way travel time of the corresponding surface seismic compressional wave data is:

[0018]

[0019] where, T pp Denoted as the two - way travel time of the surface seismic compressional wave data, with the unit of ms, k is denoted as the P - to - S wave velocity ratio, T ps Denoted as the two - way travel time of the surface seismic converted wave data, with the unit of ms.

[0020] According to a second aspect of the present invention, there is provided a time matching device for surface seismic P-wave converted wave data, comprising: an acquisition module for acquiring vertical seismic profile data, surface seismic P-wave data and surface seismic converted wave data; a calculation module for obtaining a P-wave layer velocity curve and an S-wave layer velocity curve at a well point position according to the vertical seismic profile data; a processing module for performing data processing on the vertical seismic profile data to obtain vertical seismic P-wave data and vertical seismic converted wave data; an inversion module for performing seismic inversion on the P-wave layer velocity curve, the S-wave layer velocity curve, the vertical seismic P-wave data and the vertical seismic converted wave data to obtain a vertical seismic P-wave velocity and a vertical seismic S-wave velocity; an analysis module for analyzing the vertical seismic P-wave velocity and the vertical seismic S-wave velocity to obtain a relationship formula between the P-wave velocity and the S-wave velocity; the inversion module is further configured to invert the surface seismic P-wave velocity according to the P-wave layer velocity curve and the surface seismic P-wave data; a conversion module for converting the surface seismic P-wave velocity according to the relationship formula to obtain a surface seismic S-wave velocity; a construction module for constructing a spatially and temporally varying P-wave to S-wave velocity ratio field of well-to-surface integration according to the surface seismic P-wave velocity and the surface seismic S-wave velocity; a determination module for determining the two-way travel time of the corresponding surface seismic P-wave data according to the spatially and temporally varying P-wave to S-wave velocity ratio field of well-to-surface integration and the two-way travel time of the surface seismic converted wave data, so as to obtain the surface seismic converted wave data transformed to the two-way travel time of the P-wave.

[0021] According to a third aspect of the present invention, there is provided a storage medium having stored thereon a computer program which, when executed by a processor, implements the steps of the time matching method for surface seismic P-wave converted wave data in the first aspect or any possible implementation manner of the first aspect of the present invention.

[0022] According to a fourth aspect of the present invention, there is provided an electronic device comprising a memory, a processor and a computer program stored on the memory and executable on the processor, wherein the processor, when executing the computer program, implements the steps of the time matching method for surface seismic P-wave converted wave data in the first aspect or any possible implementation manner of the first aspect of the present invention.

[0023] The technical solution provided by the present invention at least brings the following beneficial effects:

[0024] Through multiple data processes on vertical seismic profile data, surface seismic P-wave data, and surface seismic converted-wave data, the present invention obtains the P-S wave velocity ratio field. Furthermore, through the P-S wave velocity ratio field and the two-way travel time of the surface seismic converted-wave data, the surface seismic converted-wave data after time matching is obtained, which can effectively perform time matching on the surface seismic P-wave and converted-wave data, thereby improving the time matching accuracy of the surface seismic P-wave and converted-wave data, and further improving the accuracy of the joint interpretation results of the surface seismic P-wave and converted-wave data. At the same time, the method of the present invention has broad application prospects for multi-wave seismic exploration, and has strong production practicability and high efficiency. BRIEF DESCRIPTION OF THE DRAWINGS

[0025] The accompanying drawings herein are incorporated into and constitute a part of this specification, showing embodiments consistent with the present invention, and are used together with the description to explain the principles of the present invention.

[0026] 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 required for use in the description of the embodiments or related technologies. Obviously, for those of ordinary skill in the art, other drawings can be obtained based on these drawings without creative efforts.

[0027] Figure 1 It is a schematic flow chart of a method for time matching of surface seismic P-wave converted-wave data provided by an embodiment of the present invention;

[0028] Figure 2 It is a schematic diagram of data in the Z component of zero well source distance provided by an embodiment of the present invention;

[0029] Figure 3 It is a schematic diagram of data in the X component of zero well source distance provided by an embodiment of the present invention;

[0030] Figure 4 It is a schematic diagram of data in the Y component of zero well source distance provided by an embodiment of the present invention;

[0031] Figure 5 It is a schematic diagram of surface seismic P-wave data provided by an embodiment of the present invention;

[0032] Figure 6 It is a schematic diagram of surface seismic converted-wave data provided by an embodiment of the present invention;

[0033] Figure 7 It is a schematic diagram of data in the Z component of two-dimensional vertical seismic data provided by an embodiment of the present invention;

[0034] Figure 8 It is a schematic diagram of data in the X component of two-dimensional vertical seismic data provided by an embodiment of the present invention;

[0035] Figure 9 Schematic diagram of data of the two-dimensional vertical seismic data provided by the embodiment of the present invention on the Y component;

[0036] Figure 10 Schematic diagram of vertical seismic P-wave data provided by the embodiment of the present invention;

[0037] Figure 11 Schematic diagram of vertical seismic converted-wave data provided by the embodiment of the present invention;

[0038] Figure 12 Schematic diagram of data of the vertical seismic P-wave velocity provided by the embodiment of the present invention;

[0039] Figure 13 Schematic diagram of data of the vertical seismic S-wave velocity provided by the embodiment of the present invention;

[0040] Figure 14 Schematic diagram of the analysis result of the vertical seismic P-wave velocity and the vertical seismic S-wave velocity provided by the embodiment of the present invention;

[0041] Figure 15 Schematic diagram of data of the surface seismic P-wave velocity provided by the embodiment of the present invention;

[0042] Figure 16 Schematic diagram of the longitudinal and transverse wave velocity ratio field with spatio-temporal variation of well-ground integration provided by the embodiment of the present invention;

[0043] Figure 17 Schematic diagram of the surface seismic converted-wave data before time matching provided by the embodiment of the present invention;

[0044] Figure 18 Schematic diagram of the surface seismic converted-wave data after time matching provided by the embodiment of the present invention;

[0045] Figure 19 Schematic diagram of the flow of another time matching method for the surface seismic P-wave converted-wave data provided by the embodiment of the present invention;

[0046] Figure 20 Schematic block diagram of a time matching device for the surface seismic P-wave converted-wave data provided by the embodiment of the present invention;

[0047] Figure 21 Schematic block diagram of an electronic device provided by the embodiment of the present invention. Detailed implementation manners

[0048] To make the objectives, technical solutions and advantages of the embodiments of the present invention clearer, the technical solutions in the embodiments of the present invention will be clearly and completely described below with reference to the accompanying drawings in the embodiments of the present invention. Apparently, the described embodiments are some but not all of the embodiments of the present invention. All other embodiments obtained by those of ordinary skill in the art based on the embodiments of the present invention without creative efforts shall fall within the protection scope of the present invention.

[0049] As Figure 1 shown, an embodiment of the present invention provides a time matching method for surface seismic P-wave converted wave data, including:

[0050] S101: Obtain vertical seismic profile data, surface seismic P-wave data and surface seismic converted wave data;

[0051] S102: Obtain the P-wave layer velocity curve and S-wave layer velocity curve at the well point position according to the vertical seismic profile data;

[0052] S103: Process the vertical seismic profile data to obtain vertical seismic P-wave data and vertical seismic converted wave data;

[0053] S104: Perform seismic inversion on the P-wave layer velocity curve, S-wave layer velocity curve, vertical seismic P-wave data and vertical seismic converted wave data to obtain the vertical seismic P-wave velocity and vertical seismic S-wave velocity;

[0054] S105: Analyze the vertical seismic P-wave velocity and vertical seismic S-wave velocity to obtain the relationship formula between the P-wave velocity and the S-wave velocity;

[0055] S106: Invert the surface seismic P-wave velocity according to the P-wave layer velocity curve and the surface seismic P-wave data;

[0056] S107: Convert the surface seismic P-wave velocity according to the relationship formula to obtain the surface seismic S-wave velocity;

[0057] S108: Construct a well-to-surface fusion spatio-temporal variable P-wave to S-wave velocity ratio field according to the surface seismic P-wave velocity and the surface seismic S-wave velocity;

[0058] S109: Determine the two-way travel time of the corresponding surface seismic P-wave data according to the well-to-surface fusion spatio-temporal variable P-wave to S-wave velocity ratio field and the two-way travel time of the surface seismic converted wave data, and obtain the surface seismic converted wave data transformed to the two-way travel time of the P-wave.

[0059] In the method of this embodiment, it is especially applicable to the case of zero well-source distance, such as Figure 2 , Figure 3 and Figure 4As shown, the data of zero offset in this embodiment is shown. That is, when the distance between the seismic source and the observation point is zero, first, vertical seismic profile data, surface seismic P-wave data, and surface seismic converted-wave data are acquired. As Figure 5 and Figure 6 shown, a schematic diagram of the surface seismic P-wave data and a schematic diagram of the surface seismic converted-wave data provided in this embodiment are respectively shown. These seismic data are all original data collected by seismic instruments. Among them, the vertical seismic profile data refers to the seismic wave data underground, and the surface seismic P-wave data and the surface seismic converted-wave data are both seismic wave data received on the ground. As Figure 7 、 Figure 8 and Figure 9 shown, the two-dimensional vertical seismic profile data provided in this embodiment is shown. Then, based on the vertical seismic profile data, the P-wave layer velocity curve and the S-wave layer velocity curve at the well point position are determined. Then, data processing is performed on the vertical seismic profile data to obtain vertical seismic P-wave data and vertical seismic converted-wave data. As Figure 10 shown, a schematic diagram of the vertical seismic P-wave data provided in this embodiment is shown. As Figure 11 shown, a schematic diagram of the vertical seismic converted-wave data provided in this embodiment is shown. Further, seismic inversion is performed based on the P-wave layer velocity curve, the S-wave layer velocity curve, the vertical seismic P-wave data, and the vertical seismic converted-wave data to obtain the vertical seismic P-wave velocity and the vertical seismic S-wave velocity. As Figure 12 shown, a data schematic diagram of the vertical seismic P-wave velocity provided in this embodiment is shown. As Figure 13 shown, a data schematic diagram of the vertical seismic S-wave velocity provided in this embodiment is shown. Immediately afterwards, the vertical seismic P-wave velocity and the vertical seismic S-wave velocity are analyzed to obtain the relationship between the P-wave velocity and the S-wave velocity. As Figure 14 shown, a schematic diagram of the analysis results of the vertical seismic P-wave velocity and the vertical seismic S-wave velocity provided in this embodiment is shown. At the same time, the surface seismic P-wave velocity is inversely obtained by using the P-wave layer velocity curve and the surface seismic P-wave data. As Figure 15 shown, a data schematic diagram of the surface seismic P-wave velocity provided in this embodiment is shown. Then, using the above relationship, the surface seismic S-wave velocity is obtained based on the surface seismic P-wave velocity, so as to calculate the surface seismic P-wave velocity and the surface seismic S-wave velocity, and further determine the velocity ratio field of the surface P-wave and S-wave. As Figure 16 shown, a schematic diagram of the space-time variable P-wave and S-wave velocity ratio field of well-ground integration provided in this embodiment is shown. Finally, the two-way travel time of the corresponding surface seismic P-wave data is calculated by using the velocity ratio field of the surface P-wave and S-wave and the two-way travel time of the surface seismic converted-wave data, so that the data of the surface seismic P-wave and the converted-wave are on the same two-way travel time, that is, the surface seismic converted-wave data transformed to the two-way travel time of the P-wave is obtained. As Figure 17As shown, a schematic diagram of the surface seismic converted-wave data before time matching provided by this embodiment is shown. As Figure 18 shown, a schematic diagram of the surface seismic converted-wave data after time matching provided by this embodiment is shown. This embodiment can improve the efficiency and accuracy of the time matching between the P-wave and the converted-wave, and further improve the accuracy of the interpretation results during multi-wave seismic exploration.

[0060] It can be understood that multi-wave seismic exploration is a method for analyzing reservoir lithology and inverting reservoir lithology and hydrocarbon-bearing properties. By using seismic waves to understand the underground medium conditions, it can effectively reduce the multi-solution problems that may occur during seismic interpretation and make the interpretation results more accurate. However, for multi-wave seismic exploration, the propagation speeds and reflection characteristics of different waves are different, which makes it impossible for technicians to perform joint interpretation based on the data of multi-wave seismic exploration, reducing the accuracy of the interpretation results. The time matching method for P-wave and converted-wave data provided by this embodiment is applicable to the case of zero well-source distance, that is, when the distance between the seismic source and the observation point is zero. It can perform time matching on the P-wave data and the converted-wave data, so as to obtain the surface seismic converted-wave data transformed to the two-way travel time of the P-wave, solve the problem of time matching of the surface seismic P-wave converted-wave data, improve the matching accuracy, and further improve the accuracy of the joint interpretation results of the surface seismic P-wave and converted-wave data.

[0061] In addition, vertical seismic exploration is a geophysical exploration technique in which the seismic source is placed in a well and the geophones are placed on the ground (or the seismic source is placed on the ground and the geophones are placed in the well). It mainly includes zero well-source distance vertical seismic exploration, non-zero well-source distance vertical seismic exploration, two-dimensional vertical seismic exploration, and three-dimensional vertical seismic exploration, etc. Generally, in zero well-source distance vertical seismic exploration, the horizontal distance between the seismic source and the wellhead is less than or equal to 150 meters, and in non-zero well-source distance vertical seismic exploration, the horizontal distance between the seismic source and the wellhead is greater than 150 meters. The vertical seismic profile data obtained in this embodiment can be zero well-source distance vertical seismic profile data or non-zero well-source distance vertical seismic profile data. However, for the matching method of this embodiment, the effect is particularly significant when the horizontal distance between the seismic source and the wellhead is less than or equal to 150 meters. At the same time, the obtained vertical seismic profile data can be two-dimensional vertical seismic profile data or three-dimensional vertical seismic profile data. The time matching method proposed by the present invention has strong applicability and can perform time matching on two-dimensional or three-dimensional surface seismic P-wave converted-wave data by using vertical seismic data, thereby improving the accuracy of the data interpretation results.

[0062] Optionally, the steps of obtaining the longitudinal wave layer velocity curve and the shear wave layer velocity curve at the well point position according to the vertical seismic profile data include: performing wave field analysis on the vertical seismic profile data, and performing first arrival picking of the longitudinal wave and the first arrival picking of the shear wave, and calculating to obtain the longitudinal wave layer velocity and the shear wave layer velocity at the well point position; obtaining the longitudinal wave layer velocity curve and the shear wave layer velocity curve according to the longitudinal wave layer velocity and the shear wave layer velocity.

[0063] In this embodiment, the process of obtaining the longitudinal wave layer velocity curve and the shear wave layer velocity curve at the well point position specifically includes: performing wave field analysis on the vertical seismic profile data. Through wave field analysis, the noise in the data can be removed and the accuracy of data processing can be improved. Then, first arrival picking is performed on the longitudinal wave and the shear wave, that is, the first arrival data of the seismic longitudinal wave and the shear wave are obtained, and further the longitudinal wave layer velocity and the shear wave layer velocity at the well point position are obtained. Then, the longitudinal wave layer velocity curve and the shear wave layer velocity curve are drawn according to the longitudinal wave layer velocity and the shear wave layer velocity at the well point position.

[0064] Optionally, the steps of performing data processing on the vertical seismic profile data to obtain vertical seismic longitudinal wave data and vertical seismic converted wave data include: performing wave field separation and imaging processing on the vertical seismic profile data to obtain vertical seismic longitudinal wave data and vertical seismic converted wave data.

[0065] In this embodiment, the process of obtaining the vertical seismic longitudinal wave data and the vertical seismic converted wave data specifically includes: performing wave field separation and imaging processing on the vertical seismic profile data, that is, separating the original data of the vertical seismic wave field into longitudinal wave data and converted wave data, and performing data imaging processing to obtain vertical seismic longitudinal wave data and vertical seismic converted wave data.

[0066] Optionally, the steps of performing seismic inversion on the longitudinal wave layer velocity curve, the shear wave layer velocity curve, the vertical seismic longitudinal wave data, and the vertical seismic converted wave data to obtain the vertical seismic longitudinal wave velocity and the vertical seismic shear wave velocity include: performing synthetic record calibration and horizon interpretation processing on the vertical seismic longitudinal wave data and the vertical seismic converted wave data according to the longitudinal wave layer velocity curve and the shear wave layer velocity curve, and obtaining the vertical seismic longitudinal wave velocity and the vertical seismic shear wave velocity through seismic inversion.

[0067] In this embodiment, the process of obtaining the vertical seismic P-wave velocity and the vertical seismic S-wave velocity through seismic inversion includes: performing synthetic record calibration on the vertical seismic P-wave data and the vertical seismic converted-wave data according to the P-wave layer velocity curve and the S-wave layer velocity curve, recording and calibrating the vertical seismic P-wave data and the vertical seismic converted-wave data in different velocity layers, improving the accuracy and reliability of data processing, and also providing a basis for subsequent data analysis and data processing. After that, horizon interpretation processing is carried out, which can be understood as tracing the distribution and trend of each underlying layer on the seismic section and drawing the underlying contour map. Combining geological theories and actual geological conditions, the geological structure is interpreted and inferred. Further, the vertical seismic P-wave velocity and the vertical seismic S-wave velocity are obtained through seismic inversion, improving the calculation accuracy of the vertical seismic P-wave and S-wave velocities.

[0068] Optionally, the relational expression between the P-wave velocity and the S-wave velocity is:

[0069] V S = 0.58V P - 149;

[0070] Wherein, V S represents the S-wave velocity, with the unit of m / s, and V p represents the P-wave velocity, with the unit of m / s.

[0071] In this embodiment, V S represents the S-wave velocity, and V p represents the P-wave velocity. The units of both are m / s. The S-wave velocity can be further obtained through the above relational expression and the already obtained P-wave velocity.

[0072] Optionally, the steps of obtaining the surface seismic P-wave velocity by inverting according to the P-wave layer velocity curve and the surface seismic P-wave data include: performing synthetic record calibration on the surface seismic P-wave data according to the P-wave layer velocity curve, and horizon interpretation processing, and obtaining the surface seismic P-wave velocity through seismic inversion.

[0073] In this embodiment, the process of obtaining the surface seismic P-wave velocity by inversion specifically includes: performing synthetic record calibration on the surface seismic P-wave data according to the P-wave layer velocity curve, and horizon interpretation processing, and using seismic inversion to process the surface seismic P-wave data to obtain the surface seismic P-wave velocity, improving the calculation accuracy of the surface seismic P-wave velocity.

[0074] Optionally, the steps of obtaining the surface seismic S-wave velocity by converting the surface seismic P-wave velocity according to the relational expression include: performing amplitude processing on the surface seismic P-wave velocity according to the relational expression between the P-wave velocity and the S-wave velocity to obtain the surface seismic S-wave velocity.

[0075] In this embodiment, amplitude processing is performed on the ground seismic longitudinal wave velocity according to the relationship between the longitudinal wave velocity and the shear wave velocity to obtain the ground seismic shear wave velocity. Among them, amplitude processing is to calculate the ground seismic shear wave velocity by using the relationship between the longitudinal wave velocity and the shear wave velocity.

[0076] Optionally, the steps of constructing a well-to-surface fusion spatio-temporal variable longitudinal and shear wave velocity ratio field based on the ground seismic longitudinal wave velocity and the ground seismic shear wave velocity include: dividing the ground seismic longitudinal wave velocity by the ground seismic shear wave velocity to calculate the velocity ratio of the ground seismic longitudinal and shear waves; performing spatial processing and temporal processing on the velocity ratio of the ground seismic longitudinal and shear waves to construct a well-to-surface fusion spatio-temporal variable longitudinal and shear wave velocity ratio field.

[0077] In this embodiment, after obtaining the ground seismic longitudinal wave velocity and the ground seismic shear wave velocity, the ground seismic longitudinal wave velocity is divided by the ground seismic shear wave velocity to calculate the velocity ratio of the longitudinal wave to the shear wave. The continuous velocity ratio of the longitudinal wave to the shear wave forms a velocity ratio field. Then, spatial processing and temporal processing are performed on the velocity ratio of the ground seismic longitudinal and shear waves to construct a well-to-surface fusion spatio-temporal variable longitudinal and shear wave velocity ratio field. That is, spatial and temporal processing is performed on the basis of the velocity ratio field, taking into account the spatio-temporal variations of the ground seismic longitudinal and shear waves. The constructed well-to-surface fusion spatio-temporal variable longitudinal and shear wave velocity ratio field can improve the accuracy of seismic exploration.

[0078] Optionally, the formula for determining the two-way travel time of the corresponding ground seismic longitudinal wave data is:

[0079]

[0080] where T pp represents the two-way travel time of the ground seismic longitudinal wave data, with the unit of ms, k represents the longitudinal and shear wave velocity ratio, and T ps represents the two-way travel time of the ground seismic converted wave data, with the unit of ms.

[0081] In this embodiment, the two-way travel time of the ground seismic longitudinal wave data is calculated according to the above formula. The longitudinal and shear wave velocity ratio has been obtained in the previous steps, and the ground seismic converted wave data contains data on the two-way travel time. That is, the two-way travel time of the ground seismic longitudinal wave data can be calculated based on the two-way travel time of the ground seismic converted wave data, so as to obtain the ground seismic converted wave data transformed to the two-way travel time of the longitudinal wave.

[0082] In a specific application, as Figure 19 shown, the embodiment of the present invention provides another time matching method for ground seismic longitudinal wave converted wave data, including:

[0083] S201: Obtain vertical seismic profile data, ground seismic longitudinal wave data, and ground seismic converted wave data;

[0084] S202: Perform wavefield analysis on the vertical seismic profile data, pick the first arrivals of P-waves and S-waves, and calculate the P-wave layer velocity and S-wave layer velocity at the well point location;

[0085] S203: Obtain the P-wave layer velocity curve and S-wave layer velocity curve based on the P-wave layer velocity and S-wave layer velocity;

[0086] S204: Perform wavefield separation and imaging processing on the vertical seismic profile data to obtain vertical seismic P-wave data and vertical seismic converted-wave data;

[0087] S205: Perform synthetic seismogram calibration and horizon interpretation processing on the vertical seismic P-wave data and vertical seismic converted-wave data according to the P-wave layer velocity curve and S-wave layer velocity curve, and obtain the vertical seismic P-wave velocity and vertical seismic S-wave velocity through seismic inversion;

[0088] S206: Analyze the vertical seismic P-wave velocity and vertical seismic S-wave velocity to obtain the relationship between the P-wave velocity and the S-wave velocity;

[0089] S207: Perform synthetic seismogram calibration and horizon interpretation processing on the surface seismic P-wave data according to the P-wave layer velocity curve, and obtain the surface seismic P-wave velocity through seismic inversion;

[0090] S208: Perform amplitude processing on the surface seismic P-wave velocity according to the relationship between the P-wave velocity and the S-wave velocity to obtain the surface seismic S-wave velocity;

[0091] S209: Divide the surface seismic P-wave velocity by the surface seismic S-wave velocity to calculate the velocity ratio of the surface seismic P-wave to S-wave;

[0092] S210: Perform spatial processing and temporal processing on the velocity ratio of the surface seismic P-wave to S-wave to construct a space-time variable velocity ratio field of well-to-surface integration;

[0093] S211: Determine the two-way travel time of the corresponding surface seismic P-wave data according to the space-time variable velocity ratio field of well-to-surface integration and the two-way travel time of the surface seismic converted-wave data, and obtain the surface seismic converted-wave data transformed to the two-way travel time of P-waves.

[0094] The time matching method for surface seismic P-wave converted-wave data proposed in this embodiment has the characteristics of strong operability, obvious effect, high production practical value, etc. It better solves the problem of time matching between surface seismic P-wave and converted-wave data, not only improves the matching accuracy, but also is beneficial to the quality and accuracy of the joint interpretation results of surface seismic P-wave and converted-wave data.

[0095] Such as Figure 20As shown, according to an embodiment of the second aspect of the present invention, a time matching device 10 for surface seismic P-wave converted wave data is provided, including: an acquisition module 11 for acquiring vertical seismic profile data, surface seismic P-wave data, and surface seismic converted wave data; a calculation module 12 for obtaining a P-wave layer velocity curve and an S-wave layer velocity curve at the well point position according to the vertical seismic profile data; a processing module 13 for performing data processing on the vertical seismic profile data to obtain vertical seismic P-wave data and vertical seismic converted wave data; an inversion module 14 for performing seismic inversion on the P-wave layer velocity curve, S-wave layer velocity curve, vertical seismic P-wave data, and vertical seismic converted wave data to obtain vertical seismic P-wave velocity and vertical seismic S-wave velocity; an analysis module 15 for analyzing the vertical seismic P-wave velocity and vertical seismic S-wave velocity to obtain a relationship formula between the P-wave velocity and the S-wave velocity; the inversion module 14 is further used for inversely obtaining the surface seismic P-wave velocity according to the P-wave layer velocity curve and the surface seismic P-wave data; a conversion module 16 for converting the surface seismic P-wave velocity according to the relationship formula to obtain the surface seismic S-wave velocity; a construction module 17 for constructing a space-time variable P-wave to S-wave velocity ratio field of well-to-surface integration according to the surface seismic P-wave velocity and the surface seismic S-wave velocity; a determination module 18 for determining the two-way travel time of the corresponding surface seismic P-wave data according to the space-time variable P-wave to S-wave velocity ratio field of well-to-surface integration and the two-way travel time of the surface seismic converted wave data, and obtaining the surface seismic converted wave data transformed to the two-way travel time of the P-wave.

[0096] In this embodiment, the time matching device 10 for surface seismic P-wave converted wave data first obtains vertical seismic profile data, surface seismic P-wave data, and surface seismic converted wave data through the acquisition module 11. These seismic data are all original data collected by seismic instruments. Among them, the vertical seismic profile data refers to seismic wave data underground, and both the surface seismic P-wave data and the surface seismic converted wave data are seismic wave data received on the surface. Then, the calculation module 12 determines the P-wave layer velocity curve and S-wave layer velocity curve at the well point position according to the vertical seismic profile data. Next, the processing module 13 processes the vertical seismic profile data to obtain vertical seismic P-wave data and vertical seismic converted wave data. Further, the inversion module 14 performs seismic inversion according to the P-wave layer velocity curve, S-wave layer velocity curve, vertical seismic P-wave data, and vertical seismic converted wave data to obtain the vertical seismic P-wave velocity and vertical seismic S-wave velocity. Immediately afterwards, the analysis module 15 analyzes the vertical seismic P-wave velocity and vertical seismic S-wave velocity to obtain the relationship between the P-wave velocity and the S-wave velocity. At the same time, the inversion module 14 inverses the P-wave layer velocity curve and the surface seismic P-wave data to obtain the surface seismic P-wave velocity. The conversion module 16 then uses the above relationship to obtain the surface seismic S-wave velocity according to the surface seismic P-wave velocity, thereby calculating the surface seismic P-wave velocity and the surface seismic S-wave velocity. Further, the construction module 17 determines the velocity ratio field of the surface P-wave and S-wave. Finally, the determination module 18 calculates the two-way travel time of the corresponding surface seismic P-wave data based on the velocity ratio field of the surface P-wave and S-wave and the two-way travel time of the surface seismic converted wave data, so that the data of the surface seismic P-wave and the converted wave are on the same two-way travel time, that is, the surface seismic converted wave data transformed to the two-way travel time of the P-wave is obtained. This embodiment can improve the efficiency and accuracy of P-wave to converted wave time matching, and further improve the accuracy of the interpretation results in multi-wave seismic exploration.

[0097] Optionally, the calculation module 12 is specifically configured to: perform wave field analysis on the vertical seismic profile data, pick the P-wave first arrival and the S-wave first arrival, and calculate the P-wave layer velocity and S-wave layer velocity at the well point position; obtain the P-wave layer velocity curve and S-wave layer velocity curve according to the P-wave layer velocity and S-wave layer velocity.

[0098] Optionally, the processing module 13 is specifically configured to: perform wave field separation and imaging processing on the vertical seismic profile data to obtain vertical seismic P-wave data and vertical seismic converted wave data.

[0099] Optionally, the inversion module 14 is specifically configured to: perform synthetic record calibration and horizon interpretation processing on the vertical seismic P-wave data and vertical seismic converted wave data according to the P-wave layer velocity curve and S-wave layer velocity curve, and obtain the vertical seismic P-wave velocity and vertical seismic S-wave velocity through seismic inversion.

[0100] Optionally, the inversion module 14 is further specifically configured to: perform synthetic seismogram calibration and horizon interpretation processing on the surface seismic P-wave data according to the P-wave layer velocity curve, and obtain the surface seismic P-wave velocity through seismic inversion.

[0101] Optionally, the conversion module 16 is specifically configured to: perform amplitude processing on the surface seismic P-wave velocity according to the relationship between the P-wave velocity and the S-wave velocity to obtain the surface seismic S-wave velocity.

[0102] Optionally, the construction module 17 is specifically configured to: calculate the ratio of the surface seismic P-wave velocity to the surface seismic S-wave velocity to obtain the surface seismic P-to-S wave velocity ratio; perform spatial processing and temporal processing on the surface seismic P-to-S wave velocity ratio to construct a well-to-surface fusion spatio-temporal variable P-to-S wave velocity ratio field.

[0103] According to the third aspect of the present invention, there is provided a storage medium on which a computer program is stored, and when the computer program is executed by a processor, the steps of the time matching method for surface seismic P-wave converted wave data in the first aspect or any possible implementation manner of the first aspect of the present invention are implemented.

[0104] As Figure 21 shown, according to the fourth aspect of the present invention, there is provided an electronic device 20, including a memory 21, a processor 22, and a computer program stored on the memory 21 and executable on the processor 22. When the processor executes the computer program, the steps of the time matching method for surface seismic P-wave converted wave data in the first aspect or any possible implementation manner of the first aspect of the present invention are implemented.

[0105] The implementation processes of the functions and roles of each unit in the above device are specifically described in detail in the implementation processes of the corresponding steps in the above method, and will not be repeated here.

[0106] It should be noted that in this article, relational terms such as "first" and "second" are only used to distinguish one entity or operation from another entity or operation, and do not necessarily require or imply any actual relationship or order between these entities or operations. Moreover, the term "comprising", "including" or any other variant thereof is intended to cover non-exclusive inclusion, so that a process, method, article or device including a series of elements not only includes those elements, but also includes other elements not expressly listed, or also includes elements inherent to such process, method, article or device. Without further limitation, an element defined by the statement "including one..." does not exclude the existence of additional identical elements in the process, method, article or device including the element.

[0107] The above are only specific embodiments of the present invention, enabling those skilled in the art to understand or implement the present invention. Various modifications to these embodiments will be obvious to those skilled in the art, and the general principles defined herein can be implemented in other embodiments without departing from the spirit or scope of the present invention. Therefore, the present invention will not be limited to these embodiments shown herein, but rather will conform to the broadest scope consistent with the principles and novel features claimed herein.

Claims

1. A time matching method for surface seismic longitudinal wave converted wave data, characterized in that Including: Obtaining vertical seismic profile data, surface seismic P-wave data, and surface seismic converted-wave data; Obtaining a P-wave layer velocity curve and an S-wave layer velocity curve at the well point position according to the vertical seismic profile data; Performing data processing on the vertical seismic profile data to obtain vertical seismic P-wave data and vertical seismic converted-wave data; Performing seismic inversion on the P-wave layer velocity curve, the S-wave layer velocity curve, the vertical seismic P-wave data, and the vertical seismic converted-wave data to obtain a vertical seismic P-wave velocity and a vertical seismic S-wave velocity; Analyzing the vertical seismic P-wave velocity and the vertical seismic S-wave velocity to obtain a relationship between the P-wave velocity and the S-wave velocity; Inverting the surface seismic P-wave velocity according to the P-wave layer velocity curve and the surface seismic P-wave data; Converting the surface seismic P-wave velocity according to the relationship to obtain a surface seismic S-wave velocity; Constructing a well-ground integrated spatio-temporal variable P-wave to S-wave velocity ratio field according to the surface seismic P-wave velocity and the surface seismic S-wave velocity; Determining the two-way travel time of the corresponding surface seismic P-wave data according to the two-way travel time of the well-ground integrated spatio-temporal variable P-wave to S-wave velocity ratio field and the surface seismic converted-wave data, and obtaining the surface seismic converted-wave data transformed to the two-way travel time of the P-wave.

2. The time matching method for surface seismic longitudinal wave converted wave data according to claim 1, characterized in that The step of obtaining the P-wave layer velocity curve and the S-wave layer velocity curve at the well point position according to the vertical seismic profile data includes: Performing wave field analysis on the vertical seismic profile data, picking the P-wave first arrival and the S-wave first arrival, and calculating the P-wave layer velocity and the S-wave layer velocity at the well point position; Obtaining the P-wave layer velocity curve and the S-wave layer velocity curve according to the P-wave layer velocity and the S-wave layer velocity.

3. The time matching method for surface seismic longitudinal wave converted wave data according to claim 1, characterized in that The step of performing data processing on the vertical seismic profile data to obtain vertical seismic P-wave data and vertical seismic converted-wave data includes: Performing wave field separation and imaging processing on the vertical seismic profile data to obtain the vertical seismic P-wave data and the vertical seismic converted-wave data.

4. The time matching method for surface seismic longitudinal wave converted wave data according to claim 1, wherein The step of performing seismic inversion on the P-wave layer velocity curve, the S-wave layer velocity curve, the vertical seismic P-wave data, and the vertical seismic converted-wave data to obtain a vertical seismic P-wave velocity and a vertical seismic S-wave velocity includes: Performing synthetic record calibration and horizon interpretation processing on the vertical seismic P-wave data and the vertical seismic converted-wave data according to the P-wave layer velocity curve and the S-wave layer velocity curve, and obtaining the vertical seismic P-wave velocity and the vertical seismic S-wave velocity through seismic inversion.

5. The time matching method for surface seismic longitudinal wave converted wave data according to claim 1, wherein The relationship between the P-wave velocity and the S-wave velocity is: V S = 0.58 V P -149; Among them, V S represents the shear wave velocity, with the unit of m / s, and V p represents the compressional wave velocity, with the unit of m / s.

6. The time matching method for surface seismic longitudinal wave converted wave data according to claim 1, characterized in that The step of inverting the surface seismic P-wave velocity according to the P-wave layer velocity curve and the surface seismic P-wave data includes: Performing synthetic record calibration and horizon interpretation processing on the surface seismic P-wave data according to the P-wave layer velocity curve, and obtaining the surface seismic P-wave velocity through seismic inversion.

7. The time matching method for surface seismic P-wave converted wave data according to claim 1, characterized in that The step of converting the surface seismic P-wave velocity according to the relationship to obtain a surface seismic S-wave velocity includes: Perform amplitude processing on the ground seismic P-wave velocity according to the relational expression between the P-wave velocity and the S-wave velocity to obtain the ground seismic S-wave velocity.

8. The time matching method for surface seismic longitudinal wave converted wave data according to claim 1, characterized in that, The steps of constructing a well-ground integrated spatio-temporal variable P-S wave velocity ratio field according to the ground seismic P-wave velocity and the ground seismic S-wave velocity include: Divide the ground seismic P-wave velocity by the ground seismic S-wave velocity to calculate the P-S wave velocity ratio of the ground seismic waves; Perform spatial processing and temporal processing on the P-S wave velocity ratio of the ground seismic waves to construct the well-ground integrated spatio-temporal variable P-S wave velocity ratio field.

9. The time matching method for surface seismic longitudinal wave converted wave data according to claim 1, characterized in that The calculation formula for determining the two-way travel time of the corresponding ground seismic P-wave data is: Among them, T pp represents the two-way travel time of the surface seismic P-wave data, k represents the P-wave to S-wave velocity ratio, and T ps represents the two-way travel time of the surface seismic converted-wave data.

10. A time matching device for surface seismic longitudinal wave converted wave data, characterized in that, Including: An acquisition module for acquiring vertical seismic profile data, ground seismic P-wave data, and ground seismic converted wave data; A calculation module for obtaining the P-wave layer velocity curve and the S-wave layer velocity curve at the well point position according to the vertical seismic profile data; A processing module for performing data processing on the vertical seismic profile data to obtain vertical seismic P-wave data and vertical seismic converted wave data; An inversion module for performing seismic inversion on the P-wave layer velocity curve, the S-wave layer velocity curve, the vertical seismic P-wave data, and the vertical seismic converted wave data to obtain the vertical seismic P-wave velocity and the vertical seismic S-wave velocity; An analysis module for analyzing the vertical seismic P-wave velocity and the vertical seismic S-wave velocity to obtain the relational expression between the P-wave velocity and the S-wave velocity; The inversion module is further configured to invert the ground seismic P-wave velocity according to the P-wave layer velocity curve and the ground seismic P-wave data; A conversion module for converting the ground seismic P-wave velocity according to the relational expression to obtain the ground seismic S-wave velocity; A construction module for constructing a well-ground integrated spatio-temporal variable P-S wave velocity ratio field according to the ground seismic P-wave velocity and the ground seismic S-wave velocity; A determination module for determining the two-way travel time of the corresponding ground seismic P-wave data according to the well-ground integrated spatio-temporal variable P-S wave velocity ratio field and the two-way travel time of the ground seismic converted wave data, and obtaining the ground seismic converted wave data transformed to the two-way travel time of the P-wave.

11. A storage medium, on which a computer program is stored, characterized in that, When the computer program is executed by a processor, the steps of the method according to any one of claims 1 to 9 are implemented.

12. An electronic device, comprising a memory, a processor, and a computer program stored on the memory and executable on the processor, characterized in that, When the processor executes the computer program, the steps of the method according to any one of claims 1 to 9 are implemented.

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