A method, apparatus, device and medium for determining a formation horizon

Abstract

Embodiments of the present application disclose a method, device and equipment for determining a stratum horizon, and a medium. The method comprises: determining first stratum horizon information of a target area according to dual-azimuth fusion seismic data of the target area; determining a sub-analysis area that does not meet a seismic illumination requirement as an adjustment area according to analysis results of seismic illumination of a to-be-analyzed area in the target area from two azimuths, and determining an azimuth corresponding to higher seismic illumination as a target azimuth at a same position through the adjustment area; determining second stratum horizon information of the adjustment area according to seismic data of the target azimuth; and determining final stratum horizon information of the target area according to the first stratum horizon information and the second stratum horizon information. The technical solution reduces the influence of a large difference in seismic illumination on the determination of a stratum horizon, and improves the accuracy of the determination of the stratum horizon.

Description

TECHNICAL FIELD

[0001] The present application relates to the technical field of geological exploration, and in particular to a stratum horizon determination method, device, equipment and medium. BACKGROUND

[0002] The key of subsalt target exploration lies in the analysis of subsalt stratum structure scale, lithology and oil and gas bearing property, and the basis of these works is the subsalt stratum horizon interpretation. How to accurately determine the stratum horizon information is a problem to be solved.

[0003] At present, the main scheme is to collect seismic data from two directions, and to process the collected seismic data to obtain double-direction fusion seismic data, and then to perform stratum horizon interpretation according to the double-direction fusion seismic data.

[0004] However, when collecting seismic data from two directions, there is a case that the subsalt illumination is different under different directions, and when the illumination difference is large, the stratum horizon interpretation according to the double-direction fusion seismic data will have a problem of large error. SUMMARY

[0005] The present application provides a stratum horizon determination method, device, equipment and medium, which can reduce the influence of large seismic illumination difference on the determination of stratum horizon, and improve the accuracy of stratum horizon determination.

[0006] According to an aspect of the present application, a stratum horizon determination method is provided, which comprises:

[0007] determining first stratum horizon information of a target region according to double-direction fusion seismic data of the target region;

[0008] determining a sub-analysis region that does not meet the seismic illumination requirement as an adjustment region according to the seismic illumination analysis result of the to-be-analyzed region in the target region from two directions, and determining a direction with higher seismic illumination as a target direction at the same position of the adjustment region; the two directions refer to two directions in the process of transmitting from the seismic source to the geophone;

[0009] determining second stratum horizon information of the adjustment region according to seismic data of the target direction;

[0010] determining final stratum horizon information of the target region according to the first stratum horizon information and the second stratum horizon information.

[0011] According to another aspect of the present application, a stratum horizon determination device is provided, which comprises:

[0012] The first stratum horizon information determination module is configured to determine first stratum horizon information of the target region according to the dual-azimuth fusion seismic data of the target region.

[0013] The target region and target azimuth determination module is configured to determine a sub-analyzed region that does not meet the seismic illumination requirement as a region to be adjusted according to the seismic illumination analysis result of the region to be analyzed in the target region from two azimuths, and determine the azimuth corresponding to higher seismic illumination as the target azimuth through the same position of the region to be adjusted from the two azimuths; the two azimuths refer to two azimuths in the process of transmitting the seismic wave from the seismic source to the geophone.

[0014] The second stratum horizon information determination module is configured to determine second stratum horizon information of the region to be adjusted according to the seismic data of the target azimuth.

[0015] The final stratum horizon information determination module is configured to determine final stratum horizon information of the target region according to the first stratum horizon information and the second stratum horizon information.

[0016] According to another aspect of the present application, an electronic device is provided, and the electronic device comprises:

[0017] at least one processor; and

[0018] a memory connected to the at least one processor in communication; wherein

[0019] The memory stores a computer program executable by the at least one processor, and the computer program is executed by the at least one processor to enable the at least one processor to execute the stratum horizon determination method according to any one of the embodiments of the present application.

[0020] According to another aspect of the present application, a computer readable storage medium is provided, and the computer readable storage medium stores computer instructions for enabling a processor to implement the stratum horizon determination method according to any one of the embodiments of the present application when executed.

[0021] The technical scheme of the embodiment of the application comprises: determining first stratum horizon information of a target region according to two-azimuth fusion seismic data of the target region; determining a sub-to-be-analyzed region that does not meet a seismic illumination requirement as a to-be-adjusted region according to a seismic illumination analysis result of a to-be-analyzed region in the target region from two azimuths, and determining a target azimuth corresponding to higher seismic illumination of the two azimuths at a same position through the to-be-adjusted region; the two azimuths refer to two azimuths in a process in which seismic waves are emitted from a seismic source and finally transmitted to a geophone; determining second stratum horizon information of the to-be-adjusted region according to seismic data of the target azimuth; and determining final stratum horizon information of the target region according to the first stratum horizon information and the second stratum horizon information. The technical scheme reduces the influence of a too large seismic illumination difference on stratum horizon determination, and improves the accuracy of stratum horizon determination.

[0022] It should be understood that the content described in this part is not intended to identify key or important features of the embodiments of the application, nor is it used to limit the scope of the application. Other features of the application will become apparent from the following description. BRIEF DESCRIPTION OF DRAWINGS

[0023] In order to more clearly illustrate the technical solutions in the embodiments of the application, the following will briefly introduce the drawings needed to be used in the embodiments. Obviously, the drawings in the following description are only some embodiments of the application, and for those skilled in the art, other drawings can also be obtained from these drawings without creative labor.

[0024] Figure 1 is a flow chart of a stratum horizon determination method according to the stratum horizon determination method provided in the first embodiment of the application;

[0025] Figure 2 is a flow chart of a stratum horizon determination method according to the stratum horizon determination method provided in the second embodiment of the application;

[0026] Figure 3 is a structural schematic diagram of a stratum horizon determination device according to the stratum horizon determination device provided in the third embodiment of the application;

[0027] Figure 4 is a structural schematic diagram of an electronic device for implementing a stratum horizon determination method according to the stratum horizon determination method. DETAILED DESCRIPTION

[0028] In the following, the technical solutions in the embodiments of the present application will be described clearly and completely in conjunction with the drawings in the embodiments of the present application, so that those skilled in the art can better understand the present application. Obviously, the described embodiments are only a part of the embodiments of the present application, rather than all the embodiments. Based on the embodiments in the present application, all other embodiments obtained by those skilled in the art without creative work should fall within the scope of the present application.

[0029] It should be noted that the terms "first", "second", "target" and the like in the description, claims, and drawings of the present application are used to distinguish similar objects, and do not necessarily indicate a specific order or sequence. It should be understood that the data used in this way can be interchanged under appropriate circumstances, so that the embodiments of the application described herein can be implemented in an order other than those illustrated or described herein. In addition, the terms "include" and "have" and any variations thereof are intended to cover non-exclusive inclusion, for example, a process, method, system, product or device including a series of steps or units does not necessarily limit to those steps or units clearly listed, but can include other steps or units not clearly listed or inherent to these processes, methods, products or devices.

[0030] Embodiment one

[0031] Figure 1 A flowchart of a method for determining a formation horizon is provided for the first embodiment of the present application. The first embodiment of the present application can be applied to the case of determining formation horizon information. The method can be executed by a formation horizon determination device, which can be realized in the form of hardware and / or software, and can be configured in an electronic device with data processing capability. As shown in Figure 1 , the method comprises:

[0032] S110, determining first formation horizon information of the target area according to the dual-azimuth fusion seismic data of the target area.

[0033] The target area can be an area that needs to be geologically explored, and the target area can be any one or more formations. Dual-azimuth fusion seismic data refers to seismic data after fusion of two single-azimuth seismic data. The specific determination process of the dual-azimuth fusion seismic data is not limited in the embodiments of the present application. For example, the dual-azimuth can be two azimuths that are orthogonal to each other. The first formation horizon information can be the horizon information of at least one formation in the target area, for example, x meters to y meters underground is a salt rock layer, z meters to m meters underground is a low-permeability reservoir, etc.

[0034] Specifically, in one feasible approach, bi-directional fused seismic data of the target area is determined according to the method described in subsequent embodiments. In another feasible approach, bi-directional fused seismic data of the target area is obtained using existing methods for determining bi-directional fused seismic data.

[0035] Furthermore, the correspondence between the two-dimensional fused seismic data and the stratigraphic horizon can be predetermined. Then, the two-dimensional fused seismic data of the target area is acquired, and the first stratigraphic horizon information of the target area is determined based on the above correspondence.

[0036] For example, the process of determining the correspondence between bidirectional fused seismic data and the top surface of the salt rock segment in the target area can be as follows: Based on the geological background of the target area, obtain the structural pattern of salt rock development in the target area; then, based on the lithology revealed by drilling in the target area and the corresponding seismic reflection characteristics, clarify the top interface and internal reflection characteristics of the salt rock segment (for example, in a certain area, the velocity difference between the salt rock and the overlying surrounding rocks is significant, mainly manifested as: 1. The velocity of the salt rock is higher than that of the Tertiary strata, and the strata interface shows positive polarity seismic reflection; 2. The velocity of the salt rock is lower than that of the Albian marl, and the strata interface shows negative polarity seismic reflection; 3. The internal reflection characteristics of the salt body are mostly blank). Finally, by integrating the isochronous slices of the bidirectional fused seismic data, the top interface of the salt rock segment is traced using a multi-Z value seismic interpretation method to obtain the correspondence between the top surface interpretation layer of the salt body and the bidirectional fused seismic data.

[0037] For example, the process of determining the correspondence between bidirectional fused seismic data and the stratigraphic levels above the salt body can be as follows: First, perform synthetic record calibration on the target area and surrounding drilled wells to clarify the seismic reflection characteristics of the main geological strata above the salt body (including seismic reflection polarity, amplitude, continuity, and frequency characteristics). Then, construct a well-connecting framework around the salt body and perform seismic interpretation. This framework can effectively solve the problem of difficulty in comparing seismic wave groups on both sides of the salt body due to spatial obstruction. During the seismic interpretation of the well-connecting framework, a method of mutual verification between geological strata and seismic reflection characteristics is adopted to achieve the unification of stratified seismic reflection characteristics. Finally, based on the framework interpretation scheme, perform regular densification interpretation of the stratigraphic levels above the salt body to obtain the correspondence between the bidirectional fused seismic data and the stratigraphic levels above the salt body.

[0038] For example, the correspondence between the dual-azimuth fusion seismic data and the horizon of the subsalt formation is determined as follows: due to the actual situation of the exploration well, the subsalt fault-depression conversion surface and the basement are rarely revealed by drilling, and in order to assist the target evaluation requirement, the following technical process can be used: first, the target area and the surrounding drilled wells are used to calibrate the synthetic records, and the seismic reflection characteristics (including seismic reflection polarity, amplitude strength, continuity and frequency characteristics, etc.) of relatively shallow horizons such as the salt rock bottom interface and the depression period bottom surface are determined; then, for the horizons that are not revealed by drilling (such as the fault-depression conversion surface and the basement), the geological model is used to guide the seismic interpretation method to interpret the strata that are not revealed by drilling, wherein the fault-depression conversion surface has the characteristics of an unconformable interface with onlap and downcutting, and the basement is generally interpreted as the bottom envelope surface of the clastic rock stratum in the fault depression period; finally, considering that the salt rock bottom surface is the top surface of the subsalt target, further combined with the geological model of the development of the igneous rock in the rift period and the seismic forward modeling and other technical means, the salt rock bottom surface is focused on to identify the intrusive rock, and the high-precision correspondence between the dual-azimuth fusion seismic data and the horizon of the subsalt formation is determined.

[0039] In S120, a sub-analysis region that does not meet the seismic illumination requirement is determined as an adjustment region according to the analysis result of the seismic illumination of the target region in the target area, and a target azimuth is determined as the azimuth with higher seismic illumination at the same position in the two azimuths through the adjustment region.

[0040] The target region can be a region that needs further horizon interpretation, or the entire target region. For example, the target region can be the bottom surface of the salt rock layer. The seismic illumination can reflect the quality of the collected seismic data. For example, in the case of high seismic illumination, the collected seismic data can more accurately reflect the geological information. Further, one of the two azimuths can be: from the A seismic source, propagating and / or reflecting underground, and finally transmitting to the corresponding geophone; and the other azimuth can be: from the B seismic source, propagating and / or reflecting underground, and finally transmitting to the corresponding geophone.

[0041] Specifically, due to the anisotropy of the stratum and other influences, the propagation paths of the seismic waves collected in different azimuths are quite different, which causes the illumination of the subsalt in different azimuths to be different in different regions. When the illumination difference is large, the conventional dual-azimuth fusion seismic data are not as good as the single-azimuth seismic data with superior illumination. Therefore, the embodiments of the present application determine the seismic illumination of the two azimuths, and then determine the stratum horizon information of the adjustment region by using the seismic data of the target azimuth with higher seismic illumination, so as to improve the accuracy of the stratum horizon determination.

[0042] In the embodiments of the present application, a stratum model can be established according to the first stratum horizon information and the velocity information of each stratum, the stratum model is simulated by seismic illumination, the seismic illumination of the two azimuths corresponding to the to-be-analyzed area is obtained, the sub-to-be-analyzed area that does not meet the requirement of seismic illumination (for example, the difference between the seismic illumination of the two azimuths reaches a threshold) is determined as the to-be-adjusted area, and the azimuth corresponding to the higher seismic illumination of the two azimuths at the same position passing through the to-be-adjusted area is determined as the target azimuth.

[0043] In S130, the second stratum horizon information of the to-be-adjusted area is determined according to the seismic data of the target azimuth.

[0044] The second stratum horizon information can be the horizon information of all strata in the to-be-adjusted area, and the process of determining the second stratum horizon information of the to-be-adjusted area according to the seismic data of the target azimuth can be the same as that of determining the first stratum horizon information, which will not be repeated here. It should be noted that the seismic data of the target azimuth can be the original seismic data or the seismic data after migration imaging, which is not limited in the embodiments of the present application.

[0045] In S140, the final stratum horizon information of the target area is determined according to the first stratum horizon information and the second stratum horizon information.

[0046] The final stratum horizon information reflects the stratum horizon information of the target area finally determined after the method in the embodiments of the present application.

[0047] Optionally, the final stratum horizon information of the target area is determined according to the first stratum horizon information and the second stratum horizon information, including: replacing the first stratum horizon information corresponding to the to-be-adjusted area in the first stratum horizon information with the second stratum horizon information to obtain the final stratum horizon information of the target area.

[0048] It can be understood that, in the final stratum horizon information of the target area, the stratum horizon information of the strata other than the to-be-adjusted area is the first stratum horizon information, and the stratum horizon information of the strata in the to-be-adjusted area is the second stratum horizon information.

[0049] The technical scheme of the embodiment of the present application comprises: determining first stratum horizon information of a target region according to dual-azimuth fusion seismic data of the target region; determining a sub-to-be-analyzed region that does not satisfy a seismic illumination requirement as a to-be-adjusted region according to an analysis result of seismic illumination of a to-be-analyzed region in the target region from two azimuths, and determining a target azimuth corresponding to higher seismic illumination of the two azimuths at a same position through the to-be-adjusted region; the two azimuths refer to two azimuths in a process in which seismic waves are emitted from a seismic source and finally transmitted to a geophone; determining second stratum horizon information of the to-be-adjusted region according to seismic data of the target azimuth; and determining final stratum horizon information of the target region according to the first stratum horizon information and the second stratum horizon information. The technical scheme reduces the influence of too large seismic illumination difference on determination of stratum horizon, and improves the accuracy of stratum horizon determination.

[0050] Embodiment two

[0051] Figure 2 A flowchart of a stratum horizon determination method provided by the embodiment two of the present application is shown in the figure, and the embodiment of the present application specifically determines a target azimuth and a to-be-adjusted region based on the above-mentioned embodiment.

[0052] As shown in the figure, the method of the embodiment of the present application specifically comprises the following steps: Figure 2

[0053] S210, for the two azimuths, determining dual-azimuth fusion tomographic velocities and seismic data of the two azimuths after velocity correction according to a result of tomographic velocity inversion of common reflection point gathers of each azimuth; the dual-azimuth fusion tomographic velocities are velocities corresponding to a case in which a flattening effect of a same phase axis of the common reflection point gathers of each azimuth satisfies a preset requirement; the seismic data of the two azimuths after velocity correction are seismic data after moveout stretch of the common reflection point gathers of each azimuth based on the dual-azimuth fusion tomographic velocities.

[0054] The common reflection point gather refers to a set of seismic records reflected by a same underground reflection point. The preset requirement can be that the comprehensive effect of flattening of the same phase axis of the common reflection point gathers of the two azimuths is best, and the embodiment of the present application does not limit the specific preset requirement.

[0055] ​Specifically, the velocity of each orientation is assigned by tomographic velocity inversion of the common reflection point gathers of each orientation, and the flattening effect of the event lines of the common reflection point gathers of each orientation at each velocity is determined. In the case that the flattening effect of the event lines of the common reflection point gathers of two orientations is the best, the velocity corresponding to the case is the dual-orientation fusion tomographic velocity. For example, the flattening effect of the event lines of the common reflection point gathers of one orientation at C velocity is good, and the flattening effect of the event lines of the common reflection point gathers of the other orientation is also good; the flattening effect of the event lines of the common reflection point gathers of one orientation at D velocity is very good, and the flattening effect of the event lines of the common reflection point gathers of the other orientation is very poor. Among the two velocities of C and D, it can be considered that the flattening effect of the event lines of the common reflection point gathers of two orientations at C velocity is better than that at D velocity, and the velocity assignment is continuously performed to determine the velocity in the case that the flattening effect of the event lines of the common reflection point gathers of two orientations is the best.

[0056] Further, in the process of determining the dual-orientation fusion tomographic velocity, the common reflection point gathers of two orientations are stretched, and after the dual-orientation fusion tomographic velocity is determined, the correction process is ended, and the seismic data of each orientation after velocity correction is obtained.

[0057] S220, determining a dual-orientation fusion velocity model of the target region according to the dual-orientation fusion tomographic velocity of the non-salt body of the target region and the velocity of the salt body.

[0058] The non-salt body can be a part of the target region that is not a salt body. Specifically, the dual-orientation fusion tomographic velocity corresponding to the salt body part is removed from the dual-orientation fusion tomographic velocity of the target region to obtain the dual-orientation fusion tomographic velocity of the non-salt body. Further, based on the dual-orientation fusion tomographic velocity, the salt body velocity can be obtained by using the conventional constant velocity salt body construction method commonly used in the industry related to salt processing. Further, the dual-orientation fusion tomographic velocity and the salt body velocity are combined as the initial velocity of full waveform seismic inversion, and full waveform velocity inversion is carried out to obtain the dual-orientation fusion velocity model of the target region.

[0059] S230, performing migration imaging processing on the seismic data of each orientation after velocity correction based on the dual-orientation fusion velocity model to obtain the migrated seismic data of each orientation.

[0060] S240, determining dual-orientation fusion seismic data according to the migrated seismic data of each orientation.

[0061] Specifically, since the dual-azimuth fusion velocity model is to consider the velocity of the seismic data collected in different azimuths, the dual-azimuth fusion velocity model is affected by the anisotropy of the stratum, the trace gather flattening results of different azimuths based on the dual-azimuth fusion velocity are different, and the fitting degrees of two different azimuths of the seismic data to the dual-azimuth velocity are different, so the embodiments of the present application perform subsequent processing on the migrated seismic data of each azimuth to obtain dual-azimuth fusion seismic data which is more matched with the actual situation.

[0062] In the embodiments of the present application, the two azimuths include a first azimuth and a second azimuth.

[0063] Further, the dual-azimuth fusion seismic data is determined according to the migrated seismic data of each azimuth, including: determining a correlation coefficient between amplitudes of different offsets of each longitudinal sampling point of each azimuth.

[0064] The dual-azimuth fusion seismic data is determined according to the following formula:

[0065]

[0066] wherein, S DAZ is the dual-azimuth fusion seismic data; C AZ1 is the correlation coefficient corresponding to the first azimuth; C AZ2 is the correlation coefficient corresponding to the second azimuth; S AZ1 is the migrated seismic data of the first azimuth; and S AZ2 is the migrated seismic data of the second azimuth.

[0067] In the embodiments of the present application, the correlation coefficient between amplitudes of different offsets of the longitudinal sampling point reflects the relationship between amplitudes of different offsets at different acquisition times, that is, AVO (Amplitude variation with offset), and exemplarily, the closer the amplitudes of different offsets at different acquisition times, the closer the correlation coefficient to 1.

[0068] S250, determining first stratum horizon information of a target region according to the dual-azimuth fusion seismic data of the target region.

[0069] S260, assigning a velocity to each stratum horizon according to a corresponding relationship between the stratum horizon and the velocity to obtain a stratum model; the corresponding relationship between the stratum horizon and the velocity is determined according to drilling data and dual-azimuth fusion seismic velocity.

[0070] Specifically, after obtaining the first stratum horizon information, the specific distribution of the stratum horizons of the target region can be determined according to the first stratum horizon information (the stratum horizons of the target region can be reflected by a three-dimensional geological framework model), and then the stratum velocity near the wellbore can be determined according to the drilling data obtained by the drilling in the target region, the stratum velocity at other positions can be determined according to the dual-azimuth fusion seismic velocity, and then the stratum horizons are assigned with velocities according to the corresponding relationship between the stratum horizons and the velocities, so as to obtain a stratum model (the stratum model can be a three-dimensional stratum model, and the stratum model can display the stratum distribution and the corresponding velocities of the strata).

[0071] Correspondingly, the seismic illumination analysis result of the to-be-analyzed region in the target region from two azimuths includes: performing seismic illumination analysis on the to-be-analyzed region corresponding to the stratum model from two azimuths to determine the seismic illumination analysis result.

[0072] Illustratively, the stratum model is a model corresponding to the target region, a forward modeling observation system can be designed, seismic forward modeling is performed on the stratum model, and the illumination degree of each azimuth of the to-be-analyzed region is analyzed by using the simulated amplitude illumination analysis method.

[0073] S270, determining the relative deviation of the seismic amplitude values according to the seismic amplitude values of the to-be-analyzed region along two azimuths.

[0074] In the embodiments of the present application, optionally, the two azimuths include a first azimuth and a second azimuth; and the relative deviation of the seismic amplitude values is determined according to the seismic amplitude values of the to-be-analyzed region along the two azimuths, including steps A1-A3:

[0075] Step A1, determining the difference between the seismic amplitude value of the first azimuth and the seismic amplitude value of the second azimuth as a first parameter.

[0076] Step A2, determining the sum of the seismic amplitude value of the first azimuth and the seismic amplitude value of the second azimuth as a second parameter.

[0077] Step A3, determining the relative deviation according to the ratio of the first parameter to the second parameter.

[0078] The two azimuths refer to two azimuths in the process of transmitting the seismic wave from the seismic source to the geophone.

[0079] Illustratively, the relative deviation is determined according to the following formula:

[0080]

[0081] wherein RD is the relative deviation, M AZ1 is the seismic amplitude value of the first azimuth, and MAZ2 the second azimuth.

[0082] S280, determining a sub-region of the region to be analyzed, whose absolute value of the relative deviation is greater than or equal to a preset threshold value, as a region to be adjusted, and determining a target azimuth of the two azimuths corresponding to the same position of the region to be adjusted.

[0083] The preset threshold value can be determined according to actual conditions, and the embodiments of the present application do not limit this. For example, the preset threshold value can be 50%.

[0084] It should be noted that when the absolute value of the relative deviation is greater than or equal to the preset threshold value, there is a large deviation in the seismic illumination of the region to be adjusted corresponding to the two azimuths. In this case, the stratigraphic horizon can be determined according to the seismic data of the azimuth with greater seismic illumination. Therefore, the embodiments of the present application determine the target azimuth of the two azimuths corresponding to the same position of the region to be adjusted, and then perform the subsequent steps.

[0085] S290, determining the second stratigraphic horizon information of the region to be adjusted according to the seismic data of the target azimuth.

[0086] S2100, determining the final stratigraphic horizon information of the target region according to the first stratigraphic horizon information and the second stratigraphic horizon information.

[0087] The technical scheme of the embodiments of the present application determines the dual-azimuth fusion seismic data that is more in line with the actual situation according to the correlation coefficients of the azimuths and the seismic data of the offset azimuths. The difference between the seismic illuminations of the two azimuths is accurately represented by the relative deviation, and the final stratigraphic horizon information is determined through the subsequent steps, thereby reducing the influence of the large difference in seismic illumination on the determination of the stratigraphic horizon and improving the accuracy of the determination of the stratigraphic horizon.

[0088] Embodiment Three

[0089] Figure 3 A structural schematic diagram of a stratigraphic horizon determination device provided by Embodiment Three of the present application. The device can execute the stratigraphic horizon determination method provided by any embodiment of the present application, and has the corresponding function modules and beneficial effects of the execution method. As shown in the figure, the device includes: Figure 3

[0090] The first stratigraphic horizon information determination module 310 is configured to determine the first stratigraphic horizon information of the target region according to the dual-azimuth fusion seismic data of the target region.

[0091] ​The to-be-adjusted region and target azimuth determination module 320 is configured to determine, according to an analysis result of seismic illumination of a to-be-analyzed region in a target region from two azimuths, a sub-to-be-analyzed region that does not meet a seismic illumination requirement as a to-be-adjusted region, and determine, as a target azimuth, an azimuth corresponding to higher seismic illumination of a same position of the to-be-adjusted region from the two azimuths; the two azimuths refer to two azimuths in a process in which seismic waves are emitted from a seismic source and finally transmitted to a geophone.

[0092] The second formation horizon information determination module 330 is configured to determine second formation horizon information of the to-be-adjusted region according to seismic data of the target azimuth.

[0093] The final formation horizon information determination module 340 is configured to determine final formation horizon information of the target region according to the first formation horizon information and the second formation horizon information.

[0094] Optionally, the to-be-adjusted region and target azimuth determination module 320 comprises:

[0095] The relative deviation determination unit is configured to determine a relative deviation of seismic amplitude values of the to-be-analyzed region according to the seismic amplitude values of the to-be-analyzed region along the two azimuths.

[0096] The to-be-adjusted region and target azimuth determination unit is configured to determine, as the to-be-adjusted region, a sub-to-be-analyzed region in the to-be-analyzed region whose absolute value of the relative deviation is greater than or equal to a preset threshold, and determine, as the target azimuth, an azimuth corresponding to a larger seismic amplitude value of a same position of the to-be-adjusted region from the two azimuths.

[0097] Optionally, the two azimuths comprise a first azimuth and a second azimuth.

[0098] The relative deviation determination unit comprises:

[0099] The first parameter determination sub-unit is configured to determine a difference between the seismic amplitude value of the first azimuth and the seismic amplitude value of the second azimuth as a first parameter.

[0100] The second parameter determination sub-unit is configured to determine a sum of the seismic amplitude value of the first azimuth and the seismic amplitude value of the second azimuth as a second parameter.

[0101] The relative deviation determination sub-unit is configured to determine the relative deviation according to a ratio of the first parameter to the second parameter.

[0102] Optionally, the final formation horizon information determination module 340 comprises:

[0103] The final formation horizon information determining unit is configured to replace first formation horizon information corresponding to the region to be adjusted in the first formation horizon information with the second formation horizon information, to obtain final formation horizon information of the target region.

[0104] Optionally, the device further comprises:

[0105] The dual-azimuth fusion tomographic velocity determining module is configured to determine, for two azimuths, dual-azimuth fusion tomographic velocities and seismic data of the two azimuths after velocity correction according to results of tomographic velocity inversion on common reflection point gathers of the two azimuths; the dual-azimuth fusion tomographic velocity is a velocity corresponding to a condition that flattening effects of events of the common reflection point gathers of the two azimuths meet preset requirements; and the seismic data of the two azimuths after velocity correction is seismic data after NMO stretch of the common reflection point gathers of the two azimuths based on the dual-azimuth fusion tomographic velocity.

[0106] The dual-azimuth fusion velocity model determining module is configured to determine a dual-azimuth fusion velocity model of the target region according to the dual-azimuth fusion tomographic velocities of the non-salt body and the velocity of the salt body in the target region.

[0107] The migration imaging processing module is configured to perform migration imaging processing on the seismic data of the two azimuths after velocity correction based on the dual-azimuth fusion velocity model, to obtain migrated seismic data of the two azimuths.

[0108] The dual-azimuth fusion seismic data determining module is configured to determine dual-azimuth fusion seismic data according to the migrated seismic data of the two azimuths.

[0109] Optionally, the two azimuths include a first azimuth and a second azimuth.

[0110] The dual-azimuth fusion seismic data determining module comprises:

[0111] The correlation coefficient determining unit is configured to determine a correlation coefficient between amplitudes of different offsets of each longitudinal sampling point of the two azimuths.

[0112] The dual-azimuth fusion seismic data determining unit is configured to determine the dual-azimuth fusion seismic data according to the following formula:

[0113]

[0114] wherein, S DAZ is the dual-azimuth fusion seismic data; C AZ1 is the correlation coefficient corresponding to the first azimuth; C AZ2 is the correlation coefficient corresponding to the second azimuth; S AZ1 is the migrated seismic data of the first azimuth; and S AZ2 is the migrated seismic data of the second azimuth.

[0115] Optionally, the apparatus further comprises:

[0116] a formation model determination module configured to assign a velocity to each formation horizon according to a corresponding relationship between the formation horizon and the velocity, to obtain a formation model; the corresponding relationship between the formation horizon and the velocity is determined according to the drilling data and the dual-azimuth fusion seismic velocity;

[0117] Correspondingly, the seismic illumination analysis result of the to-be-analyzed region in the target region from two azimuths comprises:

[0118] The seismic illumination analysis result of the to-be-analyzed region corresponding to the formation model from two azimuths is determined.

[0119] The determination apparatus for formation horizon provided in the embodiments of the present application can execute the determination method for formation horizon provided in any of the embodiments of the present application, and has the corresponding function modules and beneficial effects of the execution method.

[0120] Embodiment four

[0121] Figure 4 A structural diagram of an electronic device 10 that can be used to implement embodiments of the present application is shown. The electronic device is intended to represent various forms of digital computers, such as laptops, desktops, tablets, personal digital assistants, servers, blade servers, mainframes, and other appropriate computers. The electronic device can also represent various forms of mobile devices, such as personal digital assistants, cellular telephones, smartphones, wearable devices (e.g., headsets, glasses, watches, etc.), and other similar computing devices. The components shown here, their connections and relationships, and their functions, are meant to be examples only, and are not intended to limit the inventiveness in the present document as described and / or claimed.

[0122] As shown in Figure 4 The electronic device 10 includes at least one processor 11, and a memory, such as a read-only memory (ROM) 12, a random access memory (RAM) 13, etc., which are in communication with the at least one processor 11, wherein the memory stores a computer program that can be executed by the at least one processor. The processor 11 can execute various appropriate actions and processes according to the computer program stored in the read-only memory (ROM) 12 or loaded from the storage unit 18 into the random access memory (RAM) 13. In the RAM 13, various programs and data required for the operation of the electronic device 10 can also be stored. The processor 11, the ROM 12, and the RAM 13 are connected to each other through a bus 14. An input / output (I / O) interface 15 is also connected to the bus 14.

[0123] Multiple components in electronic device 10 are connected to I / O interface 15, including: input unit 16, such as keyboard, mouse, etc.; output unit 17, such as various types of displays, speakers, etc.; storage unit 18, such as disk, optical disk, etc.; and communication unit 19, such as network card, modem, wireless transceiver, etc. Communication unit 19 allows electronic device 10 to exchange information / data with other devices through computer networks such as the Internet and / or various telecommunications networks.

[0124] Processor 11 can be a variety of general-purpose and / or special-purpose processing components with processing and computing capabilities. Some examples of processor 11 include, but are not limited to, a central processing unit (CPU), a graphics processing unit (GPU), various special-purpose artificial intelligence (AI) computing chips, various processors running machine learning model algorithms, a digital signal processor (DSP), and any suitable processor, controller, microcontroller, etc. Processor 11 performs the various methods and processes described above, such as methods for determining stratigraphic horizons.

[0125] In some embodiments, the stratigraphic determination method may be implemented as a computer program tangibly contained in a computer-readable storage medium, such as storage unit 18. In some embodiments, part or all of the computer program may be loaded and / or mounted on electronic device 10 via ROM 12 and / or communication unit 19. When the computer program is loaded into RAM 13 and executed by processor 11, one or more steps of the stratigraphic determination method described above may be performed. Alternatively, in other embodiments, processor 11 may be configured to perform the stratigraphic determination method by any other suitable means (e.g., by means of firmware).

[0126] Various embodiments of the systems and techniques described above herein can be implemented in digital electronic circuit systems, integrated circuit systems, field-programmable gate arrays (FPGAs), application-specific integrated circuits (ASICs), application-specific standard products (ASSPs), systems-on-a-chip (SoCs), complex programmable logic devices (CPLDs), computer hardware, firmware, software, and / or combinations thereof. These various embodiments may include implementations in one or more computer programs that can be executed and / or interpreted on a programmable system including at least one programmable processor, which may be a dedicated or general-purpose programmable processor, capable of receiving data and instructions from a storage system, at least one input device, and at least one output device, and transmitting data and instructions to the storage system, the at least one input device, and the at least one output device.

[0127] Computer programs for implementing the methods of the present application can be written in any combination of one or more programming languages. These computer programs can be provided to a processor of a general purpose computer, special purpose computer, or other programmable data processing apparatus, such that the computer program, when executed, can cause instructions defined in the flow charts and / or block diagrams to be implemented. The computer program can be executed entirely on a machine, partially on a machine, partially on a machine as a stand-alone software package and partially on a remote machine or entirely on a remote machine or server.

[0128] In the context of the present application, a computer-readable storage medium can be a tangible medium that can contain or store a computer program for use by or in connection with an instruction execution system, apparatus, or device. A computer-readable storage medium can include, but is not limited to, an electronic, magnetic, optical, electromagnetic, infrared, or semiconductor system, apparatus, or device, or any suitable combination of the foregoing. Alternatively, a computer-readable storage medium can be a machine-readable signal medium. More specific examples of a machine-readable storage medium will include one or more lines of a program of instructions in a transitory signal, a portable computer diskette, a hard disk, a random access memory (RAM), a read-only memory (ROM), an erasable programmable read-only memory (EPROM or Flash memory), an optical fiber, a portable compact disc read-only memory (CD-ROM), an optical storage device, a magnetic storage device, or any suitable combination of the foregoing.

[0129] To provide for interaction with a user, the systems and techniques described here can be implemented on an electronic device having a display device (e.g., a CRT (cathode ray tube) or LCD (liquid crystal display) monitor) for displaying information to the user and a keyboard and a pointing device (e.g., a mouse or a trackball) by which the user can provide input to the electronic device. Other kinds of devices can be used to provide for interaction with a user as well; for example, feedback provided to the user can be any form of sensory feedback (e.g., visual feedback, auditory feedback, or tactile feedback); and input from the user can be received in any form, including acoustic, speech, or tactile input.

[0130] The systems and techniques described herein can be implemented in a computing system that includes a back end component, e.g., as a data server, or that includes a middleware component, e.g., an application server, or that includes a front end component, e.g., a user computer having a graphical user interface or a Web browser through which a user can interact with an implementation of the systems and techniques described herein, or any combination of such back end, middleware, or front end components. The components of the system can be interconnected by any form or medium of digital data communication, e.g., a communication network. Examples of communication networks include a local area network (LAN), a wide area network (WAN), a blockchain network, and the Internet.

[0131] The computing system can include clients and servers. A client and server are generally remote from each other and typically interact through a communication network. The relationship of client and server arises by virtue of computer programs running on the respective computers and having a client-server relationship to each other. A server can be a cloud server, also known as a cloud computing server or cloud host, which is a host product in the cloud computing service system, to solve the defects of large management difficulty and weak business scalability in traditional physical host and VPS service.

[0132] It should be understood that the various forms of flow shown above can be re-ordered, added to, or deleted from without departing from the scope of the present disclosure. For example, the steps recited in the present disclosure can be executed in parallel, executed in sequence, or executed in a different order, as long as the desired results of the technical solutions of the present disclosure are achieved, and the present disclosure is not limited herein.

[0133] The specific implementation described above does not constitute a limitation on the scope of protection of the present application. Those skilled in the art should understand that various modifications, combinations, sub-combinations, and substitutions can be made according to design requirements and other factors. Any modifications, equivalent substitutions, and improvements made within the spirit and principles of the present application shall be included in the scope of protection of the present application.

Claims

1. A method for determining stratigraphic positions, characterized in that, include: Based on the bidirectional fused seismic data of the target area, the first stratigraphic position information of the target area is determined; Based on the seismic illumination analysis results of the target area from two directions, the sub-areas that do not meet the seismic illumination requirements are identified as areas to be adjusted, and the direction with higher seismic illumination at the same location in the area to be adjusted is identified as the target direction. The two orientations refer to the two orientations of the seismic waves as they travel from the earthquake source to the detector. Based on the seismic data of the target azimuth, determine the second stratigraphic position information of the area to be adjusted; Based on the first stratigraphic information and the second stratigraphic information, the final stratigraphic information of the target area is determined.

2. The method according to claim 1, characterized in that, Based on the seismic illumination analysis results of the target area from two azimuths, sub-areas that do not meet the seismic illumination requirements are identified as areas to be adjusted. Furthermore, the azimuth with higher seismic illumination at the same location within the area to be adjusted is identified as the target azimuth, including: The relative deviation of the seismic amplitude values ​​is determined based on the seismic amplitude values ​​of the region to be analyzed obtained along the two directions. In the region to be analyzed, the sub-region to be analyzed in which the absolute value of the relative deviation is greater than or equal to a preset threshold is identified as the region to be adjusted. In addition, the direction with the larger seismic amplitude value among the two directions passing through the same location in the region to be adjusted is identified as the target direction.

3. The method according to claim 2, characterized in that, The two directions include the first direction and the second direction; Based on the seismic amplitude values ​​of the area to be analyzed obtained along two directions, the relative deviation of the seismic amplitude values ​​is determined, including: The difference between the earthquake amplitude value at the first azimuth and the earthquake amplitude value at the second azimuth is determined as the first parameter; The sum of the earthquake amplitude values ​​at the first azimuth and the earthquake amplitude values ​​at the second azimuth is determined as the second parameter; The relative deviation is determined based on the ratio of the first parameter to the second parameter.

4. The method according to claim 1, characterized in that, Based on the first stratigraphic information and the second stratigraphic information, the final stratigraphic information of the target area is determined, including: Replace the first stratigraphic position information corresponding to the area to be adjusted in the first stratigraphic position information with the second stratigraphic position information to obtain the final stratigraphic position information of the target area.

5. The method according to claim 1, characterized in that, Before determining the first stratigraphic position information of the target area based on the bidirectional fused seismic data of the target area, the method further includes: For two azimuths, based on the results of tomographic velocity inversion of the common reflection point gathers in each azimuth, the fused tomographic velocity of both azimuths and the velocity-corrected seismic data of each azimuth are determined; the fused tomographic velocity of both azimuths is the velocity corresponding to the condition that the in-phase axis flattening effect of the common reflection point gathers in each azimuth meets the preset requirements; the velocity-corrected seismic data of each azimuth is the seismic data after dynamic stretching of the common reflection point gathers in each azimuth based on the fused tomographic velocity of both azimuths. Based on the bi-situ fusion chromatography velocities of the non-salt bodies and the salt bodies in the target region, a bi-situ fusion velocity model for the target region is determined. Based on the aforementioned bidirectional fusion velocity model, the velocity-corrected seismic data in each direction are subjected to migration imaging processing to obtain the migrated seismic data in each direction. Based on the offset seismic data from each direction, determine the fused seismic data from both directions.

6. The method according to claim 5, characterized in that, The two directions include the first direction and the second direction; Based on the offset seismic data from each direction, determine the bidirectional fused seismic data, including: Determine the correlation coefficient between the amplitudes at different offsets of each longitudinal sampling point in each direction; The bidirectional fused seismic data are determined using the following formula: Among them, S DAZ For bidirectional fusion of seismic data; C AZ1 C is the correlation coefficient corresponding to the first orientation; AZ2 S is the correlation coefficient corresponding to the second orientation; AZ1 This is the seismic data for the first azimuth after offset; S AZ2 This is the seismic data from the second orientation after offset.

7. The method according to claim 1, characterized in that, After determining the first stratigraphic position information of the target area based on the bidirectional fused seismic data of the target area, the method further includes: Based on the correspondence between stratigraphic positions and velocities, velocity values ​​are assigned to each stratigraphic position to obtain a stratigraphic model; the correspondence between stratigraphic positions and velocities is determined based on drilling data and bidirectional fused seismic velocities. Accordingly, the seismic illumination analysis results of the area to be analyzed in the target region from two directions include: Seismic illumination analysis was performed on the area to be analyzed corresponding to the stratigraphic model from two directions to determine the results of the seismic illumination analysis.

8. A device for determining stratigraphic positions, characterized in that, include: The first stratigraphic position information determination module is used to determine the first stratigraphic position information of the target area based on the two-way fused seismic data of the target area. The module for determining the area to be adjusted and the target azimuth is used to determine, based on the seismic illumination analysis results of the area to be analyzed in the target area from two azimuths, the sub-area to be analyzed that does not meet the seismic illumination requirements as the area to be adjusted, and to determine, among the two azimuths passing through the same location of the area to be adjusted, the azimuth with higher seismic illumination as the target azimuth. The two orientations refer to the two orientations of the seismic waves as they travel from the earthquake source to the detector. The second stratigraphic position information determination module is used to determine the second stratigraphic position information of the area to be adjusted based on the seismic data of the target orientation. The final stratigraphic information determination module is used to determine the final stratigraphic information of the target area based on the first stratigraphic information and the second stratigraphic information.

9. An electronic device, characterized in that, The electronic device includes: At least one processor; and A memory communicatively connected to the at least one processor; wherein, The memory stores a computer program executable by the at least one processor, which, when executed by the at least one processor, enables the at least one processor to perform the method for determining stratigraphic positions according to any one of claims 1-7.

10. A computer-readable storage medium, characterized in that, The computer-readable storage medium stores computer instructions that, when executed by a processor, implement the method for determining stratigraphic positions as described in any one of claims 1-7.

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