A method, device, medium and equipment for determining rolling chromatography speed

Abstract

Embodiments of the present application disclose a method and device for determining rolling chromatography speed, a medium and equipment. The method comprises: determining a first standard average speed of a reservoir top surface and each layer inside the reservoir at a well point and an initial average speed along layers of the reservoir top surface according to obtained logging data information and a seismic stacking velocity spectrum; correcting the initial average speed along layers of the reservoir top surface according to the first standard average speed of the reservoir top surface at the well point to determine a second standard average speed of the reservoir top surface; and taking the second standard average speed of the reservoir top surface as an initial average speed along layers of an underlying layer, correcting the initial average speed along layers of the underlying layer according to the first standard average speed of the underlying layer at the well point to determine a second standard average speed of the underlying layer, and similarly determining second standard average speeds of each layer. The accuracy of the average speed along layers of the reservoir interior is improved by establishing a rolling chromatography speed model.

Description

Technical Field

[0001] This application relates to the field of petroleum geological exploration technology, and in particular to a method, apparatus, medium and equipment for determining rolling tomography velocity. Background Technology

[0002] Exploration geology is based on the elastic differences between different rocks and ores in the Earth's crust. It explores geological structures and mineral resources by observing and studying the propagation characteristics of seismic waves underground. The velocity field of the subsurface medium is fundamental to the study of subsurface geological structures. With the continuous deepening of research into petroleum geological exploration technologies, the requirements for the accuracy of the subsurface medium velocity field are becoming increasingly stringent. In many hot exploration areas, especially those with complex structures and abrupt changes in seismic velocity due to faults or salt intrusions, the use of time-domain processing methods may produce results that are easily misinterpreted. In some cases, processing time-domain images may create or refute a distant target, causing the seismic structure to expand or shrink the trap area, or causing the target to deviate significantly from its actual distance, thus affecting the accuracy of the oilfield evaluation.

[0003] Currently, several methods are used to study the conversion of subsurface medium velocity fields from the time domain to the depth domain: the Dix formula method, the migration relocation method, the stratigraphic control velocity method, the model tomography velocity method, the well time-depth curve velocity method, and interpolation methods. However, these methods are only applicable to the geological exploration stage and cannot meet the requirements for establishing high-precision velocity models in the oilfield development stage.

[0004] Therefore, how to establish a high-precision tomography velocity model is a technical problem that urgently needs to be solved by those skilled in the art. Summary of the Invention

[0005] This application provides a method, apparatus, medium, and equipment for determining rolling tomography velocities. By establishing a rolling tomography velocity model, the accuracy of the velocity along the layers within the reservoir is improved, effectively guiding oilfield development.

[0006] In a first aspect, embodiments of this application provide a method for determining the rolling chromatography velocity, the method comprising:

[0007] Acquire well logging data and seismic stacking velocity spectrum of the target oilfield;

[0008] Based on the logging data, determine the first standard average velocity at the well point for the top surface and internal layers of the reservoir.

[0009] Based on the earthquake superimposed velocity spectrum, the earthquake mean velocity field of the target oilfield is determined, and the initial mean velocity along the reservoir top surface is extracted from the earthquake mean velocity field.

[0010] Based on the first standard average velocity of the reservoir top surface at the well point, the initial average velocity along the layer of the reservoir top surface is corrected to determine the second standard average velocity of the reservoir top surface; and the second standard average velocity of the reservoir top surface is used as the initial average velocity along the layer of the underlying layer. Based on the first standard average velocity of the underlying layer at the well point, the initial average velocity along the layer of the underlying layer is corrected to determine the second standard average velocity of the underlying layer, and so on, to determine the second standard average velocity of each internal layer.

[0011] Secondly, embodiments of this application provide an apparatus for determining the rolling chromatography velocity, the apparatus comprising:

[0012] The basic parameter acquisition module is used to acquire well logging data and seismic stacking velocity spectrum of the target oilfield;

[0013] The first standard average velocity determination module is used to determine the first standard average velocity at the well point on the top surface of the reservoir and each internal layer based on the well logging data.

[0014] The layer-based initial average velocity determination module is used to determine the seismic average velocity field of the target oilfield based on the seismic superimposed velocity spectrum, and to extract the layer-based initial average velocity of the reservoir top surface from the seismic average velocity field.

[0015] The second standard average velocity determination module is used to correct the initial average velocity along the layer of the reservoir top surface based on the first standard average velocity at the well point, and determine the second standard average velocity of the reservoir top surface; and to use the second standard average velocity of the reservoir top surface as the initial average velocity along the layer of the underlying layer, and correct the initial average velocity along the layer of the underlying layer based on the first standard average velocity at the well point, and determine the second standard average velocity of the underlying layer, and so on, to determine the second standard average velocity of each internal layer.

[0016] Thirdly, embodiments of this application provide a computer-readable storage medium having a computer program stored thereon, which, when executed by a processor, implements the method for determining the rolling tomography speed as described in embodiments of this application.

[0017] Fourthly, embodiments of this application provide an electronic device, including a memory, a processor, and a computer program stored in the memory and executable on the processor. When the processor executes the computer program, it implements the method for determining the rolling tomography speed as described in embodiments of this application.

[0018] The technical solution provided in this application involves acquiring well logging data and seismic stacked velocity spectra of a target oilfield; determining the first standard average velocity at the well point for the top surface of the reservoir and each internal layer based on the well logging data; determining the seismic average velocity field of the target oilfield based on the seismic stacked velocity spectrum, and extracting the initial average velocity along the layers of the reservoir top surface from the seismic average velocity field; correcting the initial average velocity along the layers of the reservoir top surface based on the first standard average velocity at the well point to determine the second standard average velocity of the reservoir top surface; using the second standard average velocity of the reservoir top surface as the initial average velocity along the layers of the underlying layer, correcting the initial average velocity along the layers of the underlying layer based on the first standard average velocity at the well point to determine the second standard average velocity of the underlying layer, and so on, to determine the second standard average velocity of each internal layer. By establishing a rolling tomographic velocity model, the accuracy of the velocities along the layers within the reservoir is improved, effectively guiding the development of the oilfield. Attached Figure Description

[0019] Figure 1 This is a flowchart of a method for determining the rolling chromatography velocity provided in Embodiment 1 of this application;

[0020] Figure 2 This is a flowchart of another method for determining the rolling chromatography velocity provided in Embodiment 2 of the present invention;

[0021] Figure 3 This is a structural block diagram of a device for determining the rolling chromatography velocity provided in Embodiment 3 of the present invention;

[0022] Figure 4 This is a schematic diagram of the structure of an electronic device provided in Embodiment 5 of this application. Detailed Implementation

[0023] The present application will now be described in further detail with reference to the accompanying drawings and embodiments. It should be understood that the specific embodiments described herein are merely illustrative of the application and not intended to limit it. Furthermore, it should be noted that, for ease of description, the accompanying drawings show only the parts relevant to the present application, not the entire structure.

[0024] Before discussing the exemplary embodiments in more detail, it should be noted that some exemplary embodiments are described as processes or methods depicted as flowcharts. Although the flowcharts describe the steps as sequential processes, many of these steps can be performed in parallel, concurrently, or simultaneously. Furthermore, the order of the steps can be rearranged. The process can be terminated when its operation is complete, but may also have additional steps not included in the figures. The process can correspond to a method, function, procedure, subroutine, subroutine, etc.

[0025] Example 1

[0026] Figure 1 This is a flowchart of a method for determining the rolling tomography velocity provided in Embodiment 1 of this application. This embodiment can be applied to scenarios where the velocities of each layer in the reservoir are determined. This method can be executed by the rolling tomography velocity determination device provided in this embodiment. The device can be implemented by software and / or hardware and can be integrated into an electronic device.

[0027] like Figure 1 As shown, the method for determining the rolling chromatography velocity includes:

[0028] S110: Obtain well logging data and seismic stacking velocity spectrum of the target oilfield.

[0029] The target oilfield is the area for which tomatometric velocity determination is to be performed, and it contains one or more oil reservoirs. Well logging data is the physical parameters obtained after drilling into the target oilfield, utilizing the electrochemical, electrical, acoustic, and radioactive geophysical properties of the rock formations. Examples include resistivity, spontaneous potential, acoustic velocity, and rock bulk density. The seismic stacking velocity spectrum is the best-fit hyperbola of the velocity spectrum data. Specifically, for a given phase axis on a set of common reflection point gathers, the hyperbolic formula is used to calculate the dynamic correction for each trace using a series of different velocities. The stacking velocity is the one that corrects the phase axis to a horizontal straight line.

[0030] In this embodiment of the invention, optionally, the logging data information of the target oilfield includes at least one of acoustic information, density information, spontaneous potential information, and logging curves. Different logging curves can be formed using acoustic information, density information, or spontaneous potential information.

[0031] Furthermore, well logging data can be acquired through electrical logging, acoustic logging, or radioactive logging, among other methods. Seismic stacking velocity spectra can be obtained by interpreting and analyzing seismic data to obtain curves showing the relationship between seismic wave amplitude energy and wave velocity.

[0032] S120. Based on the logging data, determine the first standard average velocity at the well point for the top surface of the reservoir and each internal layer.

[0033] It should be noted that, based on the physical properties of the strata rocks, the underground medium of the oil reservoir is divided into several internal sub-layers, and it is assumed that the underground medium of the oil reservoir is composed of several parallel internal sub-layers. In this case, each internal sub-layer is regarded as a horizontal homogeneous medium.

[0034] The first standard average velocity is the average velocity of each layer obtained from well logging data. For example, it can be determined by measuring the total thickness and total propagation time of a seismic wave as it vertically passes through a set of horizontally homogeneous media, or it can be determined using wave impedance inversion methods. It is understood that the media at the top of the reservoir and in each internal layer are relatively continuous and stable laterally.

[0035] In an embodiment of the present invention, optionally, determining the first standard average velocity at the well point for the top surface of the reservoir and each internal layer based on the well logging data information includes: performing fine calibration on the synthetic seismic record of the target oilfield based on the well logging data information to determine the calibration result; and determining the first standard average velocity at the well point for the top surface of the reservoir and each internal layer based on the calibration result.

[0036] It should be noted that fine calibration of synthetic seismic records is based on the principle of seismic wave reflection, using well logging data such as acoustic waves and density to synthesize seismic records for calibration. The synthetic seismic record is a seismic record (i.e., a seismic trace) artificially synthesized from well logging data. Fine calibration involves multiple time-depth adjustments to ensure the accuracy of the calibration results. For example, fine calibration of synthetic seismic records can be performed using the following methods: conducting a dominant frequency survey of the seismic data to ensure consistency between the dominant frequency of the synthetic seismic record and the dominant frequency of the well logging data; continuously correcting the matching relationship between the synthetic seismic record and the well-side seismic trace to ensure optimal wavegroup matching; adjusting the synthetic seismic record to change its cross-correlation coefficient; calibrating the synthetic seismic record by extracting seismic wavelets from the well-side seismic trace; stretching and compressing the well logging curves within an appropriate range; performing stratigraphic calibration by analyzing the seismic amplitude variations caused by different lithologies or fluids in the wavelet contribution; and comparing and adjusting multiple wells with geological stratigraphic correlations to complete the fine calibration of the synthetic seismic record. The calibration results can identify earthquake artifacts by comparing synthetic seismic records and original profiles, and can also be used for forward modeling of lithological structures and velocity field modeling.

[0037] In this embodiment of the invention, the first standard average velocity at the well point is determined based on the calibration results for the top surface of the reservoir and each internal layer. For example, the first standard average velocity can be calculated using the response characteristics and sonic transit time logging curves in the calibration results. This technical solution, through fine calibration of the synthetic seismic record of the target oilfield, can provide reliable basic data for accurately describing the geological structure and making lateral predictions along the layers.

[0038] S130. Based on the earthquake superimposed velocity spectrum, determine the earthquake mean velocity field of the target oilfield, and extract the initial mean velocity along the reservoir top surface from the earthquake mean velocity field.

[0039] The seismic mean velocity field is a volume of time-domain imaging data obtained using pre-stack time migration. The initial mean velocity along the layer is the propagation speed of seismic waves in the layered medium at the top of the reservoir, i.e., the layer velocity at the top of the reservoir, which can directly reflect the lithology of the strata.

[0040] In this embodiment of the invention, the seismic mean velocity field of the target oilfield is determined based on the seismic stacked velocity spectrum. The DIX formula can be used to calculate the seismic mean velocity field from the seismic stacked velocity spectrum. Alternatively, well interpolation, deterministic inversion impedance transformation, or statistical inversion impedance can also be used to determine the seismic mean velocity field of the target oilfield. It should be noted that the data points in the seismic stacked velocity spectrum can represent the velocity characteristics of the subsurface medium in the target oilfield reservoir; therefore, the variation law of the seismic mean velocity in this area can be studied through the seismic stacked velocity spectrum.

[0041] S140. Based on the first standard average velocity of the reservoir top surface at the well point, the initial average velocity along the layer of the reservoir top surface is corrected to determine the second standard average velocity of the reservoir top surface; and the second standard average velocity of the reservoir top surface is used as the initial average velocity along the layer of the underlying layer. Based on the first standard average velocity of the underlying layer at the well point, the initial average velocity along the layer of the underlying layer is corrected to determine the second standard average velocity of the underlying layer, and so on, to determine the second standard average velocity of each internal layer.

[0042] Understandably, the first standard average velocity is determined under the assumption that the layered media within each sub-layer of the reservoir are ideally homogeneous. The initial average velocity along the layers, however, considers the deflection effect of seismic rays within the layered media. Therefore, based on the first standard average velocity at the well point, the initial average velocity along the layers at the reservoir top surface is corrected to determine the second standard average velocity. This correction can be achieved using the correction amount determined by the first standard average velocity and the initial average velocity along the layers. This approach improves the accuracy of the second standard average velocity, thereby enhancing the accuracy of the rolling tomography velocity model.

[0043] In this embodiment of the invention, the first standard average velocity at the well point of each layer within the reservoir is iteratively corrected based on the second standard average velocity at the top surface of the reservoir to determine the second standard average velocity of each layer within the reservoir. The second standard average velocity at the top surface of the reservoir can be used as the initial average velocity along the layer of the underlying layer. Based on the first standard average velocity of the underlying layer at the well point, the initial average velocity along the layer of the underlying layer is corrected to determine the second standard average velocity of the underlying layer, and so on, to determine the second standard average velocity of each layer within the reservoir.

[0044] This invention provides a method for determining rolling tomography velocities. The method involves acquiring well logging data and seismic stacking velocity spectra of a target oilfield; determining the first standard average velocity at the well point for the reservoir top surface and each internal layer based on the well logging data; determining the seismic average velocity field of the target oilfield based on the seismic stacking velocity spectrum, and extracting the initial average velocity along the reservoir top surface from the seismic average velocity field; correcting the initial average velocity along the reservoir top surface based on the first standard average velocity at the well point to determine the second standard average velocity along the reservoir top surface; using the second standard average velocity of the reservoir top surface as the initial average velocity along the overlying layer; correcting the initial average velocity along the overlying layer based on the first standard average velocity at the well point to determine the second standard average velocity of the overlying layer; and so on, to determine the second standard average velocity of each internal layer. By establishing a rolling tomography velocity model, the accuracy of reservoir internal layer velocities is improved, effectively guiding oilfield development.

[0045] Example 2

[0046] Figure 2 This is a flowchart of another method for determining the rolling chromatography velocity provided in Embodiment 2 of the present invention. Based on the above embodiments, the present invention provides a preferred embodiment. Figure 2 As shown, the method includes:

[0047] S210: Obtain well logging data and seismic stacking velocity spectrum of the target oilfield.

[0048] S220. Based on the logging data of the target oilfield, identify the abnormal data information in the logging data.

[0049] Understandably, changes in wellbore diameter, such as in mudstone sections, can cause local distortions in well logging data, leading to inaccuracies in the fine calibration results of seismic synthetic records. Therefore, quality control and optimization of well logging data are necessary. Anomalies typically manifest as changes in acoustic waves and density, which can be visually observed through the corresponding characteristics of the well logging curves.

[0050] In an embodiment of the present invention, optionally, determining abnormal data information in the logging data information based on the logging data information of the target oilfield includes: comparing the characteristics of the logging data information of the target oilfield with the characteristics of pre-determined normal logging data information to determine the abnormal data information in the logging data information.

[0051] The characteristics of pre-determined normal logging data can be relevant data from developed oilfields, formation characteristics, or interpretation experience. For example, by comparing the relevant characteristics of logging data from the target oilfield with those from developed oilfields, abnormal changes such as local fluctuations in the logging curve of the target oilfield can be identified as abnormal data.

[0052] S230. Based on the abnormal data information, the logging data information of the target oilfield is corrected and updated to determine the target logging data information.

[0053] In this process, the logging data of the target oilfield is corrected and updated. For example, the logging curves in the logging data of the target oilfield can be smoothed and corrected through processing methods such as depth correction or multi-distance curve regression.

[0054] S240. Based on the well logging data, perform fine calibration on the synthetic seismic record of the target oilfield and determine the calibration result.

[0055] S250. Based on the calibration results, determine the first standard average velocity at the well point for the top surface of the reservoir and each internal layer.

[0056] S260. Based on the calibration results, perform stratigraphic analysis on the target oilfield to obtain stratigraphic analysis results; and based on the stratigraphic analysis results, perform stratigraphic interpretation and tracing on the reservoir top surface and internal layers of the target oilfield to determine the temporal structure of the reservoir top surface and internal layers of the target oilfield.

[0057] Among these, stratigraphic analysis involves studying and analyzing the seismic interpretation scheme for the target oilfield based on the fine calibration results of the synthetic seismic record and the seismic interpretation schemes of adjacent areas. Stratification is a crucial step in interpreting the geological data of the target oilfield, providing fundamental data for subsequent accurate seismic data interpretation. This can be done manually, semi-automatically, or automatically. Temporal tectonics is the statistical analysis of data from the reservoir's top surface and internal layers over a temporal framework.

[0058] In this embodiment of the invention, stratigraphic interpretation and tracing are performed on the top surface of the target oilfield and its internal layers to determine the time-domain structure of the top surface of the target oilfield and its internal layers. For example, technicians can manually trace stratigraphic lines at similar and continuous time sampling points of waveforms based on the dynamic and kinematic response characteristics of seismic waves in the same direction, through analysis of phase axis amplitude, phase, and continuity of the same phase axis. Then, the stratigraphic lines are interpolated to obtain the time-domain structure of the top surface of the target oilfield and its internal layers.

[0059] The advantage of this setup is that by performing stratigraphic analysis on the target oilfield based on the finely calibrated results of the synthetic seismic record, the stratigraphic interpretation of the target oilfield reservoir can be more accurate, thereby improving the precision of the stratification of each layer within the reservoir.

[0060] It should be noted that the execution order of S260, S250, and S270-S280 is not limited in the embodiments of the present invention. S260 can be executed first, followed by S250, S270, and S280; S250, S270, and S280 can be executed first, followed by S260; or S260, S250, and S270-S280 can be executed simultaneously.

[0061] S270. Based on the earthquake superimposed velocity spectrum, determine the earthquake mean velocity field of the target oilfield, and extract the initial mean velocity along the reservoir top surface from the earthquake mean velocity field.

[0062] S280. Based on the first standard average velocity of the reservoir top surface at the well point, the initial average velocity along the layer of the reservoir top surface is corrected to determine the second standard average velocity of the reservoir top surface; and the second standard average velocity of the reservoir top surface is used as the initial average velocity along the layer of the underlying layer. Based on the first standard average velocity of the underlying layer at the well point, the initial average velocity along the layer of the underlying layer is corrected to determine the second standard average velocity of the underlying layer, and so on, to determine the second standard average velocity of each internal layer.

[0063] S290. Based on the time-domain structure of the reservoir top surface and internal layers of the target oilfield and the second standard average velocity of the reservoir top surface and internal layers, perform time-depth conversion to determine the inversion result.

[0064] Among them, time-depth conversion is to convert the geological strata constructed in the time domain and the given stratum velocity into the geological strata in the depth domain based on the principle that depth equals velocity multiplied by time, thereby realizing time-depth conversion and obtaining inversion results.

[0065] For example, let's take an oilfield as an example for explanation. At the bottom of this oilfield is a mudstone section. The well diameter in this mudstone section is enlarged, causing distortion in the well logging curves and resulting in inaccurate calibration of the seismic composite record. By referencing the characteristics of normal well logging curves, the distorted content of the mudstone section in the well logging curves is restored, improving the accuracy of the seismic composite record. After time-depth conversion, a seismic profile is obtained. The interpreted layers in the converted depth domain match the well point layering, and the seismic amplitude attributes in the converted depth domain also match the seismic amplitude attributes in the time domain. Furthermore, the structural depth of each layer within the reservoir at the well point remains consistent with the depth at the well point location. Additionally, the seismic attributes and inversion results along the well trajectory in the depth domain are consistent with the characteristics of the corresponding well logging curves. This indicates that the model has high precision and is suitable for determining the velocity during the reservoir development stage.

[0066] This invention provides a method for determining rolling tomography velocity. By adopting this technical solution, through quality monitoring of well logging data and time-depth conversion to obtain inversion results, the accuracy of seismic synthetic record calibration results can be improved, thereby increasing the accuracy of rolling tomography velocity, meeting the needs of oilfield development, and effectively guiding oilfield development.

[0067] Example 3

[0068] Figure 3 This is a structural block diagram of a rolling chromatography velocity determination device provided in Embodiment 3 of the present invention. This device can execute the rolling chromatography velocity determination method provided in any embodiment of the present invention, and possesses the corresponding functional modules and beneficial effects of the method. For example... Figure 3 As shown, the device may include:

[0069] The basic parameter acquisition module 310 is used to acquire well logging data and seismic stacking velocity spectrum of the target oilfield;

[0070] The first standard average velocity determination module 320 is used to determine the first standard average velocity at the well point on the top surface of the reservoir and each internal layer based on the well logging data.

[0071] The layer-based initial average velocity determination module 330 is used to determine the seismic average velocity field of the target oilfield based on the seismic superimposed velocity spectrum, and to extract the layer-based initial average velocity of the reservoir top surface from the seismic average velocity field.

[0072] The second standard average velocity determination module 340 is used to correct the initial average velocity along the layer of the reservoir top surface based on the first standard average velocity at the well point, and determine the second standard average velocity of the reservoir top surface; and to use the second standard average velocity of the reservoir top surface as the initial average velocity along the layer of the underlying layer, and correct the initial average velocity along the layer of the underlying layer based on the first standard average velocity at the well point, and determine the second standard average velocity of the underlying layer, and so on, to determine the second standard average velocity of each internal layer.

[0073] This invention provides a rolling tomography velocity determination device, which acquires well logging data and seismic stacking velocity spectrum of a target oilfield; determines the first standard average velocity at the well point for the reservoir top surface and each internal layer; determines the seismic average velocity field of the target oilfield based on the seismic stacking velocity spectrum, and extracts the initial average velocity along the reservoir top surface from the seismic average velocity field; corrects the initial average velocity along the reservoir top surface based on the first standard average velocity at the well point to determine the second standard average velocity along the reservoir top surface; and uses the second standard average velocity of the reservoir top surface as the initial average velocity along the overlying layer, corrects the initial average velocity along the overlying layer based on the first standard average velocity at the well point to determine the second standard average velocity of the overlying layer, and so on, to determine the second standard average velocity of each internal layer. By establishing a rolling tomography velocity model, the accuracy of reservoir internal layer velocities is improved, effectively guiding oilfield development.

[0074] Furthermore, the logging data information of the target oil field includes at least one of the following: acoustic information, density information, spontaneous potential information, and logging curves.

[0075] Furthermore, the method also includes:

[0076] An abnormal data information determination module is used to determine abnormal data information in the logging data information after obtaining the logging data information of the target oilfield.

[0077] The target logging data information determination module is used to correct and update the logging data information of the target oilfield based on the abnormal data information, and determine the target logging data information.

[0078] Furthermore, the abnormal data information determination module includes:

[0079] An abnormal data information determination unit is used to compare the characteristics of the logging data information of the target oilfield with the characteristics of the pre-determined normal logging data information to determine the abnormal data information in the logging data information.

[0080] Furthermore, the first standard average speed determination module 320 includes:

[0081] The calibration result determination unit is used to perform fine calibration on the synthetic seismic record of the target oilfield based on the well logging data information, and determine the calibration result;

[0082] The first standard average velocity determination unit is used to determine the first standard average velocity at the well point of the reservoir top surface and each internal layer based on the calibration results.

[0083] Furthermore, the method also includes:

[0084] The time-domain structure determination module is used to determine the first standard average velocity of the reservoir top surface and internal layers at the well point based on the well logging data, and then perform stratigraphic analysis on the target oilfield based on the calibration results to obtain stratigraphic analysis results; and perform stratigraphic interpretation and tracing on the reservoir top surface and internal layers of the target oilfield based on the stratigraphic analysis results to determine the time-domain structure of the reservoir top surface and internal layers of the target oilfield.

[0085] Furthermore, the method also includes:

[0086] The inversion result determination module is used to perform time-depth conversion based on the time-domain structure of the reservoir top surface and internal layers of the target oilfield and the second standard average velocity of the reservoir top surface and internal layers to determine the inversion result.

[0087] The above-mentioned product can perform the method for determining the rolling chromatography speed provided in the embodiments of this application, and has the corresponding functional modules and beneficial effects of the method.

[0088] Example 4

[0089] Embodiment 4 of the present invention provides a computer-readable storage medium having a computer program stored thereon. When executed by a processor, the program implements the method for determining the rolling tomography speed as provided in all embodiments of the present application.

[0090] Acquire well logging data and seismic stacking velocity spectrum of the target oilfield;

[0091] Based on the logging data, determine the first standard average velocity at the well point for the top surface and internal layers of the reservoir.

[0092] Based on the earthquake superimposed velocity spectrum, the earthquake mean velocity field of the target oilfield is determined, and the initial mean velocity along the reservoir top surface is extracted from the earthquake mean velocity field.

[0093] Based on the first standard average velocity of the reservoir top surface at the well point, the initial average velocity along the layer of the reservoir top surface is corrected to determine the second standard average velocity of the reservoir top surface; and the second standard average velocity of the reservoir top surface is used as the initial average velocity along the layer of the underlying layer. Based on the first standard average velocity of the underlying layer at the well point, the initial average velocity along the layer of the underlying layer is corrected to determine the second standard average velocity of the underlying layer, and so on, to determine the second standard average velocity of each internal layer.

[0094] Any combination of one or more computer-readable media may be used. Computer-readable media may be computer-readable signal media such as magnetic disks, hard disks, random access memory (RAM), read-only memory (ROM), erasable programmable read-only memory (EPROM or flash memory), optical fibers, portable compact disk read-only, or computer-readable storage media. Computer-readable storage media may be, for example—but not limited to—electrical, magnetic, optical, electromagnetic, infrared, or semiconductor systems, apparatuses, or devices, or any combination thereof. More specific examples (a non-exhaustive list) of computer-readable storage media include: electrical connections having one or more wires, portable computer memory (CD-ROM), optical storage devices, magnetic storage devices, or any suitable combination thereof. In this document, computer-readable storage media may be any tangible medium that contains or stores a program that can be used by or in conjunction with an instruction execution system, apparatus, or device.

[0095] Computer-readable signal media may include data signals propagated in baseband or as part of a carrier wave, carrying computer-readable program code. Such propagated data signals may take various forms, including—but not limited to—electromagnetic signals, optical signals, or any suitable combination thereof. Computer-readable signal media may also be any computer-readable medium other than computer-readable storage media, capable of transmitting, propagating, or transmitting programs for use by or in connection with an instruction execution system, apparatus, or device.

[0096] The program code contained on a computer-readable medium may be transmitted using any suitable medium, including—but not limited to—wireless, wire, optical fiber, RF, etc., or any suitable combination thereof.

[0097] Computer program code for performing the operations of this invention can be written in one or more programming languages ​​or a combination thereof, including object-oriented programming languages ​​such as Java, Smalltalk, and C++, as well as conventional procedural programming languages ​​such as "C" or similar programming languages. The program code can be executed entirely on the user's computer, partially on the user's computer, as a standalone software package, partially on the user's computer and partially on a remote computer, or entirely on a remote computer or server. In cases involving remote computers, the remote computer can be connected to the user's computer via any type of network—including a local area network (LAN) or a wide area network (WAN)—or can be connected to an external computer (e.g., via the Internet using an Internet service provider).

[0098] Example 5

[0099] Embodiment 5 of this application provides an electronic device. Figure 4 This is a schematic diagram of the structure of an electronic device provided in Embodiment 5 of this application. Figure 4 As shown, this embodiment provides an electronic device 400, which includes: one or more processors 420; and a storage device 410 for storing one or more programs. When the one or more programs are executed by the one or more processors 420, the one or more processors 420 implement the method for determining the rolling tomography speed provided in this embodiment, the method including:

[0100] Acquire well logging data and seismic stacking velocity spectrum of the target oilfield;

[0101] Based on the logging data, determine the first standard average velocity at the well point for the top surface and internal layers of the reservoir.

[0102] Based on the earthquake superimposed velocity spectrum, the earthquake mean velocity field of the target oilfield is determined, and the initial mean velocity along the reservoir top surface is extracted from the earthquake mean velocity field.

[0103] Based on the first standard average velocity of the reservoir top surface at the well point, the initial average velocity along the layer of the reservoir top surface is corrected to determine the second standard average velocity of the reservoir top surface; and the second standard average velocity of the reservoir top surface is used as the initial average velocity along the layer of the underlying layer. Based on the first standard average velocity of the underlying layer at the well point, the initial average velocity along the layer of the underlying layer is corrected to determine the second standard average velocity of the underlying layer, and so on, to determine the second standard average velocity of each internal layer.

[0104] Of course, those skilled in the art will understand that the processor 420 also implements the technical solution of the method for determining the rolling tomography speed provided in any embodiment of this application.

[0105] Figure 4 The electronic device 400 shown is merely an example and should not impose any limitations on the functionality and scope of use of the embodiments of this application.

[0106] like Figure 4 As shown, the electronic device 400 includes a processor 420, a storage device 410, an input device 430, and an output device 440; the number of processors 420 in the electronic device can be one or more. Figure 4 Taking a processor 420 as an example; the processor 420, storage device 410, input device 430, and output device 440 in the electronic device can be connected via a bus or other means. Figure 4 For example, China and Israel are connected via bus 450.

[0107] Storage device 410, as a computer-readable storage medium, can be used to store software programs, computer-executable programs, and module units, such as the program instructions corresponding to the method for determining the rolling tomography speed in the embodiments of this application.

[0108] Storage device 410 may primarily include a program storage area and a data storage area. The program storage area may store the operating system and at least one application program required for a given function; the data storage area may store data created based on terminal usage. Furthermore, storage device 410 may include high-speed random access memory and non-volatile memory, such as at least one disk storage device, flash memory, or other non-volatile solid-state storage device. In some instances, storage device 410 may further include memory remotely located relative to processor 420, which can be connected via a network. Examples of such networks include, but are not limited to, the Internet, intranets, local area networks, mobile communication networks, and combinations thereof.

[0109] Input device 430 can be used to receive input digital, character, or voice information, and to generate key signal inputs related to user settings and function control of the electronic device. Output device 440 may include electronic devices such as a display screen and a speaker.

[0110] The rolling chromatography velocity determination apparatus, medium, and device provided in the above embodiments can execute the rolling chromatography velocity determination method provided in any embodiment of this application, and have the corresponding functional modules and beneficial effects for executing the method. Technical details not described in detail in the above embodiments can be found in the rolling chromatography velocity determination method provided in any embodiment of this application.

[0111] Note that the above description is merely a preferred embodiment of the present invention and the technical principles employed. Those skilled in the art will understand that the present invention is not limited to the specific embodiments described herein, and various obvious changes, readjustments, and substitutions can be made without departing from the scope of protection of the present invention. Therefore, although the present invention has been described in detail through the above embodiments, the present invention is not limited to the above embodiments, and may include many other equivalent embodiments without departing from the concept of the present invention, the scope of which is determined by the scope of the appended claims.

Claims

1. A method for determining the rolling chromatography velocity, characterized in that, The method includes: Acquire well logging data and seismic stacking velocity spectrum of the target oilfield; Based on the well logging data, the synthetic seismic record of the target oilfield is finely calibrated to determine the calibration result; wherein, the synthetic seismic record is a seismic record artificially synthesized using the well logging data. Based on the calibration results, the first standard average velocity at the well point is determined for the top surface of the reservoir and each internal layer. Based on the earthquake superimposed velocity spectrum, the earthquake mean velocity field of the target oilfield is determined, and the initial mean velocity along the reservoir top surface is extracted from the earthquake mean velocity field. Based on the first standard average velocity of the reservoir top surface at the well point, the initial average velocity along the layer of the reservoir top surface is corrected to determine the second standard average velocity of the reservoir top surface; and the second standard average velocity of the reservoir top surface is used as the initial average velocity along the layer of the underlying layer. Based on the first standard average velocity of the underlying layer at the well point, the initial average velocity along the layer of the underlying layer is corrected to determine the second standard average velocity of the underlying layer, and so on, to determine the second standard average velocity of each internal layer.

2. The method according to claim 1, characterized in that, The well logging data of the target oilfield includes at least one of the following: acoustic information, density information, spontaneous potential information, and well logging curves.

3. The method according to claim 1, characterized in that, After acquiring the logging data information of the target oilfield, the method further includes: Based on the logging data of the target oilfield, identify abnormal data information in the logging data. Based on the abnormal data information, the logging data information of the target oilfield is corrected and updated to determine the target logging data information.

4. The method according to claim 3, characterized in that, Based on the logging data of the target oilfield, abnormal data information in the logging data is identified, including: By comparing the characteristics of the logging data information of the target oilfield with the characteristics of the pre-determined normal logging data information, abnormal data information in the logging data information is identified.

5. The method according to claim 1, characterized in that, After determining the first standard average velocity at the well point for the top surface and internal layers of the reservoir based on the logging data, the method further includes: Based on the calibration results, the target oilfield is subjected to stratigraphic analysis to obtain stratigraphic analysis results; and based on the stratigraphic analysis results, the reservoir top surface and internal layers of the target oilfield are subjected to stratigraphic interpretation and tracing to determine the temporal structure of the reservoir top surface and internal layers of the target oilfield.

6. The method according to claim 5, characterized in that, The method further includes: Based on the time-domain structure of the reservoir top surface and internal layers of the target oilfield, and the second standard average velocity of the reservoir top surface and internal layers, time-depth conversion is performed to determine the inversion results.

7. A device for determining the rolling chromatography velocity, characterized in that, The device includes: The basic parameter acquisition module is used to acquire well logging data and seismic stacking velocity spectrum of the target oilfield; The first standard average velocity determination module is used to determine the first standard average velocity at the well point on the top surface of the reservoir and each internal layer based on the well logging data. The layer-based initial average velocity determination module is used to determine the seismic average velocity field of the target oilfield based on the seismic superimposed velocity spectrum, and to extract the layer-based initial average velocity of the reservoir top surface from the seismic average velocity field. The second standard average velocity determination module is used to correct the initial average velocity along the layer of the reservoir top surface based on the first standard average velocity at the well point, and determine the second standard average velocity of the reservoir top surface; and to use the second standard average velocity of the reservoir top surface as the initial average velocity along the layer of the underlying layer, correct the initial average velocity along the layer of the underlying layer based on the first standard average velocity at the well point, determine the second standard average velocity of the underlying layer, and so on, to determine the second standard average velocity of each internal layer. The first standard average speed determination module includes: The calibration result determination unit is used to perform fine calibration on the synthetic seismic record of the target oilfield based on the well logging data information, and determine the calibration result; wherein, the synthetic seismic record is a seismic record artificially synthesized using the well logging data information; The first standard average velocity determination unit is used to determine the first standard average velocity at the well point of the reservoir top surface and each internal layer based on the calibration results.

8. A computer-readable storage medium having a computer program stored thereon, characterized in that, When executed by a processor, the program implements the method for determining the rolling tomography speed as described in any one of claims 1-6.

9. An electronic device, comprising a memory, a processor, and a computer program stored in the memory and executable on the processor, characterized in that, When the processor executes the computer program, it implements the method for determining the rolling tomography speed as described in any one of claims 1-6.

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