4 results about "Apparent velocity" patented technology

This invention relates to a method and apparatus for designing seismic data acquisition trace spacing. The method includes: determining different first apparent velocities of effective waves and different second apparent velocities of interfering waves based on raw single-shot data; determining a first frequency corresponding to a first preset minimum energy value for each effective wave and a second frequency corresponding to a second preset minimum energy value for each interfering wave; determining a first candidate maximum wavenumber for each effective wave that does not produce spatial aliasing based on the first frequency and the first apparent velocity, and determining a second candidate maximum wavenumber for each interfering wave that does not produce spatial aliasing based on the second frequency and the second apparent velocity; determining a target maximum wavenumber from the first and second candidate maximum wavenumbers, and then determining the seismic data acquisition trace spacing for the target work area; and designing a trace spacing that can balance exploration costs and technical requirements using old single-shot data, saving costs and fully utilizing the value of old data.

The invention discloses a surface wave apparent velocity analysis method and device based on deep learning, equipment and a storage medium, and the method comprises the steps: extracting part of seismic data as a data set, and taking the seismic data which is not extracted as to-be-processed data; analyzing the data set to obtain a corresponding apparent velocity label; the data set and the corresponding apparent velocity label are converted to a t-v domain through RT transformation; the converted data set is preprocessed; according to a preprocessing result, extracting a part of the data set as a training set, and taking the remaining data set as a verification set; constructing a deep neural network, and training a U-net model; converting the to-be-processed data to a t-v domain through RT conversion; using the U-net model to predict the data to be processed; a prediction result is converted to a t-x domain through inverse RT transformation; converting the t-x domain prediction result into apparent velocity information; and performing surface wave suppression on the surface wave apparent velocity result. The method is well suitable for surface wave analysis work of seismic data of different terrains, the manual workload is reduced, and the analysis efficiency and the analysis result accuracy are improved.

This invention belongs to the field of seismic data processing technology for petroleum exploration, specifically relating to a pre-stack time migration denoising method and apparatus. The denoising method includes the following steps: (1) processing seismic data to obtain a pre-stack time migration profile, and selecting a stable wave impedance interface for the work area on the pre-stack time migration profile; (2) performing geological correction on the pre-stack time migration profile based on the stable wave impedance interface for the work area to obtain a geologically corrected profile; (3) performing F-K filtering on the geologically corrected profile to obtain an F-K filtered profile; (4) performing wave impedance interface inverse correction on the F-K filtered profile to obtain the final profile. The pre-stack time migration denoising method of this invention adopts the concept of "geological correction," combined with F-K filtering to effectively suppress migration noise. It features a simple and easy-to-draw time window, a small apparent velocity range that is easy to control, and improved operational efficiency. The denoised profile exhibits good amplitude preservation, greatly improving profile quality.

This application discloses a method, apparatus, and computer equipment for detecting anomalous first arrival times, belonging to the field of oil and gas exploration technology. The method includes: acquiring seismic data from seismic traces, the seismic data including multiple first arrival times; preprocessing the first arrival times to obtain second arrival times; acquiring global features corresponding to the seismic data, determining a first anomalous first arrival time and reference seismic data based on the global features within the second arrival time, the global features including apparent velocity; dividing the reference seismic data into data segments, determining the local features corresponding to the data segments, and determining a second anomalous first arrival time within the second arrival time based on the local features. This method, by preprocessing the first arrival times to obtain the second arrival time, can improve the accuracy of the determined arrival time; and by determining the first and second anomalous first arrival times within the second arrival time, it can improve the accuracy and reliability of the determined anomalous first arrival times.