Seismic Data Processing Ghost Interference Reduction
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Solution Overview
Problem
Current seismic data processing techniques face challenges in accurately separating upgoing and downgoing wavefields, leading to 'ghost' interference issues that limit bandwidth and hinder deep water seismic surveys, particularly in marine environments.
Innovation Solution
The method employs a modified generalized matching pursuit technique to jointly interpolate and deghost seismic data by using multi-component seismic sensors, separating wavefield components into pressure and particle motion velocity components, and applying a two-component ghosting operator to reduce noise and enhance data accuracy.
Engineering Contradictions & Design Principles
Engineering Contradiction Analysis
1Reliability
If conventional seismic data processing techniques are used, then the processing method is simple, but ghost interference remains that limits bandwidth and hinders deep water surveys
Solution Approach 1:
The wavefield is segmented into upgoing and downgoing components through deghosting operations. The method separates the total acoustic wavefield into distinct wavefield components, applying different processing treatments to each component to eliminate ghost interference while preserving primary signals.
Solution Approach 2:
A predicted wavefield is introduced as an intermediary element in the processing workflow. The predicted wavefield serves as a reference model that is iteratively compared with and updated against the observed seismic data, facilitating the separation of ghost and primary signals through predictive deconvolution techniques.
2Measurement precision
If deghosting operations are applied to separate wavefield components, then ghost interference is reduced, but residual energy remains that limits imaging accuracy
Solution Approach 1:
The method implements an iterative feedback mechanism where the predicted wavefield is continuously updated based on the residual difference between predicted and observed data. This feedback loop refines the deghosting operation progressively, minimizing residual energy and improving imaging accuracy with each iteration.
Solution Approach 2:
Traditional mechanical filtering approaches are replaced with predictive deconvolution techniques that use wavefield modeling and iterative optimization. The method substitutes simple frequency-domain filtering with a more sophisticated time-domain predictive approach that adapts to the actual wavefield characteristics.
3Adaptability or versatility
If multi-component sensors are used to record pressure and particle motion, then wavefield separation capability is improved, but device complexity increases
Solution Approach 1:
The processing method is designed to handle multiple sensor types and configurations universally. It can process data from single-component, two-component, or three-component sensors, and can accommodate different sensor geometries and deployment configurations, making the method broadly applicable across various survey types.
Solution Approach 2:
The method exploits changes in wavefield parameters (pressure, particle motion velocity, acceleration) to separate upgoing and downgoing waves. By analyzing multiple physical parameters simultaneously, the method achieves robust wavefield separation that is insensitive to individual parameter variations or noise.
Data Source
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AI summary
Described herein are implementations of various technologies for a method for seismic data processing. The method may receive seismic data for a region of interest. The seismic data may be acquired in a seismic survey. The method may receive a summation that is based on a particle motion velocity component of a seismic wavefield in the vertical direction and the pressure component of the seismic wavefield. The method may predict an upgoing pressure component of the seismic wavefield for the region of interest. The method may compare the predicted upgoing pressure component to the received seismic data that corresponds to the received summation. The method may update the predicted upgoing pressure component based on the comparison. The method may use the updated upgoing pressure component in hydrocarbon exploration or production for the region of interest.