# Study on Seismic Attenuation Based on Wave-Induced Pore Fluid Dissolution and Its Application
###### Abstract  
Seismic wave attenuation is affected by wave-induced pore fluid dissolution. The mechanism of wave-induced pore fluid dissolution is the mutual dissolution between different fluids caused by pore fluid pressure. Compared with the traditional WIFF (wave-induced fluid flow) mechanism, the wave-induced pore fluid dissolution mechanism can predict the attenuation of the seismic frequency band and can be used in well-to-seismic calibration. Conventional methods neglect the velocity dispersion caused by the interaction between pore fluids, which will lead to errors in attenuation prediction. In this paper, we focus on accurately predicting the velocity dispersion at low porosity and permeability, which can be used in multi-scale data matching. The stretch between the synthetic data by using logging data and seismic data needs to be calibrated for more accurate interpretation. The kernel of well-to-seismic calibration is the knowledge of the velocity dispersion between the logging frequency band and seismic frequency band. We calibrate the difference between the two kinds of data by using the rock physical model. Both the model test and field data application prove the feasibility and accuracy of the proposed strategy. rock physical model; upscaling model; pore fluid dissolution +
Footnote †: journal: Applied Sciences  
**Citation**: [PERSON]; [PERSON]; [PERSON]; [PERSON]. Well logging data and seismic data are the two most basic forms of raw data in the process of oilfield exploration and development, and they play an important role in detailed reservoir description, including reservoir prediction. The reflected reservoir information is inconsistent, resulting in multiple solutions for reservoir prediction and description. Determining how to perform well-to-seismic matching has become an indispensable and important part of predicting reservoir lithology, physical parameters and oil potential in oil and gas exploration and development research. There are three main methods for velocity matching and calibration of well-to-seismic data:  
1. The [PERSON] effective average method uses effective medium theory and a layered method to achieve high-frequency to low-frequency velocity correction. [11] deeply discussed the effect of [PERSON] effective averaging on elastic scattering characteristics in the medium; ref. [12] used [PERSON] effective averaging to conduct in-depth research on logging data scaling upscaling. The P and S wave velocities lead to rock physical analysis conclusions comparable to seismic scales. 2. The multi-resolution analysis method stretches the signals between adjacent events of the sonic logging synthetic seismic traces to align them with the corresponding events on the side-well traces. Ref. [13] applied multi-resolution analysis technology to the resampling of logging data and the matching of synthetic records and seismic traces, and the matching accuracy was high. 3. The rock physical model calibration method combines velocity dispersion theory and an absorption attenuation mechanism to achieve velocity calibration at different scales. Based on the resonant Q model [14], many researchers [15] measured the sonic logging velocity in different target blocks. Dispersion calibration was performed to improve the well-seismic matching effect. [PERSON]. [16] combined the DEM model and the microscopic dispersion theoretical model to extrapolate the logging frequency band velocity to the seismic frequency band for well-seismic matching and inversion calculations and achieved good results in carbonate reservoirs. In practical application, the Backus effective averaging method is simple and effective but does not consider the attenuation effect. Multiresolution analysis is highly automated but still requires accurate synthetic seismic record and stratigraphic correlation. The rock physical model calibration method can directly match data of different scales.