Petrophysics estimates reservoir parameters are based on formation reflections, but generally neglect porosity heterogeneity. In the Berryman theory, the pore aspect ratio is considered in petrophysical modeling. As we cannot acquire the pore aspect ratio directly, a fixed value is set empirically without considering the heterogeneity of the reservoir. We propose pore aspect ratio correction through Hunger Games Search (HGS). HGS quickly develops the optimal solution space for pore aspect ratio by simulating the way social animals forage. The revised pore aspect ratio improves the accuracy of forward modeling. In the new rock physics modeling with revised pore aspect ratio, the correlation coefficient for P-wave velocity improved from 0.843 to 0.924, and for S-wave velocity from 0.784 to 0.857. We added the revised pore aspect ratio to the petrophysical inversion process. A bidirectional long-short-term memory network is established to realize the joint inversion of multiple reservoir parameters considering the heterogeneity of porosity. The proposed scheme was applied in a tight sandstone reservoir. The results show that the physical parameters and pore space structure can be effectively inverted.

Traveltime picking accuracy is frequently affected by incoherent or random data noise. Within this context, we put forth a new denoising method called iterative interferometric denoising filtering. This method leverages the pseudo-Wigner distribution function to capture the offset and time-symmetric patterns of source wavelets convolved in seismic signals. Incoherent or random noises without this characteristic are eliminated via this approach. The processed data have waveform information distortion and more frequency components. However, the traveltime information can be considered correct, and the improved signal-to-noise ratio makes traveltime picking much more convenient. Our method’s practical applications in a synthetic and in two field datasets show that this technology can increase the signal-to-noise ratio, and the picked traveltime information can be used in traveltime tomography. These two field datasets were collected near the Aqaba Gulf and the Qademah fault, located in King Abdullah Economic City.

A physics-based approach called waveform parsimonious refraction interferometry (WPRI) which interpolates head or refraction waveform is introduced in this work. WPRI yields a significant advantage in exploration and engineering applications, as it mitigates the excessive time and labor cost in 2D field acquisitions that require dense receivers and shots while improving coverage in refraction seismic imaging processes. Our proposed method generates the virtual seismic refraction waveform which involves kinematic and dynamic information with near-perfect accuracy for near-surface seismic waveform inversion and migration. To achieve this, we record data from two shot locations situated at opposite ends of the seismic profile, as well as a handful of near-offset traces along the profile. The virtual head or refraction wavefield is then determined through the convolution and cross-correlation of the recorded wavefields with the objective of eliminating common wavepath. Furthermore, we introduce a source wavelet deconvolution step to correct dynamic discrepancies present in the virtual waveform. By implementing this type of technique, we are able to produce virtual seismic data that is highly accurate and can be effectively employed in near-surface seismic imaging applications.