The impact of true amplitude DMO on amplitude versus offset

Ramos, Antonio C. Buginga; Oliveira, Adelson S. de; Tygel, Martin

doi:10.1190/1.1821158

Cited by 4 publications

(2 citation statements)

References 6 publications

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“…We acknowledge, that even for regular datasets, amplitudes may be subtly affected by this process due to less sampling of the DMO operator at near offsets and large times. However, a simple integral DMO (Hale, 1991) handles the amplitudes at near offsets generally well compared to DMO corrections in the FeK domain (Ramos et al, 1999). Pre-stack depth/time migration was not carried out due to the demand of resources which are beyond the scope for the purpose of an initial screening of the study site.…”

Section: Datamentioning

confidence: 99%

Analysing sand-dominated channel systems for potential gas-hydrate-reservoirs using an AVO seismic inversion technique on the Southern Hikurangi Margin, New Zealand

Fohrmann

Pecher

2012

Marine and Petroleum Geology

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Section: Datamentioning

confidence: 99%

Analysing sand-dominated channel systems for potential gas-hydrate-reservoirs using an AVO seismic inversion technique on the Southern Hikurangi Margin, New Zealand

Fohrmann

Pecher

2012

Marine and Petroleum Geology

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“…The major problem in the AVO processing is to combines processing parameters and algorithms in a same way, generating a minimum of amplitude bias. Ramos suggested that the AVO technique success relies on the applied processing sequence, particularly in presence of reverberations and strong multiples (Ramos et al, 1999). The main aim of seismic data processing for the AVO modeling is to extract the rock properties, along with the structural image enhancement.…”

Section: Avo Processingmentioning

confidence: 99%

A Contribution of the CDP Gathers and Pre-Stack Seismic Inversion in the Prospect Evaluation: A Case Study of El Mansoura Field, Nile Delta, Egypt

Hussein

El-Ata

El-Behiry

2019

American Journal of Engineering and Applied Sciences

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This case study showing the usefulness of the Common Depth Point (CDP's) analysis to assess the amplitude response which is similar at two cases (gas-bearing and dry sands) after stack, using the Amplitude Versus Offset (AVO) analysis and the pre-stack inversion to understand the reservoir configuration and its relationship to the different amplitude response. The results led to a high success of exploration ratio as the positives vastly outweigh the negatives. Several lessons have been learned, which how to differentiate between the similar amplitude responses for two dry and gas discovery wells-by understanding the relationship between the near traces (near offset) and the far traces (far offset) from the CDP gathers in order to reduce the amplitude anomalies to their right justification. Consequently, a variation in the reflectivity strength is observed, which is controlled by the mechanical properties of the rocks: compression wave (VP), shear wave (Vs) and density. These properties are affected by litho logy and fluid contents. The analysis of the CDP's gathers and the inversion results help in validating the prospects before drilling and in determining the response of the seismic amplitude deviation with the offset, so it is possible to confirm the amplitude anomaly if it is related to hydrocarbon or not.

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Full-angle extended elastic impedance

Sharifi

Mirzakhanian

2019

Interpretation

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Application of seismic interpretation for fluid detection in carbonate reservoirs has been a major challenge for researchers in the past few decades. In this context, many approaches have been introduced, but they failed to be effective enough in the presence of different pore types in carbonate rocks. On this basis, we have developed a novel method called full-angle extended elastic impedance (FEEI) analysis as an alternative to seismic interpretation for fluid detection. Investigating the entire trend of changes in extended elastic impedance (EEI) values with [Formula: see text] angles (the intercept-gradient coordinate rotation angles), FEEI analysis can efficiently discriminate fluid types in carbonate reservoirs. The first steps in the application of the proposed method include performing fluid substitution modeling and making FEEI templates using FEEI analysis for different saturation scenarios. Subsequently, the derived FEEI method was subjected to validation and verification based on a carbonate case study with five existing wells drilled into a zone containing oil and brine. Next, we inverted the prestack seismic data to EEI data at corresponding [Formula: see text] angles, followed by interpreting the resultant EEI data by FEEI templates. Comparisons between the obtained EEI-inverted sections indicated the robustness and reliability of the proposed approach in estimating the type of pore fluid in the selected carbonate interval. Finally, estimation results were successfully tested on a blind well, which ended up with promising results, and we discuss the uncertainties associated with this methodology. The findings of this research include the introduction of a novel EEI template (i.e., FEEI template) and two new rock-physics templates for fluid detection, with the considered case study confirming the applicability of the proposed FEEI in a carbonate field.

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The impact of true amplitude DMO on amplitude versus offset

Cited by 4 publications

References 6 publications

Analysing sand-dominated channel systems for potential gas-hydrate-reservoirs using an AVO seismic inversion technique on the Southern Hikurangi Margin, New Zealand

Analysing sand-dominated channel systems for potential gas-hydrate-reservoirs using an AVO seismic inversion technique on the Southern Hikurangi Margin, New Zealand

A Contribution of the CDP Gathers and Pre-Stack Seismic Inversion in the Prospect Evaluation: A Case Study of El Mansoura Field, Nile Delta, Egypt

Full-angle extended elastic impedance

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