Aline Bourgeois, Gisèle Etienne, A.M. Melis, Pierre-Yves Dequirez, Alfredo Mazzotti, U. Spagnolini, Fabio Rocca, R. Eschard, A. De Nicolao, G. Ravagnan, J. Drufuca, Gilles Lambaré, G. Bernasconi, Vincent Richard, D. Macé, and V. Richard
Over the past decade, theory and experiments have shown that changes of reflection amplitude with offset (AVO) in multi-offset seismic records are strongly affected by relative changes of Poisson's ratio. AVO analysis opens the possibility to distinguish ‘bright spots’ due to gas accumulation from those caused by other changes in lithology AVO analysis is generally carried out with ray tracing and the Zoeppritz equations as tools for forward modeling. Some inversion procedures have been developed to infer changes in the contrast of the elastic parameters. However, it was recognized that the quality of the available modeling and inversion techniques was insufficient. The alternative approach we propose for the modeling is (i) an extension of the reflectivity method to smoothly varying media, and (ii) a cost-efficient linearized finite-difference technique.In our study we have minimized structural difficulties in order to concentrate on a 2D target zone in a quasi-layered background media. Then small changes in elastic parameter contrasts can be estimated by inversion using a linear least-squares approach: the waveform match between the synthetic and the seismic multi-offset gathers is obtained by perturbing the model parameters in the target zone. We have also evaluated the impact of the use of a priori information. Finally a 2D seismic non-linear modeling has been carried out to understand what reservoir-scale information is contained in the seismic reflection data. Participants in this project were AGIP (Italian oil company), the Politecnico di Milano(POLIMI) and the Institut Francais du Petrole (IFP). Each partner of this project has contributed specialskills and experience. The task of AGIP, the industrial partner, was to analyse a real data ase with the maximum depth possible, and to extract all information on the elastic parameters.The role of the academic partner, Politecnico di Milano, was to improve elastic reflectivity modeling and to evaluate the uncertainties of both amplitude-versus-offset (AVO) studies and of linearized elastic inversion that are caused by uncertainties in the model of the overburden and by noise in the data. An effort was also made to implement the inversion technique in the (ω-k domain. The role of IFP was to develop both linearized elastic modeling and inversion techniques using finite differences, and to evaluate the inversion technique on a large-scale synthetic data set. In addition, a multidisciplinary team of IFP has carried out a numerical simulation of synthetic data bas d on controlled earth parameters followed by processing and interpretation. Part I deals with the impact of a priori information on seismic inversion.It was decided to improve the most accurate modeling technique, i.e., the well known reflectivity method, so that it better represents shorter offsets; subsequently it was extended to media that vary continuously with depth, and to media that vary smoothly in lateral direction. This was achieved by the hybridization of ray tracing and reflectivity methods. A powerful (and essentially exact) 3D modeling technique resulted, albeit limited to quasi ID media. The AGIP group was able to analyse a real data case that was suitable for this kind of modeling. This group has carried out a careful and systematic AVO analysis and a comparison between the elastically modeled data and the real data. The processing and interpretation steps are described below. Another important step was to determine error bars in linearized inversion. For this, it was useful to move the problem from the spatial domain to the frequency-wave number domain. This move opened the possibility to bette understand the ‘conditioning‘. The inversion in the ω-k domain (with some preliminary results) is presented below. It was necessary to understand not only linearized inversion, but the limits of AVO in general. To this end a complete study of the interaction between AVO and velocity errors was carried out. This thorough understanding is particularly important if the velocity is not as perfectly known as in the real data case we analysed. Part II describes a 2D linearized elastic inversion technique and its evaluation on synthetic data.A 2D linearized elastic modeling procedure based on the computation of the Jacobian matrix using finite differences was proposed, analysed and implemented. Its accuracy was tested for models containing a few scattering points. Besides linearized modeling, a linearized inversion technique using a least-squares formulation was implemented to find the elastic perturbations in the 2D target zone. The inversion was tested on seismic data generated from scattering points. Next a large-scale synthetic data set generated for a gas-bearing sand model by a full-wave elastic finite-difference code was inverted. We show that, by using a plane stratified reference medium and limited windows for parameters data centered on the reflected P-P waves, one can determine the band-limited perturbations of the P-impedance and - to a lesser degree - the band-limited perturbations of the S-impedance at reasonable effort. In addition we show that the inversion results are closer to the actual perturbations than the results obtained with more conventional seismic processing procedures. Part III describes a numerical simulation of synthetic data for the Mesaverde outcrop.The objective was to understand what geological information is embodied in the seismic data that can be used to delineate and characterize reservoirs. Both geological and elastic models were constructed from the Mesaverde outcrop study and from industrial logs of equivalent formations. Then (marine) synthetic data were generated using a full-wave 2D elastic propagation code. Conventional seismic data processing was applied to obtain a stacked section. This section was calibrated using impedance logs at theoretical well locations (this process corresponds to wavelet-extraction processing). Finally complementary direct and inverse stratigraphie impedance modeling techniques were applied to build the most likely impedance section and to give a geological significance to the impedance variations.