Applied 3D Full-Wave Modelling. Lisbeth Engell-Sørensen, Centre for Integrated Petroleum Research, Unifob, [email protected] , http://www.cipr.uib.no , http://www.ii.uib.no/~lisbeth and Jan Pajchel, Norsk Hydro AS, Research Centre. Main Purpose.
The main purpose of this talk is to describe the work carried out in two projects between Norsk Hydro and CIPR.
The main purposes of the two projects have been:
The projects are based on a 3D FD code made by Sintef, Trondheim and parallelized by LES at Parallab,Unifob
The main purpose of the work is to study waveform propagation and generate realistic data for testing of processing and migration tools applied in basaltic regions.
The work is based on a three-dimensional finite difference (FD) code, TIGER, made by SINTEF. The code computes wave propagation in a 3D anisotropic elastic media for micro seismic and traditional seismic sources.
The FD code was optimised by Parallab to run on parallel computers. The parallel code enables us to model large-scale realistic geological models in reasonable time.
Wave propagation in a general anisotropic, inhomogeneous elastic solid initiated by a body force is given by the equation of motion (Ben-Menahem et al, 1991):
Einstein’s summation convention for repeated indices is used. fj is body force density, ui are displacement components, ij is stress tensor, Cijkl is the tensor of elastic moduli, kare spatial partial derivatives, t is temporal derivative, Ti = ijnjis the traction on a surface with normal n, Cijkl = Cjikl = Cijlk = Cklij (21 independent Cijkl coefficients).
The displacement, u, due to body forces, f, throughout V and to boundary conditions, u and T, on S is (Aki and Richards, 1980)
where G is Green’s tensor. The first term is the contribution from the body forces in V and the surface integral gives the contributions from the boundary conditions on the boundary S of V.
The general anisotropic code uses 21 elastic coefficients.
Eight independent coefficients are needed as input parameters for the general TI medium: density, P-, S-velocity, three Thomson parameters: , , , and two angles for the TI symmetry axis
The parallel code uses multiple processors in order to manipulate subsets of large amounts of data simultaneously
1. Model large problems in limited time
2. Larger memory problems on more processors
Message Passing paradigm MPI (’nested’ parallelism)
The geological model is a basalt model, which covers from 24 km to 37 km of a real shot line in horizontal direction and from the water surface to 3.5 km depth.
The vertical parameter distribution is obtained from observations in two wells. At the depth of between 1100 m to 1500 m, a basalt horizon covers the whole sub surface layers.
The 2½D model has been constructed using the compound modelling software from Norsk Hydro.
The model is interpolated to a 3D grid. Each shot includes a subset of the global 3D grid in order to minimize computations.
The seismic sections show clearly the wave propagation within and near the basalt layer.
Diffractions are observed near the fault, possibly due to the fault geometry
1025 m Displacement Source (z)
1275 Displacement Source (z)m
We have shown that it is possible to simulate a line survey in realistic (3D) geological models in reasonable time by using high performance computers.
The offset gathers exhibit the characteristics of real data and are therefore well suited for processing and migration tests.
The main purpose is to compute five test shots along a seismic line in the Gulf of Mexico (GOM) above a salt structure.
One task is to identify seismic reflections and wave conversions at the salt boundaries.
The simulated geological model is a salt model, which covers 14.525 km of a real shot line in horizontal direction and from the water surface to 10.010 km depth.
The vertical parameter distribution is obtained from observations in one well and from Depth Migrated Sections and Interval Velocity Sections (P-waves). The S velocity of the salt was obtained from Vp/Vs relationship in the literature.
The 21/2D model is interpolated to a 3D grid. Each shot uses all the global model.
The seismic sections show clearly reflections from the top of the salt and possible reflections from the bottom of the salt.
We have simulated five shots in a line survey in a realistic model as the GOM salt model in reasonable time.
It has been possible to obtain CSG, which exhibit the characteristics of real data and are therefore well suited for further processing and migration tests.
It is seen from preliminary interpretations, that the salt boundaries are imaged.
In order to model sub salt reflections a source with lower peak frequency might be needed.
The authors would like to thank Norsk Hydro, GEUS, and SINTEF for very helpful discussions and Parallab for being helpful with using the new IBM, p690 Regatta system.
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