Upload
hahuong
View
232
Download
2
Embed Size (px)
Citation preview
Full Waveform Inversion Using Oriented Time Migration Method
Thesis by
Zhen-dong Zhang
In Partial Fulfillment of the Requirements
For the Degree of
Masters of Science
King Abdullah University of Science and Technology, Thuwal,
Kingdom of Saudi Arabia
Copyright © April 2016
Zhen-dong Zhang
All Rights Reserved
2
The thesis of Zhen-dong Zhang is approved by the examination committee
Committee Chairperson: Tariq Alkhalifah
Committee Member: Yike Liu
Committee Member: Ibrahim Hoteit
Committee Member: Ying Wu
3
ABSTRACT
Full Waveform Inversion Using Oriented Time Migration
Method
Zhen-dong Zhang
Full waveform inversion (FWI) for reflection events is limited by its linearized up-
date requirements given by a process equivalent to migration. Unless the background
velocity model is reasonably accurate the resulting gradient can have an inaccurate
update direction leading the inversion to converge into what we refer to as local min-
ima of the objective function. In this thesis, I first look into the subject of full model
wavenumber to analysis the root of local minima and suggest the possible ways to
avoid this problem. And then I analysis the possibility of recovering the correspond-
ing wavenumber components through the existing inversion and migration algorithms.
Migration can be taken as a generalized inversion method which mainly retrieves the
high wavenumber part of the model. Conventional impedance inversion method gives
a mapping relationship between the migration image (high wavenumber) and model
parameters (full wavenumber) and thus provides a possible cascade inversion strat-
egy to retrieve the full wavenumber components from seismic data. In the proposed
approach, consider a mild lateral variation in the model, I find an analytical Frechet
derivation corresponding to the new objective function. In the proposed approach, the
gradient is given by the oriented time-domain imaging method. This is independent
of the background velocity. Specifically, I apply the oriented time-domain imaging
4
(which depends on the reflection slope instead of a background velocity) on the data
residual to obtain the geometrical features of the velocity perturbation. Assuming
that density is constant, the conventional 1D impedance inversion method is also ap-
plicable for 2D or 3D velocity inversion within the process of FWI. This method is not
only capable of inverting for velocity, but it is also capable of retrieving anisotropic pa-
rameters relying on linearized representations of the reflection response. To eliminate
the cross-talk artifacts between different parameters, I utilize what I consider being
an optimal parameterization. To do so, I extend the prestack time-domain migration
image in incident angle dimension to incorporate angular dependence needed by the
multiparameter inversion. For simple models, this approach provides an efficient and
stable way to do full waveform inversion or modified seismic inversion and makes the
anisotropic inversion more practical. Results based on synthetic data of isotropic and
anisotropic case examples illustrate the benefits and limitations of this method.
5
ACKNOWLEDGEMENTS
Sincere thanks to my supervisor, Professor Tariq Alkhalifah and also my co-supervisor,
Professor Yike Liu at Institute of Geology and Geophysics, Chinese Academy of Sci-
ences. Professor Alkhalifah has consistently given me great care and concern especially
when I first arrived at KAUST. His profound knowledge, energy and enthusiasm for
Geophysics and excellent instructions help me a lot. Professor Yike Liu was my first
teacher in Geophysics. His patience and foresight in Geophysics help me to get in-
volved in research quickly.
Thanks to the members of my thesis examination committee, Professor Ibrahim Hoteit,
and Professor Ying Wu, for their valuable comments and precious time.
Thanks to KAUST for its support and specifically the seismic wave analysis group
(SWAG) members for their valuable insights.
Thanks to my parents and my friends for their support, patience and help.
6
TABLE OF CONTENTS
Copyright 1
Examination Committee Approval 2
Abstract 3
Acknowledgements 5
List of Figures 8
1 Introduction 10
2 Full Model Wavenumber Inversion 14
2.1 Velocity Model Building . . . . . . . . . . . . . . . . . . . . . . . . . 14
2.1.1 Initial Velocity Model . . . . . . . . . . . . . . . . . . . . . . . 15
2.1.2 Enhance the Resolution . . . . . . . . . . . . . . . . . . . . . 17
2.2 Migration and Inversion . . . . . . . . . . . . . . . . . . . . . . . . . 19
2.2.1 Oriented Time Migration . . . . . . . . . . . . . . . . . . . . . 19
2.2.2 Numerical Example . . . . . . . . . . . . . . . . . . . . . . . . 21
3 Inversion Algorithm and Numerical Examples 24
3.1 Derivation of the Algorithm . . . . . . . . . . . . . . . . . . . . . . . 24
3.1.1 Impedance Inversion and FWI . . . . . . . . . . . . . . . . . . 24
3.1.2 Multi-parameter Inversion for VTI Media . . . . . . . . . . . . 26
3.1.3 Mono-parameter Inversion for Isotropic Media . . . . . . . . . 28
3.2 Parameterization . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 29
3.3 The Workflow for This Method . . . . . . . . . . . . . . . . . . . . . 31
3.4 Numerical Example . . . . . . . . . . . . . . . . . . . . . . . . . . . . 33
3.4.1 Monoparameter Case . . . . . . . . . . . . . . . . . . . . . . . 33
3.4.2 Multiparameter Case . . . . . . . . . . . . . . . . . . . . . . . 35
7
4 Concluding Remarks 38
4.1 Discussion . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 38
4.2 Conclusion . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 39
4.3 Future Research Work . . . . . . . . . . . . . . . . . . . . . . . . . . 40
References 42
8
LIST OF FIGURES
2.1 The objective function corresponding to a model with the residual miss-
ing the wavenumber given by the horizontal axis (Courtesy of Alkhal-
ifah, 2015). . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 15
2.2 The wavenumber issue. Notice that the intermediate wavenumber com-
ponents of the model are insensitive to the data (Adapted from Imaging
the Earth Interior). . . . . . . . . . . . . . . . . . . . . . . . . . . . . 18
2.3 Description of geometry parameters (Courtesy of Clayton, 1977). . . . 20
2.4 Velocity model used in the example. . . . . . . . . . . . . . . . . . . . 22
2.5 Conventional time migration image. Notice that time migration cannot
image the structures which has large dipping angles. . . . . . . . . . . 23
2.6 Extended time migration image. The third axis is the incident angle. 23
3.1 Radiation pattern for parameters Vp0, δ and ε. The red line indicates
Vp0; the green line indicates ε, and the blue line indicates δ. . . . . . . 30
3.2 Radiation pattern for parameters Vn, η and δ. The red line indicates
Vn; the green line indicates η, and the blue line indicates δ. . . . . . . 31
3.3 Monoparameter inversion results: (a) true velocity model, (b) initial
velocity model, and (c) inverted velocity model. . . . . . . . . . . . . 33
3.4 Comparison of velocity models. The red line indicates true velocity; the
dashed green line indicates initial velocity, and the black line indicates
inverted velocity. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 34
3.5 Normalized data residual for five iterations at 4 Hz. The data residual
is decreasing with the iteration steps increasing. More iterations should
be implemented to get a better approximation to the true velocity in
one stage. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 35
3.6 Multiparameter inversion results: (a) true Vn model, (b) true η model,
(c) true δ model, (d) inverted Vn model, (e) inverted η model and (f)
inverted δ model. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 36
9
3.7 Initial models used in mulitiparameter inversion: (a) Vn, (b) η and (c)
δ. They are smoothed version of the true models. . . . . . . . . . . . 36
3.8 Comparison of the inverted models at x = 1.5km. (a) The red line
indicates true Vn; the green line indicates initial Vn, and the blue line
indicates the inverted Vn. (b) The red line indicates true η; the green
line indicates initial η, and the blue line indicates the inverted η. (c)
The red line indicates true δ; the green line indicates initial δ, and the
blue line indicates the inverted δ. . . . . . . . . . . . . . . . . . . . . 37
10
Chapter 1
Introduction
Full waveform inversion (FWI) is a nonlinear optimization procedure which aims to
better estimate subsurface parameters to reduce the misfit between predicted and
observed data. Given initial estimates of subsurface parameters, the predicted data
is calculated by numerically solving the relevant wave equations such as acoustic,
elastic and quasi-acoustic. Usually, we evaluate the data misfit in the 2-norm sense
and calculate the perturbations by solving a least-squares local optimization problem
[1]. This procedure is repeated in an iterative fashion until the data residual is
acceptable. For gradient-based optimization methods, gradients could be calculated
by the multiplication of Frechet derivations and data misfits or by the adjoint-state
method. Frechet derivations cannot be calculated numerically in practice due to
the unaffordable computational cost for large models. This makes the adjoint-state
method the more practical and widely used method since Lailly [2] and Tarantola [3]
have shown that it is nothing but a process of cross-correlating the forward-propagated
source wavefield and the back-propagated data residual.
Full waveform inversion has not been widely used in the industry mainly because
of its local minima problem and huge computational cost. Gradient-based local op-
timization methods require that the initial models should be close to true models,
which guarantees convergence to the global minima. To be more specific, the initial
models should be able to produce synthetic data that is within a half-cycle of the ob-
11
served data everywhere, and the physical temporal length of a half cycle depends on
the frequency used in inversion [4]. It is not easy to build such precise initial models
in practice. Because of this, various methods have been introduced to mitigate the
local minima problem, including multiscale inversion method by Bunks et al. [5], the
damping method by Shin et al. [6] and the unwrapped phase method by Choi and
Alkhalifah [7] and Alkhalifah [8]. Global optimization methods introduced by Sen
and Stoffa [9] are intended to find the global minima with arbitrary initial models,
but they are not widely used mainly because their computational costs are not af-
fordable. Even for the local optimization methods, the computational cost is huge.
Most of the computation time of full waveform inversion are occupied by extrapo-
lating the wavefield using numerical methods including finite-difference, spectral and
finite-element methods. To speed up the forward and backward propagation of the
wavefield the Graphic Process Unit (GPU) based method by Yang et al. [10] was
introduced to FWI. There are also many dimensionality reduction approaches used
to reduce the computational cost of modeling and inversion including source encod-
ing methods [11, 12, 13] and randomized source methods [14, 15, 16]. Although we
cannot numerically calculate Frechet derivations in practice, for simple models, we
can find its approximate analytical solutions [17, 18]. No backward extrapolations are
needed in each iteration, and thus, the computational cost and memory requirements
are reduced.
General seismic inversion methods, including the 1D impedance inversion [19, 20,
21, 22], provide a possible way to calculate the velocity perturbation from the image
of the data residual using perturbation theory. Under the assumption of a mild lat-
eral velocity variation, the 1D inversion method could easily be used for 2D or 3D
inversions. Calculating the image corresponding to velocity perturbations, migration
of the data residual is needed. Both wave equation and ray-theory based depth migra-
tion methods depend strongly on the migration velocity. Actually, the velocity model
12
is usually considerably inaccurate at the beginning of full waveform inversion. This
leads to inaccurate focusing and positioning of reflectors (perturbations). Such inac-
curacies for depth based imaging tend to be larger than those corresponding to time
domain imaging methods. For conventional velocity analysis time domain processing
methods are considered more robust [23, 24]. Here vertical time replaces depth as
the vertical axis. The oriented time-domain imaging method developed by Fomel [25]
is independent of the velocity model, and provides a better chance of guaranteeing
an accurate representation of the image. This is especially true at the beginning of
the inversion process. In other words, the energy of the data is transformed to the
migration image without leakage to extended images. This property is crucial for our
proposed objective function which evaluates the data misfit in the image domain. We
know that local slopes estimated from prestack reflection data contain all the infor-
mation of the reflection geometry [26]. Once they are calculated correctly, the seismic
velocities, incident angles, and some other wave geometry parameters become data
attributes. For multiparameter inversion, incident angles are needed to distinguish
the contributions to the waveform from different parameters.
Since the aim of FWI is to fit the full information content of observed and predicted
data, the simulation engine embedded in the FWI algorithm should honor all of
the physics of wave propagation as much as possible [1]. Multiparameter inversion
including velocity, density, attenuation and anisotropic parameters helps improve
the FWI results and is drawing more and more attention in full waveform inversion
analysis [27, 28, 29, 30]. I propose a new multiparameter inversion method for VTI
media based on the pseudo-acoustic wave equation introduced by Alkhalifah [31].
One of the difficulties in multiparameter FWI is to eliminate the crosstalk artifacts
between different parameters. One remedy is to select the optimal parameterization,
which not only can adequately describe the subsurface model but also can be inverted
from the observed data [27, 29, 32]. When considering the parameters as virtual
13
sources in the model space, I can calculate their radiation patterns, which indicate
their contributions to the waveform recorded at the surface. Their contributions
depend on the scattering angles in the model space or roughly the offsets in the data
space. When back projecting the data residual in the data domain to the parameter
perturbation in the model domain, the radiation patterns act like filters. Due to the
limited separation of the acquisition geometry, some parameters cannot be retrieved if
their unique contributions are not identified in the observed data. Another difficulty
is the variable influence of different parameters on the waveform. The hierarchical
strategies [33, 28, 34] can retrieve different parameter classes successively and partly
mitigate the poor positioning of FWI. Since the incident angles help to distinguish the
contributions of the parameters, the extended images in the incident angle dimension
are needed. The extended images can be calculated easily because the incident angles
are also data attributes.
This thesis is divided into four chapters. After the introduction, I analyze the
wavenumber components of gradients used in full waveform inversion. In the third
chapter the algorithm and numerical examples of the proposed method are delivered.
Finally, I draw the conclusion from the developed theory and numerical examples and
suggest future work.
14
Chapter 2
Full Model Wavenumber Inversion
The velocity model can be separated into low and high wavenumber components [35].
The ultimate goal of FWI is to recover all the wavenumber components available in
recorded data from low to high [36]. To avoid the cycle-skipping problem the initial
velocity model should provide correct kinematic information (low wavenumber) for
the simulated data. High wavenumber components mainly provide the dynamic infor-
mation such as the reflection coefficient of the model. In practice, the low wavenumber
information is recovered by tomography and the high wavenumber part is provided by
migration. In the proposed method, I assume the initial model has correct kinematic
information and utilize time migration method to reveal the dynamic information
(high wavenumber). We evaluate the data misfit by the difference between the ob-
served and calculated data so that the forward modeling engine will describe the
propagation of the P wave as precisely as possible. This means that the calculated
data is acquired by solving the acoustic wave equation.
2.1 Velocity Model Building
Velocity information is the vital component in seismic data processing and it is one
of the most reliable ways to understand the subsurface structures. For migration
purpose a smooth RMS velocity model (usually used as the initial velocity model for
15
FWI) is good enough, however, with the help of full waveform inversion methods we
can get a higher resolution velocity model and thus a better understanding of the
subsurface properties. This is especially relevant for some complex velocity models
where tomography complicates a solution. In such cases the FWI method can provide
an accurate solution [37].
2.1.1 Initial Velocity Model
Limited by the sinusoid nature of seismic data, the initial velocity model should be
close to the true velocity model to avoid getting stuck in local minima. Specifi-
cally, the initial velocity model might have low resolution, but it should be kineti-
cally close to the true velocity model. Alkhalifah [36] demonstrates the importance
of low-wavenumber components in full waveform inversion as shown in Figure 2.1.
Low-wavenumber components which are mainly built by the initial model missing
could lead to large data residual. However high-wavenumber components which could
provide a high-resolution model cannot generate large data residual when they are
missing in the inverted model.
Figure 2.1: The objective function corresponding to a model with the residual missingthe wavenumber given by the horizontal axis (Courtesy of Alkhalifah, 2015).
For a successful application of full waveform inversion, it is critical to generate a
critical initial velocity model which guarantees the inversion is converging to the global
16
minimum. Conventional velocity estimation methods have been well developed in the
past years and provide kinematic accurate velocity models as the initial model for
full waveform inversion. These methods include first-arrival traveltime tomography,
normal move-out (NMO) velocity scanning in data domain, and migration velocity
analysis (MVA) or differential semblance optimization (DSO) in the image domain.
Through implements on the BP salt dome model, Chauris et al. [38] indicate that in
the simplest zone corresponding to smooth velocity models, the tomographic models
are good enough for waveform inversion with realistic frequency contents. In the
complex part going through a salt body, one need very low frequencies or a further
refinement of the tomographic model. Weibull and Nilsen [39] suggest using wave-
equation-migration velocity analysis (WEMVA) to build reliable initial models for
full waveform inversion.
The migration velocity analysis (MVA) approach has a long history and has plenty
of variations in application, but the underlying principle has not been changed. This
approach is usually measuring the focus of energy in the image domain; However,
Van Leeuwen and Mulder [40] implemented MVA in the data domain to recover the
background velocity model which could be used as the initial velocity model for full
waveform inversion. This method could be incorporated with the proposed inversion
method; here we give a short introduction to this method. Different from wave-
form inversion, this method focuses on fitting the curvatures of the calculated data
and observed data by a correlation method. The objective function for temporary
correlation is defined below,
Jt =1
St
∫ ∫ ∆tmax
−∆tmax
W (∆t)(Ct[p, q](∆t, h))2d∆tdh, (2.1)
and
17
Ct[p, q](∆t, h) =
∫p(t, h)q(t+ ∆t, h)dt, (2.2)
St =1
St
∫ ∫ ∆tmax
−∆tmax
(Ct[p, q](∆t, h))2d∆tdh. (2.3)
p(t, h) and q(t, h) are calculated and observed seismograms, where t and h denote
time and offset respectively. Ct is the temporal correlation of these two seismograms.
∆t denotes the maximal shift of the correlation which could reduce the influence of
crosstalk. W (∆t) is a weighting function measuring the amount of the energy away
from zero shift or around zero shift.
The weighting function used to measure the energy away from the center is,
W1(∆t) = (∆t
∆tmax)2. (2.4)
This weighting function penalizes peaks at non-zero shift and thus measures the
amount of energy away from the center.
A weighting that measures energy around zero shift is a Gaussian function,
W2(∆t) = −e−α∆t2 . (2.5)
The minus sign ensures that minimizing the functional will maximize the amount of
energy around the center, and α controls the bandwidth of the function.
The gradient for the optimization could be derived using the adjoint-state tech-
nique. See the paper [40] for more details.
2.1.2 Enhance the Resolution
The initial velocity model which is kinematically accurate with respect to the true
model could fulfill the imaging task. However, the refined velocity model which has
18
higher resolution (up to one-half of the propagated wavelength) could be used for di-
rect interpretation [37]. For short-offset acquisition the seismic wavefield recorded at
the receivers is insensitive to intermediate wavenumber components which generate a
gap in wavenumber components between the initial velocity model and the final-high
resolution velocity model as shown in Figure 2.2. To narrow the wavenumber gap,
it requires that the initial velocity should be sufficiently accurate [1], otherwise, the
initial velocity might be not very accurate. Because of this the data set should con-
tain low-frequency large-offset information [41]. The full waveform inversion method
utilizes the waveform residual to update the initial velocity model and the updates
are corresponding to the high wavenumber part of the velocity model.
Figure 2.2: The wavenumber issue. Notice that the intermediate wavenumber com-ponents of the model are insensitive to the data (Adapted from Imaging the EarthInterior).
For gradient-based optimization methods, gradients are added to initial models
after properly scaling. Thus, the wavelength components of the gradients (model
updates) decide the resolution of the inverted model. Conventional full waveform
inversion methods start from a quite low frequency or frequency band. With more
frequency information more details of the substructure are resolvable and add resolu-
tion to the initial velocity model. The wavenumber formula for the gradient is given
by
19
Kδv = Ks + Kr =ω
v0
cosθ
2n. (2.6)
Where v0 is the background velocity, ω is the angular frequency and θ is the
scattering angle. n is the unit vector which is defined as n = Ks+Kr
|Ks+Kr| . The updated
model has the best resolution in n direction which is perpendicular to the wavepath.
A wavenumber filter could be designed to select the appreciate wavenumber com-
ponents added to the background velocity model [36]. A specially designed filter can
filter out the unwanted part of the gradients, and it provides a possible way to apply
the proposed method to more complex models, which will be my future work.
2.2 Migration and Inversion
Seismic migration and inversion share the same objectives and underlying physical
principles; Migration can be taken as an inversion process which inverts for the re-
flectivity from seismic data [42]. Reflectivity can be turned into impedance or other
subsurface parameters by a linear transform provided by convolution model. Thus it
is a migration process that is the essential part embedded in waveform inversion.
Both wave equation and ray theory based depth migration methods depend criti-
cally on the migration velocity. Actually, at the beginning of a full waveform inversion,
the velocity model is usually considerably inaccurate, which leads to inaccurate focus-
ing and positioning of reflectors (perturbations). Such inaccuracies for depth-based
imaging tend to be larger than those corresponding to time domain imaging methods.
For conventional velocity analysis, time domain processing methods are more robust.
2.2.1 Oriented Time Migration
The oriented time-domain imaging method developed by Fomel [25] largely applies a
prestack time migration utilizing velocity information extracted from the local event
20
Figure 2.3: Description of geometry parameters (Courtesy of Clayton, 1977).
slopes in the reflection data. Thus, this method is independent of the velocity model,
which could help us avoid putting the reflectors (or perturbations) in the wrong
position due to the erroneous initial velocity model. This method is applicable for
VTI media under the assumption that the moveout is non-hyperbolic.
The basic idea of this migration method is to find a mapping relationship between
images and data attributes. Equations 2.7, 2.8 and 2.9 are geometrical descriptions
of Figure 2.3, and the description is valid for both isotropic and anisotropic media.
t =2h cosα
v sin β, (2.7)
ph =∂t
∂h=
2 cosα sin β
v, (2.8)
py =∂t
∂y=
2 sinα cos β
v. (2.9)
Where h denotes the half-offset, y denotes the midpoint in the image domain. ph
and py are estimated slopes which will be explained later.
21
Sava and Fomel [43] provide a description for data attributes shown in equations
2.10 and 2.11.
τ = tcos2 α− sin2 β
cosα cos β, (2.10)
y − x = hsinα cosα
sin θ cos θ. (2.11)
Here x denotes true reflection point on surface.
The time-migrated image domain (τ, x) is mappable from the prestack domain
(t, h, y) using the following formulas,
τ 2 =tph[(t− hph)2 − h2p2
y]2
(t− hph)2[tph + h(p2y − p2
h)], (2.12)
x = y − htpytph + h(p2
y − p2h). (2.13)
The event slopes in recorded data, given by ph = ∂t/∂h and py = ∂t/∂y, can be
estimated using the plane-wave destruction algorithm of Fomel [44]. Different from
the isotropic case, we need to calculate the incident angle using equation 2.14 besides
the time τ and midpoint x in the image domain for the anisotropic case. Since the
incident angle is one of the attributes of the data, the extended images can be easily
calculated by sweeping over all the possible incident angles and reorganize them in
the incident angle dimension.
sin2θ =hpht. (2.14)
2.2.2 Numerical Example
Time migration plays an essential part in the proposed inversion algorithm. In this
part, we verify the extended migration algorithm by part of Marmousi-II model as
shown in Figure 2.4. There are 50 shots evenly distributed on the surface. Each shot
22
Figure 2.4: Velocity model used in the example.
has a Ricker wavelet with a peak frequency of 5 Hz as the source. The migration
image is shown in Figure 2.5 and it is a conventional image without incident angles.
Notice the fact that time migration cannot image the large-dipping portion of the
model. The extended image is shown in Figure 2.6. The third dimension is incident
angles, and the images look discontinuous mainly because the sampling is not frequent
enough in the estimated slopes. However, after stacking all the images along incident
angles the image should coincide with Figure 2.5.
23
Figure 2.5: Conventional time migration image. Notice that time migration cannotimage the structures which has large dipping angles.
Figure 2.6: Extended time migration image. The third axis is the incident angle.
24
Chapter 3
Inversion Algorithm and
Numerical Examples
3.1 Derivation of the Algorithm
In this section, I derive an analytical solution to approximate Frechet derivations.
The analytical solution is fit for a new objective function which is equivalent to the
conventional objective function. The analytical approximations of Frechet derivation
help reduce the computational time and memory requirement in every iteration.
3.1.1 Impedance Inversion and FWI
Impedance inversion methods provide a relationship between impedance and image
in time domain [19, 20]. Under the assumption that the density is constant, and the
lateral velocity variation is negligible, the 1D inversion method can be extended to a
2D or 3D case. After converting the seismic data residual to images, we can combine
the full waveform inversion method with the acoustic impedance inversion method
and derive an efficient way to calculate the parameter’s perturbations. In this section,
I propose a new objective function and derive the gradients for different parameters.
If we take the full waveform inversion as a least-squares local optimization problem
25
then the conventional misfit function is given by
J =1
2‖ L(m)− dobs ‖2, (3.1)
where m represents the model parameters and here in an acoustic, constant density,
case, it is given by the anisotropic parameters and velocities. L denotes the for-
ward modeling operator and dobs is the observed seismic data. The operator ‖ . ‖2
corresponds to the l2 norm.
Instead of evaluating the data misfit directly, I propose a new misfit function
which is given by the image of data residual,
J =1
2‖ I(τ,x) ‖2, (3.2)
where I(τ,x) is the prestack time migration image of the data residual. Thanks to the
velocity-independent property of the dip-oriented migration method, the images are
always focused at zero time lag and zero subsurface offset. In other words, equations
3.1 and 3.2 are equivalent to each other because there is no energy leakage.
To minimize the new misfit function, gradient-based optimization methods are
needed [1]. Here, I use the steepest descent method which is given by
mnew = mold − α∂I(τ,x)
∂mI(τ,x), (3.3)
wherem denotes the model parameters, which could be velocity, density and anisotropic
parameters according to the assumed approximations of the subsurface model, and α
is the step length which can be calculated using a line search method [45]. The Frechet
derivation, ∂I∂m
, has an explicit form with the help of the widely used convolutional
model [20] in conventional impedance inversion method.
26
The general form of the convolutional model is given by
I(τ,x) = R(τ,x) ∗ s(τ). (3.4)
Here, I(τ,x) denotes the image in the time domain, R(τ,x) denotes the reflection
coefficient and s(τ) denotes the source wavelet used for forward modeling.
The parameters, including the velocity, density, and anisotropic parameters, are
hidden in the specific form of R(τ,x) which depends on the assumptions made of the
subsurface. In the next section, I derive the specific form of equation 3.3 for VTI
media. As a special case, the isotropic form is also given when there is no anisotropic,
and thus, no incident angle dependence.
3.1.2 Multi-parameter Inversion for VTI Media
For VTI media, the reflection coefficient given by [46] is shown below,
RV TIP (θ) =
1
2
∆Z
Z+
1
2(∆Vp0Vp0
− (2Vs0Vp0
)2 ∆G
G+ ∆δ)sin2θ +
1
2(∆Vp0Vp0
+ ∆ε)sin2θtan2θ,
(3.5)
where θ denotes the incident angle, which is important to suppress the crosstalk
artifacts between different parameters, Z = ρVp0 is the vertical P-wave impedance,
and G = ρVs0 denotes the vertical shear modulus, which is assumed to be zero in the
pseudo-acoustic approximation. The perturbations ∆δ and ∆ε are the differences in
anisotropy between two points. Here I set the density to equal 1.
Using the approximation introduced by [20] in conventional impedance inversion,
1
2
∆Z(τ, x)
Z(τ, x)=
1
2
∂ln(Z(τ, x))
∂τ, (3.6)
27
Inserting equations 3.6 and 3.5 into equation 3.4 and get,
IV TIP (θ) =1
2[lnVp0(1 + sin2θ + sin2θtan2θ)] ∗ s+
1
2[δsin2θ + εsin2θtan2θ] ∗ s. (3.7)
If each of the parameters, Vp0, δ, and ε, is perturbed successively, the image with
respect to the perturbations of each parameter is given by,
(I + ∆I)V TIvp0(θ) = 1
2[ln(Vp0 + ∆Vp0) ∗ (1 + sin2θ + sin2θtan2θ)] ∗ s (3.8)
+12[δsin2θ + εsin2θtan2θ] ∗ s,
(I + ∆I)V TIδ (θ) = 12[lnVp0 ∗ (1 + sin2θ + sin2θtan2θ)] ∗ s
+12[(δ + ∆δ)sin2θ + εsin2θtan2θ] ∗ s,
(I + ∆I)V TIε (θ) = 12[lnVp0 ∗ (1 + sin2θ + sin2θtan2θ)] ∗ s
+12[δsin2θ + (ε+ ∆ε)sin2θtan2θ] ∗ s.
Subtracting equation 3.7 from equation 3.8 and using Taylor expansion for ln(1+x) ≈
x, when x is small, I get the relationships between perturbed parameters and the
image of data residual, given by
∆IV TIvp0(θ) ≈ 1
2[ δVp0Vp0
(1 + sin2θ + sin2θtan2θ)] ∗ s, (3.9)
∆IV TIδ (θ) ≈ 12[∆δsin2θ] ∗ s,
∆IV TIε (θ) ≈ 12[∆εsin2θtan2θ] ∗ s.
By virtue of the associativity law of convolution and integral over the reflection
28
angles, the gradients are given by
∇vp0 ≈ 12[∑θ I(τ,x,θ)(1+sin2θ+sin2θtan2θ)
Vp0] ∗ s, (3.10)
∇δ ≈ 12[∑
θ I(τ,x, θ)sin2θ] ∗ s,
∇ε ≈ 12[∑
θ I(τ,x, θ)sin2θtan2θ] ∗ s,
where I(τ,x, θ) is the extended image along the incident angle axis. The incident
angle exposes the varying contributions to the waveform from the parameters, Vp0, δ
and ε, which is used to mitigate the crosstalk artifacts between them in the inversion
step. In addition to utilizing the incident angle directly, I also want to choose an
optimal parameter set which has fewer overlaps as a function of incident angle. More
details about choosing the optimal parameterization for the proposed method are
shown in the next section.
3.1.3 Mono-parameter Inversion for Isotropic Media
The derivation for monoparameter case is straightforward. Noting the fact that equa-
tion 3.5 is a good approximation for the reflection coefficient of vertical-incident P-
wave by setting the shear velocity, anisotropic parameters and incident angle equal
zero. Thus, the reduced form of equation 3.10 is the gradient for the monoparameter
inversion such that the vertical P-wave velocity inversion is given by,
∇vp0 ≈1
2[I(τ,x)
Vp0] ∗ s. (3.11)
29
No incident angle information is needed since I only invert for a monoparameter, ver-
tical P-wave velocity. The steepest descent method could be implemented to minimize
the proposed objective function.
3.2 Parameterization
For multiparameter inversion, the coupled effects of the parameters prevent the con-
vergence [34, 29]. Usually, different parameters have different sensitivities to different
scattering angles, which are also called radiation patterns. In this part, I test two
sets of parameters based on the previous analysis (i.e. equation 3.10) and choose the
optimal one based on the inversion purpose and inversion strategy. Figure 3.1 shows
the radiation patterns for the first set which includes Vp0, δ, and ε. It is obvious that
Vp0 is sensitive to all the scattering angles. On the other hand, δ and ε have over-
lapped scattering angles, which means that they have some crosstalk errors if I invert
these two parameters simultaneously. This set of parameters is reasonable if I keep
δ and ε fixed and invert Vp0 only. However, if I want to invert all three parameters
simultaneously, I need to change the parametrization. By virtue of the chain rule, I
represent the VTI media by the following parameters Vn, η and δ.
∣∣∣∣∣∣∣∣∣∣∂I∂Vn
∂I∂η
∂I∂δ
∣∣∣∣∣∣∣∣∣∣=
∣∣∣∣∣∣∣∣∣∣∂Vp0∂Vn
∂ε∂Vn
∂δ∂Vn
∂Vp0∂η
∂ε∂η
∂δ∂η
∂Vp0∂δ
∂ε∂δ
∂δ∂δ
∣∣∣∣∣∣∣∣∣∣
∣∣∣∣∣∣∣∣∣∣∂I∂Vp0
∂I∂ε
∂I∂δ
∣∣∣∣∣∣∣∣∣∣. (3.12)
The relationships between different anisotropic parameters are written as,
Vn = Vp0√
1 + 2δ
η = ε−δ1+2δ
=⇒
Vp0 = Vn√1+2δ
ε = (1 + 2δ)η + δ
δ = δ
. (3.13)
30
0.20.40.60.81
30
210
60
240
90 270
120
300
150
330
180
0
Vp0EpsilonDelta
Figure 3.1: Radiation pattern for parameters Vp0, δ and ε. The red line indicates Vp0;the green line indicates ε, and the blue line indicates δ.
Then I can get a new formula for the parameter perturbations and the image of
the data residual, given by
∣∣∣∣∣∣∣∣∣∣∆I
∆Vn
∆I∆η
∆I∆δ
∣∣∣∣∣∣∣∣∣∣≈
∣∣∣∣∣∣∣∣∣∣1√
1+2δ0 0
0 1 + 2δ 0
−Vn(1 + 2δ)−32 1 + 2η 1
∣∣∣∣∣∣∣∣∣∣
∣∣∣∣∣∣∣∣∣∣∆I
∆Vp0
∆I∆ε
∆I∆δ
∣∣∣∣∣∣∣∣∣∣. (3.14)
The gradients for Vn, η and δ are given by,
∣∣∣∣∣∣∣∣∣∣∇vn
∇η
∇δ
∣∣∣∣∣∣∣∣∣∣≈
∣∣∣∣∣∣∣∣∣∣1√
1+2δ0 0
0 1 + 2δ 0
−Vn(1 + 2δ)−32 1 + 2η 1
∣∣∣∣∣∣∣∣∣∣
∣∣∣∣∣∣∣∣∣∣∇vp0
∇ε
∇δ
∣∣∣∣∣∣∣∣∣∣. (3.15)
The radiation patterns for parameters Vn, η and δ are shown in Figure 3.2. For this
31
0.20.40.60.81
30
210
60
240
90 270
120
300
150
330
180
0VnmoEtaDelta
Figure 3.2: Radiation pattern for parameters Vn, η and δ. The red line indicates Vn;the green line indicates η, and the blue line indicates δ.
set of parameters, Vn is sensitive to all the scattering angles, δ is more sensitive to small
scattering angles and η is more sensitive to large scattering angles. Thus, I choose this
set of parameters as the optimal one since I intend to recover all the parameters of the
subsurface. The crosstalk effects between δ and η could be eliminated by adding the
scattering angle information in the inversion process. To reduce the variable effects
of Vn and the other two parameters, I invert Vn for the first several iteration and then
invert these three parameters jointly, which is referred to as the hierarchy method
[33, 28] and is fully described in the workflow.
3.3 The Workflow for This Method
In summary, the hierarchy-inversion strategy used for the multiparameter inversion
includes the following steps:
32
1. Establish initial parameter models in depth and time. The initially estimated
parameters should be good enough to avoid ending up in a local minimum.
2. Select a frequency band to invert within the data.
3. Using the depth version of the models, calculate the synthetic data by solving
the pseudo-acoustic wave equation for VTI media, which was first introduced
by [31].
4. Evaluate the data residual for each shot and organize the data into CMP gath-
ers.
5. Migrate the data residual using the oriented time-domain imaging method. Here
I calculate the extended images along the incident-angle axis.
6. Calculate the parameter’s perturbations.
7. Update Vn for the first several iterations and then parameters δ and η.
8. Repeat steps 3–7 until the data residual is acceptable.
9. Repeat steps 2–8 for the multi-scale approach until the data residual is accept-
able and the frequency range from low to high is covered.
For monoparameter inversion, the implementation is more straightforward and
simple, I need to solve the pure acoustic wave equation to generate the data in step 8,
and only P-wave velocity is inverted in step 7. The only significant computational cost
in this implementation is generating the observed data by solving the wave equation.
The gradient might not be perfect, but it tends to be stable. Besides, the gradient is
rarely perfect in FWI, as it depends on the background velocity model.
33
Velo
city (km
/s)Velo
city (km
/s)Velo
city (km
/s)
Figure 3.3: Monoparameter inversion results: (a) true velocity model, (b) initialvelocity model, and (c) inverted velocity model.
3.4 Numerical Example
3.4.1 Monoparameter Case
I use the multi-scale method introduced by Bunks et al. [5] for the inversion and start
with a peak frequency of 4 Hz. There is a total of four-frequency selection stages used
here ranging from 4 Hz to 10 Hz, and each stage includes five iterations. According
to the assumptions made in the approach I choose the left, laterally smooth, part of
the Marmousi velocity model to test the proposed method. I consider 50 shots with
100 geophones in each shot uniformly distributed in the horizontal direction. Each
shot is a point-source Ricker wavelet.
The initial velocity shown in Figure 3.3b is a smoothed version of the true ve-
locity model shown in Figure 3.3a. The smoothing operator is given by a triangle
34
filtering with a window size of 1/4 of the total grid points in depth and 1/10 of the
total grid points in the horizontal direction. Figure 3.3c shows the inverted velocity
model. To make the comparison more intuitive, I plot the velocities versus depth in
Figure 3.4. Since not all the wavenumber components can be recovered from the pro-
posed inversion, the true velocity here is wavenumber-filtered one. The corresponding
cutting wavenumber is calculated by equation 2.6. Figure 3.5 illustrates the normal-
ized data residual for the first five iterations in the first stage. The data residual
decreases as a function of iteration steps, which means that the simulated data fits
the observed one better and better per iteration. Comparing to the adjoint-state
method, the proposed method saves about two thirds of the total computational cost
per iteration. The most time-consuming part of FWI and the proposed method is
the extrapolation of wavefield. Conventional FWI needs two forward extrapolations
and one backward extrapolation per iteration; the proposed method requires only one
forward extrapolation per iteration.
3.4.2 Multiparameter Case
The next synthetic example is part of Marmousi II model, and the original model is
not anisotropic. I use the following equations ε = 0.25ρ − 0.3 and δ = 0.125ρ − 0.1
to generate the anisotropic models [47]. I also use the multi-scale method for the
inversion and start with a peak frequency of 2 Hz. There is a total of 4 frequency
selection stages used here ranging from 2 Hz to 5 Hz, and each stage contains twenty
iterations. Only the parameter Vn is updated in the first ten iterations in each stage,
then Vn, η and δ are inverted simultaneously. The water layer is set to be isotropic,
and the velocity is assumed to be already known. I consider 50 shots with 100
geophones in each shot uniformly distributed in the horizontal direction. Each shot
is a point-source Ricker wavelet.
The initial models shown in Figure 3.7 are smoothed versions of the true models
35
0
0.2
0.4
0.6
0.8
1
1.2
1.4
1.6
Dep
th (k
m)
1.5 2 2.5 3Velocity (km/s)
Velocities at the Dashed Lines
Initial VelocityTrue VelocityInverted Velocity
Figure 3.4: Comparison of velocity models. The red line indicates true velocity;the dashed green line indicates initial velocity, and the black line indicates invertedvelocity.
1 1.5 2 2.5 3 3.5 4 4.5 50.7
0.75
0.8
0.85
0.9
0.95
1
Nor
mal
ized
Dat
aR
esid
ual
Iteration Steps
Normalized Data Residual for 5 Iterations at 4 Hz
Figure 3.5: Normalized data residual for five iterations at 4 Hz. The data residual isdecreasing with the iteration steps increasing. More iterations should be implementedto get a better approximation to the true velocity in one stage.
36
True Vnmo
0 1 2 3Distance (km)
0
1
2
3
Dep
th (k
m)
1.5
2
2.5
True Eta
0 1 2 3Distance (km)
0
1
2
3
Dep
th (k
m)
0.02
0.04
0.06
0.08
0.1
True Delta
0 1 2 3Distance (km)
0
1
2
3
Dep
th (k
m)
0.05
0.1
0.15
0.2
Inverted Vnmo
0 1 2 3Distance (km)
0
1
2
3
Dep
th (k
m)
1.5
2
2.5
Inverted Eta
0 1 2 3Distance (km)
0
1
2
3
Dep
th (k
m)
0.02
0.04
0.06
0.08
0.1
Inverted Delta
0 1 2 3Distance (km)
0
1
2
3
Dep
th (k
m)
0.05
0.1
0.15
0.2
Vel
ocity
(km
/s)
Vel
ocity
(km
/s)
a)
b)
c)
d)
e)
f)
Figure 3.6: Multiparameter inversion results: (a) true Vn model, (b) true η model, (c)true δ model, (d) inverted Vn model, (e) inverted η model and (f) inverted δ model.
Initial Vnmo
0 1 2 3Distance (km)
0
1
2
3
Dep
th (k
m)
1.5
2
2.5
Initial Eta
0 1 2 3Distance (km)
0
1
2
3
Dep
th (k
m)
0.02
0.04
0.06
0.08
0.1
Initial Delta
0 1 2 3Distance (km)
0
1
2
3
Dep
th (k
m)
0.05
0.1
0.15
0.2
Vel
ocity
(km
/s)
a)
b)
c)
Figure 3.7: Initial models used in mulitiparameter inversion: (a) Vn, (b) η and (c) δ.They are smoothed version of the true models.
37
shown in Figures 3.6a, 3.6b, and 3.6c. The smoothing operator is given by a triangle
filtering with a window size of 1/10 of the total grid points in depth and 1/10 of the
total grid points in the horizontal direction. Figures 3.6d, 3.6e, and 3.6f are inverted
velocity, η and δ at 5 Hz, respectively. Note the fact that the updating range of η
in Figure 3.6e decreases with increasing depth, which matches the previous analysis;
the parameter η mainly affects the traveltime of large scattering angle data. To make
the comparison more intuitive, I plot the parameters versus depth at x = 1.5km
in Figure 3.8. The Vn profile shown in Figure 3.8a can be well recovered since it
has an isotropic radiation pattern. This will influence the full offset range. I only
managed to invert the shallow part of η shown in Figure 3.8b and the inverted result
is acceptable. Since the maximum peak frequency used in the inversion is 5 Hz, the
resolution of the inverted parameter δ is not very high. More details of the models
are expected to be retrieved if I use higher peak frequencies in the inversion. In
multiparameter case, the proposed method saves more computational cost because
more wavefield extrapolations are needed for different parameters in conventional
FWI. However, the implementation of conventional multiparameter FWI is tricky,
for straightforward implementation of FWI, our proposed method can save up to six
sevenths of the total computational cost.
38
0
0.5
1
1.5
2
2.5
3
3.5
Dep
th(k
m)
1 2 3 4Velocity(km/s)
True VnmoInitial VnmoInverted Vnmo
0
0.5
1
1.5
2
2.5
3
3.5
Dep
th(k
m)
0 0.05 0.1
True EtaInitial EtaInverted Eta
0
0.5
1
1.5
2
2.5
3
3.5
Dep
th(k
m)
0 0.1 0.2
True DeltaInitial DeltaInverted Delta
a) b) c)
Figure 3.8: Comparison of the inverted models at x = 1.5km. (a) The red lineindicates true Vn; the green line indicates initial Vn, and the blue line indicates theinverted Vn. (b) The red line indicates true η; the green line indicates initial η, andthe blue line indicates the inverted η. (c) The red line indicates true δ; the green lineindicates initial δ, and the blue line indicates the inverted δ.
39
Chapter 4
Concluding Remarks
4.1 Discussion
Considering the inaccurate velocities we tend to work with at the beginning of the
FWI process; the gradient is usually far from perfect. Using an imperfect algorithm
to compute the gradient is, thus, justified considering its update linearized nature
and the imperfect physical assumptions we usually make. The proposed approach is
based on the assumptions that the density of the media is constant, and the lateral
velocity change is small. Subject to the prestack time-domain migration limitations,
the velocity model can not be too complicated. The cycle skipping problem is a
troublesome problem for local optimization methods and to avoid it we will need a
good initial velocity model. The numerical examples indicate that the performance
of this method depends on the accuracy of the initial velocity model to obtain proper
residual. The results are stable overall thanks to the time domain implementation.
Time-domain based imaging tends to be less sensitive to inaccurate velocities than
depth ones. The new formula for calculating the velocity perturbation is also derived
as a special case when there is no anisotropic and no angle dependence. From the
radiation patterns of the anisotropic parameters, we can find the data dependency on
different parameters. In the data domain, Vn has equal contributions to all scattering
angles, and thus, influences all offsets, which allows for a reasonable retrieval of it
40
from the data. On the other hand, δ mainly affects the amplitude of the near-offset
data, and thus, it promotes the waveform fitting at short offsets in FWI. Meanwhile,
η mainly affects the traveltime of far-offset data; thus, the FWI updating capability
of η reduces with depth.
The real value of this approach is in its ability to handle anisotropy in a more
robust matter, which is usually a challenge in complex media. The opportunity to
divide the update process to an imaging step and a parameter-inversion step allows
for better control of the anisotropy update. A featured seismic impedance inver-
sion method has been utilized for years. However, I utilize this at the update stage
maintaining the more elaborate (FWI) objective of fitting the modeled data to the
observed ones. This approach promises to deliver a practical orthorhombic anisotropy
inversion in a less complex setting. For that case, the number of parameters is much
larger (double at minimum), but so is the required azimuth coverage in the acquisition
to hopefully constrain these parameters.
4.2 Conclusion
Based on the analysis of model wavenumber components, I suggest a cascade inversion
strategy to reconstruct the full model wavenumber components. After time-domain
migration, I apply the analytical Frechet derivations to map the perturbations of
images to the perturbations of model parameters. And I propose a new objective
function in the time image domain. It is based on the fact that the energy of migration
image of the data residual should be zero when the predicted data and observed data
are the same. Because of the oriented time domain imaging method, the migration
image always focuses at zero subsurface offset. This means that no extended migration
images are needed to evaluate the data misfit in the image domain. In addition using
the oriented time-domain migration method allows us to avoid relying on the initial
41
velocity model for the gradient and provides more stable updates. Considering the
poor velocity models we tend to start the FWI method with, the velocity free gradient
calculation can help improve convergence as it has a more convex nature. Another
advantage of the proposed method is that the computational cost is about half of
the conventional full waveform inversion method. This method is also applicable
to VTI anisotropic media. By extending the oriented time-domain migration image
along incident angle axis, I can separate the data dependency on different anisotropic
parameters, which helps eliminate the crosstalk artifacts between them. I used the
optimal parametrization for the proposed VTI anisotropic inversion method, and
the numerical examples verify its effectiveness. The proposed method provides a
robust inversion strategy for anisotropic media. It reduces the extrapolation time
and memory requirements comparing to the conventional FWI algorithms in each
iteration. This method helps more when it is applied to the orthorhombic media.
4.3 Future Research Work
Since the migration algorithm and impedance inversions have been widely used in the
industry, the proposed method should also be applicable for field data. Some primary
tests have been done on a field data set. However, I need to try more parameter sets
to make the inversion results more reliable.
This method can partly handle complex models when applying wavenumber filter
to the data. To fulfill the assumptions made previously, I need to design a wavenumber
filter which preserves only horizontal parts of the subsurface structures.
This proposed method is also applicable to orthorhombic media. It provides a
practical method for orthorhombic inversion due to its reduced memory and compu-
tation requirements. I will extend the existing 2D oriented time migration method to
3D case and also find an optimal parametrization for orthorhombic multiparameter
42
inversion. For 3D case, the computational efficiency of the proposed method becomes
more important for its practical use. Thus, a set of high-level parallel codes needs to
be developed in the future.
43
REFERENCES
[1] J. Virieux and S. Operto, “An overview of full-waveform inversion in exploration
geophysics,” Geophysics, vol. 74, no. 6, pp. WCC1–WCC26, 2009.
[2] P. Lailly, “The seismic inverse problem as a sequence of before stack migrations,”
in Conference on inverse scattering: theory and application, Society for Industrial
and Applied Mathematics, Philadelphia, PA, 1983.
[3] A. Tarantola, “Inversion of seismic reflection data in the acoustic approxima-
tion,” Geophysics, vol. 49, no. 8, pp. 1259–1266, 1984.
[4] W. B. Beydoun and A. Tarantola, “First born and rytov approximations: Model-
ing and inversion conditions in a canonical example,” The Journal of the Acous-
tical Society of America, vol. 83, no. 3, pp. 1045–1055, 1988.
[5] C. Bunks, F. M. Saleck, S. Zaleski, and G. Chavent, “Multiscale seismic waveform
inversion,” Geophysics, vol. 60, no. 5, pp. 1457–1473, 1995.
[6] C. Shin, D.-J. Min, K. J. Marfurt, H. Y. Lim, D. Yang, Y. Cha, S. Ko, K. Yoon,
T. Ha, and S. Hong, “Traveltime and amplitude calculations using the damped
wave solution,” Geophysics, vol. 67, no. 5, pp. 1637–1647, 2002.
[7] Y. Choi and T. Alkhalifah, “Frequency-domain waveform inversion using the
unwrapped phase,” in 2011 SEG Annual Meeting. Society of Exploration Geo-
physicists, 2011.
[8] T. Alkhalifah, “Research note: Full-waveform inversion of the unwrapped phase
of a model,” Geophysical Prospecting, vol. 62, no. 2, pp. 397–403, 2014.
[9] M. K. Sen and P. L. Stoffa, Global optimization methods in geophysical inversion.
Cambridge University Press, 2013.
[10] P. Yang, J. Gao, and B. Wang, “A graphics processing unit implementation of
time-domain full-waveform inversion,” Geophysics, vol. 80, no. 3, pp. F31–F39,
44
2015.
[11] J. R. Krebs, J. E. Anderson, D. Hinkley, R. Neelamani, S. Lee, A. Baumstein,
and M.-D. Lacasse, “Fast full-wavefield seismic inversion using encoded sources,”
Geophysics, vol. 74, no. 6, pp. WCC177–WCC188, 2009.
[12] H. Ben-Hadj-Ali, S. Operto, and J. Virieux, “An efficient frequency-domain full
waveform inversion method using simultaneous encoded sources,” Geophysics,
vol. 76, no. 4, pp. R109–R124, 2011.
[13] C. Castellanos, L. Metivier, S. Operto, R. Brossier, and J. Virieux, “Fast full
waveform inversion with source encoding and second-order optimization meth-
ods,” Geophysical Journal International, vol. 200, no. 2, pp. 718–742, 2015.
[14] P. P. Moghaddam, F. J. Herrmann et al., “Randomized full-waveform inversion:
a dimenstionality-reduction approach,” in 2010 SEG Annual Meeting. Society
of Exploration Geophysicists, 2010.
[15] T. van Leeuwen and F. J. Herrmann, “Fast waveform inversion without source-
encoding,” Geophysical Prospecting, vol. 61, no. s1, pp. 10–19, 2013.
[16] C. Wang, D. Yingst, J. Brittan, P. Farmer, and J. Leveille, “Fast multi-parameter
anisotropic full waveform inversion with irregular shot sampling,” in SEG Tech-
nical Program Expanded Abstracts 2014. Society of Exploration Geophysicists,
2014, pp. 1147–1151.
[17] H. Khaniani, B. John, and M. Gary, “Full waveform inversion algorithm using
time imaging methods,” in CSPG/CSEG/CWLS GeoConvention 2012, 2012.
[18] Z.-D. Zhang, T. Alkhalifah et al., “Full waveform inversion using oriented time-
domain imaging method,” in 2015 SEG Annual Meeting. Society of Exploration
Geophysicists, 2015.
[19] D. Oldenburg, T. Scheuer, and S. Levy, “Recovery of the acoustic impedance
from reflection seismograms,” Geophysics, vol. 48, no. 10, pp. 1318–1337, 1983.
[20] B. H. Russell, Introduction to seismic inversion methods. Society of Exploration
Geophysicists, 1988, vol. 2.
[21] O. Yilmaz, Seismic data analysis. Society of exploration geophysicists Tulsa,
45
2001.
[22] S. Yuan, S. Wang, C. Luo, and Y. He, “Simultaneous multitrace impedance
inversion with transform-domain sparsity promotion,” Geophysics, vol. 80, no. 2,
pp. R71–R80, 2015.
[23] T. Alkhalifah, “Tau migration and velocity analysis: Theory and synthetic ex-
amples,” Geophysics, vol. 68, no. 4, pp. 1331–1339, 2003.
[24] R.-E. Plessix, “A pseudo-time formulation for acoustic full waveform inversion,”
Geophysical Journal International, p. ggs056, 2012.
[25] S. Fomel, “Velocity-independent time-domain seismic imaging using local event
slopes,” Geophysics, vol. 72, no. 3, pp. S139–S147, 2007.
[26] L. Casasanta and S. Fomel, “Velocity-independent τ -p moveout in a horizontally
layered vti medium,” Geophysics, vol. 76, no. 4, pp. U45–U57, 2011.
[27] R.-E. Plessix and Q. Cao, “A parametrization study for surface seismic full wave-
form inversion in an acoustic vertical transversely isotropic medium,” Geophysical
Journal International, vol. 185, no. 1, pp. 539–556, 2011.
[28] V. Prieux, R. Brossier, S. Operto, and J. Virieux, “Multiparameter full waveform
inversion of multicomponent ocean-bottom-cable data from the valhall field. part
1: imaging compressional wave speed, density and attenuation,” Geophysical
Journal International, p. ggt177, 2013.
[29] T. Alkhalifah and R.-E. Plessix, “A recipe for practical full-waveform inversion
in anisotropic media: An analytical parameter resolution study,” Geophysics,
vol. 79, no. 3, pp. R91–R101, 2014.
[30] L. Metivier, R. Brossier, S. Operto, and J. Virieux, “Acoustic multi-parameter
fwi for the reconstruction of p-wave velocity, density and attenuation: precondi-
tioned truncated newton approach,” in 2015 SEG Annual Meeting. Society of
Exploration Geophysicists, 2015.
[31] T. Alkhalifah, “An acoustic wave equation for anisotropic media,” Geophysics,
vol. 65, no. 4, pp. 1239–1250, 2000.
[32] J.-W. Oh, T. Alkhalifah, and D.-J. Min, “Multi-stage full waveform inversion
46
strategy for 2d elastic vti media,” in SEG Technical Program Expanded Abstracts
2015. Society of Exploration Geophysicists, 2015, pp. 1204–1208.
[33] R. Brossier, S. Operto, J. Virieux et al., “Two-dimensional seismic imaging of the
valhall model from synthetic obc data by frequency domain elastic full-waveform
inversion,” in 2009 SEG Annual Meeting. Society of Exploration Geophysicists,
2009.
[34] S. Operto, Y. Gholami, V. Prieux, A. Ribodetti, R. Brossier, L. Metivier, and
J. Virieux, “A guided tour of multiparameter full-waveform inversion with mul-
ticomponent data: From theory to practice,” The Leading Edge, vol. 32, no. 9,
pp. 1040–1054, 2013.
[35] T. Alkhalifah, Full Waveform Inversion in an Anisotropic World: Where are
the Parameters Hiding?, ser. Education tour series. Houten : EAGE, 2014.
[Online]. Available: https://books.google.com.sa/books?id=jTEYrgEACAAJ
[36] ——, “Full model wavenumber inversion (fmwi),” in 77th EAGE Conference and
Exhibition 2015, 2015.
[37] F. Mancini, J. Moss, K. Prindle, and T. Ridsdill-Smith, “Where can full wave-
form inversion have the biggest impact in the exploration and production cycle?”
in 77th EAGE Conference and Exhibition 2015, 2015.
[38] H. Chauris, M. Noble, and C. Taillandier, “What initial velocity model do we
need for full waveform inversion?” in Workshop 11, 70th EAGE Conference
and Technical Exhibition, Eur. Ass. of Geoscientists and Engineers, 2008, pp.
Workshop–11.
[39] A. Weibull and Nilsen, “Initial velocity models for full waveform inversion,” in
2012 SEG Annual Meeting. Society of Exploration Geophysicists, 2012.
[40] T. Van Leeuwen and W. Mulder, “Velocity analysis based on data correlation,”
Geophysical Prospecting, vol. 56, no. 6, pp. 791–803, 2008.
[41] R.-E. Plessix, G. Baeten, J. W. de Maag, M. Klaassen, Z. Rujie, T. Zhifei et al.,
“Application of acoustic full waveform inversion to a low-frequency large-offset
land data set,” in 2010 SEG Annual Meeting. Society of Exploration Geophysi-
cists, 2010.
47
[42] R. Stolt and A. Weglein, “Migration and inversion of seismic data,” Geophysics,
vol. 50, no. 12, pp. 2458–2472, 1985.
[43] P. C. Sava and S. Fomel, “Angle-domain common-image gathers by wavefield
continuation methods,” Geophysics, vol. 68, no. 3, pp. 1065–1074, 2003.
[44] S. Fomel, “Applications of plane-wave destruction filters,” Geophysics, vol. 67,
no. 6, pp. 1946–1960, 2002.
[45] R. G. Pratt, “Seismic waveform inversion in the frequency domain, part 1: The-
ory and verification in a physical scale model,” Geophysics, vol. 64, no. 3, pp.
888–901, 1999.
[46] A. Ruger, “P-wave reflection coefficients for transversely isotropic models with
vertical and horizontal axis of symmetry,” Geophysics, vol. 62, no. 3, pp. 713–722,
1997.
[47] J. Yan and P. Sava, “Elastic wave-mode separation for vti media,” Geophysics,
vol. 74, no. 5, pp. WB19–WB32, 2009.
48
A Papers Submitted and Under
Preparation
• Rao, Y., Wang, Y., Zhang, Z.D., Ning, Y., Chen, X, and Li, J., “Reflection seismic
waveform tomography of physical modelling data“, Journal of Geophysics and Engi-
neering, 13, no. 2 (2016): 146.
• Zhang, Z.D. and Alkhalifah, T, “Full waveform inversion using oriented time-domain
imaging method for VTI medium“, Submitted to Journal of Geophysics International,
2016.
• Zhang, Z.D. and Alkhalifah, T., “Full Waveform Inversion using Oriented Time-
Domain Imaging Method“, SEG Technical Program Expanded Abstracts, 2015.
• Zhang, Z.D. and Alkhalifah, T., “Efficient Quasi-P Wavefield Extrapolation Using
an Isotropic Lowrank Approximation“, EAGE Expanded Abstracts, 2016.
• Zhang, Z.D. and Alkhalifah, T., “Full Waveform Inversion Using Oriented Time-
domain Imaging Method for VTI Medium“, EAGE Expanded Abstracts, 2016.