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1. INTRODUCTION
Fault zones are classically described like thick zones
(metres to kilometres depending mainly on the slip
dimension) with a complex internal structure made
up of: (1) a single or multiple core zones, where
most displacements are accommodated, and (2) a
fractured damage zone surrounded by (3) the host
rock [1]. Recent studies on carbonate reservoirs,
have shown that the heterogeneity of a multilayer
sedimentary system could strongly control the fault
zone architecture [2,3].The lithology variations
(shale and limestone) have an important impact on
the fault zone characteristics [4,5]. Shale can be
either a brittle material or a plastic one(s), its
rheology is independent of temperature, depth (or
burial) or strain [6,7]. One of the main consequences
is the capacity of the clays to retard the propagation
of fractures, leading to a strong decrease of the fault
zone thickness in clay formations [3]. In limestone
formations, the damage zone thickness will depend
on the initial properties of the sedimentary layers. In
the porous layers, there is an important
accommodation of the deformation by micro-
mechanisms resulting in a progressive decrease in
the porosity toward the fault core [8]. Inversely, in
the low-porosity layers, deformations are
accommodated toward the fault core by: an increase
in the fracture porosity, in the micro-cracks porosity,
and by displacements along pre-existing fractures
[4]. The fault zone appears as relatively stiff and low
permeable zones intercalated with low stiffness and
high fracture permeability zones that extend one to
tens of meters from the fault following the initial
ARMA 13-246
Relation between fault zone architecture, earthquake
magnitude and leakage associated with CO2 injection in
a multilayered sedimentary system
Pierre Jeanne, Antonio Pio Rinaldi, and Jonny Rutqvist. Lawrence Berkeley National Laboratory, Earth Sciences Division, Berkeley, CA,USA
Frédéric Cappa.
Lawrence Berkeley National Laboratory, Earth Sciences Division, Berkeley, CA,USA
GeoAzur, University of Nice Sophia-Antipolis, Cote d’Azur Observatory, Nice, France
Yves Guglielmi.
CEREGE (UMR7330), Aix-Marseille University, CNRS-IRD, France
Copyright 2013 ARMA, American Rock Mechanics Association
This paper was prepared for presentation at the 47th US Rock Mechanics / Geomechanics Symposium held in San Francisco, CA, USA, 23-26
June 2013.
This paper was selected for presentation at the symposium by an ARMA Technical Program Committee based on a technical and critical review of the paper by a minimum of two technical reviewers. The material, as presented, does not necessarily reflect any position of ARMA, its officers, or members. Electronic reproduction, distribution, or storage of any part of this paper for commercial purposes without the written consent of ARMA is prohibited. Permission to reproduce in print is restricted to an abstract of not more than 200 words; illustrations may not be copied. The abstract must contain conspicuous acknowledgement of where and by whom the paper was presented.
ABSTRACT: In this study, we have examined the influence of the fault zone characteristics on pressure diffusion and fault
reactivation by CO2 injection. Especially, we studied the effect of lithological and rock physical properties on the fault zone
response inside a multilayer sedimentary system. Through numerical analysis, we compared four models where the complexity of
the fault zone internal architecture is considered. Results show how the presence of hydromechanical heterogeneity influences the
pressure diffusion, as well as the effective normal and shear stress evolutions. The more complex the fault zone architecture is and
the more heterogeneities that are present, the faster the pressurization within the damage zone occurs. But, these hydromechanical
heterogeneities (i) strengthen the fault zone resulting in earthquake of smaller magnitude, and (ii) impede fluid migration along the
fault. We also show that the effects of the hydromechanical heterogeneities within the reservoir are negligible relative to those
between the caprock and the reservoir.
properties contrasts and geometry of the sedimentary
layers [4]. Hydraulic injection into boreholes reveals
horizontal and vertical contrasting permeability
values (up to two orders of magnitude) within the
damage zone [9].
Over the last decades, numerous studies based on
hydromechanical models have shown that the
presence of fluids within the fault zone may lead to
the appearance of overpressure that could trigger
earthquakes [10]. This phenomena has been noticed
in projects related to: CO2 sequestration [11], oil
industry [12], or naturally by the upwelling of deep
fluids [13]. Cappa [13] demonstrated that the
damage zone properties significantly affect the
locations and the evolution of fluid overpressures.
Hydromechanical models represent fault cores with
a very low permeability allowing its pressurization
during the fluid injection. Damage zones are
considered either as negligible for small fault zone
[11], or as continuous and thick layers adjacent to
the fault core for mature fault zone. In this last case
the damage zone is represented either with uniform
materials adjacent to the fault surface [14,15], with
material properties varying symmetrically on both
sides of the fault [13,16] or with dissimilar materials
across the fault [17,18]. But, the impacts of the
variations of damage zone thickness related to the
lithology and to the rock physical properties
variations of the host rock (especially in multilayer
reservoir) are never taken into consideration. In this
paper we address the two following questions: (1) is
there a link between fault zone architecture and its
capacity to be reactivated by CO2 injection, and (2)
what are the impacts on the induced seismicity and
on the CO2 leakage? We first present the
methodology used to estimate the magnitude of
seismic events occurring during the fault rupture.
Then, we analyze the hydromechanical behavior of a
fault zone represented either by: (1) a continuous
damage zone, or by a discontinuous damage zone
caused by (2) lithology variations, and plus by (3)
the initial properties of the sedimentary layers in a
limestone reservoir.
2. ESTIMATION OF EARTHQUAKE
MAGNITUDE
The mechanical behavior of the fault core is
represented by a combination of solid elements and
ubiquitous-joints oriented as weak planes in a Mohr-
Coulomb model [10]. The Mohr-Coulomb criterion
for failure can be written as [19]:
nsc ' (1)
where τ is the critical shear stress necessary for slip
occurrence, c is the cohesion, and μs is the static
friction (μs=tanφ, where φ is the friction angle). In
order to allow us to model a sudden slip, we used a
Mohr-Coulomb model with strain softening
frictional strength properties, consistent with a
seismological slip-weakening fault model. In our
model the frictional coefficient varies from a static
value of 0.6 to a value of 0.2 when the shear strain
within the fault zone is greater than a certain critical
value (10-3
), and a rupture occurs.
Following the approach used by Cappa and Rutqvist
[10,20,21] and Mazzoldi et al. [11], the magnitude of
a seismic event is estimated using seismological
theories. The energy releases during an earthquake is
directly correlated with rupture area along the fault
plane and displacement [22,23]. Hanks and
Kanamori [24] proposed a relationship to link these
two parameters with the seismic moment (M0):
M0 = G × Dave × A (2)
where G is the shear modulus of the host rock, Dave
is the average displacement along the fault surface
and A is the rupture area during a single event. M0
can be directly related to magnitude (M) by the
Equations (3) [25]:
M (log10M0 /1.5) 6.1 (3)
3. NUMERICAL MODEL
The simulations were performed using the coupled
thermo-hydro-mechanical simulator TOUGH-FLAC
[26], which link the flow simulator TOUGH2 [27]
and the geomechanical code FLAC3D
[28]. This
simulator is well described by Rutqvist [26], and it
was previously applied to study fault instability
processes related to fluid overpressure [20,21]. The
hydromechanical coupling used in this study relates
the porosity (hm) to the mean stress ('M), and then
the permeability (hm) depends on the porosity
changes. The formulation was first derived by
Davies and Davies [29] and then modified for
carbon sequestration application by Rutqvist and
Tsang [30]:
hm (0 r)exp(5 108 'M )r
hm 0 exp[22.2(hm /0 1)]
(4)
Fig. 1: The modeled hydro-mechanical environment
where subindex 0 refers to the initial unstressed
value (for both porosity and permeability, 0 and 0),
and r is the residual porosity at high stress. We
applied the changes to the fault zone only (damage
zone and fault core).
Figure 1 shows the geometry and initial conditions
of the models (2 km × 2 km). The model extends
vertically from 500 to 2500 m in depth and
horizontally far enough from the injection zone (2
km) to simulate laterally infinite acting conditions.
The model represents a multi-layered carbonate
system. Two thick shale formations (150 m) with
low permeability (kcap = 10-19
m2) isolate a storage
aquifer 100 m in thickness where CO2 is injected.
This aquifer is composed by an alternation of porous
( = 20%) and low permeable layers (k = 10-14
m2)
with low porosity ( = 5%) and more permeable
layers (k = 10-13
m2). Each layer is 5 m thick. The
reservoir above and below the two shale formations
have permeability of 10-14
and 10-17
m2 respectively.
The fault zone is 1 km long, dipping 80° and it is
500 m away from the injection well. Considering a
1000 m-long well the CO2 would be injected at a
constant rate of 20 kg/sec, which corresponds to the
industrial rate, such as the case of In Salah (Algeria)
[31]. The injection occurs during five years.
The fault core is represented by constant
hydromechanical properties (E= 5GPa, K= 10-17
m2),
and is embedded in a damage zone. The damage
zone is 45 m thick, and composes of two parts: a 5 m
thin zone embedding the core (DZ2), surrounding by
a 40m thick area (DZ1). In this way, we can
consider the horizontal hydromechanical
heterogeneity reflecting increases of deformations
toward the fault core. Then, we have performed
three simulations to consider vertical
hydromechanical heterogeneities.
From Model 1 to 4 the damage zone complexity was
added incrementally. Model 1 represents a thin
damage zone (only DZ2) without vertical
heterogeneity. Model 2 considers the impact of
variations in the initial host rock properties on the
damage zone properties, where the permeabilities
increase of two orders of magnitude relative to the
host rock and the Young modulus decrease up to 5
GPa. Model 3 take into account the different
rheology behavior between shale and limestone. The
damage zone is only 5 m thick in the caprock, while
the permeability increases one order of magnitude
and the Young modulus decreases to 9 GPa (Fig.
2c). In Model 4, we also considered different
rheology linked to the variation in rock physical
properties within the limestone (Fig. 2d). In the
initial porous and un-fractured layers, the damage
zone is 5 m thick, while the permeability increase
one order of magnitude
Table 1: Rock characteristics common to the four models in the simulations.
and the Young modulus decrease to 12 GPa. In the
low-porosity and fractured layers the properties are
similar to those used in Model 2 and 3. The
hydromechanical properties common to all the
simulation are given in Table 1.
We set the initial conditions as a linear pore pressure
and temperature gradient (9.81 MPa/km and 25
˚C/km, respectively) with an atmospheric pressure of
0.1 MPa and a temperature of 10 ˚C at the ground
surface. This results in a pore pressure of 5 MPa and
temperature of 22.5 ˚C at the top of our model (at
500 m depth).
Boundaries were open for fluid flow (i.e. at constant
pressure and temperature), except for the left
boundary, where no flow occurred. The simulations
were conducted in an isothermal mode, implying
that the temperature gradient is maintained during
the simulation. Null displacement conditions were
set normal to the left and bottom boundaries,
whereas constant stress was imposed normal to the
right and top boundaries (Fig. 1).
4. MODELLING RESULTS
Common to all the simulations, the results show
sharp stress drops and subsequent fault slips after
several months of CO2 injection, whereas the CO2 is
mainly located near the injection point. Ruptures
nucleate at the bottom of the reservoir and spread
mainly along the fault portion inside the reservoir
and inside the lower caprock. Numerous studies
have described this behavior [11,20]. The pore
pressure increase, inside the reservoir, reduces the
effective stress normal to the fault surface, hence
reducing the shear strength of the fault. The shear
stress along the fault is reduced resulting in a
minimum value at the top of the reservoir. These
shear stress changes are caused by poroelastic
effects occurring within the aquifer, as the pressure
increase (i.e., reservoir swelling). The sum of the
two effects results in a rupture that nucleates at the
bottom of the reservoir.
The four different models show variations at the
rupture in: the timing (129 to 200 days), the seismic
events magnitude (from 2.15 to 3.12), the pressure
change (Fig. 3a), the rupture lengths (from 185 to
596 m) (Fig. 3b), the maximum displacement along
the fault (2.9 to 8.9 cm) and the shear stress
evolution (Fig. 3d). Parameters explaining the time
delay between these models are the evolutions of the
effective normal stress and the shear stress. In Model
1, fluids can flow easiest through the thin damage
zone within the reservoir and the caprock. The good
fluid diffusion prevents an important reservoir
swelling, and the shear stress evolves slowly.
Rupture occurs after 200 days, it extends over 596 m
and results in seismic event of magnitude 3.12. This
large rupture zone is due to the pressure change
within the fault core. The absence of heterogeneity
allows larger pore pressure diffusion (Fig. 3, red
line). In Model 2 and 3 the vertical hydraulic
heterogeneities impedes diffusion (Fig. 3a). The
fluid pressures within the damage zone in the
reservoir evolve faster, leading to a fast decrease of
the effective normal stress and a higher reservoir
Figure 2: Schemes representing the four models of fault zone architecture and their hydro-mechanical properties. Damage
zones are represented by (a) thin and continuous with homogenous properties (Model 1), (b) thick and continuous with
properties varying along with the initial host rock properties (Model 2), or as a discontinuous damage zone caused by (c)
the variation of lithology (Model 3), and by (d) the variation of initial host rock properties inside the reservoir aquifer
(Model 4).
swelling. More important, the larger the permeability
contrast between the caprock and the reservoir are,
the earlier ruptures occurs (Fig.3c). In Model 2 slip
occurs after 155 days, with a seismic magnitude of
2.44 and a rupture extending over 260 m (Fig. 3,
green line). In Model 3, slip occurs after 129 days,
with a magnitude of 2.15 and a rupture extending
over 185 m (Fig. 3, black line). Results for Model 3
and 4 (Fig. 3, blue line) are similar. This means the
effects of the hydromechanical heterogeneities
within the reservoir are negligible relative to those
between the caprock and the reservoir.
Hydraulic heterogeneities influence also the fluid
migration through the fault zone. The most
important leakage occurs in Model 1 (Fig. 4a and b).
4.38% of the total CO2 injected has leaked through
the upper caprock after 5 years, and 5.33% after 20
years. We can notice that most of the leakage
appears during the injection. In Model 2, 3 and 4 no
leakage appears (Fig.4 c, d, e and f). The presences
of low permeable layers within the damage zone
prevent a good fluid migration along the fault, and
help the CO2 to be confined within the injection
reservoir. Less leakage occurs for a more complex
fault zone architecture.
Figure 3: Results of (a) pressure change, (b) slip offset of the fault walls, (c) slip and (d) shear stress evolution at point P
(located at the bottom of the reservoir within the fault) in simulations with TOUGH-FLAC, for the four models.
Figure 4: Evolution of the CO2 plume and leakage at the end of injection (1800 days) and 15 years after (7200 days) for
Model 1 (a & b), Model 2 (c & d), Models 3 and 4 (e & f).
5. CONCLUSION
In this study, we have examined the influence of the
fault zone architecture inside a multilayer
sedimentary system on pressure diffusion within the
fault zone and its activation by CO2 injection. We
have considered the rheological behaviors of the
geological layers affected by the fault. We have
compared deformations and leakages occurring in a
5 m thin fault zone with a homogenous damage zone
and in fault zones nine time bigger (45 m thick) with
heterogeneous properties. It appears that the most
important factors for the hydromechanical behavior
of the fault zone is not its size, but the
hydromechanical contrast within the damage zone
along the fault core. The more complex fault zone
architecture is, the faster slip but with less leakage.
This is caused by the presence of hydromechanical
heterogeneities which (i) favor rapid damage zone
pressurization, and (ii) strengthens the fault zone
(less deformable layers) resulting in small
earthquake, and (iii) prevents a good fluid migration
along the fault. In our simulations, the lack of
difference between Model 3 and 4, indicates that
only the hydromechanical heterogeneities linked to
the lithological variations influence the
hydromechanical behavior of the fault zone.
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