Stable-unstable flow of geothermal fluids in fractured rock
Transcript of Stable-unstable flow of geothermal fluids in fractured rock
Stable–unstable flow of geothermal fluids in fractured rock
T. GRAF1 AND R. THERRIEN2
1Center of Geosciences, Georg-August-University Gottingen, Goldschmidtstraße 3, 37077 Gottingen, Germany;2Departement de Geologie et Genie Geologique, Universite Laval, Ste-Foy, Quebec, G1K 7P4, Canada
ABSTRACT
Density-driven geothermal flow in 3-D fractured rock is investigated and compared with density-driven haline flow.
For typical matrix and fracture hydraulic conductivities, haline flow tends to be unstable (convecting) while geother-
mal flow is stable (non-convecting). Thermal diffusivity is generally three orders of magnitude larger than haline dif-
fusivity and, as a result, large heat conduction diminishes growth of geothermal instabilities while low mass diffusion
enables formation of unstable haline ‘fingering’ within fractures. A series of thermal flow simulations is presented to
identify stable and unstable conditions for a wide range of hydraulic conductivities for matrix and fractures. The clas-
sic Rayleigh stability criterion can be applied to classify these simulations when fracture aperture is very small. How-
ever, the Rayleigh criterion is not applicable when the porous matrix hydraulic conductivity is very small, because
stabilizing fracture–matrix heat conduction is independent of matrix hydraulic conductivity. In that case, the numeri-
cally estimated critical fracture conductivity is nine orders of magnitude larger than the theoretically calculated criti-
cal fracture conductivity based on Rayleigh theory. The numerical stability analysis presented here may be used as a
guideline to predict if a geothermal system in 3-D fractured rock is stable or unstable.
Key words: density, fracture, geothermal, numerical model, stable, unstable
Received 21 April 2008; accepted 25 November 2008
Corresponding author: T. Graf, Center of Geosciences, Georg-August-University Gottingen, Goldschmidtstraße 3,
37077 Gottingen, Germany.
Email: [email protected]. Tel: +49-551-39 7919. Fax: +49-551-39 9379.
Geofluids (2009) 9, 138–152
INTRODUCTION
Understanding the circulation of deep groundwater is essen-
tial to address issues related to nuclear waste disposal, seawa-
ter intrusion, and geothermal energy production.
Groundwater flow can be driven by spatial density differ-
ences that can result from increases in salinity (haline flow)
and/or temperature (geothermal flow). When, for example,
a fluid of high density overlies a less dense fluid, the system
is potentially unstable and density-driven flow may take
place, thereby enhancing fluid convection and increasing, for
example, geothermal energy productivity (Farvolden et al.
1988; Kolditz & Clauser 1998; Hurter & Schellschmidt
2003; Graf & Therrien 2005; Bataille et al. 2006). Here, we
will use the term ‘stable’ when referring to non-convecting
systems and ‘unstable’ when referring to convecting systems.
Fractures can highly disturb the convective pattern of
density-driven flow (Murphy 1979; Shikaze et al. 1998;
Valliappan et al. 1998; Bachler et al. 2003; Graf & Therrien
2007a,b). Fractures are high-permeability structures located
within low-permeability rock, and can therefore permit
density-driven convective flow. In that case, unstable ‘fin-
gers’ form where solutes (or thermal energy) are transported
at a rate that is several orders of magnitude larger than that
resulting from diffusion (or conduction) alone. Conversely,
fractures may also dissipate fingers by creating large haline
(or geothermal) gradients between the fracture and the sur-
rounding rock matrix. In that case, diffusion (or conduc-
tion) may reduce the growth of fingers and stabilize
groundwater flow.
Clearly, the magnitude of fracture and matrix permeabil-
ity controls whether a system is convecting (unstable) or
non-convecting (stable). The greater the permeability of
fracture and rock matrix, the greater the potential of con-
vective flow. If fractures are absent or if fracture permeabil-
ity is very low relative to matrix permeability, it can be
expected that the Rayleigh criterion (Rayleigh 1916) can
be used as the stability criterion. Otherwise, the Rayleigh
criterion fails and numerical models have to be used to
simulate density-driven groundwater flow, and to verify
whether a system is stable or unstable. Here, we will apply
the Rayleigh criterion to fractured systems where fracture
Geofluids (2009) 9, 138–152 doi: 10.1111/j.1468-8123.2008.00233.x
� 2009 Blackwell Publishing Ltd
permeability is very small, such that the system can be con-
sidered to be homogeneous.
Numerical simulations of haline convection in 2-D homo-
geneous porous media (Elder 1967; Wooding 1969; Voss &
Souza 1987; Schincariol et al. 1994; Wooding et al. 1997;
Oldenburg & Pruess 1998; Simmons et al. 1999, 2002) and
in 2-D fractured porous media (Graf & Therrien 2007a)
have indicated that: (i) distinct fingers grow near the salt
source; (ii) at early simulation times (<1 year), the number
of fingers is high and distinct convection develops; and (iii)
at later times (>1 year), fingers coalesce to a single dense
plume and convection is less apparent.
Kolditz (1995) numerically investigated 3-D geothermal
flow at the Soultz-sous-Forets site in France, but without
accounting for density variations. Simulations presented by
Kolditz (1995) suggest that high-permeability fractures are
the dominant transport path for geothermal energy and
that conductive heat flow from the fractures into the sur-
rounding rock matrix eliminates thermal gradients at the
fracture–matrix interface.
Bachler et al. (2003) used an analytical model to study the
impact of fracture zones on hydrothermal convection in the
Rhine Graben. They found that temperature anomalies typi-
cally follow fracture zones, suggesting the presence of con-
vection cells with rotation axes normal to the fractures.
Bachler et al. (2003) concluded that low- and high-tempera-
ture anomalies correspond to the downwelling and upwell-
ing regions of the convection cells, respectively. Bachler
et al. (2003) also undertook a 3-D numerical study of ther-
mal convection, which confirmed their analytical results.
The goal of the present study was to investigate further
density-driven geothermal flow in 3-D fractured porous
rock. We used the HydroGeoSphere numerical model
(Therrien & Sudicky 1996; Therrien et al. 2008) to com-
pare convective flow patterns (fingering) of haline and geo-
thermal flow. Furthermore, the role of fracture and matrix
permeability in the generation and dissipation of geothermal
instabilities was investigated. We identify conditions leading
to geothermal convective flow within the fracture plane, and
determine whether fracture–matrix conduction suppresses
unstable flow. Other questions considered here include the
following: Does the number of geothermal fingers change
with time? Is the number of fingers high at early times, and
do fingers coalesce at later times? Does geothermal density-
driven convection also develop in the rock matrix?
NUMERICAL MODEL
The HydroGeoSphere model
HydroGeoSphere is a 3-D variable-density, saturated–
unsaturated groundwater flow, multi-component solute
transport, and heat transfer model for fractured porous
media, and is based on the FRAC3DVS model (Therrien
& Sudicky 1996). The HydroGeoSphere model applies the
control volume finite element (CVFE) method to the flow
equation, the Galerkin finite element method with full
upstream weighting to solute transport and heat transfer
equations (Therrien & Sudicky 1996; Graf & Therrien
2005). It is assumed that 2-D fracture elements and 3-D
matrix elements share common nodes in the 3-D grid.
Thus, heads, concentrations, and temperatures are assumed
to be identical along the fracture–matrix interface.
For haline flow simulations, the flow equation is coupled
with the solute transport equation, and for the case of geo-
thermal flow, the flow equation is coupled with the heat
transfer equation. This coupling arises because density vari-
ations cause nonlinearities in the flow equation. In both
cases, the coupled system of equations is solved by the
Picard iteration.
The HydroGeoSphere model applies the first level of the
Oberbeck–Boussinesq (OB) approximation (Oberbeck
1879; Boussinesq 1903; Holzbecher 1998; Kolditz et al.
1998) to discretize groundwater flow, solute transport and
heat transfer equations. The OB assumption reflects the
degree to which density variations are accounted for. Level
1 of the OB approach considers density effects only in the
buoyancy term of the momentum equation (Darcy equa-
tion) and neglects density in the governing equations. This
assumption is generally correct because spatial density vari-
ations are commonly minor relative to the absolute density
value (Murphy 1979; Evans & Raffensperger 1992; Kol-
ditz et al. 1998; Bachler et al. 2003). The OB assumption
is, however, not valid when density variations are large.
One example where the OB assumption is not valid is
given in Straus & Schubert (1977), who studied natural
convection of water in thick geothermal layers, where tem-
perature differences of 345 K cause fluid density variations
by a factor of 2. In another example, Jupp & Schultz
(2000, 2004) have examined hydrothermal convection cells
in a porous medium where fluid density varies by a factor
of 25. In comparison, fluid density varies by a factor of
1.25 in the simulations presented here, and the level 1 OB
approximation is valid.
The spatiotemporally discretized matrix equations are
solved using the WATSIT iterative solver package for gen-
eral sparse matrices (Clift et al. 1996) and a conjugate gra-
dient stabilized (CGSTAB) acceleration technique (Rausch
et al. 2005). A more detailed description of the model can
be found in Therrien et al. (2008). Governing equations
for groundwater flow, solute transport, and heat transfer
are presented below.
Governing equations
The following three equations describe 3-D haline and
geothermal variable-density flow in porous media (Bear
1988; Holzbecher 1998):
Flow of geothermal fluids in fractured rock 139
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�r � �vf g � Cfluid ¼ SSoh0
otð1Þ
�r � Jsolute � Csolute ¼ �oc
otð2Þ
�r � Jheat � Cheat ¼ �~cð ÞboT
otð3Þ
where Equations (1), (2), and (3) are for fluid flow, sol-
ute transport, and heat transfer, respectively. The diver-
gence operator is given by �[L)1], / is the dimensionless
matrix porosity, v[L T)1] is the average fluid velocity,
SS[L)1] is specific storage, h0[L] is freshwater head, t[T]
is time, c[)] is relative solute concentration, q[M L)3] is
fluid density, �~cð Þb M L�1 T �2H�1� �
is bulk heat capacity,
and T[Q] is absolute temperature. Sources and sinks are
denoted by C, and the solute mass flux and thermal
energy flux are represented by Jsolute and Jheat, respec-
tively, with:
Jsolute ¼ Jadvection þ Jdispersion þ Jdiffusion ð4Þ
Jheat ¼ Jconvection þ Jconduction ð5Þ
The specific storage coefficient accounts for the com-
pressibility of both matrix and fluid, and it is defined as
(Frind 1982):
SS ¼ �0g �m þ ��flð Þ ð6Þ
where q0[M L)3] is reference density, g [L T)2] is gravita-
tional acceleration, am[M)1 L T2] is matrix compressibility
and afl[M)1 L T2] is fluid compressibility.
The fluid flow, solute transport and heat transfer conti-
nuity equations for 2-D discrete fractures are written as
(Therrien & Sudicky 1996; Holzbecher 1998):
�r � vfr� �
� Cfrfluid þ qnjIþ � qnjI� ¼ S fr
S
ohfr0
otð7Þ
�r � J frsolute � Cfr
solute þ XnjIþ � XnjI� ¼ocfr
otð8Þ
�r � J frheat � Cfr
heat þ KnjIþ � KnjI� ¼ �~cð ÞloT fr
otð9Þ
where the last two terms on the left-hand side in each
equation denote normal components of fluid flux, solute
mass flux and heat exchange across the fracture–matrix
interfaces I + and I ). Specific storage in the fracture,
S frS L�1� �
, can be derived from Equation (6) by assum-
ing that the fracture is incompressible, such that
am ¼ 0, and by setting its porosity to 1 (Graf & Therrien
2005):
S frS ¼ �0g�fl ð10Þ
Constitutive equations
Fluid velocity
For variable-density flow conditions, the average fluid
velocity, vi, is a function of both the freshwater head,
h0[L], and relative fluid density, qr ¼ (q/q0) ) 1[)]. Fluid
velocities for matrix and fracture are given by Darcy’s law
(Bear 1988):
vi ¼ �K 0
ij
�
�0
�
oh0
oxjþ �r�j
� �i; j ¼ 1; 2;3 ð11Þ
vfri ¼ �K fr
0
�0
�fr
oh0
oxjþ �fr
r �j cos’
� �i; j ¼ 1;2 ð12Þ
where i and j are spatial indices, l0[M L)1T)1] is reference
viscosity, l and lfr[both M L)1T)1] are fluid viscosity in
matrix and fracture, respectively, xj [L] is space, gj [)] is an
indicator for flow direction with gj ¼ 0 in horizontal
directions and gj ¼ 1 otherwise, and u[)1�] is the incline
of the fracture, with u ¼ 0� for a vertical fracture and
u ¼ 90� for a horizontal fracture. The freshwater hydraulic
conductivities, K0ij and K fr
0 L T�1� �
, of both media are
given by (Bear 1988):
K0ij ¼
�ij�0g
�0
ð13Þ
K fr0 ¼ð2bÞ2�0g
12�0
ð14Þ
where jij[L2] is the permeability of the porous medium,
g[L T)2] is gravitational acceleration, and (2b) [L] is frac-
ture aperture.
Fluid density
If haline flow is simulated, fluid density is only a function
of relative solute concentration c, and it is calculated
with:
� ¼ �0 þo�
oc� c ð15Þ
where ¶q/¶c ¼ (qmax ) q0)/(1 ) 0)[M L)3] is the haline
expansion coefficient. Equation (15) is linear and implies
that freshwater density at c ¼ 0 is q ¼ q0, and that salt-
water density at c ¼ 1 is q ¼ qmax.
If geothermal flow is simulated, fluid density is only a
function of fluid temperature T, and calculated using
(Holzbecher 1998):
140 T. GRAF & R. THERRIEN
� 2009 Blackwell Publishing Ltd, Geofluids, 9, 138–152
where TC [Q] and T [Q] are temperatures in Celsius and
Kelvin, respectively, with T ¼ TC + 273.15.
Fluid viscosity
If haline flow is simulated, the model uses relative
concentration (c ¼ C/C0) as the primary unknown. In
that case, the absolute concentration C is undetermined
and, thus, fluid viscosity has to be assumed to be
constant:
� ¼ �0 ð17Þ
If geothermal flow is simulated, fluid viscosity is only a
function of fluid temperature T, and calculated using (Hol-
zbecher 1998):
Summary of equations for haline and geothermal flow
When simulating haline flow, the HydroGeoSphere model
solves for coupled groundwater flow and solute transport,
and does not consider heat transfer. Flow velocities in the
fracture and the rock matrix are given by Darcy’s law.
Fluid density is calculated using a linear relationship
between density and solute concentration, and fluid viscos-
ity is assumed to be constant.
Here, relative concentration is chosen as the transport
variable because absolute concentrations are a priori
unknown, and fluid viscosity has to be assumed to be con-
stant (Equation 17). This assumption of constant viscosity
for haline flow is a limitation of the results presented here,
because fluid viscosity can change by a factor of 1.5
between freshwater and saltwater. Further studies will
explore the impact of that assumption.
When simulating geothermal flow, HydroGeoSphere
solves for coupled groundwater flow and heat transfer, and
does not consider solute transport. Flow velocities in the
fracture and the rock matrix are given by Darcy’s law.
Table 1 identifies the equations that describe haline and
geothermal flow.
Numerical formulation of buoyancy
HydroGeoSphere simulates variable–density flow in the 3-D
porous matrix and in the 2-D fracture. We use 3-D eight-
node (block) elements to represent the porous rock matrix,
and 2-D three-node (triangular) elements to represent the
non-planar fracture. The numerical formulation of buoyancy
in both matrix and fracture elements is presented below.
Buoyancy vector in 3-D porous matrix elements
Upon discretizing the groundwater flow equation (1) in
the 3-D rock matrix using the CVFE method, the nodal
entries of the buoyancy vector in matrix element e,
ge[L2T)1], are given by
geI ¼
ZV e
K 0ij
�0
��e��e
r �owe
I
ozdV e I ¼ 1; . . . ; 8 ð19Þ
where Ve[L3] is the volume of matrix element e,
��e M L�1T�1� �
is average viscosity in e, ��er �½ � is average
� ¼1000 � 1� TC�3:98ð Þ2
503570 �TCþ283
TCþ67:26
� for 0�C � TC � 20�C
996:9 � 1� 3:17� 10�4 TC � 25ð Þ � 2:56� 10�6 TC � 25ð Þ2�
for 20�C < TC � 175�C
1758:4þ 1000 � T �4:8434� 10�3 þ T 1:0907� 10�5 � T � 9:8467� 10�9 � �
for 175�C < TC � 300�C
8>><>>:
ð16Þ
� ¼1:787� 10�3 � exp �0:03288þ 1:962� 10�4 � TC
�� TC
�for 0�C � TC � 40�C
10�3 � 1þ 0:015512 � TC � 20ð Þð Þ�1:572 for 40�C < TC � 100�C0:2414 � 10 ^ 247:8= TC þ 133:15ð Þð Þ � 10�4 for 100�C < TC � 300�C
8<: ð18Þ
Table 1 Equations used to simulate haline and geothermal flow in fractured
porous rock. Reference is made to the equation number in the text.
Equation Haline flow Geothermal flow
Governing equations
Groundwater flow 1 and 7 1 and 7
Solute transport 2 and 8 NA
Heat transfer NA 3 and 9
Constitutive equations
Flow velocity 11 and 12 11 and 12
Fluid density 15 16
Fluid viscosity 17 18
NA, not applicable.
Flow of geothermal fluids in fractured rock 141
� 2009 Blackwell Publishing Ltd, Geofluids, 9, 138–152
relative density in e, and weI �½ � is the value of the 3-D
approximation function in e at node I. With usual 3-D
approximation functions for regular 3-D block elements
(cf. Istok 1989), Equation (19) can be integrated for all
eight nodes such that the elemental buoyancy vector
becomes
ge¼K0ij
�0
�e �er �
Lx �Ly
4� �1 �1 �1 �1 1 1 1 1f gT ð20Þ
where Lx and Ly[L] are edge lengths of matrix block e in
x- and y-direction, respectively.
Buoyancy vector in 2-D fracture elements
According to Frind (1982) and Graf & Therrien (2005),
nodal entries of the buoyancy vector in fracture element
(fe), gfe[L2 T)1], are calculated as
g feI ¼
ZAfe
K fr0
�0
��fe��fe
r � cos’owfe
I
o�zdAfe I ¼ 1;2;3 ð21Þ
where Afe[L2] is the surface area of fracture element (fe),
��fe M L�1 T�1� �
is the average viscosity in fe, ��fer �½ � is the
average relative density in fe, wfeI �½ � is the value of the 2-D
approximation function in fe at node I, and �z [L] is the
local z-axis of fe. Upon integration in Equation (21), Graf
& Therrien (2007c,2008b) have derived the following
form of the elemental buoyancy vector for 2-D triangular
fracture elements:
gfe ¼ K fr0
�0
��fe��fe
r � cos’1
2
�x3 � �x2
�x1 � �x3
�x2 � �x1
8<:
9=; ð22Þ
where �xI [L] is the value of the local x-coordinate of
node I.
GEOTHERMAL FLOW IN FRACTURED ROCK
Comparison between haline and geothermal flow in
fractured rock
A 2-D test problem of forced convection
A simplified test problem is presented here to highlight
physical differences between haline and geothermal flow
in fractured rock. The flow system is shown in Fig. 1
and consists of a 2-D domain of dimensions 8 m ·10 m. Forced convection (imposed hydraulic gradient
¶h0/¶x ¼ 0.0625) is assumed to be the main lateral dri-
ving force of salt and heat, while density-driven flow is
neglected. An open fracture is located along the x-axis,
in the flow direction, and it is embedded in a low-per-
meability porous rock matrix. The fracture inlet is
assigned Dirichlet boundary conditions, either C ¼ C0 or
T ¼ T0, while all other boundary conditions are assumed
to be zero-dispersive or zero-conductive flux boundaries
(i.e. ¶C/¶n ¼ 0 and ¶T/¶n ¼ 0, where n is the direc-
tion normal to the domain boundary). Simulation
parameters are given in Table 2, and grid spacing is
chosen to satisfy stability criteria formulated by Weathe-
rill et al. (2008).
Results shown in Fig. 1A indicate that haline transport is
controlled by forced convection (advection) in the fracture
and that fracture–matrix diffusion plays a minor role. Con-
versely, thermal transport is dominated by both fracture–
matrix conduction, and conduction within the matrix
(Fig. 1B).
The fundamental difference between haline and geother-
mal flow is that solutes are mainly transported by advective
transport whereas in this example, heat is mainly trans-
ported by heat conduction through the rock formation.
0 . 9
0 . 7
0 . 5
0 . 3
0 . 1
0 . 9
0 . 7
0 . 5
0 . 3
0 . 1
T T = 0
Rock matrix
Fracture
Flow
T T / 0
x - distance (m)
y-
dis
tan
ce (
m)
1 0 2 3 4 5 6 7 8
0
1
2
3
4
5
6
7
8
9
10
0.1
0.3
0.5
0.7
0.9
C C = 0
Rock matrix
Fracture
Flow
C C / 0
x - distance (m)
y-
dis
tan
ce (
m)
1 0 2 3 4 5 6 7 8
0
1
2
3
4
5
6
7
8
9
10
0.1
0.3
0.5
0.7
0.9
(A) (B)
Fig. 1. Comparison of 2-D haline (A) and geothermal (B) forced convection in fractured rock. Simulation parameters are given in Table 2.
142 T. GRAF & R. THERRIEN
� 2009 Blackwell Publishing Ltd, Geofluids, 9, 138–152
Haline diffusivity is typically three orders of magnitude
smaller than thermal diffusivity. Thus, fracture–matrix con-
duction is 1000 times faster than fracture–matrix diffusion.
As a result, thermal gradients between fracture and matrix
equilibrate much faster than haline gradients.
A 3-D test problem of free convection
A second test problem is introduced to compare haline
and thermal free convection in 3-D fractured rock.
Changes of density are fully accounted for (Equations 15
and 16) such that density-driven flow resulting from free
convection is the main driving force.
The model domain for the 3-D test problem is a cubic
box having a side length equal to 10 m. The box repre-
sents a porous matrix and contains a single non-planar
fracture. The fracture is represented by nine planar facets
as shown in Fig. 2, and it is discretized by triangular frac-
ture elements using the technique presented by Graf &
Therrien (2008a). Fracture geometry and facet vertex
locations are given by Graf & Therrien (2008b). Simula-
tion parameters are given in Table 2. The 3-D grid spac-
ing for the haline and the thermal convection simulation
is equal to 0.1 m and 0.143 m, respectively. Numerical
stability analyses have indicated that the spacing used is
appropriate for both haline and thermal convection
simulations.
Two simulations of the 3-D test problem are carried
out: (i) free haline convection; and (ii) free geothermal
convection. Lateral boundaries of both simulations are
assumed to be impermeable and top and bottom bound-
aries are assigned a constant hydraulic head h0 ¼ 0; the
initial condition for flow is h0 ¼ 0. The total simulation
time is 10 years in all cases.
In the first simulation, a constant concentration c ¼ 1 is
assigned to the top boundary, and all other boundaries are
assigned a zero-dispersive flux boundary condition. The
initial concentration is c ¼ 0. In Equation (15), the maxi-
mum density (qmax) is assumed to be equal to
1200 kg m)3, giving the relative density of +0.2 in Equa-
tions (11) and (12).
In the second simulation, a constant temperature
T ¼ 250�C is assigned to the bottom boundary, and all
other boundaries are assigned a zero-conductive flux
boundary condition. Water density at 250�C is about
800 kg m)3, giving the relative density of )0.2 in Equa-
tions (11) and (12). The initial temperature is T ¼ 0�C.
The model does not consider phase changes of water such
that water is assumed to be liquid at 0�C. An additional
simulation with the initial condition T ¼ 1�C, not pre-
sented here, showed that the results are not sensitive to
the initial temperature. Effects associated with the density
maximum at 4�C were also not observed.
Density-driven forces and flow parameters are identical
in both simulations. The two simulations, however, differ
in the transport behavior of species: (i) low haline diffusi-
vity and constant fluid viscosity; and (ii) high thermal
diffusivity and variable fluid viscosity. This difference in
transport behavior is exhibited in Fig. 3. The figure shows
isohalines and isotherms in the fracture at different times.
Clearly, convective (unstable) groundwater circulation
Table 2 Model parameters used for the 2-D and 3-D test problems.
Parameter Value
Reference density* (q0) 1000 kg m)3
Reference viscosity� (l0) 1.124 · 10)3 kg m)1 sec)1
Acceleration due to gravity (g) 9.80665 m sec)2
Tortuosity* (s) 0.1
Matrix permeability*� (jij) 10)15 m2
Matrix porosity§ (/) 0.35
Matrix longitudinal dispersivity* (al) 0.1 m
Matrix transverse dispersivity* (at) 0.005 m
Fracture dispersivity*– (afr) 0.1 m
Fracture aperture*� (2b) 0.05 mm
Aqueous diffusion coefficient* (Dd) 5 · 10)9 m2 sec)1
Specific heat of rock** (~cs) 1030 J kg)1 K)1
Specific heat of water** (~cl) 4184 J kg)1 K)1
Thermal conductivity of rock�� (ks) 2.45 W m)1 K)1
Thermal conductivity of water�� (kl) 0.6 W m)1 K)1
Density of rock**�� (qs) 2650 kg m)3 K)1
*cf. Shikaze et al. (1998).
�cf. Kolditz et al. (1998).�Kept constant unless indicated otherwise.§cf. Frind (1982).–cf. Therrien & Sudicky (1996).**cf. Oldenburg & Pruess (1998).��cf. Bolton et al. (1996).
x - direction (m)
02
46
810
y - direction (m)0 2 4 6 8 10
z -
dir
ecti
on
(m
)
0
2
4
6
8
10
5
1
4
9
8
76
3
2
1
2
3
4
5
6
7
8
9
10
Fig. 2. Geometry of the triangulated non-planar fracture for comparison of
haline and thermal convection. Circled numbers are facet IDs and numbers
in italic are facet vertex IDs.
Flow of geothermal fluids in fractured rock 143
� 2009 Blackwell Publishing Ltd, Geofluids, 9, 138–152
establishes in the case of haline flow, whereas the thermal
flow regime remains stable and convection is absent. The
difference in convective pattern is due to different diffusi-
vities. Low haline diffusivity allows for the existence of
large haline fracture–matrix gradients, thus facilitating the
formation of distinct fingers within the fracture plane.
The number of haline fingers is large at early times, and
the fingers coalesce at later times. On the other hand,
large thermal diffusivity evens out thermal fracture–
matrix gradients, thereby dissipating convection in the
fracture and stabilizing the flow regime. This result is in
agreement with previous findings by Kolditz (1995) and
Bachler et al. (2003).
Fluid viscosity is assumed to be constant for haline flow,
and haline fingers are produced by density variations. In
contrast, fluid viscosity is variable for thermal flow. Visco-
(E)
(F)
(B)
(A)
(C)
0.5 year
(D)
1 year
2 year
0.5 year
1 y
2 yearr
C C / 0
C C / 0
C C / 0
Temperature (°C)
z -
dir
ecti
on
(m
)
x - direction (m)
y - direction (m)
Temperature (°C)
z -
dir
ecti
on
(m
)
x - direction (m)
y - direction (m)
Temperature (°C)
z -
dir
ecti
on
(m
)
x - direction (m)
y - direction (m)
z -
dir
ecti
on
(m
)
x - direction (m)
y - direction (m)
z -
dir
ecti
on
(m
)
x - direction (m)
y - direction (m)
z -
dir
ecti
on
(m
)
x - direction (m)
y - direction (m)
Fig. 3. Comparison of 3-D haline (A–C) and geothermal (D–F) free convection in fractured rock. Density-driven forces and flow parameters are identical.
144 T. GRAF & R. THERRIEN
� 2009 Blackwell Publishing Ltd, Geofluids, 9, 138–152
sity decreases close to the domain bottom (where the
buoyancy effect is large), thereby increasing hydraulic
conductivity and potentially facilitating the generation
of fingers. Nevertheless, varying fluid viscosity in the case
of thermal flow did not appear to facilitate the generation
of thermal fingers (Fig. 3 D-F). This is an intriguing result,
and it is due to the high thermal diffusivity that stabilizes
thermal flow.
The sensitivity of haline flow results to variations of the
parameters listed in Table 2 has been studied by Graf &
Therrien (2007a). The heat transfer parameters listed in
Table 2 are typical for plutonic rock, and are not subject
to major variations. Therefore, the geothermal flow results
presented here can be expected to be insensitive to varia-
tions of heat transfer parameters.
Results presented in this section and in Figs 1 and 3
suggest that fracture and matrix permeability control
whether a geothermal flow regime is stable (convective cir-
culation is absent) or unstable (convective circulation
exists). For example, large fracture permeability leads to
large flow velocities in the fracture, thereby enhancing con-
vective circulation and reducing the relative importance of
fracture–matrix conduction. While Graf & Therrien
(2007c, 2008b) have studied haline flow in the model
domain of Fig. 2, the present paper focuses on stable–
unstable geothermal flow in the same model domain for
different permeability ratios. These simulations are dis-
cussed in the following section.
Stable–unstable geothermal flow in fractured rock
Numerical analysis of stability
A series of 3-D geothermal flow simulations using the
model domain shown in Fig. 2 is simulated. In each simu-
lation, matrix and fracture permeability are modified, and
each simulation is classified as ‘unstable’ or ‘stable’
depending on whether convective circulation occurred or
not, respectively. Circulation was detected visually by
inspecting the velocity field in the fracture. Convection
occurs if a circular pattern in the flow field is observed.
Table 3 summarizes stable/unstable simulations, and pro-
vides corresponding matrix and fracture conductivity that
have been calculated using Equations (13) and (14).
Hydraulic conductivities equal to 10)50 and 10)25 m sec)1
both correspond to the same scenario where the rock
matrix is essentially impermeable. However, simulations
using both values are shown for completeness, to cover a
wide range of values for the matrix.
Figure 4 shows that some geothermal flow simulations
(where each simulation is labelled as sim in the text) are
unstable with distinct convective patterns (e.g. sim 6, 9, 11,
12, 14), while others are stable with undisturbed horizontal
isotherms (e.g. sim 5, 8, 18, 20, 21). Figure 5 shows the sta-
bility behavior of each simulation listed in Table 3 as a func-
tion of fracture and matrix conductivity. The grey curve
shown in Fig. 5 separates the plot area into an area of stable
simulations and an area of unstable simulations. Crossing
the grey curve from the stable field to the unstable field rep-
resents the onset of instability. We applied the Rayleigh cri-
terion to address whether the position of the vertical and
horizontal segments of the grey curve can be predicted.
A modified form of sim 18 (stable) was simulated where
the system was perturbed by increasing the initial tempera-
ture on facet vertex 5 by 10%, as previously done by
Weatherill et al. (2004) for a haline convection problem.
That perturbation does not trigger convection, suggesting
that the generation of fingers is only attributed to the pres-
ence of a buoyancy force that is larger in facets 6 and 7
(vertical) than in facets 8 and 9 (inclined).
In heterogeneous (e.g. fractured) media, the classical Ray-
leigh criterion fails to predict the onset of unstable flow. The
reason is that the 2-D fracture is located within a thermally
conducting medium. Therefore, a Rayleigh criterion for the
fracture-only situation can not be applied. However, if a very
small fracture aperture is assumed, presence of the fracture
may be neglected, and homogeneity can be assumed. In that
case, the thermal Rayleigh number for the porous matrix,
Ra [)], can be formulated as (Nield & Bejan 1999):
Table 3 Summary of stable/unstable geothermal flow simulations and cor-
responding matrix and fracture hydraulic conductivities.
Simulation ID
Matrix–K0ij
(m sec)1)
Fracture–K fr0
(m sec)1)
Fracture
aperture
(mm)
Stable simulations
2 10)50 72.706 10
3 10)50 290.826 20
5 10)50 454.415 25
8 10)25 454.415 25
15 10)10 454.415 25
16 10)8 454.415 25
17 10)8 491.496 26
18 10)8 530.030 27
20 10)8 290.826 20
21 10)8 7.27 · 10)7 0.001
23 10)10 530.030 27
Unstable simulations
1 10)50 744.514 32
4 10)50 654.358 30
6 10)50 570.019 28
7 10)25 654.358 30
9 10)25 570.019 28
10 10)10 570.019 28
11 10)5 570.019 28
12 10)5 491.496 26
13 10)5 418.789 24
14 10)5 290.826 20
19 10)8 570.019 28
22 10)5 7.27 · 10)7 0.001
The IDs of simulations whose results are presented in Fig. 4 are highlighted(in bold and italic).
Flow of geothermal fluids in fractured rock 145
� 2009 Blackwell Publishing Ltd, Geofluids, 9, 138–152
Ra ¼ � � g � � � � � DTð Þ �H� �Dth
ð23Þ
where b [Q)1] is thermal expansion coefficient, j [L2] is
permeability, DT [Q] is temperature difference between
top and bottom of the model domain, H [L] is domain
height, and Dth[L2 T)1] is thermal diffusivity of the porous
matrix (Nield & Bejan 1999).
The Rayleigh criterion states that unstable flow begins if
Ra is larger than the critical Rayleigh number Rac. In a
homogeneous (e.g. unfractured) system with boundary
conditions described above, we have Rac ¼ 3 (Nield &
sim 6 t = 0.3 year sim 12 t = 0.1 year
sim 14 t = 0.1 yearsim 9 t = 0.3 year
sim 11 t = 0.1 year sim 5,8,18,20,21 t = 0.1 year
(E)
(F)
(B)
(A)
(C)
(D)
z -
dir
ecti
on
(m
)
Temperature (°C)
x - direction (m)
y - direction (m)
z -
dir
ecti
on
(m
)
Temperature (°C)
x - direction (m)
y - direction (m)
z -
dir
ecti
on
(m
)
Temperature (°C)
x - direction (m)
y - direction (m)
z -
dir
ecti
on
(m
)
Temperature (°C)
x - direction (m)
z -
dir
ecti
on
(m
)
Temperature (°C)
x - direction (m)
y - direction (m)
z -
dir
ecti
on
(m
)
Temperature (°C)
x - direction (m)
y - direction (m)
y - direction (m)
Fig. 4. Selected scenarios of stable-unstable geothermal flow in 3-D fractured rock. Convection cells and thermal fingers develop in unstable scenarios (e.g.
sim 6, 9, 11, 12, 14; A–E), while stable scenarios are characterized by undisturbed horizontal isotherms (e.g. sim 5, 8, 18, 20, 21; F). Associated fracture and
matrix conductivities are given in Table 3.
146 T. GRAF & R. THERRIEN
� 2009 Blackwell Publishing Ltd, Geofluids, 9, 138–152
Bejan 1999). We used Equation (23) to calculate the
matrix permeability that corresponds to Ra ¼ 3. With
Equations (16) and (18), we calculated water density and
viscosity at 125�C, which is the average between initial
temperatures on top (0�C) and bottom (250�C) of the
model domain. The thermal expansion coefficient at
125�C is b ¼ 10)3 K)1 (Holzbecher 1998). The critical
matrix permeability for Ra ¼ 3 was obtained as
1.78 · 10)14 m2, and the critical matrix hydraulic conduc-
tivity is 7.43 · 10)7 m sec)1. Therefore, the vertical grey
line shown in Fig. 5 represents the Rayleigh criterion
Ra > Rac to predict the onset of unstable flow.
Likewise, if a very low matrix hydraulic conductivity is
assumed, unstable flow occurs only in the fracture. If the
rock matrix is neglected for the moment, the criterion
Ra ¼ 3 gives the critical fracture aperture as
3.97 · 10)4 mm [where fracture permeability ¼ (2b)2/
12], and the critical fracture hydraulic conductivity is
5.49 · 10)7 m sec)1. However, the critical fracture
hydraulic conductivity obtained from plotting numerical
results (Fig. 5) is 550 m sec)1, exceeding the theoretically
calculated conductivity by nine orders of magnitude. The
very high fracture conductivity required to trigger unstable
flow is due to stabilizing conductive heat flux from the
fracture into the low-permeability rock matrix. Only an
increase of fracture conductivity by the factor 109 leads to
destabilizing convection in the fracture that is larger than
stabilizing fracture–matrix conduction.
Clearly, hydraulic conductivities of matrix and fracture
control whether thermal convection in the fracture occurs
(Fig. 5). When matrix conductivity increases and fracture
conductivity is very small (crossing the vertical line of
Ra ¼ 3 in Fig. 5), thermal convection occurs in the
porous matrix but not in the fracture. The reason is that:
(i) fracture velocities are too small for convection to occur,
and (ii) the Rayleigh criterion (Ra > Rac ¼ 3) determines
the onset of convection in the matrix. For example, the
convective pattern shown in Fig. 4 for sim 14 represents
convection in the matrix, not in the fracture. Interestingly,
the high-temperature zone (for sim 14), whose center is
located at x 7 m, y 8 m, z 3 m, is therefore a cross-
section of a thermal finger that is located in the matrix and
that is rising across the fracture.
Conversely, increasing fracture conductivity at small
matrix conductivity (crossing the horizontal line in Fig. 5)
leads to thermal convection only within the fracture plane.
For example, for sim 6 and sim 9, convection in the matrix
is absent because the vertical line of Ra ¼ 3 has not been
crossed. Therefore, the results of sim 6 and sim 9 are virtu-
ally identical, and only show thermal convection in the
fracture (Fig. 4).
Unstable geothermal flow in 3-D fractured rock
In this section, we discuss the formation of fingering in
unstable geothermal flow systems. Fig. 6 presents results of
unstable geothermal flow of sim 12. Isotherms in the frac-
ture are shown in Fig. 6A–C. Clearly, unstable flow with
distinct fingering develops in the fracture. The number of
fingers decreases from 6 (0.05 year) to 4 (0.1 year) to 2–3
(0.15 year), which is in agreement with results of haline
fingering. Comparison of isotherms at early times
(Fig. 6A,D) indicates that the high-permeability fracture
acts as a trigger to form unstable fingers. Interestingly,
geothermal instabilities also grow in the porous matrix as
illustrated in Fig. 6E,F. The reason is that sim 12 plots on
the right of the Ra ¼ 3-line in Fig. 5, thus falling into an
area where unstable flow is initiated by large matrix con-
ductivity.
0
200
400
600
800
1E-60 1E-50 1E-40 1E-30 1E-20 1E-10 1E + 00
Stable Unstable
Clay Granite Dolomite Limestone Sandstone
Basalt Schist
Tuff
Matrix - (m sec–1)K ij 0
Fra
ctu
re -
(m
sec
–1)
K 0 fr
Fra
ctu
re a
per
ture
(m
m)
30
10
15
20
0
25
Ra
=3
6 9 11
14
12 18 5 8
20
21
4
1
7
10 19
16 13
22
3
2
23
15 17
Fig. 5. Stability diagram showing fracture
hydraulic conductivity vs. matrix hydraulic con-
ductivity. Here, the stability index is shown by
symbol ‘�’ when a simulation was classified as
stable and by symbol ‘·’ when it was classified
as unstable. The results show the dependence of
stability/instability on hydraulic conductivity of
both fracture and matrix. The grey curve indi-
cates the approximate locus of minimum critical
fracture–K0fr or matrix–K0
ij required to produce
unstable geothermal flow. The IDs of simulations
whose results are presented in Fig. 4 are high-
lighted (in bold and italic).
Flow of geothermal fluids in fractured rock 147
� 2009 Blackwell Publishing Ltd, Geofluids, 9, 138–152
Results presented in Fig. 5 suggest that, in low-perme-
ability fractured rock (clay, granite), thermal convection
will only occur for extremely large fractures of aperture
>27 mm, as shown by the horizontal line in Fig. 5. On the
other hand (as demonstrated by Graf & Therrien 2008b),
haline convection happens at much smaller fracture
(E)
(F)
(B)
(A)
(C)
(D)
0.05 year 0.05 year
0.1 year
0.15 year 0.15 year
0.1 year
Temperature (°C)
z -
dir
ecti
on
(m
)
x - direction (m)
y - direction (m)
Temperature (°C)
z -
dir
ecti
on
(m
)
x - direction (m)
y - direction (m)
Temperature (°C)
z -
dir
ecti
on
(m
)
x - direction (m)
y - direction (m)
Temperature (°C)
z -
dir
ecti
on
(m
)
x - direction (m)
y - direction (m)
Temperature (°C)
z -
dir
ecti
on
(m
)
x - direction (m)
y - direction (m)
Temperature (°C)
z -
dir
ecti
on
(m
)
x - direction (m)
y - direction (m)
Fig. 6. Results of geothermal convection in 3-D fractured rock (sim 12) with isotherms 25�C to 225�C (interval 25�C). Figures (A–C) show isotherms in the
fracture, indicating that the number of thermal fingers decreases with time. Figures (D–F) show isotherms in the porous matrix along three cross-sections,
indicating that geothermal instabilities also grow in the porous matrix as illustrated in (E) and (F).
148 T. GRAF & R. THERRIEN
� 2009 Blackwell Publishing Ltd, Geofluids, 9, 138–152
apertures. It can therefore be concluded that thermal
convection in fractured rock can only be established in very
high-permeability fracture zones.
The finding of unstable thermal fingering in the porous
matrix (Fig. 6E,F) contrasts with the results of unstable
haline flow in 3-D fractured rock (Graf & Therrien
2008b). In the latter case, fingers are restricted to the frac-
ture, and low fracture–matrix diffusion is the key process
to enable haline fingering in the fracture.
SUMMARY AND CONCLUSIONS
In this study, we investigate stable–unstable geothermal
flow in 3-D fractured rock. Results are compared with
haline flow, and difference in haline and thermal diffusivi-
ties is shown to be the reason for different behavior of
haline and thermal flow. For given matrix and fracture
hydraulic conductivities, haline flow tends to be unstable
(convecting) while thermal flow is stable (non-convecting).
The reason is that thermal diffusivity is generally three
orders of magnitude larger than haline diffusivity. Thus,
low diffusion enables formation of unstable ‘fingering’
while large conduction diminishes growth of instabilities.
A series of stable–unstable thermal flow simulations was
then carried out where hydraulic conductivity of matrix
and fracture vary over a wide range. Simulations indicate
that the classic Rayleigh criterion can be applied when frac-
ture aperture is very small. Conversely, the Rayleigh crite-
rion fails when the porous matrix is assumed to be
impermeable because stabilizing fracture–matrix conduc-
tion is independent of matrix hydraulic conductivity. The
numerically estimated critical fracture conductivity is nine
orders of magnitude larger than the theoretically calculated
critical fracture conductivity based on Rayleigh theory.
Simulations of a selected scenario of unstable thermal
flow (sim 12) illustrate that unstable ‘fingers’ form in the
fracture (Fig. 6). At early simulation times, the number of
fingers is high and distinct convection develops while at
later times, fingers coalesce and convection is less apparent.
This result is in agreement with findings of prior free con-
vective flow studies in homogeneous and heterogeneous
media (Wooding 1969; Wooding et al. 1997; Simmons
et al. 1999, 2002; Graf & Therrien 2008b).
Another result of the sim 12 simulation is that unstable
thermal fingers also grow within the porous matrix. This
outcome contrasts with the results of unstable haline flow
in 3-D fractured rock (Graf & Therrien 2008b) where
the presence of fingers is restricted to the fracture. In that
case, low haline fracture–matrix diffusion prevents finger
growth in the matrix but enables haline fingering in the
fracture.
In summary, results presented here indicate that:
(1) Low haline diffusivity facilitates the formation of dis-
tinct fingers in a fracture.
(2) Large thermal diffusivity evens out thermal fracture–
matrix gradients, thereby stabilizing the flow in a frac-
ture.
(3) Fracture and matrix permeability control whether a
geothermal flow regime is stable or unstable.
(4) The classic Rayleigh criterion can be applied in frac-
tured rock when fracture aperture is very small.
(5) The Rayleigh criterion fails in fractured rock when the
porous matrix is assumed to be impermeable.
(6) In unstable geothermal flow regimes, numerous ‘fin-
gers’ form at early times. The number of fingers
decreases with time. This outcome is in agreement
with results of haline flow.
(7) Thermal convection in fractured rock can only be
established in very high-permeability fracture zones.
(8) In unstable thermal 3-D flow regimes, thermal fingers
grow in the fracture and porous matrix. This outcome
contrasts with the results of 3-D unstable haline flow
where fingers only form in a fracture.
The results presented here are also applicable to larger
spatial domains because the scale considered here (10 m)
allows for simulating all relevant processes (convection,
conduction, fracture–matrix interaction) of thermal flow.
On a larger scale, the convective pattern may be different,
but the effect of thermal convection within the fracture,
relative to fracture–matrix conduction, can be expected to
be identical to those at the scale of this study.
This study has shown that it is important to analyze
haline and geothermal convection within a 3-D framework.
Clearly, numerically estimated stability criteria of 2-D sys-
tems are not applicable to 3-D. The numerical stability
analysis presented here may help to predict if other scenar-
ios of thermal flow in 3-D fractured rock are stable or
unstable. This classification could aid to predict the long-
term efficiency and productivity of geothermal systems.
While the present study and the study by Graf & Therrien
(2008b) focus on haline and thermal convection in
fractured rock, respectively, the interaction between thermal
and haline (thermohaline) convection in fractured rock
remains unexplored. Because temperature and salt have
different diffusivities, thermohaline convection is commonly
termed ‘double-diffusive convection’ (DDC) (Pritchard &
Richardson 2007). DDC has been studied in: (i) homoge-
neous porous media (Evans & Nunn 1989; Fournier 1990;
Oldenburg et al. 1995; Oldenburg & Pruess 1998; Beji
et al. 1999); (ii) anisotropic porous media (Tyvand 1980);
(iii) oceans (Stern 1960; Turner 1979; Schmitt 1994); (iv)
laboratory experiments (Yoshida et al. 1987; Turner 1995);
and (v) groundwater wells (Love et al. 2007), where
DDC is properly documented and understood (Brandt &
Fernando 1995).
Double-diffusive convection occurs in many systems
including geothermal reservoirs, waste disposal, groundwa-
ter contamination, chemical transport in packed-bed reac-
Flow of geothermal fluids in fractured rock 149
� 2009 Blackwell Publishing Ltd, Geofluids, 9, 138–152
tors, grain-storage installations, food processing and others.
Recently, double-diffusive natural convection in porous
media has received considerable attention in the context of
numerous potential applications. Fournier (1990) has
hypothesized that DDC plays a major role in the dynamics
of a geothermal reservoir. Fournier (1990) has pointed out
that ‘few geochemists and reservoir engineers involved with
the exploitation of geothermal resources appear to be aware
of this phenomenon’ and that ‘reservoir engineers should
keep in mind that double-diffusive convection may greatly
influence results of tracer tests and the behavior of injected
waste fluids’. Fournier’s hypothesis has been confirmed
later by Oldenburg & Pruess (1998) who performed
numerical simulations in the Salton Sea Geothermal System
in Southern California, showing that DDC in geothermal
reservoirs is a key process.
However, many questions remain to be answered about
the nature of DDC in active geothermal systems. Little is
known about the size and shape of individual DDC cells
that may form in rocks of different porosities or in frac-
tured rocks, or about the conditions under which indivi-
dual cells may form and persist.
Double-diffusive convection may explain layered convec-
tion and the occurrence of distinct fluid types in geothermal
reservoirs, where different convection cells contain locally
well-mixed fluids (Fournier 1990; Oldenburg & Pruess
1998). However, the presence of fractures has been
neglected in previous studies of DDC, although fractured
geothermal reservoirs are systems where DDC is likely to
control the transport of thermal energy. Therefore, DDC in
fractured rock will be the subject of our future studies.
ACKNOWLEDGEMENTS
We thank Ontario Power Generation (OPG), the Nuclear
Waste Management Organization (NWMO), and the Natu-
ral Sciences and Engineering Research Council of Canada
(NSERC) for financial support of this project. Author TG
wishes to acknowledge Martin Sauter (Georg-August-
University Gottingen) for providing travel funds. We thank
the editorial board of Geofluids (Steve Ingebritsen, Martin
Appold, Peter Nabelek) and two anonymous reviewers for
giving detailed comments that considerably improved the
manuscript.
NOMENCLATURE
Latin letters
(2b) [L] Fracture aperture
A [L2] Surface area
~c [L2 T)2Q)1] Specific heat
c [)] Relative solute concentration
C [M L)3] Absolute solute concentration
Dd [L2 T)1] Aqueous diffusion coefficient
Dth [L2 T)1] Thermal diffusivity
g [L T)2] Acceleration due to gravity
h0 [L] Equivalent freshwater head
H [L] Domain height
I+ I) [)], Fracture–matrix interface
J Variable flux
k [M L T)3Q)1] Thermal conductivity
K0ij [L T)1] Freshwater hydraulic conductivity of porous
matrix
K fr0 [L T)1] Freshwater hydraulic conductivity of fracture
Lv [L] Geometry of porous matrix element v ¼ x,y,z
q [M L)3 T)1] Fluid flux
Ra [)] Rayleigh number
Rac [)] Critical Rayleigh number
SS [L)1] Specific storage
t [T] Time
T [Q] Absolute temperature in Kelvin
TC [Q] Relative temperature in centigrade
v [L T)1] Linear flow velocity
w [)] Approximation function
Greek letters
afl [M)1 L T2] Fluid compressibility
afr [L] Fracture dispersivity
al [L] Matrix longitudinal dispersivity
am [M)1 L T2] Matrix compressibility
at [L] Matrix transverse dispersivity
b [Q)1] Thermal expansion coefficient
C variable Sources and sinks
gj [)] Indicator for flow direction
j [L2] Permeability
K [M T)3] Convective–dispersive–conductive heat flux
l [M L)1 T)1] Fluid viscosity
q [M L)3] Fluid density
qr [)] Relative fluid density
s [)] Factor of tortuosity
/ [)] Matrix porosity
u [1�] Fracture incline
X [M M)1 T)1] Advective–dispersive–diffusive solute flux
Sub- and superscripts
0 [)] Reference fluid
b [)] Bulk
e [)] Porous matrix element
fe [)] Fracture element
fr [)] Fracture
i, j [)] Spatial indices
I [)] Nodal index
l [)] Liquid phase
n [)] Normal direction
s [)] Solid phase
Special symbols
¶ [)] Partial differential operator
150 T. GRAF & R. THERRIEN
� 2009 Blackwell Publishing Ltd, Geofluids, 9, 138–152
D [)] Difference
� [L)1] Divergence operator
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