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Reality Conceptual Computational
MeshVoro
Freeman et a. LBNL
http://sn.wi kipedia.Org/wiki/File:Marcellu
Tetrahedralization of region surrounding
the horizontal well
TIGHT RESERVOIR
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Computational Model Selection
Water
Hydraulic
Fracturing
Water Cycle Acquisitlon
Chemical
Mixing
Produced
Water
Research
Approach
Data
Mining
Conceptual simple
Model <
Computational
Solutions
Wastewater
Treatment
Model
Type
Intellectual
Property
Well
Operations
Lab
Studies
Toxicity
Assessmen
Scenario
Evaluations
Case
Studies
not too
simple
complex
analytical
semi-analytical
numerical
first principles
empirical
stochastic
deterministic
public
domain
trade
secret
open
source
proprietary
-------
Computational Model Selection
Property
multidimensional
multiphase
Attributes
2D, 3D
liquid, gas
temporality (time)
transient
multicomponent
non-isothermal
fractured-media
coupling
water, brine, introduced
chemicals
heat
equivalent continuum, dual
porosity, multiple interacting
continua, dual permeability
fully coupled (mass and
energy), fully implicit
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Conceptual Models Scenarios
Geophysical
likelihood of
pathways?
Potential for
fluid migration?
(a)
V
1
p**1
Groundwater Aquifer
J r
1 I*- Hydro-Fractures
**(' I . \ Shale Gas
^ ^ " Reservoir
MMI-MB
(b)
1
J
1
V
T
pN^
Groundwater Aquifer
,
:N g f . , S,a,eG,s
(0 ^
1
\
V
v
V
Groundwater Aquifer
^~- Oit/Gas Reservoir
'
V
(d)
(
^4
Fault '
=^
Oroundwater Aquifer
X
\^ 1
V>T ! r- ! r ğ V Shal.Gas
E*oĞl-oĞ
W r^^
*
j
)\ '
"
v\
1
Older Well
i
^ '
L. '.
Groundwater Aquifer
H
|^
- Hydro -Fracture
^ 4- 1 n \ Shale Gas
-0 Reservo-r
Not to
r7^>i ii RFF
.ujiijijjmjyl LAWREN
scale!
IKELEY LAB
CE BERKELEY NATIONAL LABORATORY
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Scenario Assumptions
7 sub-domains for modeling (see diagrams)
Shale Open wellbore
Overburden Conventional Petroleum reserve
Aquifer Fault
Fracture
Each sub-domain has defined flow properties:
Permeability
Porosity
Thermal Properties
And geo-mechanical properties:
Vertical stress gradient
Minimum principal horizontal stress
Young's modulus
Poisson's ratio
Fracturing Pressure
Fault properties
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Scenario Assumptions
Properties & Conditions applying to all scenarios:
Constant bottom hole flowing pressure (at the shale reservoir)
Reference value: 3.3 MPa (=500 psi);
Range: 2 MPa to 5 MPa
Water production rate from aquifer (full penetration)
Reference value: 50 m3;
Range: 20 to 100 m3/hr
Initial pressure
Reference value: Hydrostatic;
Range: 1.5*hydrostatic (shale only)
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Scenario Assumptions
Properties & Conditions applying to all scenarios:
Solute diffusion coefficients in water -
Reference cases, from CRC
Salt: 1.5E-9m2/s
Benzene: 1.1 E-9 m2/s
Methane: 1.5E-9m2/s
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Scenario A: Migration Along Well Bore
Qw = 50m3/hr (20-100m3/hr)
Groundwater Aquifer
100m(20m-200m)
970m(100m-3000m)
Hydro-Fractures
30m(10m-100m)
Shale Gas
Constant Bottomhole Pressure = 3MPa (2MPa-5MPa)
Pressure Distribution: Hydrostatic (1.5 x hydrostatic shale only)
ESD11-040
Not to
scale!
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Note: see supplementary slides for properties associated with zones
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Scenario B: Hydraulically Induced Fracture
Qw = 50m3/hr (20-100m3/hr)
Hydraulically-
Groundwater Aquifer
Induced Fracture /^
100m 20m-200m
970m(100m-3000m)
(F2) IGM1
'
.
30 m (10m-100m)
Shale Gas
Reservoir
Constant Bottomhole Pressure = 3MPa (2MPa-5MPa)
Pressure Distribution: Hydrostatic (1.5 x hydrostatic shale only)
ESD11-043
Not to
scale!
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Scenario C: Hydraulically Induced Fracture Through Oil/Gas
Qw = 50m3/hr (20-100m3/hr)
Groundwater Aquifer
F3) (GMU
100m(20m-200m)
Oil/Gas Reservoir
f
970m
(100m-3000m)
F2BIGM1J I
30m(10m-10pm)
Shale Gas
Reservoir
(M) (GMI)
jr
i
en
c
e
o
00
Q}
"6
"rc
y
t:
j
LU
|
Constant Bottomhole Pressure = 3MPa (2MPa-5MPa)
Pressure Distribution. Hydrostatic (1.5 x hydrostatic shale only)
6S011-044
Not to
scale!
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Scenario D: Natural Pathway (Fault or Fracture)
Qw = 50m3/hr (20-100m3/hr)
Groundwater Aquifer
(F3) (GM1
970m(100m-3000m)
30m (10m-10pm)
Shale Gas
Reservoir
c
g
'w
CD
.0
I
LU
o
Constant Bottomhole Pressure = 3MPa (2MPa-5MPa)
Pressure Distribution: Hydrostatic (1.5 x hydrostatic shale only)
ESD11-042
Not to
scale!
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Scenario E: Artificial Pathway (Old Well)
Older Well
^D Qw = 50m3/hr (20-100m3/hr)
Non-Sealed Tubing
Disintegrating
Cement
970m (100m-3000m)
Hydro-Fracture
/W\ 30m (10m-100m)
Shale Gas
Reservoir
Constant Bottomhole Pressure = 3MPa (2MPa-5MPa)
Pressure Distribution: Hydrostatic (1.5 x hydrostatic shale only)
ESD11-041
Not to
scale!
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Publication Plan
1. Gas flow tightly coupled geomechanics
2. 3D Voronoi mesh building
3. RGas and RGasH2O modeling with
TOUGH+
4. RGasH2OCont modeling with TOUGH+
5. T+M coupled flow-thermal-geomechanical
Accepted with minor revisions, SPE Journal
4/8/2013
In preparation
Accepted 6/18/2013 with minor Computers & Geosciences
revisions
In preparation
Published online as proof,
5/22/2013
Computers &
Geosciences
6. Modeling fault reactivation
Published online, 5/14/2013 Journal of Petroleum
Science and Engineering
7. Fracture propagation in the overburden
8. Geomechanical failure of well cement
Assessment of impact
9. Gas migration pathways
10. Contaminant transport pathways
Accepted with minor revisions,
4/18/2013
In preparation
In preparation
In preparation
Int. Journal Rock
Mechanics and Mining
Sciences
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www.epa.gov/hfstudy
Disclaimer: Mention of trade names or
commercial products does not constitute
endorsement by the EPA.
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Supplementary Slides
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F1: Flow properties of sub-domain 1 (shale)
Shale permeability
Reference value: 1.0E-18 m2; Range: 1.0E-16 to 1.0E-21 m2
Shale porosity
Reference value: 0.10; Range: 0.05 to 0.15
Thermal properties (invariable)
Saturated thermal conductivity: 4 W/m/K
Dry thermal conductivity: 1 W/m/K
Rock specific heat: 1000 J/kg
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F2: Flow properties of sub-domain 2 (overburden)
Overburden permeability:
Reference value: 0.0 m2
Overburden porosity
Reference value: 0.05
Thermal properties (invariable)
Saturated thermal conductivity: 4 W/m/K
Dry thermal conductivity: 1 W/m/K
Rock specific heat: 1000 J/kg
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F3: Flow properties of sub-domain 3 (aquifer)
Aquifer permeability
Reference value: 1.0E-12 m2; Range: 1.0E-11 to5.0E-12 m2
Aquifer porosity
Reference value: 0.30; Range: 0.15 to 0.40
Thermal properties (invariable)
Saturated thermal conductivity: 3.5 W/m/K
Dry thermal conductivity: 0.75 W/m/K
Rock specific heat: 1000 J/kg
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F4: Flow properties of sub-domain 4 (fracture)
Fracture permeability: function of aperture b, i.e., k = b2/12 m2
Reference value: b = 1 .OE-3 m; Range: 1 .OE-4 m to 1 .OE-2 m
Fracture porosity
Reference value: 0.70; Range: 0.50 to 1.0
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F5: Flow properties of sub-domain 5 (open wellbore)
Permeability
Reference value: 1 .OE-8 m2
Fracture porosity
Reference value: 1.0
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F6: Flow properties of sub-domain 6 (conventional
petroleum reservoir)
Permeability
Reference value: 1.0E-14 m2
Porosity
Reference value: 0.20
Thermal properties (invariable)
Saturated thermal conductivity: 4 W/m/K
Dry thermal conductivity: 1 W/m/K
Rock specific heat: 1000 J/kg
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F7: Flow properties of sub-domain 7 (fault)
Fault permeability
Reference value: 1.0E-16 m2; Range: 1.0E-14 to 1.0E-19 m2
Fault porosity
Reference value: 0.30; Range: 0.15 to 0.40
Thermal properties (invariable)
Saturated thermal conductivity: 3.5 W/m/K
Dry thermal conductivity: 0.75 W/m/K
Rock specific heat: 1000 J/kg
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GM1: Geomechanical property set 1
Vertical stress gradient (maximum principal stress)
26487 Pa/m, corresponding to an overburden density of about
2700 kg/m3.
Minimum principal horizontal stress
Reference value: 0.6*Vertical stress; Range: 0.5 to 0.7*Vertical
stress
Young's Modulus (Marcellus shale and overburden)
Reference value: 30 GPa; Range: 10-50 GPa
Poisson's ratio
Reference value: 0.2; Range: 0.15 to 0.25
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GM2: Geomechanical property set 2
Tensile strength - Reference cases
Casing-to-cement: 2 MPa
Cement: 5.0 MPa
Shale: 8.0 Mpa
Young's modulus - Reference cases
Casing-to-cement: 10 GPa
Cement: 10.0 GPa
Shale: 30 GPa (4-50 GPa)
Poisson's ratio - Reference cases
Casing-to-cement: 0.18
Cement: 0.18
Shale: 0.35
Fracturing pressure
Depends on depth, up to 150 MPa; extreme case up to 28 GPa
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GM3: Geomechanical property set 3 (fault)
Fault properties - Cohesionless fault with coefficient of friction
Reference value: 0.6; Range: 0.5 to 0.7
Fault properties - residual friction (after slip) in a slip-
weakening model
Reference value: 0.2
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Important references used as data sources
Agrawal, A., Wei, Y, Cheng, K., and Holditch, S.A. 2010. A Technical and Economic Study of Completion Techniques in Five Emergin
US Gas Shales. SPE paper 135396 presented at the SPE Annual Technical Conference and Exhibition held in Florence, Italy 19-22
September.
Cipolla, C.L., Lolon, E.P, Erdle, J.C., and Rubin, B. Reservoir Modeling in Shale-Gas Reservoirs. SPEREE (August 2010) 638-653.
Eseme, E., Urai, J.L., Krooss, B.M. and Littke, R. 2007. AReview of Mechanical Properties of Oil Shales: Implications for Exploitation
and Basin Modelling. Oil Shale, (24) 2.
Fisher, K., and Warpinski, N. 2011. Hydraulic Fracture-Height Growth: Real Data. SPE paper 145949 presented at the SPE Annual
Technical Conference and Exhibition held in Denver, Colorado 30 October-2 November.
Gottschling, J.C. 2009. Horizontal Marcellus Well Cementing in Appalachia. SPE paper 125985 presented at the 2009 SPE Eastern
Regional Meeting held in Charleston, West Virginia, 23-25 September.
Lee, D.S., Herman, J.D., Elsworth, D., Kim, H.T., and Lee, H.S. A Critical Evaluation of Unconventional Gas Recovery from the
Marcellus Shale, Northeastern United States. KSCE Jrounal of Civil Engineering (2011) 15(4):679-687.
Li, Y. 1973. Diffusion of ions in sea water and deep-sea sediments. Geochimica et Cosmochimica Acta, Volume 38, Issue 5, May 1974,
Pages 703-714, ISSN 0016-7037, 10.1016/0016-7037(74)90145-8.
Soeder, DJ. 1988. Porosity and Permeability of Eastern Devonian Gas Shales. SPEFE (March 1988) 116-124.
Yeager, B.B., and Meyer, B.R. 2010. Injection/Fail-off Testing in the Marcellus Shale: Using Reservoir Knowledge to Improve
Operational Efficiency. SPE paper 139067 presented at the SPE Eastern Regional Meeting held in Morgantown, West Virginia 12-14
October.
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