analysis of feasibility of extensive fracture development
TRANSCRIPT
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Analysis of Feasibility of Extensive Fracture Development and Fault Activation Induced by Hydraulic Fracturing
George Moridis, Jihoon Kim and Jonny Rutqvist, LBNL Research Triangle Park • April 17, 2013
Technical Workshop Series: Well Construction/Operation and Subsurface Modeling
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Hydraulic Fracturing
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Fracturing Horizontal wells
Simulation domain
σ H
σ h
σV
Along with the minimum total principal stress
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Sequential Implicit Algorithm
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Fluid- heat flow
Geomechanics
Jp JS T
'σ ε lK
Update porosity permeability
lc,∆Φ lpk , lK
Update mechanical loading
Failure status
Flow: finite volume (e.g., TOUGH+RealGasH2O)
Geomechanics: finite element (e.g., ROCMECH)
Coupled flow & geomechanic simulator, shortly T+M.
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T+M Code
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T+M: TOUGH+RealGasH2O+ROCMECH: Flow + thermal + geomechanical processes Rigorously coupled Processes
• Thermo-poro-mechanics (two-way coupling) • Dynamic multiple continuum approach • Simultaneous tensile & shear failure • Leak-off to the reservoir formation from full 3D flow simulation
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Code Verification (T+M) 2D Plane strain geomechanics
4 Numerical and analytical results are in good agreement.
Poromechanical effects
Fracture propagation
Static fractures
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Failure scenarios (?)
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HF extending from shale to shallow aquifer through the overburden
HF extending from shale to shallow aquifer through weak cement (not discussed today)
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3D Domain
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Horizontal well
x y
z
Fracture plane
Fracture
Traction boundary
6.0E GPa=
0.3ν =
17.10GP MPa=
58.75 oT C=0 78.76 10pk D−= ×
4.0cT MPa=z
Investigate fracture propagation in shale gas reservoirs -properties of Marcellus shale
skgQinj /8=
σ h
σV
σ H
MPa3.23 MPa1.29 MPa4.36
GP
MPa1.17
Fluid Injection
1.0, =iwS
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Fracture Propagation (I)
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Example of fracture propagation
Larger fracture aperture near the fracture top
x z
Fracture aperture Fractured areas
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Fracture Propagation (II)
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Fast pressure diffusion due to high permeability
Saw-tooth (oscillatory) pressure, fracture aperture, displacement
Can be considered as microearthquakes induced by tensile failure
Injection point
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Shear stress study: an example
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2Jx
z
High shear stress near the fracture tips
Investigating the probability of shear failure
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Complex multiphase flow with gravity segregation within the fracture
Coexistence of water & gas 6.0, =iwS
Simple calculation by only the injection volume might significantly underestimate the fracture volume and propagation.
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Water injection: fundamental issues
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9.0, =iwS
Water & gas still coexist within the fracture. Water saturation drops at the time when fracturing occurs.
Does not approach Sw = 1.0
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Higher Injection Rate
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Higher injection rate = faster fracture propagation
skgQinj /16=Higher peak pressure
Injection point
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Heterogeneity effects
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A strong geological formation can block vertical fracture propagation
A strong geological formation with τc = 10 MPa
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Conclusions
• Developed a hydraulic fracturing simulator • Investigated fracture propagation scenarios in Marcellus shales
• Identifying the factors controlling fracture propagation • Estimation based on the injection volume may significantly underestimate the fracture volume & its propagation
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Rigorous modeling of fracture propagation & accurate geophysical monitoring are strongly recommended
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Failure scenarios (?)
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Fault activation during the hydraulic fracturing process
Code: TOUGH+ RealGasH2O+ FLAC3d
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Constant rate of P-increase
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Constant rate of injection
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Acknowledgements • The research described in this presentation has been funded by the U.S.
Environmental Protection Agency through Interagency Agreement (DW-89-922359-01-0, DW-89-922359-01-C) to the Lawrence Berkeley National Laboratory, and by the Research Partnership to Secure Energy for America (RPSEA - Contract No. 08122-45) through the Ultra-Deepwater and Unconventional Natural Gas and Other Petroleum Resources Research and Development Program as authorized by the US Energy Policy Act (EPAct) of 2005. Information presented is part of the EPA’s ongoing study (www.epa.gov/hfstudy). EPA intends to use this, combined with other information, to inform its assessment of the potential impacts to drinking water resources from hydraulic fracturing. Mention of trade names or commercial products does not constitute endorsement or recommendation for use.
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Thank you