Development of connected permeability in massive crystalline rocks through hydraulic fracture propagation and shearing accompanying fluid injection

Preisig, Giona; Eberhardt, E.; Gischig, Valentin; Roche, Vincent; Baan, Mirko van der; Valley, Benoît; Kaiser, Peter K.; Duff, Damien; Lowther, Robert

doi:10.1002/9781119166573.ch26

Cited by 21 publications

(26 citation statements)

References 18 publications

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“…As shown in Figure a, we consider a simple configuration of hydroshear failure for the MEQs generated during stimulation of fractured reservoirs. A shear displacement of δ (m) is uniformly applied to a square fracture plane with a fracture length of l (m), although in reality the shear displacement would have a nonuniform distribution [ Preisig et al , ]. For such a MEQ, the seismic moment is defined as [ Aki and Richards , ]

M_{0} = μ_{0} A δ,

where M 0 is the seismic moment (N m), μ 0 is the shear modulus for the host rock, and A is the surface area of the fracture (m 2 ).…”

Section: Resultsmentioning

confidence: 99%

Linking microearthquakes to fracture permeability change: The role of surface roughness

Ishibashi

Watanabe

Asanuma

et al. 2016

Geophysical Research Letters

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Despite its importance, the relation between microearthquakes (MEQs) and changes in hydraulic properties during hydraulic stimulation of a fractured reservoir has rarely been explored, and it is still not well understood. To investigate this relation, we first formulate a plausible scale dependence, where fracture length and shear displacement are variables, for channeling flow through heterogeneous aperture distributions for joints and faults. By combining this formulation with the concept of the seismic moment, we derive quantitative relations between the moment magnitude (Mw) of MEQs and the fracture permeability change in the directions orthogonal to (kfault,⊥/kjoint) and parallel to (kfault,∥/kjoint) the shear displacement, in the form kfault,⊥true/knormaljnormalonormalinormalnnormalt=116.4×100.46Mw and kfault,true/true/true/knormaljnormaloint=13.1×100.46Mw. Despite the simplicity of the derivation, these relations have the potential to explain the results of field experiments on hydraulic stimulation, such as the enhanced geothermal systems at Soultz‐sous‐Fôret and Basel.

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M_{0} = μ_{0} A δ,

where M 0 is the seismic moment (N m), μ 0 is the shear modulus for the host rock, and A is the surface area of the fracture (m 2 ).…”

Section: Resultsmentioning

confidence: 99%

Linking microearthquakes to fracture permeability change: The role of surface roughness

Ishibashi

Watanabe

Asanuma

et al. 2016

Geophysical Research Letters

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“…Recent research on enhanced geothermal reservoirs (Preisig et al 2016;Miller 2016;Taron et al 2016), ore-forming systems (Micklethwaite et al 2016;Weis 2016), and the hydrologic effects of earthquakes (e.g. Okada et al 2016) yields broadly consistent results regarding permeability enhancement by dynamic stresses.…”

Section: Static or Dynamic Permeability?mentioning

confidence: 81%

Crustal permeability

Ingebritsen

Gleeson

2017

Hydrogeol J

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“…Information on the in situ stress state is fundamental to any seismo‐thermo‐hydro‐mechanical characterization of fractured reservoirs (Amann et al, ; Ghassemi, ; Preisig et al, ; Zoback, ). Complete characterization of a stress tensor requires six parameters at any point.…”

Section: In Situ Stress Characterizationmentioning

confidence: 99%

Fracture Network Characterization Using Stress‐Based Tomography

et al. 2018

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Information on structural features of a fracture network at early stages of Enhanced Geothermal System development is mostly restricted to borehole images and, if available, outcrop data. However, using this information to image discontinuities in deep reservoirs is difficult. Wellbore failure data provides only some information on components of the in situ stress state and its heterogeneity. Our working hypothesis is that slip on natural fractures primarily controls these stress heterogeneities. Based on this, we introduce stress‐based tomography in a Bayesian framework to characterize the fracture network and its heterogeneity in potential Enhanced Geothermal System reservoirs. In this procedure, first a random initial discrete fracture network (DFN) realization is generated based on prior information about the network. The observations needed to calibrate the DFN are based on local variations of the orientation and magnitude of at least one principal stress component along boreholes. A Markov Chain Monte Carlo sequence is employed to update the DFN iteratively by a fracture translation within the domain. The Markov sequence compares the simulated stress profile with the observed stress profiles in the borehole, evaluates each iteration with Metropolis‐Hastings acceptance criteria, and stores acceptable DFN realizations in an ensemble. Finally, this obtained ensemble is used to visualize the potential occurrence of fractures in a probability map, indicating possible fracture locations and lengths. We test this methodology to reconstruct simple synthetic and more complex outcrop‐based fracture networks and successfully image the significant fractures in the domain.

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Development of connected permeability in massive crystalline rocks through hydraulic fracture propagation and shearing accompanying fluid injection

Cited by 21 publications

References 18 publications

Linking microearthquakes to fracture permeability change: The role of surface roughness

Linking microearthquakes to fracture permeability change: The role of surface roughness

Crustal permeability

Fracture Network Characterization Using Stress‐Based Tomography

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