Seismicity Based Reservoir Characterization of Basel Geothermal Site

Dinske, C.; Shapiro, Serge A.; Ladner, F.

doi:10.3997/2214-4609.201400030

Cited by 2 publications

(1 citation statement)

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“…Even after terminating the fluid injection, seismic activity can still be monitored for several hours to days, as, for instance, in the Barnett Shale (Shapiro and Dinske ), Basel (Häring et al . ; Dinske, Shapiro, and Ladner ; Goertz‐Allmann and Wiemer ), the Canyon Sands (Fischer et al . ), Cooper Basin (Baisch et al .…”

Section: Introductionmentioning

confidence: 99%

Back front of seismicity induced by non-linear pore pressure diffusion

Hummel

Shapiro

2015

Geophysical Prospecting

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A B S T R A C TBorehole fluid injections are accompanied by microseismic activity not only during but also after termination of the fluid injection. Previously, this phenomenon has been analysed, assuming that the main triggering mechanism is governed by a linear pressure diffusion in a hydraulically isotropic medium. In this context the socalled back front of seismicity has been introduced, which allows to characterize the hydraulic transport from the spatiotemporal distribution of post-injection induced events. However, rocks are generally anisotropic, and in addition, fluid injections can strongly enhance permeability. In this case, permeability becomes a function of pressure. For such situations, we carry out a comprehensive study about the behaviour and parametrization of the back front. Based on a model of a factorized anisotropic pressure dependence of permeability, we present an approach to reconstruct the principal components of the diffusivity tensor. We apply this approach to real microseismic data and show that the back front characterizes the least hydraulic transport. To investigate the back front of non-linear pore-fluid pressure diffusion, we numerically consider a power-law and an exponential-dependent diffusivity. To account for a post-injection enhanced hydraulic state of the rock, we introduce a model of a frozen (i.e., nearly unchanged after the stimulation) medium diffusivity and generate synthetic seismicity. We find that, for a weak non-linearity and 3D exponential diffusion, the linear diffusion back front is still applicable. This finding is in agreement with microseismic data from Ogachi and Fenton Hill. However, for a strong non-linear fluid-rock interaction such as hydraulic fracturing, the back front can significantly deviate from a time dependence of a linear diffusion back front. This is demonstrated for a data set from the Horn River Basin. Hence, the behaviour of the back front is a strong indicator of a non-linear fluid-rock interaction. I N T R O D U C T I O NFor the successful development and operation of hydrocarbon and geothermal reservoirs, knowledge of the hydraulic transport is of crucial importance. Although today's quantification of the reservoir permeability is mainly based on log measurements, these measurements only provide very time-restricted information in the ultimate vicinity of the wellbore. In such a way these measurements therefore cannot capture hydraulic processes linked to, for instance, hydraulic stimulation *

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