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We present hydro‐mechanical measurements that characterize shear on natural fractures in schist, amphibolite, and rhyolite specimens from the enhanced geothermal system (EGS) Collab Project's Experiment 1 and 2 sites (E1 and E2) at the Sanford Underground Research Facility. We employed a triaxial direct shear method augmented with X‐ray imaging to perform hydroshearing (injection‐induced shearing) and mechanical shearing on naturally fractured specimens at in situ stress conditions. Measurements included fracture permeability, strength, stress‐dependent aperture, shear dilation, and frictional strength. Results reveal that in situ natural fractures must be permeable, weak, and shear‐oriented to be hydrosheared, and only a subset of the observable in situ fractures were suitable. When sheared, the fracture permeability typically increased by a factor of 10 or more and this increase was retained over time. However, shear slip did not always result in permeability increase. High phyllosilicate content associated with exceptionally weak fractures exhibited poor or even decreased permeability after stimulation. These measurements in combination with site data were used to conduct a slip‐tendency analysis for different fracture sets, and we selected the top candidate natural fractures for hydroshearing at the EGS Collab sites. We also found that the lower in situ shear stress and stronger fractures at the E2 site make hydroshearing more challenging than at the E1 site. Overall, the methods and analysis used in our work can be applied to any geothermal project to identify in situ joint sets that are best suited for hydroshearing, which in turn can help to optimize well placement and energy production. Plain Language Summary: Geothermal energy is attractive because it is green, clean, and "always on". However, technical challenges and high‐capital costs historically hindered its development. Among the technical challenges, is a need to reliably increase the rock permeability to promote productive geothermal wells. One leading method is called "hydroshearing", where fluid is injected to encourage shear slip along pre‐existing natural fractures and thus open the fractures to increase permeability. Our research focuses on the enhanced geothermal system (EGS) Collab Project's field sites where we characterize actual natural fractures so that we can predict shear slip via hydroshearing and then identify the best locations for drilling wells suitable for hydroshearing. This work included measuring a suite of coupled hydraulic and mechanical properties for crystalline geothermal rocks drilled from this field site. We demonstrate that pre‐existing natural fractures must be mechanically weak, favorably oriented, and sufficiently permeable to be hydrosheared. Combining measured in situ stresses with natural fractures properties, we were able to identify suitable natural fractures for hydroshearing and to better optimize well design at the EGS Collab sites. This positive outcome from our work could be similarly applied to full‐scale geothermal systems to improve well productivity, reduce the risk of failed wells, and to improve economics. Key Points: Hydroshearing requires a natural fracture that is mechanically weak, hydraulically conductive, and favorably orientedFracture shear slip does not always result in permeability enhancement; when phyllosilicate rich, we observed decreasing permeabilitySlip‐tendency analysis improved by hydro‐mechanical measurement helps to select the best candidate fracture for hydroshearing in the field [ABSTRACT FROM AUTHOR]

Enhanced Geothermal Systems could provide a substantial contribution to the global energy demand if their implementation could overcome inherent challenges. Examples are insufficient created permeability, early thermal breakthrough, and unacceptable induced seismicity. Here we report on the seismic response of a mesoscale hydraulic fracturing experiment performed at 1.5‐km depth at the Sanford Underground Research Facility. We have measured the seismic activity by utilizing a 100‐kHz, continuous seismic monitoring system deployed in six 60‐m length monitoring boreholes surrounding the experimental domain in 3‐D. The achieved location uncertainty was on the order of 1 m and limited by the signal‐to‐noise ratio of detected events. These uncertainties were corroborated by detections of fracture intersections at the monitoring boreholes. Three intervals of the dedicated injection borehole were hydraulically stimulated by water injection at pressures up to 33 MPa and flow rates up to 5 L/min. We located 1,933 seismic events during several injection periods. The recorded seismicity delineates a complex fracture network comprised of multistrand hydraulic fractures and shear‐reactivated, preexisting planes of weakness that grew unilaterally from the point of initiation. We find that heterogeneity of stress dictates the seismic outcome of hydraulic stimulations, even when relying on theoretically well‐behaved hydraulic fractures. Once hydraulic fractures intersected boreholes, the boreholes acted as a pressure relief and fracture propagation ceased. In order to create an efficient subsurface heat exchanger, production boreholes should not be drilled before the end of hydraulic stimulations. Key Points: Mesoscale hydraulic fracturing in crystalline rock is observed with multigeophysical sensor array at close proximityCreated fracture network consists of multistrand hydraulic fractures and reactivated preexisting structuresHydraulic fracture growth is strongly influenced by rock fabric, preexisting fractures, and stress heterogeneities [ABSTRACT FROM AUTHOR]

Abstract: We form methane hydrate by injecting methane gas into a brine‐saturated, coarse‐grained sample under hydrate‐stable thermodynamic conditions. Hydrate forms to a saturation of 11%, which is much lower than that predicted assuming three‐phase (gas‐hydrate‐brine) thermodynamic equilibrium (67%). During hydrate formation, there are temporary flow blockages. We interpret that a hydrate skin forms a physical barrier at the gas‐brine interface. The skin fails periodically when the pressure differential exceeds the skin strength. Once the skin is present, further hydrate formation is limited by the rate that methane can diffuse through the solid skin. This process produces distinct thermodynamic states on either side of the skin that allows gas to flow through the sample. This study illuminates how gas can be transported through the hydrate stability zone and thus provides a mechanism for the formation of concentrated hydrate deposits in sand reservoirs. It also illustrates that models that assume local equilibrium at the core‐scale and larger may not capture the fundamental behaviors of these gas flow and hydrate formation processes. [ABSTRACT FROM AUTHOR]

Abstract: For better understanding of frequency dependence (dispersion) of seismic wave velocities caused by stress‐induced fluid flow, broadband laboratory measurements were performed on a suite of synthetic glass media containing both equant pores and thermal cracks. Complementary forced oscillation, resonant bar, and ultrasonic techniques provided access to millihertz‐hertz frequencies, ~1 kHz frequency, and ~1 MHz frequency, respectively. The wave speeds or effective elastic moduli and associated dissipation were measured on samples under dry, argon‐ or nitrogen‐saturated, and water‐saturated conditions in sequence. The elastic moduli, in situ permeability, and crack porosity inferred from in situ X‐ray computed tomography all attest to strong pressure‐induced crack closure for differential (confining‐minus‐pore) pressures <30 MPa, consistent with zero‐pressure crack aspect ratios <4 × 10−4. The low permeabilities of these materials allow access to undrained conditions, even at subhertz frequencies. The ultrasonically measured elastic moduli reveal consistently higher shear and bulk moduli upon fluid saturation—diagnostic of the saturated‐isolated regime. For a glass rod specimen, containing cracks but no pores, saturated‐isolated conditions apparently persist to subhertz frequencies—requiring in situ aspect ratios (minimum/maximum dimension) <10−5. In marked contrast, the shear modulus measured at subhertz frequencies on a cracked glass bead specimen of 5% porosity, is insensitive to fluid saturation, consistent with the Biot‐Gassmann model for the saturated‐isobaric regime. The measured dispersion of the shear modulus approaches 10% over the millihertz‐megahertz frequency range for the cracked and fluid‐saturated media—implying that laboratory ultrasonic data should be used with care in the interpretation of field data. [ABSTRACT FROM AUTHOR]

Abstract: Depressurization of hydrate‐bearing sediments (HBS) can cause the movement of fine particles, and in turn, such fines migration affects fluid flow and mechanical behavior of sediments, ultimately affecting long‐term hydrocarbon production and wellbore stability. This study investigated how and to what extent depressurization of HBS causes fines migration using X‐ray computed tomography (CT) imaging. Methane hydrate was synthesized in sediments with 10% fines content (FC), composed of sands with silt and/or clay, and the hydrate‐bearing samples were stepwisely depressurized while acquiring CT images. The CT images were analyzed to quantify the spatial changes in FC in the host sediment and thus to capture the fines migration during depressurization. It was found that the FC changes began occurring from the hydrate dissociation regions. This confirms that the multiphase flow caused by depressurization accompanies fines migration. Depressurization of HBS with a hydrate saturation of ~20–40% caused FC reduction from ~10% to ~6–9%, and the extent of fines migration differed with the particle sizes of the host sands and the types of fines. It was found that fines migration was more pronounced with coarse sands and with silty fines. Such observed level of FC reduction is estimated to increase sediment permeability by several factors based on the Kozeny‐type permeability model. Our results support the notion that the extent of fines migration and its effect on fluid flow behavior need to be assessed in consideration of physical properties of host sediment and fine particles to identify optimum depressurization strategies. [ABSTRACT FROM AUTHOR]