An advanced analytical solution for pressure build-up during CO2 injection into infinite saline aquifers: The role of compressibility

Wu, Haiqing; Bai, Bing; Li, Xiaochun

doi:10.1016/j.advwatres.2017.12.010

Cited by 6 publications

(4 citation statements)

References 37 publications

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“…The effect of operational aspects, expressed as pore pressure changes, is mainly controlled by the injected volume, injection rate, and reservoir boundaries, that is, compartmentalization (Mathias et al., 2009 ; Nordbotten et al., 2005 ; Wu et al., 2016 , 2018 ), and it affects the magnitude of induced earthquakes. Therefore, we further explore the ( S Dmax , k 0 ) space for different values of pressure buildup (Figures 9 and 10 ).…”

Section: Resultsmentioning

confidence: 99%

Analytical Solution to Assess the Induced Seismicity Potential of Faults in Pressurized and Depleted Reservoirs

Vilarrasa

Simone

et al. 2021

JGR Solid Earth

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Induced seismicity has become a widespread issue as a result of the proliferation of geo-energy projects (Foulger et al., 2018). On one hand, geothermal energy production and geologic carbon storage are essential technologies to reach zero or negative net carbon emissions. On the other hand, the increased energy demand is boosting other operations, such as seasonal natural gas storage, subsurface energy storage, and disposal of wastewater from conventional and non-conventional oil and gas production. Injecting or pumping fluids at depth-a widespread practice in geo-energy operations-alters the in-situ stress field and may lead to fault rupture and induced seismicity (Buijze et al., 2017; Ellsworth, 2013; Grigoli et al., 2018). In several cases, the authorities have decided to cancel projects believed to be associated with large induced earthquakes and a non-exhaustive list includes the

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Section: Resultsmentioning

confidence: 99%

Analytical Solution to Assess the Induced Seismicity Potential of Faults in Pressurized and Depleted Reservoirs

Vilarrasa

Simone

et al. 2021

JGR Solid Earth

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“…In the field of petroleum engineering, the evaluation of caprock sealing properties helps locate oil-gas accumulations but the evolution of caprock sealability after exploitation is less of a concern. After CO 2 is injected into the reservoir, the fluid pressure of the reservoir is significantly increased and the pressure increment is gradually attenuated from the injection well to other areas [69]. The reduction of effective stress in the reservoir will inevitably lead to uneven uplift of the overburden [70] and deformation in the caprock.…”

Section: Discussionmentioning

confidence: 99%

Investigation of the Effect of Confining Pressure on the Mechanics-Permeability Behavior of Mudstone under Triaxial Compression

et al. 2019

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Injecting CO 2 into a reservoir disturbs the geostress field, which leads to variations in the permeability of caprock and affects its sealing performance. In this paper, the evolution characteristics of the permeability of Yingcheng mudstone were experimentally studied during deviatoric compression under different confining pressures. As the confining pressure increased, the strength of the mudstone increased bilinearly, the angle between the fault and the maximum principle stress increased, and the fault became flatter. During compression, the permeability of mudstone first decreased and then increased and the turning point of the permeability was between the onset of dilatancy and the turning point of volumetric strain; when the fault formed, the permeability increased sharply and the fault-induced increment was reduced exponentially with increasing confining pressure. In addition, the mudstone transformed to the ductile failure mode when the effective confining pressure was greater than 35 MPa, which means that the permeability did not jump within a small strain. Finally, a practical strain-based model of permeability evolution that separately considers compaction and dilatancy was proposed, and the predicted permeability values were in good agreement with the experimental results. This study revealed the effect of confining pressure on permeability evolution during compression and can help evaluate the sealing ability of mudstone caprock.

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“…Several semianalytical solutions have been proposed to estimate pressure buildup both within the vicinity of the injection well and for the far‐field. However, these solutions are based on certain assumptions that make their use less appropriate for reservoirs that are strongly heterogeneous, have high structural complexity, and are relatively small.…”

Section: Methods and Approachmentioning

confidence: 99%

Two risk metrics for CO₂storage reservoirs with varying domain size, heterogeneity, and injection rate

Singh

Bromhal

2019

Greenhouse Gases

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Two parameters that play the most important role in the appraisal of environmental risk performance at carbon dioxide (CO2) storage sites are the prospective impact of the pore pressure increase and CO2 saturation. In this context, this study investigates the spatiotemporal evolution of pressure buildup and CO2 saturation as a function of flow region's size, average porosity and permeability, and heterogeneity, as well as the injection rate and total volume of injected fluid. The practical importance of this study is to investigate the factors that affect the extent of pressure buildup and areal extent of CO2 plume both during and after injection, which will impact risk assessment as well as influence effective monitoring operations. This study pursues the above objective using two risk metrics that are based on numerical simulations and illustrated using representative models of three realistic storage sites with varying volumetric storage potential and geological settings, all with open geologic systems. The two metrics (the spatiotemporal extent of pressure buildup and CO2 saturation plume, respectively) used in this study are able to capture the geologic (structural and petrophysical) and operational complexities that cannot be incorporated into analytical or semianalytical solutions. The results of this study suggest that in addition to the average permeability, the areal extent of the pressure buildup during the injection period is strongly related to the injection rate, whereas the postinjection period may be more strongly influenced by the reservoir heterogeneity. The areal extent of the saturation plume during active injection is highly correlated to the mass of injected fluid, and the postinjection behavior is impacted by the shape of the reservoir–seal interface. These findings are consistent with other recent studies by the National Risk Assessment Partnership (NRAP) on characteristic reservoir behavior. The results have been used to generate pressure and saturation plume profiles (over time) that can be used to support risk‐based decision making. © 2019 Society of Chemical Industry and John Wiley & Sons, Ltd.

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An advanced analytical solution for pressure build-up during CO2 injection into infinite saline aquifers: The role of compressibility

Cited by 6 publications

References 37 publications

Analytical Solution to Assess the Induced Seismicity Potential of Faults in Pressurized and Depleted Reservoirs

Analytical Solution to Assess the Induced Seismicity Potential of Faults in Pressurized and Depleted Reservoirs

Investigation of the Effect of Confining Pressure on the Mechanics-Permeability Behavior of Mudstone under Triaxial Compression

Two risk metrics for CO₂storage reservoirs with varying domain size, heterogeneity, and injection rate

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An advanced analytical solution for pressure build-up during CO2 injection into infinite saline aquifers: The role of compressibility

Cited by 6 publications

References 37 publications

Analytical Solution to Assess the Induced Seismicity Potential of Faults in Pressurized and Depleted Reservoirs

Analytical Solution to Assess the Induced Seismicity Potential of Faults in Pressurized and Depleted Reservoirs

Investigation of the Effect of Confining Pressure on the Mechanics-Permeability Behavior of Mudstone under Triaxial Compression

Two risk metrics for CO2storage reservoirs with varying domain size, heterogeneity, and injection rate

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Two risk metrics for CO₂storage reservoirs with varying domain size, heterogeneity, and injection rate