The Seismic Response to Injected Carbon Dioxide: Comparing Observations to Estimates Based Upon Fluid Flow Modeling

Vasco, D. W.; Alfi, Masoud; Hosseini, Seied Ali; Zhang, Rui; Daley, Thomas M.; Ajo‐Franklin, Jonathan; Hovorka, Susan

doi:10.1029/2018jb016429

Cited by 13 publications

(5 citation statements)

References 69 publications

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“…These specific features of the point bar are consistent with the general ones in the cross section shown in Figure c. Our interpreted flow channel network may contain a certain uncertainty, as shown by existing studies based on the time‐lapse surface seismic surveys over the entire anticlinal structure (e.g., Vasco et al, ).…”

Section: Discussion Of Multiscale and Multipath Channeling Of Co2 Flowsupporting

confidence: 89%

Dynamic Processes of CO₂Storage in the Field: 1. Multiscale and Multipath Channeling of CO₂Flow in the Hierarchical Fluvial Reservoir at Cranfield, Mississippi

Zhou

Zhang

Hosseini

et al. 2020

Water Resources Research

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A consistent picture of dynamic channeling, invasion, spreading, and breakthrough (CISB) of supercritical CO2 in the hierarchical fluvial reservoir at Cranfield, Mississippi is presented after 10 years of integration and analysis of complementary field monitoring and characterization data. The dynamic CISB with small‐scale CO2‐flow channels in the F1‐F2‐F3 cross section (F1, F2, and F3 are one injection and two monitoring wells) was imaged by daily electrical resistance tomography (ERT) and time‐lapse crosswell seismic surveys. One, three, and four CO2 flow channels logged at F1, F2, and F3, respectively, were dynamically connected with strong temporal variations in CO2 saturation during 221 days of drainage with injection rate doubling twice and 81 days of imbibition. Three intermediate‐scale CO2 flow channels (with highest CO2 saturation) normal to the cross section were ERT‐imaged during late‐time drainage. A large‐scale, sinuous fluvial CO2 flow channel was imaged by repeat surface seismic survey at the end of the imbibition. The fluvial sandstone channel sinuously bypasses the F1‐F2‐F3 cross section in a point bar, but the channel is connected to the cross section through an intermediate‐scale sandstone channel, forming a complicated flow channel network. The multiscale flow channel network (in the fluvial channel‐point bar system) revealed from the observed CISB enables us to consistently interpret the hydrological monitoring data of three tracer tests, each conducted during an injection rate step, and preinjection hydraulic‐thermal‐tracer tests. This interpretation of the CISB and flow channel network can guide future modeling and data inversion to best understand the effects of natural heterogeneity on CO2 storage efficiency and residual trapping.

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Section: Discussion Of Multiscale and Multipath Channeling Of Co2 Flowsupporting

confidence: 89%

Dynamic Processes of CO₂Storage in the Field: 1. Multiscale and Multipath Channeling of CO₂Flow in the Hierarchical Fluvial Reservoir at Cranfield, Mississippi

Zhou

Zhang

Hosseini

et al. 2020

Water Resources Research

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“…At the current state of technology, relatively large uncertainty in the geophysical inversion results can exist, especially for quantitative inversion of the CO 2 plume. 14,36,37 Joint inversion or joint interpretation of data from multiple monitoring methods, including both the indirect geophysical monitoring data and the direct downhole measurements might improve the accuracy of the estimated depth interval and the CO 2 mass. Also, brine migration, which might be observable using some Figure 7.…”

Section: Discussionmentioning

confidence: 99%

Evaluating probability of containment effectiveness at a GCS site using integrated assessment modeling approach with Bayesian decision network

et al. 2021

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Improved scientific and engineering understanding of the behavior of geologic CO 2 storage together with established regulatory framework and incentive structures raise the prospects for accelerated, large-scale deployment of this greenhouse gas emissions reduction approach. Incentive structures call for the establishment of appropriate verification and accounting approaches to support claims of the integrity of a geologic storage complex and to justify taking credit for long-term storage. In this study, we present a framework for assessing the probability of containment effectiveness over the lifetime of a geologic carbon storage site (e.g., after 70 years of injection and postinjection site performance) using forward stochastic model realizations based on site characterization data and using a monitoring-informed Bayesian network based on hypothetical detectability from surface seismic surveys over the site injection and post-injection phases. The National Risk Assessment Partnership's open-source Integrated Assessment Model (NRAP-Open-IAM) was utilized to develop an ensemble of 10,000 a priori stochastic forecasts of CO 2 containment. Those simulations were used to train the Bayesian network model to estimate the prior probabilities of the CO 2 leakage mass into overlying, monitorable aquifers considering the uncertainties in the reservoir properties, permeability of potentially leaky wells and the overlying aquifers. The conditional probabilities in the Bayesian network were either learned from the NRAP-Open-IAM simulations or derived from the predefined detection thresholds for the monitoring method. Observations obtained from monitoring, over time during the site operation phases were then used to generate updated posterior probabilities of containment (and any loss from containment) in the Bayesian network by propagating the prior probabilities through the conditional

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“…We consider a single fluid inhabiting the pores, though it is likely to be fluid mixture that we might have to model as an effective composite fluid. An alternative approach would be to adopt the recent extension of Biot theory to N f fluids as in Vasco, Alfi, et al (2019) assuming small changes in saturation, allowing for a local linearization. Such an approach may be appropriate for our application, as the permeability is extremely low and the initial fluid leak‐off is likely to be small prior to the generation of microseismic events around the hydrofracture.…”

Section: Methodsmentioning

confidence: 99%

Seismicity and Stress Associated With a Fluid‐Driven Fracture: Estimating the Evolving Geometry

2020

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A coupled approach, combining the theory of rate-and state-dependent friction and methods from poroelasticity, forms the basis for a quantitative relationship between displacements and fluid leak-off from a growing fracture and changes in the rate of seismic events in the region surrounding the fracture. Poroelastic Green's functions link fracture aperture changes and fluid flow from the fracture to changes in the stress field and pore pressure in the adjacent formation. The theory of rate-and state-dependent friction provides a connection between Coulomb stress changes and variations in the rate of seismic events. Numerical modeling indicates that the Coulomb stress changes can vary significantly between formations with differing properties. The relationship between the seismicity rate changes and the changes in the formation stresses and fluid pressure is nonlinear, but a transformation produces a quantity that is linearly related to the aperture changes and fluid leak-off from the fracture. The methodology provides a means for mapping changes in seismicity into fracture aperture changes and to image an evolving fracture. An application to observed microseismicity associated with a hydrofracture reveals asymmetric fracture propagation within two main zones, with extended propagation in the upper zone. The time-varying volume of the fracture agrees with the injected volume, given by the integration of rate changes at the injection well, providing validation of the estimated aperture changes. These measurements are essentially point observations obtained during fracture movement (Guglielmi, Cappa, et al., 2015). Thus, there is a need for imaging fracture evolution at the field scale. Imaging the opening of a fracture is a difficult task due to the limited width of the feature, the rapid changes in properties, the significant depth of the event, and the complexity of the process, though there have been improvements in seismic imaging (Grechka et al., 2017). Much of the deformation within the fracture, and directly on the fracture surface, is aseismic or at frequencies that require broadband sensors (Guglielmi, Cappa, et al., 2015; Tary et al., 2014). One common feature of an opening fracture is an increase in the number of microseismic events in the surrounding region due to fluid flow and changes in the local stress field. This leads to changes in the rate of microseismicity around the fracture. Such fracture-related microseismicity is illustrated in Figure 1, where we plot events associated with the injection of fluid into a newly created hydrofracture that was monitored using microseismicity. The events detected during the monitoring are from a field experiment that we will analyze in section 3. The microseismic events resulting from the injection of fluid into the fracture were identified and located using 80 seismometers in four boreholes

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The Seismic Response to Injected Carbon Dioxide: Comparing Observations to Estimates Based Upon Fluid Flow Modeling

Cited by 13 publications

References 69 publications

Dynamic Processes of CO₂Storage in the Field: 1. Multiscale and Multipath Channeling of CO₂Flow in the Hierarchical Fluvial Reservoir at Cranfield, Mississippi

Dynamic Processes of CO₂Storage in the Field: 1. Multiscale and Multipath Channeling of CO₂Flow in the Hierarchical Fluvial Reservoir at Cranfield, Mississippi

Evaluating probability of containment effectiveness at a GCS site using integrated assessment modeling approach with Bayesian decision network

Seismicity and Stress Associated With a Fluid‐Driven Fracture: Estimating the Evolving Geometry

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The Seismic Response to Injected Carbon Dioxide: Comparing Observations to Estimates Based Upon Fluid Flow Modeling

Cited by 13 publications

References 69 publications

Dynamic Processes of CO2Storage in the Field: 1. Multiscale and Multipath Channeling of CO2Flow in the Hierarchical Fluvial Reservoir at Cranfield, Mississippi

Dynamic Processes of CO2Storage in the Field: 1. Multiscale and Multipath Channeling of CO2Flow in the Hierarchical Fluvial Reservoir at Cranfield, Mississippi

Evaluating probability of containment effectiveness at a GCS site using integrated assessment modeling approach with Bayesian decision network

Seismicity and Stress Associated With a Fluid‐Driven Fracture: Estimating the Evolving Geometry

Contact Info

Product

Resources

About

Dynamic Processes of CO₂Storage in the Field: 1. Multiscale and Multipath Channeling of CO₂Flow in the Hierarchical Fluvial Reservoir at Cranfield, Mississippi

Dynamic Processes of CO₂Storage in the Field: 1. Multiscale and Multipath Channeling of CO₂Flow in the Hierarchical Fluvial Reservoir at Cranfield, Mississippi