An improved simplified analytical model for CO2 plume movement and pressure buildup in deep saline formations

Oruganti, Yagna Deepika; Mishra, Srikanta

doi:10.1016/j.ijggc.2012.12.024

Cited by 17 publications

(14 citation statements)

References 9 publications

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“…Finally, a sensitivity analysis suggested that the mobility of the brine‐CO 2 zone had the largest impact on the outermost plume tip location. This finding is consistent with previous work where Mishra determined the correct mobility at which the sharp interface model and numerical simulator were in precise agreement lending insight into the necessary mobility to resolve discrepancies (Oruganti and Mishra ). Having already considered how gas saturation influences permeability, this finding suggested that treating the wet‐gas viscosity as a pure CO 2 viscosity may not be applicable.…”

Section: Comparison Of the Simulator And The Sharp Interface Modelsupporting

confidence: 91%

“…This was achieved by assuming constant pressure injection and by calculating the pressure gradients at any instant under the assumption of steady‐state conditions for each value of the time‐varying flow rate. Oruganti and Mishra () evaluated the three‐region model of Burton et al finding the CO 2 saturation in the formation agreed well with full‐physics simulators but that pressure‐buildup was ostensibly underpredicted. Oruganti and Mishra found that the agreement was improved when a representative two‐phase mobility was calculated based on the actual mobility profile in the two‐phase region.…”

Section: Introductionmentioning

confidence: 93%

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An Evaluation of Sharp Interface Models for CO₂‐Brine Displacement in Aquifers

2015

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Understanding multiphase transport within saline aquifers is necessary for safe and efficient CO2 sequestration. To that end, numerous full-physics codes exist for rigorously modeling multiphase flow within porous and permeable rock formations. High-fidelity simulation with such codes is data- and computation-intensive, and may not be suitable for screening-level calculations. Alternatively, under conditions of vertical equilibrium, a class of sharp-interface models result in simplified relationships that can be solved with limited computing resources and geologic/fluidic data. In this study, the sharp-interface model of Nordbotten and Celia (2006a,2006b) is evaluated against results from a commercial full-physics simulator for a semi-confined system with vertical permeability heterogeneity. In general, significant differences were observed between the simulator and the sharp-interface model results. A variety of adjustments were made to the sharp-interface model including modifications to the fluid saturation and effective viscosity in the two-phase region behind the CO2 -brine interface. These adaptations significantly improved the predictive ability of the sharp interface model while maintaining overall tractability.

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Section: Comparison Of the Simulator And The Sharp Interface Modelsupporting

confidence: 91%

Section: Introductionmentioning

confidence: 93%

An Evaluation of Sharp Interface Models for CO₂‐Brine Displacement in Aquifers

2015

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“…Alternative approaches were later proposed for computing the effective mobility in the two-phase region and hence develop the pressure solution for this three-region model. Burton et al [5] calculated an effective two-phase mobility based on the average brine saturation while Oruganti and Mishra [6] used an effective mobility averaged over the distance in the two-phase region.…”

Section: Previous Workmentioning

confidence: 99%

“…For example, the Nordbotten et al [7] sharp-interface model does not honor two-phase behavior behind CO 2 -brine interface while the semi-analytical three region model by Oruganti and Mishra [6] is applicable only for confined (i.e. 1D radial flow) systems.…”

Section: Previous Workmentioning

confidence: 99%

“…We add an overlying cap rock and vertically layered heterogeneity to the aquifer considered in the simplified 1D 3-region model of Burton et al [5] and Oruganti and Mishra [6], thus introducing buoyancy and heterogeneity effects on plume migration. Our analysis approach is based on a combination of first-principles approach and inspectional analysis from detailed numerical experiments using following methods:…”

Section: Current Model and Analysis Approachmentioning

confidence: 99%

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Reduced Physics Modeling of CO2 Injectivity

Ganesh

Mishra

2014

Energy Procedia

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Understanding pressure and plume propagation in the reservoir is an essential component of feasibility and risk assessment of geologic carbon sequestration operations. Detailed numerical simulations of supercritical CO 2 injection in deep saline aquifers generally involve extensive reservoir characterization and high computational effort. Validated simplified models that are based on the most critical physical processes, on the other hand, can be efficient alternatives for rapid screening of CO 2 sequestration projects. Sensitivity analysis using a set of well-designed full-physics compositional simulations provides useful insight regarding parameter influences on pressure propagation in our domain of interest. We developed a robust 2D simplified physics model to characterize CO 2 injectivity in semi-confined layered saline aquifer systems as a function of dimensionless variables characterizing rock and fluid properties based on sensitivity analysis results. Our simplified model for injectivity can thus be used to determine the CO 2 injection rate for a given target pressure differential or alternatively, the pressure differential resulting from injecting CO 2 at a target rate.

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Simplified physics model of CO₂ plume extent in stratified aquifer‐caprock systems

Ganesh

Mishra

2015

Greenhouse Gases

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The extent of plume migration as injected CO2 displaces the native reservoir fluids is a crucial performance metric to ensure safe and effective geologic sequestration. In this paper, we develop and validate a simplified physics model for the outer extent of CO2‐brine interface in a stratified aquifer‐caprock system. This involves quantifying the total storage efficiency, which is defined as the product of the volumetric sweep and displacement efficiencies, based on simulations covering an extensive parameter space of different reservoir and caprock properties. We model CO2 injection into a 2‐D radially symmetric brine‐filled reservoir with vertical permeability variations that is in hydraulic communication with a caprock. Based on insights from a suite of detailed numerical simulations of our system, the most important terms in the simplified model for total storage efficiency involve the relative permeability model followed by integrated measures of reservoir heterogeneity. A relationship is established for the plume extent at the end of injection from the amount of CO2 injected and the storativity (porosity‐thickness product) of the reservoir. © 2015 Society of Chemical Industry and John Wiley & Sons, Ltd

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An improved simplified analytical model for CO2 plume movement and pressure buildup in deep saline formations

Cited by 17 publications

References 9 publications

An Evaluation of Sharp Interface Models for CO₂‐Brine Displacement in Aquifers

An Evaluation of Sharp Interface Models for CO₂‐Brine Displacement in Aquifers

Reduced Physics Modeling of CO2 Injectivity

Simplified physics model of CO₂ plume extent in stratified aquifer‐caprock systems

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An improved simplified analytical model for CO2 plume movement and pressure buildup in deep saline formations

Cited by 17 publications

References 9 publications

An Evaluation of Sharp Interface Models for CO2‐Brine Displacement in Aquifers

An Evaluation of Sharp Interface Models for CO2‐Brine Displacement in Aquifers

Reduced Physics Modeling of CO2 Injectivity

Simplified physics model of CO2 plume extent in stratified aquifer‐caprock systems

Contact Info

Product

Resources

About

An Evaluation of Sharp Interface Models for CO₂‐Brine Displacement in Aquifers

An Evaluation of Sharp Interface Models for CO₂‐Brine Displacement in Aquifers

Simplified physics model of CO₂ plume extent in stratified aquifer‐caprock systems