Geologic CO2 sequestration and permeability uncertainty in a highly heterogeneous reservoir

Jayne, Richard; Wu, Hao; Pollyea, Ryan M.

doi:10.1016/j.ijggc.2019.02.001

Cited by 39 publications

(40 citation statements)

References 39 publications

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“…The 1‐D and 2‐D model results discussed above reveal that an advancing CO 2 plume is accompanied in space and time by a positive thermal anomaly at its leading edge. This result is discordant with a recent study by Jayne et al (), which found that the positive thermal anomaly advances ahead of the CO 2 plume in a highly heterogeneous basalt reservoir. While Jayne et al () suggested that thermal monitoring may be an effective strategy for heterogeneous reservoirs, they did not provide a mechanistic explanation.…”

Section: Resultssupporting

confidence: 68%

“…This result is discordant with a recent study by Jayne et al (), which found that the positive thermal anomaly advances ahead of the CO 2 plume in a highly heterogeneous basalt reservoir. While Jayne et al () suggested that thermal monitoring may be an effective strategy for heterogeneous reservoirs, they did not provide a mechanistic explanation. As a result, we further analyzed a simulation from Jayne et al () to make the mechanistic connection between the temperature distribution in a heterogeneous reservoir and the thermodynamic processes responsible for the thermal signature discussed above.…”

Section: Resultssupporting

confidence: 68%

“…Numerical models are frequently utilized to study the thermal processes associated with CO 2 storage in geologic reservoirs (André et al, 2010;Han et al, 2010;Hurter et al, 2007;Jayne et al, 2019;Oldenburg, 2007;Pruess, 2005a;Zhao & Cheng, 2017). These studies focus largely on Joule-Thomson cooling that occurs during a CO 2 injection; this refers to the cooling that occurs when a gas, for example, CO 2 , expands.…”

Section: Introductionmentioning

confidence: 99%

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Using Heat as a Predictor of CO₂ Breakthrough in Highly Heterogeneous Reservoirs

Jayne

Zhang

Pollyea

2019

Geophysical Research Letters

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Injecting supercritical CO2 into the subsurface changes the temperature, pressure, and geochemistry of the storage reservoir. Understanding these perturbations within the reservoir may be used to monitor the CO2 plume during a carbon capture and sequestration (CCS) project. Here we analyze results from 1‐D, 2‐D, and 3‐D numerical modeling studies to investigate how the thermal signature of the CO2‐water system evolves during CCS. These models show that the thermodynamic processes of the CO2‐water system results in a characteristic thermal profile within a homogeneous storage reservoir during a CO2 injection. This thermal signature is characterized by warming front of up to 4 °C, which is caused by CO2 dissolution and migrates contemporaneously with free‐phase CO2 migration. When reservoir properties are highly heterogeneous, this thermal front travels well ahead of free‐phase CO2, thus implying that thermal monitoring may be an effective predictor of CO2 breakthrough.

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Section: Resultssupporting

confidence: 68%

Section: Resultssupporting

confidence: 68%

Section: Introductionmentioning

confidence: 99%

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Using Heat as a Predictor of CO₂ Breakthrough in Highly Heterogeneous Reservoirs

Jayne

Zhang

Pollyea

2019

Geophysical Research Letters

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“…develop and implement ensemble simulation methods to quantify spatially variable sealing behavior within the low‐volume Snake River Plains basalts. Jayne et al . extend these methods into flood basalt formations to show how permeability uncertainty affects the injectivity and leakage during CCS in flood basalt formations.…”

Section: Introductionmentioning

confidence: 99%

A probabilistic assessment of geomechanical reservoir integrity during CO₂sequestration in flood basalt formations

Jayne

Pollyea

2019

Greenhouse Gases

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Recent field experiments in Iceland and Washington State (USA) show that basalt formations may be favorable targets for carbon capture and sequestration (CCS) because CO2 mineralization reactions proceed rapidly. These results imply that there is tremendous opportunity for implementing CCS in large igneous provinces. However, the magnitude of this opportunity comprises commensurate levels of uncertainty because basalt reservoirs are characterized by highly heterogeneous, fracture‐controlled hydraulic properties. This geologic uncertainty is propagated as parametric uncertainty in quantitative risk models, thus limiting the efficacy of models to predict CCS performance attributes, such as reservoir integrity and storage potential. To overcome these limitations, this study presents a stochastic approach for quantifying the geomechanical performance attributes of CCS operations in a highly heterogeneous basalt reservoir. We utilize geostatistical reservoir characterization to develop an ensemble of equally probable permeability distributions in a flood basalt reservoir with characteristics of the Wallula Basalt Pilot Project. We then simulate industrial‐scale CO2 injections within the ensemble and calculate the mean and variance of fluid pressure over a 1‐year injection period. These calculations are combined with the state of stress in southeast Washington State to constrain the spatial extent at which shear failure, fracture initiation, and borehole breakdown may occur. Results from this study show that (i) permeability uncertainty alone causes injection pressure to vary over 25 MPa, (ii) shear failure is likely to occur at 7 times greater distances from the injection than the CO2 migrates, and (iii) joint initiation pressures are localized within the volume comprising the CO2 plume. © 2019 Society of Chemical Industry and John Wiley & Sons, Ltd.

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“…Prior studies in this area have been either specific to estimation of area of review using semianalytical solutions 37,38 for a single-phase flow using homogeneous reservoir properties or they numerically analyzed pressure/saturation on a single site to investigate other specific issues. [39][40][41][42] Another metric that provides a measure of the lateral extent of a reservoir impacted by a fluid drawdown is radius of investigation, 43 which is popular in well-test analysis of oil and gas wells, but this metric is not adequate for carbon storage reservoirs for three reasons: (1) storage reservoirs considered in this study are open boundaries (constant pressure), whereas the radius of investigation is strictly applicable to no-flow closed systems 43 ; (2) radius of investigation assumes a homogeneous and geometrically ideal (cylindrical shaped) reservoir, whereas the reservoirs for CO 2 storage can range from moderately ideal to complex in terms of their geometry and heterogeneity; and (3) radius of investigation is meant for a drainage/drawdown test in a closed reservoir, whereas the scenario simulated in this study is analogous to a buildup test with open boundaries. Despite these limitations, radius of investigation estimated through well-test analysis can be a useful measure in reservoir characterization when there is little information on reservoir properties and heterogeneities.…”

Section: Introductionmentioning

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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Geologic CO2 sequestration and permeability uncertainty in a highly heterogeneous reservoir

Cited by 39 publications

References 39 publications

Using Heat as a Predictor of CO₂ Breakthrough in Highly Heterogeneous Reservoirs

Using Heat as a Predictor of CO₂ Breakthrough in Highly Heterogeneous Reservoirs

A probabilistic assessment of geomechanical reservoir integrity during CO₂sequestration in flood basalt formations

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

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Geologic CO2 sequestration and permeability uncertainty in a highly heterogeneous reservoir

Cited by 39 publications

References 39 publications

Using Heat as a Predictor of CO2 Breakthrough in Highly Heterogeneous Reservoirs

Using Heat as a Predictor of CO2 Breakthrough in Highly Heterogeneous Reservoirs

A probabilistic assessment of geomechanical reservoir integrity during CO2sequestration in flood basalt formations

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

Contact Info

Product

Resources

About

Using Heat as a Predictor of CO₂ Breakthrough in Highly Heterogeneous Reservoirs

Using Heat as a Predictor of CO₂ Breakthrough in Highly Heterogeneous Reservoirs

A probabilistic assessment of geomechanical reservoir integrity during CO₂sequestration in flood basalt formations

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