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Collaborating Authors
Gomes, Jorge S.
Abstract CO2 Storage as a technology is one that has been widely applied for the achievement of a greener world. It is considered as the only technology that mitigates global warming whilst, yet, allowing for the continuous use of fossil fuels which power our world today. Trapping efficiency of CO2 in saline aquifers depends on engineering design strategies and aquifer parameters. The range of plausible factors that could affect the efficiency creates the need for an optimization approach to reduce the risk and uncertainties associated with the process. This paper presents an uncertainty and optimization model for the residual and solubility trapping mechanisms in CO2 storage processes using the design of experiments and response surface methodology for representative aquifer models at field scale. Extensive numerical experiments were conducted using a commercial simulator and an optimum set of conditions was suggested for site based storage activities using the desirability concept. The factors for optimization in this study were broadly classified into aquifer and design parameters based on the controllability or non-controllability of selected factors. Aquifer parameters selected are the rock heterogeneity quantified using the Dykstra Parson coefficient, spatial continuity of properties estimated using the correlation lengths, temperature, mean permeability, anisotropy, residual gas saturation while the design parameters selected are the well type, injection strategy and completion intervals. These factors were selected based on literature search, intuitions and discussions. The aquifer model was kept constant for accurate analysis. The objective functions are the residual trapping coefficient (RTC) and the solubility trapping coefficient (STC). The process for the optimization technique utilized was a three pronged approach involving screening, characterizing and optimizing the parameters. Screening of parameters was performed using the factorial methods, the characterizing was performed using the Box Behnken response surface methodology while the optimization was performed using desirability functions. For results analysis, Pareto plots were constructed to show the effect of main factors and interaction factors on the objective functions, response surface plots were also made to show response effects. Results were validated with a commercial simulator. This study provides engineers with a better understanding of the most influential factors on trapping capacity during CO2 storage thus enabling them to make decisions with less risk and more certainty.
- Asia (0.46)
- North America > United States (0.28)
- Africa > Nigeria > Gulf of Guinea > Niger Delta > Niger Delta Basin > OPL 217 > Agbami-Ekoli Field > Agbami Field (0.99)
- Africa > Nigeria > Gulf of Guinea > Niger Delta > Niger Delta Basin > OPL 216 > Agbami-Ekoli Field > Agbami Field (0.99)
Abstract The capacity for the storage of carbon dioxide in saline aquifers remains enormous. Of all geological storage media, it provides the best storage capacity. In this study, the potential of the Shuaiba Formation, in the Falaha syncline, for geologic sequestration is assessed. A regional geo-model was built using seismic and well data (logs, cores) from the Falaha Syncline and nearby fields. The model was built to honor the heterogeneity and sequence stratigraphy of the Shuaiba carbonate platform using a five-order hierarchical conceptual model of the Shuaiba formation that merged sequence architecture and reservoir architecture together. This was achieved by honoring lithofacies, facies association packages and rock types in their corresponding depositional settings in the sequence framework. Dynamic simulations were then conducted on an upscaled geological model using a compositional reservoir simulator to determine its storage and flow capacity, plume migration pathways and to understand the physics of the fluid flow in the aquifer. Simulations are made to be conservative thus accounting for structural/stratigraphic, solubility (dissolution in resident brine) and residual trapping without accounting for the slower mineral trapping process. Detailed sensitivity studies were conducted during the simulations to understand the effect of well parameters, rock and fluid properties amongst others on the storage capacity in the aquifer. Simulation results indicate that significant volumes could be stored in the aquifer and could take a significant amount of time before the injected gas reaches the surrounding hydrocarbon producing fields. This study provides the first full field approach to characterize and to quantify the suitability of the identified aquifer for long term storage of carbon dioxide in the subsurface of UAE.
- Geology > Geological Subdiscipline > Stratigraphy (1.00)
- Geology > Structural Geology > Tectonics > Compressional Tectonics > Fold and Thrust Belt (0.94)
- Geology > Rock Type > Sedimentary Rock > Carbonate Rock (0.66)
- Government > Regional Government > North America Government > United States Government (1.00)
- Energy > Oil & Gas > Upstream (1.00)
- Europe > Norway > North Sea > Central North Sea > South Viking Graben > PL 046 > Utsira Formation (0.99)
- Europe > Norway > Barents Sea > Hammerfest Basin > License 100 > Block 7121/7 > Snøhvit Field > Stø Formation (0.99)
- Europe > Norway > Barents Sea > Hammerfest Basin > License 100 > Block 7121/7 > Snøhvit Field > Nordmela Formation (0.99)
- (72 more...)