A method for examining the geospatial distribution of CO2 storage resources applied to the Pre-Punta Gorda Composite and Dollar Bay reservoirs of the South Florida Basin, U.S.A.

Roberts-Ashby, Tina L.; Ashby, Brandon N.

doi:10.1016/j.marpetgeo.2016.06.010

Cited by 7 publications

(4 citation statements)

References 14 publications

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“…The presence of such minerals can induce chemical reactions other than those considered here, and in general, the response of a deep saline aquifer to CO 2 injection can be strongly affected by the mineralogy 5,74–76 . However, the formation considered herein was based on the Dollar Bay aquifer; well log data for this formation do not indicate the presence of any other minerals 55 The analysis herein considers only the effects of the salinity of the native brine.…”

Section: Resultsmentioning

confidence: 99%

“…The simulated aquifer used in this study is based on the Dollar Bay formation in the South Florida basin 55 . For instance, the simulated aquifer was presumed to be located at a depth of approximately 2750 m below ground surface; the temperature and pressure of the formation were chosen to be consistent with this depth (75°C and 386 bar, respectively).…”

Section: Methodsmentioning

confidence: 99%

“…The thickness of the injection zone was 69.5 m, and comprised 11 distinct layers. The identification of 11 distinct layers is based on the information gained from isolith, isopach, and porosity maps developed for the Dollar Bay formation, 55 and on personal communication with scientists from the United States Geological Survey who have investigated the Dollar Bay formation. The stratigraphy is characterized by high‐permeability (6.9 × 10 –14 – 4.0 × 10 –13 m 2 ) dolomite layers, intercalated with lower‐permeability (2.0 × 10 –15 – 4.9 × 10 –14 m 2 ) limestone.…”

Section: Methodsmentioning

confidence: 99%

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Effect of brine salinity on the geological sequestration of CO₂ in a deep saline carbonate formation

et al. 2020

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When supercritical CO2 is injected into a deep saline aquifer, the salinity of the brine can influence both the solubility of the injected CO2 in the brine and the subsequent aqueous geochemical reactions that occur. The objective of this study is to assess the effect of brine salinity on CO2 storage in deep saline carbonate formations. Specifically, the study aims to quantitatively assess the effect of brine salinity on (a) the amount of CO2 that can be sequestered in the aqueous phase, (b) the storage efficiency of the repository, (c) the change in pH of the residual brine after dissolution of CO2, and (d) changes in the mineralogy and porosity of the rock matrix that result from mineral dissolution and precipitation reactions induced by CO2 injection. Injection of CO2 into a model layered carbonate formation was simulated using the reactive‐transport code TOUGHREACT 3.3. The simulations consisted of 50 years of injection into a partially completed injection well, followed by 50 years of equilibration (no injection). Salinity of the brine was varied between 1% and 15% to determine the effects of salinity. Because the solubility of CO2 decreases as the salinity of the brine increases, an increase in brine salinity from 1% to 15% resulted in a 19% decrease in storage efficiency and a 25% decrease in the mass of CO2 dissolved in the aqueous phase. However, despite the strong effect of brine salinity on CO2 dissolution, there was almost no effect of salinity on the pH change in the residual brine: the chemical activity coefficient of the dissolved CO2 increases with brine salinity, counteracting the effects of decreased solubility. Consequently, brine salinity had little effect on mineral dissolution or precipitation, or on changes in formation porosity. The study therefore helps to choose sequestration sites depending upon the salinity of the brine: lower salinity results in more solubility trapping and better storage efficiency without noticeable differences in pH drop or mineral dissolution. © 2020 Society of Chemical Industry and John Wiley & Sons, Ltd.

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Section: Resultsmentioning

confidence: 99%

Section: Methodsmentioning

confidence: 99%

Section: Methodsmentioning

confidence: 99%

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Effect of brine salinity on the geological sequestration of CO₂ in a deep saline carbonate formation

et al. 2020

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“…A holistic approach for optimal site determination incorporates environmental, technical, economic, and social criteria 65,66 . The innovative integration of GIS with ML streamlines site selection and impact assessment, with successful applications observed in diverse fields 17,[66][67][68][69][70][71][72][73] .…”

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confidence: 99%

Artificial intelligence-driven assessment of salt caverns for underground hydrogen storage in Poland

Derakhshani,

Lankof,

GhasemiNejad

et al. 2024

Sci Rep

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This study explores the feasibility of utilizing bedded salt deposits as sites for underground hydrogen storage. We introduce an innovative artificial intelligence framework that applies multi-criteria decision-making and spatial data analysis to identify the most suitable locations for storing hydrogen in salt caverns. Our approach integrates a unified platform with eight distinct machine-learning algorithms—KNN, SVM, LightGBM, XGBoost, MLP, CatBoost, GBR, and MLR—creating rock salt deposit suitability maps for hydrogen storage. The performance of these algorithms was evaluated using various metrics, including Mean Squared Error (MSE), Mean Absolute Error (MAE), Mean Absolute Percentage Error (MAPE), Root Mean Square Error (RMSE), and Correlation Coefficient (R2), compared against an actual dataset. The CatBoost model demonstrated exceptional performance, achieving an R2 of 0.88, MSE of 0.0816, MAE of 0.1994, RMSE of 0.2833, and MAPE of 0.0163. The novel methodology, leveraging advanced machine learning techniques, offers a unique perspective in assessing the potential of underground hydrogen storage. This approach is a valuable asset for various stakeholders, including government bodies, geological services, renewable energy facilities, and the chemical/petrochemical industry, aiding them in identifying optimal locations for hydrogen storage.

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Influence of geostatistical interpolation method and cell-size resolution on CO2 storage capacity estimates: Application to saline aquifers with sparse data availability in Israel

Calvo,

Taragan,

Rosenzweig

2023

International Journal of Greenhouse Gas Control

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A method for examining the geospatial distribution of CO2 storage resources applied to the Pre-Punta Gorda Composite and Dollar Bay reservoirs of the South Florida Basin, U.S.A.

Cited by 7 publications

References 14 publications

Effect of brine salinity on the geological sequestration of CO₂ in a deep saline carbonate formation

Effect of brine salinity on the geological sequestration of CO₂ in a deep saline carbonate formation

Artificial intelligence-driven assessment of salt caverns for underground hydrogen storage in Poland

Influence of geostatistical interpolation method and cell-size resolution on CO2 storage capacity estimates: Application to saline aquifers with sparse data availability in Israel

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A method for examining the geospatial distribution of CO2 storage resources applied to the Pre-Punta Gorda Composite and Dollar Bay reservoirs of the South Florida Basin, U.S.A.

Cited by 7 publications

References 14 publications

Effect of brine salinity on the geological sequestration of CO2 in a deep saline carbonate formation

Effect of brine salinity on the geological sequestration of CO2 in a deep saline carbonate formation

Artificial intelligence-driven assessment of salt caverns for underground hydrogen storage in Poland

Influence of geostatistical interpolation method and cell-size resolution on CO2 storage capacity estimates: Application to saline aquifers with sparse data availability in Israel

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Product

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Effect of brine salinity on the geological sequestration of CO₂ in a deep saline carbonate formation

Effect of brine salinity on the geological sequestration of CO₂ in a deep saline carbonate formation