Academic literature on the topic 'Deep saline aquifers'
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Journal articles on the topic "Deep saline aquifers"
1
Zahid, Anwar, Farhana Islam, M. Rashidul Hassan, Kamrul Islam, and Nur Ahmed. "Analysis of Aquifer Pumping Test Data to Determine Deep Groundwater Security in Southeastern Bangladesh." Journal of Natural Resources and Development 8 (December 1, 2018): 125–43. http://dx.doi.org/10.5027/jnrd.v8i0.12.
Full textAbstract:
In southeastern Bangladesh, where water quality in the upper aquifers is a serious constraint, future development will likely be confined to deep fresh groundwater. Owing to the importance and pervasive use of deep groundwater, the sustainability of water use has received extensive attention. However, excessive extraction from deep aquifers may pose a threat to the storage as well as the quality of water due to the high susceptibility to salinization and arsenic contamination from upper aquifers. Hence, determining the extension of aquifer units and the characterizing aquifer sediments are very important to ensure sustainable development and management of limited fresh groundwater resources. The study area extends over six districts of the southeastern coastal region of Bangladesh. In order to assess and monitor deep fresh groundwater potential in the study area, aquifer pumping tests were performed at six locations with up to 72 h of constant-discharge prior to recovery. Different methods were used to analyze the drawdown and recovery data considering aquifers as confined or leaky-confined. Based on transmissivity values it was found that the studied deep aquifers have moderate to high potential for potable water supply. However, this deep fresh groundwater may not be safe for a longer period where upper aquifer units contain saline groundwater and where there is no significant aquitard encountered above or below the deep aquifer. Irrigation extraction of the deep groundwater is not recommended.
2
Dangi, Shankar Lal, Shruti Malik, Pijus Makauskas, Vilte Karliute, Ravi Sharma, and Mayur Pal. "Assessment of CO2 leakage using mechanistic modelling approach for CO2 injection in deep saline aquifer of Lithuanian basin in presence of fault and fractures." Baltic Carbon Forum 2 (October 13, 2023): 15–16. http://dx.doi.org/10.21595/bcf.2023.23619.
Full textAbstract:
Injecting CO2 into deep saline aquifers is a prominent strategy for carbon capture and storage (CCS) to mitigate greenhouse gas emissions. However, ensuring the long-term integrity of CO2 storage is crucial to prevent leakage and potential environmental hazards. This paper investigates the impact of fracture permeability on CO2 leakage volumes in the context of CO2 injection into Syderiai deep saline aquifer for carbon capture and storage (CCS) applications. It explores the relationship between fracture permeability and the potential for CO2 leakage, as well as the volume of CO2 dissolved in water above and below the cap rock. Furthermore, the study examines how the leakage volume may evolve over time in Syderiai deep saline aquifer. A mechanistic model of Syderiai deep saline aquifer, of Lithuanian basin, was developed based on average permeability, porosity, NTG and thickness (Fig. 1) and is used in this analysis.
3
Khanal, Aaditya, and Md Fahim Shahriar. "Physics-Based Proxy Modeling of CO2 Sequestration in Deep Saline Aquifers." Energies 15, no. 12 (June 14, 2022): 4350. http://dx.doi.org/10.3390/en15124350.
Full textAbstract:
The geological sequestration of CO2 in deep saline aquifers is one of the most effective strategies to reduce greenhouse emissions from the stationary point sources of CO2. However, it is a complex task to quantify the storage capacity of an aquifer as it is a function of various geological characteristics and operational decisions. This study applies physics-based proxy modeling by using multiple machine learning (ML) models to predict the CO2 trapping scenarios in a deep saline aquifer. A compositional reservoir simulator was used to develop a base case proxy model to simulate the CO2 trapping mechanisms (i.e., residual, solubility, and mineral trapping) for 275 years following a 25-year CO2 injection period in a deep saline aquifer. An expansive dataset comprising 19,800 data points was generated by varying several key geological and decision parameters to simulate multiple iterations of the base case model. The dataset was used to develop, train, and validate four robust ML models—multilayer perceptron (MLP), random forest (RF), support vector regression (SVR), and extreme gradient boosting (XGB). We analyzed the sequestered CO2 using the ML models by residual, solubility, and mineral trapping mechanisms. Based on the statistical accuracy results, with a coefficient of determination (R2) value of over 0.999, both RF and XGB had an excellent predictive ability for the cross-validated dataset. The proposed XGB model has the best CO2 trapping performance prediction with R2 values of 0.99988, 0.99968, and 0.99985 for residual trapping, mineralized trapping, and dissolution trapping mechanisms, respectively. Furthermore, a feature importance analysis for the RF algorithm identified reservoir monitoring time as the most critical feature dictating changes in CO2 trapping performance, while relative permeability hysteresis, permeability, and porosity of the reservoir were some of the key geological parameters. For XGB, however, the importance of uncertain geologic parameters varied based on different trapping mechanisms. The findings from this study show that the physics-based smart proxy models can be used as a robust predictive tool to estimate the sequestration of CO2 in deep saline aquifers with similar reservoir characteristics.
4
Yang, Xiao Yi, Yan Feng Liu, and Jian Jun Wang. "CO2 Storage Capacity Assessment of Deep Saline Aquifer in Central Depression of Songliao Basin." Advanced Materials Research 734-737 (August 2013): 1905–9. http://dx.doi.org/10.4028/www.scientific.net/amr.734-737.1905.
Full textAbstract:
Carbon Capture and Storage (CCS) is one of the effective means to reduce the carbon dioxide concentration in atmosphere. Deep saline aquifer is the most potential storage sites because of its wide spread and the huge storage capacity. The storage capacity of deep saline aquifer was determined by hydrogeological parameters of the assessed aquifer. Spatial discretization method based on the geostatistical method takes account of the spatial variability of hydrogeological parameters involved in capacity assessment, which applied by inputting the value of hydrological parameters of every cell and calculating the storage capacity of each cell. The total storage capacity in assessed area was the summation of all cells. In the Central Depression of Songliao Basin, the theoretical carbon dioxide storage capacity of deep saline aquifers was estimated as 81.80Gt with spatial discretization method. Compared with the other methods, this method can reflect the spatial characteristics of the carbon dioxide storage capacities and was more precise.
5
Wang, Kai, Weifeng Lv, Zemin Ji, Ninghong Jia, Shumin Ni, Wen Jiang, Jinhong Cao, and Moxi Zhang. "A Study on the Dissolution Behavior of Typical Minerals in Continental Deposited Reservoirs during CO2 Geological Storage." Energies 16, no. 22 (November 13, 2023): 7560. http://dx.doi.org/10.3390/en16227560.
Full textAbstract:
CO2 sequestration in saline aquifers is one of the most potential sequestration modes, and saline aquifers are ideal sites for CO2 geological sequestration. After CO2 is injected into a saline aquifer, it will have a long-term complex geochemical reaction with the formation of minerals and water, and the minerals will undergo multiple reactions such as dissolution and reprecipitation. Therefore, an in-depth study of the geochemical reaction mechanisms between CO2 and formation minerals is of great significance to the accurate calculation and prediction of CO2 storage volume and the safety evaluation of long-term CO2 sequestration. In China, continental saline aquifers are widely distributed, whose mineral compositions and texture maturity are markedly different from those of the marine sedimentary basins in North America, and their stratigraphic environments are more complicated. The studies on the CO2–water–rock (mineral) still have many research gaps or insufficiencies, and there is no report on the dissolution mechanisms of individual minerals in the reaction. Taking one certain block of Daqing Oilfield, which is a typical continental deposit in China, as an example, we analyze the dissolution laws and four types of typical continental deposited minerals under the effect of CO2 and the change features of ionic compositions and pH of the formation water in the process of geochemical reaction. The research results indicate that CO2 has different dissolution degrees for the four types of minerals, among which, feldspar, as the main mineral in continental sedimentary formations, has the lowest dissolution rate. Furthermore, in terms of the water type (Na+-enriched NaHCO3) of the saline aquifer in the deep part of the continental deposit, feldspar can precipitate into the secondary minerals represented by dawsonite in the later stage, which can act as the potential minerals of carbon fixation to increase the CO2 mineralization storage volume in continental deposited saline aquifers.
6
Katayama, Taiki, Reo Ikawa, Masaru Koshigai, and Susumu Sakata. "Microbial methane formation in deep aquifers associated with the sediment burial history at a coastal site." Biogeosciences 20, no. 24 (December 21, 2023): 5199–210. http://dx.doi.org/10.5194/bg-20-5199-2023.
Full textAbstract:
Abstract. Elucidating the mechanisms underlying microbial methane formation in subsurface environments is essential to understanding the global carbon cycle. This study examined how microbial methane formation (i.e., methanogenesis) occurs in natural-gas-bearing sedimentary aquifers throughout the sediment burial history. Water samples collected from six aquifers of different depths exhibited ascending vertical gradients in salinity from brine to fresh water and in temperature from mesophilic to psychrophilic conditions. Analyses of gas and water isotopic ratios and microbial communities indicated the predominance of methanogenesis via CO2 reduction. However, the hydrogen isotopic ratio of water changed along the depth and salinity gradient, whereas the ratio of methane changed little, suggesting that in situ methanogenesis in shallow sediments does not significantly contribute to methane in the aquifers. The population of methane-producing microorganisms (methanogens) was highest in the deepest saline aquifers, where the water temperature, salinity, and total organic carbon content of the adjacent mud sediments were the highest. Cultivation of the dominant hydrogenotrophic methanogens in the aquifers showed that the methanogenesis rate was maximized at the temperature corresponding to that of the deepest aquifer. These results suggest that high-temperature conditions in deeply buried sediments are associated with enhanced in situ methanogenesis and that methane that forms in the deepest aquifer migrates upward into the shallower aquifers by diffusion.
7
Cao, Shuang Cindy, Jong Won Jung, and Jong Wan Hu. "CO2-Brine Displacement in Geological CO2 Sequestration: Microfluidic Flow Model Study." Applied Mechanics and Materials 752-753 (April 2015): 1210–13. http://dx.doi.org/10.4028/www.scientific.net/amm.752-753.1210.
Full textAbstract:
Geological CO2 sequestration is a promising method to reduce atmospheric CO2. Deep saline aquifers are one of the most important sites due to their capacity for CO2 storage. Thus, a better understanding of immiscible brine-CO2 mobility and their saturations including invading patterns in deep saline aquifers as CO2 storage sites is required. Microfluidic model provides the opportunity to discover unrecognized processes and to explore existing theories in fluid flow through porous media. In this study, the microfluidic model is used to explore the effects of both the supercritical carbon dioxide (scCO2) injecting velocity and ionic strength in saline aquifers on scCO2 invading patterns in geological CO2 sequestration. The results show that scCO2-brine displacement ratio increases with (1) increased scCO2 injecting velocity up to 40 μL/min, and (2) decreased ionic strength in the range of 1M~5M NaCl.
8
Kurtzman, D., S. Baram, and O. Dahan. "Soil–aquifer phenomena affecting groundwater under vertisols: a review." Hydrology and Earth System Sciences 20, no. 1 (January 15, 2016): 1–12. http://dx.doi.org/10.5194/hess-20-1-2016.
Full textAbstract:
Abstract. Vertisols are cracking clayey soils that (i) usually form in alluvial lowlands where, normally, groundwater pools into aquifers; (ii) have different types of voids (due to cracking), which make flow and transport of water, solutes and gas complex; and (iii) are regarded as fertile soils in many areas. The combination of these characteristics results in the unique soil–aquifer phenomena that are highlighted and summarized in this review. The review is divided into the following four sections: (1) soil cracks as preferential pathways for water and contaminants: in this section lysimeter-to basin-scale observations that show the significance of cracks as preferential-flow paths in vertisols, which bypass matrix blocks in the unsaturated zone, are summarized. Relatively fresh-water recharge and groundwater contamination from these fluxes and their modeling are reviewed; (2) soil cracks as deep evaporators and unsaturated-zone salinity: deep sediment samples under uncultivated vertisols in semiarid regions reveal a dry (immobile), saline matrix, partly due to enhanced evaporation through soil cracks. Observations of this phenomenon are compiled in this section and the mechanism of evapoconcentration due to air flow in the cracks is discussed; (3) impact of cultivation on flushing of the unsaturated zone and aquifer salinization: the third section examines studies reporting that land-use change of vertisols from native land to cropland promotes greater fluxes through the saline unsaturated-zone matrix, eventually flushing salts to the aquifer. Different degrees of salt flushing are assessed as well as aquifer salinization on different scales, and a comparison is made with aquifers under other soils; (4) relatively little nitrate contamination in aquifers under vertisols: in this section we turn the light on observations showing that aquifers under cultivated vertisols are somewhat resistant to groundwater contamination by nitrate (the major agriculturally related groundwater problem). Denitrification is probably the main mechanism supporting this resistance, whereas a certain degree of anion-exchange capacity may have a retarding effect as well.
9
Kurtzman, D., S. Baram, and O. Dahan. "Soil–aquifer phenomena affecting groundwater under vertisols: a review." Hydrology and Earth System Sciences Discussions 12, no. 9 (September 21, 2015): 9571–98. http://dx.doi.org/10.5194/hessd-12-9571-2015.
Full textAbstract:
Abstract. Vertisols are cracking clayey soils that: (i) usually form in alluvial lowlands where normally, groundwater pools into aquifers, (ii) have different types of voids (due to cracking) which make flow and transport of water, solutes and gas complex, and (iii) are regarded as fertile soils in many areas. The combination of these characteristics results in the unique soil–aquifer phenomena that are highlighted and summarized in this review. The review is divided into the following four sections: (1) soil cracks as preferential pathways for water and contaminants; in this section lysimeter- to basin-scale observations that show the significance of cracks as preferential flow paths in vertisols which bypass matrix blocks in the unsaturated zone are summarized. Relatively fresh-water recharge and groundwater contamination from these fluxes and their modeling are reviewed, (2) soil cracks as deep evaporators and unsaturated-zone salinity; deep sediment samples under uncultivated vertisols in semiarid regions reveal a dry (immobile), saline matrix, partly due to enhanced evaporation through soil cracks. Observations of this phenomenon are compiled in this section and the mechanism of evapoconcentration due to air flow in the cracks is discussed, (3) impact of cultivation on flushing of the unsaturated zone and aquifer salinization; the third section examines studies reporting that land-use change of vertisols from native land to cropland promotes greater fluxes through the saline unsaturated-zone matrix, eventually flushing salts to the aquifer. Different degrees of salt flushing are assessed as well as aquifer salinization on different scales, and a comparison is made with aquifers under other soils, (4) relatively little nitrate contamination in aquifers under vertisols; In this section we turn the light on observations showing that aquifers under cultivated vertisols are somewhat resistant to groundwater contamination by nitrate (the major agriculturally related groundwater problem). Denitrification is probably the main mechanism supporting this resistance, whereas a certain degree of anion-exchange capacity may have a retarding effect as well.
10
Rayward-Smith, W. J., and Andrew W. Woods. "Some implications of cold CO2injection into deep saline aquifers." Geophysical Research Letters 38, no. 6 (March 2011): n/a. http://dx.doi.org/10.1029/2010gl046412.
Full textDissertations / Theses on the topic "Deep saline aquifers"
1
Khudaida, Kamal. "Modelling CO2 sequestration in deep saline aquifers." Thesis, Loughborough University, 2016. https://dspace.lboro.ac.uk/2134/21104.
Full textAbstract:
In spite of the large number of research works on carbon capture and sequestration (CCS), the migration and behaviour of CO2 in the subsurface (i. e. strata below the earth's surface) still needs further understanding and investigations with the aim of encouraging the governmental policy makers to adopt CCS technology as one of the most viable means to tackle the global warming threats. In this research work, a series of numerical simulations has been carried out using STOMP-CO2 simulation code to determine the flow behaviour and ultimate fate of the injected supercritical carbon dioxide (scCO2) into saline aquifers in medium terms of storage (i. e. few thousand years). The characteristics of the employed simulator, including the mathematical algorithm, governing equations, equations of states and phase equilibria calculations are explained in details.
2
Izgec, Omer. "Experimental And Numarical Investigation Of Carbon Dioxide Sequestration In Deep Saline Aquifers." Master's thesis, METU, 2005. http://etd.lib.metu.edu.tr/upload/3/12606213/index.pdf.
Full textAbstract:
Started as an EOR technique to produce oil, injection of carbon dioxide which is essentially a greenhouse gas is becoming more and more important. Although there are a number of mathematical modeling studies, experimental studies are limited and most studies focus on injection into sandstone reservoirs as opposed to carbonate ones. This study presents the results of computerized tomography (CT) monitored laboratory experiments to characterize relevant chemical reactions associated with injection and storage of CO2 in carbonate formations. Porosity changes along the core plugs and the corresponding permeability changes are reported for varying CO2 injection rates, temperature and salt concentrations. CT monitored experiments are designed to model fast near well bore flow and slow reservoir flows. It was observed that either a permeability improvement or a permeability reduction can be obtained. The trend of change in rock properties is very case dependent because it is related to distribution of pores, brine composition and as well the thermodynamic conditions. As the salt concentration decreased the porosity and thus the permeability decrease was less pronounced. Calcite scaling is mainly influenced by orientation and horizontal flow resulted in
larger calcite deposition compared to vertical flow. The duration of CO2 &ndashrock contact and the amount of area contacted by CO2 seems to have a more pronounced effect compared to rate effect. The experiments were modeled using a multi-phase, non-isothermal commercial simulator where solution and deposition of calcite were considered by the means of chemical reactions. The calibrated model was then used to analyze field scale injections and to model the potential CO2 sequestration capacity of a hypothetical carbonate aquifer formation. It was observed that solubility and hydrodynamic storage of CO2 is larger compared to mineral trapping.
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Vilarrasa, Riaño Víctor. "Thermo-hydro-mechanical impacts of carbon dioxide (CO2) injection in deep saline aquifers." Doctoral thesis, Universitat Politècnica de Catalunya, 2012. http://hdl.handle.net/10803/96669.
Full textAbstract:
Los procesos termo-hidro-mecánicos relacionados con el almacenamiento geológico
de carbono deben ser entendidos y cuantificados para demostrar a la opinión pública
de que la inyección de dióxido de carbono (CO2) es segura. Esta Tesis tiene como
objetivo mejorar dicho conocimiento mediante el desarrollo de métodos para: (1)
evaluar la evolución tanto de la geometría de la pluma de CO2 como de la presión de
los fluidos; (2) definir un ensayo de campo que permita caracterizar la presión de
inyección máxima sostenible y los parámetros hidromecánicos de las rocas sello y
almacén; y (3) proponer un nuevo concepto de inyección que es energéticamente
eficiente y que mejora la estabilidad de la roca sello en la mayoría de escenarios
geológicos debido a efectos termo-mecánicos.
modelo viscoplástico. Las simulaciones ilustran que, dependiendo de las condiciones
de contorno, el momento más desfavorable ocurre al inicio de la inyección. Sin
embargo, si los contornos son poco permeables, la presión de fluido continúa
aumentando en todo el acuífero, lo que podría llegar a comprometer la estabilidad de
la roca sello a largo plazo.
Para evaluar dichos problemas, proponemos un ensayo de caracterización
hidromecánica a escala de campo para estimar las propiedades hidromecánicas de las
rocas sello y almacén. Obtenemos curvas para la sobrepresión y el desplazamiento
vertical en función del término de la deformación volumétrica obtenido del análisis
adimensional de las ecuaciones hidromecánicas. Ajustando las medidas de campo a
estas curvas se pueden estimar los valores del módulo de Young y el coeficiente de
Poisson del acuífero y del sello. Los resultados indican que la microsismicidad
inducida tiene más probabilidades de ocurrir en el acuífero que en el sello. El inicio de
la microsismicidad en el sello marca la presión de inyección máxima sostenible para
asegurar un almacenamiento permanente de CO2 seguro.
Finalmente, analizamos la evolución termodinámica del CO2 y la respuesta termohidro-
mecánica de las rocas sello y almacén a la inyección de CO2 líquido (frío).
Encontramos que inyectar CO2 en estado líquido es energéticamente más eficiente
porque al ser más denso que el CO2 supercrítico, requiere menor presión en cabeza
de pozo para una presión dad en el acuífero. De hecho, esta presión también es
menor en el almacén porque se desplaza un volumen menor de fluido. La disminución
de temperatura en el entorno del pozo induce una reducción de tensiones debido a la
contracción térmica del medio. Esto puede producir deslizamiento de fracturas
existentes en acuíferos formados por rocas rígidas bajo contrastes de temperatura
grandes, lo que podría incrementar la inyectividad de la roca almacén. Por otro lado, la
estabilidad mecánica de la roca sello mejora cuando la tensión principal máxima es la
vertical.
Primero, investigamos numérica y analíticamente los efectos de la variabilidad de la
densidad y viscosidad del CO2 en la posición de la interfaz entre la fase rica en CO2 y
la salmuera de la formación. Introducimos una corrección para tener en cuenta dicha
variabilidad en las soluciones analíticas actuales. Encontramos que el error producido
en la posición de la interfaz al despreciar la compresibilidad del CO2 es relativamente
pequeño cuando dominan las fuerzas viscosas. Sin embargo, puede ser significativo
cuando dominan las fuerzas de gravedad, lo que ocurre para tiempos y/o distancias
largas de inyección.
Segundo, desarrollamos una solución semianalítica para la evolución de la geometría
de la pluma de CO2 y la presión de fluido, teniendo en cuenta tanto la compresibilidad
del CO2 como los efectos de flotación dentro del pozo. Formulamos el problema en
términos de un potencial de CO2 que facilita la solución en capas horizontales, en las
que hemos discretizado el acuífero. El CO2 avanza inicialmente por la porción superior
del acuífero. Pero a medida que aumenta la presión de CO2, la pluma crece no solo
lateralmente, sino también hacia abajo, aunque no tiene porqué llegar a ocupar todo el
espesor del acuífero. Tanto la interfaz CO2-salmuera como la presión de fluido
muestran una buena comparación con las simulaciones numéricas.
En tercer lugar, estudiamos posibles mecanismos de rotura, que podrían llegar a
producir fugas de CO2, en un sistema acuífero-sello con simetría radial, utilizando unEls processos termo-hidro-mecànics relacionats amb l’emmagatzematge geològic de carboni han de ser entesos i quantificats per tal de demostrar a l’opinió pública de que la injecció de diòxid de carboni (CO2) és segura. Aquesta Tesi té com a objectiu millorar aquest coneixement mitjançant el desenvolupament de mètodes per a: (1) avaluar l'evolució tant de la geometria del plomall de CO2 com de la pressió dels fluids; (2) definir un assaig de camp que permeti caracteritzar la pressió d'injecció màxima sostenible i els paràmetres hidromecànics de les roques segell i magatzem; i (3) proposar un nou concepte d'injecció que és energèticament eficient i que millora l'estabilitat de la roca segell en la majoria d’escenaris geològics a causa d'efectes termo-mecànics. Primer, investiguem numèricament i analítica els efectes de la variabilitat de la densitat i viscositat del CO2 en la posició de la interfície entre la fase rica en CO2 i la salmorra de la formació. Introduïm una correcció per tal de tenir en compte aquesta variabilitat en les solucions analítiques actuals. Trobem que l'error produït en la posició de la interfície en menysprear la compressibilitat del CO2 és relativament petit quan dominen les forces viscoses. Malgrat això, l’error pot ser significatiu quan dominen les forces de gravetat, la qual cosa té lloc per a temps i/o distàncies llargues d'injecció. Segon, desenvolupem una solució semianalítica per a l'evolució de la geometria del plomall de CO2 i la pressió de fluid, tenint en compte tant la compressibilitat del CO2 com els efectes de flotació dins del pou. Formulem el problema en termes d'un potencial de CO2 que facilita la solució en capes horitzontals, en les quals hem discretitzat l'aqüífer. El CO2 avança inicialment per la porció superior de l'aqüífer. Però a mesura que augmenta la pressió de CO2, el plomall de CO2 no només creix lateralment, sinó que també ho fa cap avall, encara que no té perquè arribar a ocupar tot el gruix de l'aqüífer. Tant la interfície CO2-salmorra com la pressió de fluid mostren una bona comparació amb les simulacions numèriques. En tercer lloc, estudiem possibles mecanismes de trencament, que podrien arribar a produir fugues de CO2, en un sistema aqüífer-segell amb simetria radial, utilitzant un model viscoplàstic. Les simulacions il·lustren que, depenent de les condicions de contorn, el moment més desfavorable té lloc a l'inici de la injecció. Tot i això, si els contorns són poc permeables, la pressió de fluid continua augmentant en tot l'aqüífer, la qual cosa podria arribar a comprometre l'estabilitat de la roca segell a llarg termini. Per a avaluar aquests problemes, proposem un assaig de caracterització hidromecànica a escala de camp per a estimar les propietats hidromecàniques de les roques segell i magatzem. Obtenim corbes per a la sobrepressió i el desplaçament vertical en funció del terme de la deformació volumètrica obtingut de l'anàlisi adimensional de les equacions hidromecàniques. Ajustant les mesures de camp a aquestes corbes es poden estimar els valors del mòdul de Young i el coeficient de Poisson de l'aqüífer i del segell. Els resultats indiquen que la microsismicitat induïda té més probabilitats d'ocórrer en l'aqüífer que en el segell. L'inici de la microsismicitat en el segell marca la pressió d'injecció màxima sostenible per tal d’assegurar un emmagatzematge permanent de CO2 segur. Finalment, analitzem l'evolució termodinàmica del CO2 i la resposta termo-hidromecànica de les roques segell i magatzem a la injecció de CO2 líquid (fred). Trobem que injectar CO2 en estat líquid és energèticament més eficient perquè al ser més dens que el CO2 supercrític, requereix una pressió menor al cap de pou per a una pressió donada a l’aqüífer. De fet, aquesta pressió també és menor a l’aqüífer perquè es desplaça un volum menor de fluid. La disminució de temperatura a l'entorn del pou indueix una reducció de tensions a causa de la contracció tèrmica del medi. Això pot produir lliscament de fractures existents en aqüífers formats per roques rígides sota contrastos de temperatura grans, la qual cosa podria incrementar la injectivitat de la roca magatzem. D’altra banda, l'estabilitat mecànica de la roca segell millora quan la tensió principal màxima és la vertical.
Coupled thermo-hydro-mechanical (THM) effects related to geologic carbon storage should be understood and quantified in order to convince the public that carbon dioxide (CO2) injection is safe. This Thesis aims to improve such understanding by developing methods to: evaluate the CO2 plume geometry and fluid pressure evolution; define a field test to characterize the maximum sustainable injection pressure and the hydromechanical (HM) properties of the aquifer and the caprock; and propose an energy efficient injection concept that improves the caprock mechanical stability in most geological settings due to thermo-mechanical effects. First, we investigate numerically and analytically the effect of CO2 density and viscosity variability on the position of the interface between the CO2-rich phase and the formation brine. We introduce a correction to account for this variability in current analytical solutions. We find that the error in the interface position caused by neglecting CO2 compressibility is relatively small when viscous forces dominate. However, it can become significant when gravity forces dominate, which is likely to occur at late times and/or far from the injection well. Second, we develop a semianalytical solution for the CO2 plume geometry and fluid pressure evolution, accounting for CO2 compressibility and buoyancy effects in the injection well. We formulate the problem in terms of a CO2 potential that facilitates solution in horizontal layers, in which we discretize the aquifer. We find that when a prescribed CO2 mass flow rate is injected, CO2 advances initially through the top portion of the aquifer. As CO2 pressure builds up, CO2 advances not only laterally, but also vertically downwards. However, the CO2 plume does not necessarily occupy the whole thickness of the aquifer. Both CO2 plume position and fluid pressure compare well with numerical simulations. Third, we study potential failure mechanisms, which could lead to CO2 leakage, in an axysimmetric horizontal aquifercaprock system, using a viscoplastic approach. Simulations illustrate that, depending on boundary conditions, the least favorable situation may occur at the beginning of injection. However, in the presence of low-permeability boundaries, fluid pressure continues to rise in the whole aquifer, which may compromise the caprock integrity in the long-term. Next, we propose a HM characterization test to estimate the HM properties of the aquifer and caprock at the field scale. We obtain curves for overpressure and vertical displacement as a function of the volumetric strain term obtained from a dimensional analysis of the HM equations. We can then estimate the values of the Young¿s modulus and the Poisson ratio of the aquifer and the caprock by introducing field measurements in these plots. Results indicate that induced microseismicity is more likely to occur in the aquifer than in the caprock. The onset of microseismicity in the caprock can be used to define the maximum sustainable injection pressure to ensure a safe permanent CO2 storage. Finally, we analyze the thermodynamic evolution of CO2 and the THM response of the formation and the caprock to liquid (cold) CO2 injection. We find that injecting CO2 in liquid state is energetically more efficient than in supercritical state because liquid CO2 is denser than supercritical CO2. Thus, the pressure required at the wellhead is much lower for liquid than for gas or supercritical injection. In fact, the overpressure required at the aquifer is also smaller because a smaller fluid volume is displaced. The temperature decrease close to the injection well induces a stress reduction due to thermal contraction of the media. This can lead to shear slip of pre-existing fractures in the aquifer for large temperature contrasts in stiff rocks, which could enhance injectivity. In contrast, the mechanical stability of the caprock is improved in stress regimes where the maximum principal stress is the vertical.
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Tian, Liang. "CO2 storage in deep saline aquifers : Models for geological heterogeneity and large domains." Doctoral thesis, Uppsala universitet, Luft-, vatten och landskapslära, 2016. http://urn.kb.se/resolve?urn=urn:nbn:se:uu:diva-279382.
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This work presents model development and model analyses of CO2 storage in deep saline aquifers. The goal has been two-fold, firstly to develop models and address the system behaviour under geological heterogeneity, second to tackle the issues related to problem scale as modelling of the CO2 storage systems can become prohibitively complex when large systems are considered. The work starts from a Monte Carlo analysis of heterogeneous 2D domains with a focus on the sensitivity of two CO2 storage performance measurements, namely, the injectivity index (Iinj) and storage efficiency coefficient (E), on parameters characterizing heterogeneity. It is found that E and Iinj are determined by two different parameter groups which both include correlation length (λ) and standard deviation (σ) of the permeability. Next, the issue of upscaling is addressed by modelling a heterogeneous system with multi-modal heterogeneity and an upscaling scheme of the constitutive relationships is proposed to enable the numerical simulation to be done using a coarser geological mesh built for a larger domain. Finally, in order to better address stochastically heterogeneous systems, a new method for model simulations and uncertainty analysis based on a Gaussian processes emulator is introduced. Instead of conventional point estimates this Bayesian approach can efficiently approximate cumulative distribution functions for the selected outputs which are CO2 breakthrough time and its total mass. After focusing on reservoir behaviour in small domains and modelling the heterogeneity effects in them, the work moves to predictive modelling of large scale CO2 storage systems. To maximize the confidence in the model predictions, a set of different modelling approaches of varying complexity is employed, including a semi-analytical model, a sharp-interface vertical equilibrium (VE) model and a TOUGH2MP / ECO2N model. Based on this approach, the CO2 storage potential of two large scale sites is modelled, namely the South Scania site, Sweden and the Dalders Monocline in the Baltic Sea basin. The methodologies developed and demonstrated in this work enable improved analyses of CO2 geological storage at both small and large scales, including better approaches to address medium heterogeneity. Finally, recommendations for future work are also discussed.
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DA, COL FEDERICO. "Modelling Techniques to Monitor the Injection of Carbon Dioxide in Deep Saline Aquifers." Doctoral thesis, Università degli Studi di Trieste, 2017. http://hdl.handle.net/11368/2908149.
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In this thesis we want to model all steps of a CO2 injection in deep saline aquifers, from the injection to the monitoring by means of seismic methods. After outlining the main physical and chemical processes which allow the CO2 to be trapped for very long periods of time, we present two numerical examples. In the first one, CO2 is injected in a complex aquifer, part of an anticlinal structure, with characteristics resembling those of the Sleipner field. The injection is monitored via an active cross-hole seismic experiment; in particular, we perform a tomographic inverion of the direct arrivals. In the second example, CO2 is injected at a constant rate for one hour in a homogenous aquifer. It is then monitored with a passive seismic method. In fact, the overpressure caused by the injection, may lead to the formation of microcracks and therefore to the emission of seismic waves. We approximate the position of the CO2 plume by finding these emitting points by means of a reverse-time migration algorithm.
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Ozgur, Emre. "Assessment Of Diffusive And Convective Mechanisms During Carbon Dioxide Sequestration Into Deep Saline Aquifers." Master's thesis, METU, 2006. http://etd.lib.metu.edu.tr/upload/12608014/index.pdf.
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The analytical and numerical modeling of CO2 sequestration in deep saline aquifers having different properties was studied with diffusion and convection mechanisms. The complete dissolution of CO2 in the aquifer by diffusion took thousands, even millions of years. In diffusion dominated system, an aquifer with 100 m thickness saturated with CO2 after 10,000,000 years. It was much earlier in convective dominant system. In diffusion process, the dissolution of CO2 in aquifer increased with porosity increasehowever, in convection dominant process dissolution of CO2 in aquifer decreased with porosity increase. The increase in permeability accelerated the dissolution of CO2 in aquifer significantly, which was due to increasing velocity. The dissolution process in the aquifer realized faster for the aquifers with lower dispersivity. The results of convective dominant mechanism in aquifers with 1md and 10 md permeability values were so close to that of diffusion dominated system. For the aquifer having permeability higher than 10 md, the convection mechanism began to dominate gradually and it became fully convection dominated system for 50 md and higher permeability values. These results were also verified with calculated Rayleigh number and mixing zone lengths. The mixing zone length increased with increase in porosity and time in diffusion dominated system. However, the mixing zone length decreased with increase in porosity and it increased with increase in dispersivity and permeability higher than 10 md in convection dominated system.
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Anbar, Sultan. "Development Of A Predictive Model For Carbon Dioxide Sequestration In Deep Saline Carbonate Aquifers." Master's thesis, METU, 2009. http://etd.lib.metu.edu.tr/upload/12610692/index.pdf.
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Although deep saline aquifers are found in all sedimentary basins and provide very large storage capacities, a little is known about them because they are rarely a target for the exploration. Furthermore, nearly all the experiments and simulations made for CO2 sequestration in deep saline aquifers are related to the sandstone formations. The aim of this study is to create a predictive model to estimate the CO2 storage capacity of the deep saline carbonate aquifers since a little is known about them. To create a predictive model, the variables which affect the CO2 storage capacity and their ranges are determined from published literature data. They are rock properties (porosity, permeability, vertical to horizontal permeability ratio), fluid properties (irreducible water saturation, gas permeability end point, Corey water and gas coefficients), reaction properties (forward and backward reaction rates) and reservoir properties (depth, pressure gradient, temperature gradient, formation dip angle, salinity), diffusion coefficient and
Kozeny-Carman Coefficient. Other parameters such as pore volume compressibility and density of brine are calculated from correlations found in literature. To cover all possibilities, Latin Hypercube Space Filling Design is used to construct 100 simulation cases and CMG STARS is used for simulation runs. By using least squares method, a linear correlation is found to calculate CO2 storage capacity of the deep saline carbonate aquifers with a correlation coefficient 0.81 by using variables found from literature and simulation results. Numerical dispersion effects have been considered by increasing the grid dimensions. It has been found that correlation coefficient decreased to 0.77 when the grid size was increased from 250 ft to 750 ft. The
sensitivity analysis shows that the most important parameter that affects CO2 storage capacity is depth since the pressure difference between formation pressure and fracture pressure increases with depth. Also, CO2 storage mechanisms are investigated at the end of 300 years of simulation. Most of
the gas (up to 90%) injected into formation dissolves into the formation water and negligible amount of CO2 reacts with carbonate. This result is consistent with sensitivity analysis results since the variables affecting the solubility of
CO2 in brine have greater affect on storage capacity of aquifers.
Dimensionless linear and nonlinear predictive models are constructed to estimate the CO2 storage capacity of all deep saline carbonate aquifers and it is found that the best dimensionless predictive model is linear one independent of bulk volume of the aquifer.
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Ndjaka, Ange. "THERMOPHYSICAL PROCESSES AND REACTIVE TRANSPORT MECHANISMS INDUCED BY CO2 INJECTION IN DEEP SALINE AQUIFERS." Electronic Thesis or Diss., Pau, 2022. http://www.theses.fr/2022PAUU3003.
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Le stockage du CO2 dans les aquifères salins profonds a été reconnu comme l'une des voies les plus prometteuses pour atténuer les émissions atmosphériques de CO2 et répondre ainsi aux enjeux du changement climatique. Cependant, l’injection du CO2 dans le milieu poreux perturbe considérablement son équilibre thermodynamique. La zone proche du puits d’injection est particulièrement impactée avec une forte réactivité géochimique associée à d’intenses échanges thermiques. Cela a un impact majeur sur l’injectivité du réservoir et l’intégrité du stockage. A ces effets s’ajoute une complexité supplémentaire liée à la présence de deux phases non miscibles : la saumure et le CO2. Ces effets conduisent à des processus Thermo-Hydro-Mécaniques-Chimiques (THMC) fortement couplés, dont les interprétations ne sont pas encore abouties ni formellement implémentées dans les modèles numériques.Ce travail de thèse, associant des mesures expérimentales et des modélisations numériques, porte sur l’étude du couplage entre les gradients thermiques et les processus diffusifs de transport réactif se déroulant dans les aquifères salins, notamment dans la zone proche du puits d’injection. Nous avons étudié les échanges entre une phase froide CO2 anhydre qui s’écoule dans des zones de forte perméabilité, et une phase aqueuse salée chaude piégée dans la porosité de la roche. La stratégie de l'étude commence par une approche simple en milieu libre sans flux de CO2 afin d'étudier la réactivité des solutions salines de différentes compositions chimiques et d’évaluer l'impact d'un gradient thermique sur ce réseau réactionnel.Nous avons développé une cellule expérimentale permettant de superposer 2 à 3 couches de solution de concentration et composition chimique différentes. L’analyse de la lumière diffusée par les fluctuations de non-équilibre de la concentration et de la température permet de remonter aux coefficients de diffusion des sels dans l’eau. Nos résultats sont en bon accord avec les valeurs de la littérature. Pour ce qui est de l’étude du transport réactif diffusif, l’analyse du contraste des images a permis de mettre en évidence le fait que la précipitation de minéral, par mise en contact de deux couches aqueuses de sels réactifs, s’accompagne d’une instabilité convective qui s’estompe dans le temps. La modélisation numérique des résultats expérimentaux avec PHREEQC par une approche de diffusion multi-espèce hétérogène permet de rendre compte des instabilités convectives. Différents gradients de température ont été appliqués au système réactif, tout en conservant une température moyenne de 25 °C. Les observations expérimentales et les interprétations numériques montrent que le gradient de température n'a pas d’influence significative sur le comportement du système.Ensuite, nous avons étudié numériquement le processus de dessiccation (évaporation de l’eau) à l’interface entre une saumure piégée dans la porosité de la roche et du CO2 circulant dans une structure porale drainante, simulant les conditions de l’aquifère du Dogger du bassin parisien. Un modèle couplant l’évaporation de l’eau dans le flux de CO2 et la diffusion multi-espèces hétérogène des sels prévoit l’apparition d’un assemblage minéral au niveau du front d’évaporation, principalement composé d’halite et d’anhydrite. La modélisation de ce phénomène à l’échelle du réservoir nécessite la prise en compte de la vitesse d’évaporation en fonction du taux d’injection du CO2 et de l’évolution de la porosité au niveau de l’interface.Ce travail de thèse a permis de mettre en évidence plusieurs phénomènes physico-chimiques, thermo-physiques et de transport diffusif aux interfaces de phase. Ce qui ouvre de nouvelles perspectives d’amélioration des approches numériques et de modélisation à grande échelle notamment du proche puits d’injection du CO2 et des réservoirs de stockage géologique et soutenir les futurs développements industriels et technologiques pour la transition écologiqueCO2 storage in deep saline aquifers has been recognised as one of the most promising ways to mitigate atmospheric CO2 emissions and thus respond to the challenges of climate change. However, the injection of CO2 into the porous medium considerabely disturbs its thermodynamic equilibrium. The near-well injection zone is particularly impacted with a strong geochemical reactivity associated with intense heat exchanges. This has a major impact on injectivity of the reservoir and the integrity of the storage. In addition to these effects, there is the added complexity of the presence of two immiscible phases: brine (wetting fluid) and CO2 (non-wetting fluid). These effects lead to highly coupled Thermo-Hydro-Mechanical-Chemical (THMC) processes, whose interpretations have not yet been completed nor formally implemented into the numerical models.This thesis work, combining experimental measurements and numerical modelling, focuses on the study of the coupling between the thermal gradients and the diffusive reactive transport processes taking place in the deep saline aquifers, particularly in the near-well injection zone. We studied the exchanges between a cold anhydrous CO2 phase flowing in high permeability zones, and a hot salty aqueous phase trapped in the porosity of the rock. The strategy of the study starts with a simple approach in a free medium without CO2 flow, in order to study the reactivity of saline solutions of different chemical compositions, and to evaluate the impact of a thermal gradient on this reaction network.We have developed an experimental cell that allow to superimpose 2 to 3 layers of solution of different concentration and chemical composition. The analysis of the light scattered by the non-equilibrium fluctuations of concentration and temperature allows to obtain the diffusion coefficients of salts in water. Our results are in good agreement with literature values. Regarding the study of diffusive reactive transport, the analysis of the contrast of the images allowed us to highlight the fact that the precipitation of minerals, obtained by superimposing two aqueous layers of reactive, is accompanied by a convective instability that fades with time. Numerical modelling of the experimental results with PHREEQC using a heterogeneous multicomponent diffusion approach has allowed us to account for these convective instabilities. Different temperature gradients were applied to the reactive system, while keeping a mean temperature of 25 °C. The experimental observations and numerical interpretations swhow that the temperature gradient has no significant influence on the behaviour of the system. Subsequently, we numerically studied the desiccation process (evaporation of water) at the interface between a brine trapped in the rock porosity and the CO2 flowing in a draining pore structure, simulating the conditions of the Dogger aquifer of the Paris basin. A model coupling the evaporation of water in the CO2 stream and the heterogeneous multicomponent diffusion of salts predicts the appearance of a mineral assemblage at the evaporation front, mainly composed by halite and anhydrite. Modelling this phenomenon at the reservoir scale would requires taking into account the evaporation rate as a function of the CO2 injection rate and the change in porosity at the interface.This thesis work has made it possible to highlight several physicochemical, thermophysical and diffusive transport phenomena at phase interfaces. This opens up new perspectives for improving numerical approaches and large-scale modelling, in particular of near-well injection of CO2 and geological storage reservoirs, and supports future industrial developments and technologies for the ecological transition
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Jacob, Ruth E. "PROCESSES RELATED TO HYDRODYNAMIC AND MINERAL TRAPPING FOR THE PURPOSE OF CARBON STORAGE IN DEEP SALINE AQUIFERS." Case Western Reserve University School of Graduate Studies / OhioLINK, 2016. http://rave.ohiolink.edu/etdc/view?acc_num=case1450735566.
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Szulczewski, Michael Lawrence. "Storage capacity and injection rate estimates for CO₂ sequestration in deep saline aquifers in the conterminous United States." Thesis, Massachusetts Institute of Technology, 2009. http://hdl.handle.net/1721.1/53087.
Full textAbstract:
Thesis (S.M.)--Massachusetts Institute of Technology, Dept. of Civil and Environmental Engineering, 2009.Includes bibliographical references (p. 141-148).
A promising method to mitigate global warming is injecting CO₂ into deep saline aquifers. In order to ensure the safety of this method, it is necessary to understand how much CO₂ can be injected into an aquifer and at what rate. Since offsetting nationwide emissions requires storing very large quantities of CO₂, these properties must be understood at the large scale of geologic basins. In this work, we develop simple models of storage capacity and injection rate at the basin scale. We develop a storage capacity model that calculates how much CO₂ an aquifer can store based on how the plume of injected CO₂ migrates. We also develop an injection rate model that calculates the maximum rate at which CO₂ can be injected into an aquifer based on the pressure rise in the aquifer. We use these models to estimate storage capacities and maximum injection rates for a variety of reservoirs throughout the United States, and compare the results to predicted emissions from coal-burning power plants over the next twenty-five years and fifty years. Our results suggest that the United States has enough storage capacity to sequester all of the CO₂ emitted from coal-burning plants over the next 25 years. Furthermore, our results indicate that CO₂ can be sequestered at the same rate it is emitted for this time period without fracturing the aquifers. For emissions over the next 50 years, however, the results are less clear: while the United States will likely have enough capacity, maintaining sufficiently high injection rates could be problematic.
by Michael Lawrence Szulczewski.
S.M.
Books on the topic "Deep saline aquifers"
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Wirojanagud, Prakob. Numerical modeling of regional ground-water flow in the Deep-Basin Brine aquifer of the Palo Duro Basin, Texas Panhandle. Austin, Tex: Bureau of the Economic Geology, University of Texas at Austin, 1986.
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Warnecki, Marcin. Analysis of additional gas production possibility from deep saline aquifers in the process of CO2 sequestration. Instytut Nafty i Gazu - Państwowy Instytut Badawczy, 2016. http://dx.doi.org/10.18668/pn2016.211.
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Potential hazards to water resources along a test-flight path, 1952: Possible disposal of liquid waste in a deep saline aquifer, 1954; [and] Hydrologic aspects of a proposed burial ground, 1965. Reston, Va: U.S. Geological Survey, 1991.
Find full textBook chapters on the topic "Deep saline aquifers"
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Shukla Potdar, Richa, and V. Vishal. "Trapping Mechanism of CO2 Storage in Deep Saline Aquifers: Brief Review." In Geologic Carbon Sequestration, 47–58. Cham: Springer International Publishing, 2016. http://dx.doi.org/10.1007/978-3-319-27019-7_3.
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Dinesh, P., M. R. Behera, P. G. Ranjith, and N. Muthu. "Application of an Efficient Numerical Model for CO2 Sequestration in Deep Saline Aquifers." In Lecture Notes in Civil Engineering, 685–708. Singapore: Springer Singapore, 2019. http://dx.doi.org/10.1007/978-981-13-3119-0_45.
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Rosenzweig, Ravid, Ran Calvo, and Uri Shavit. "The Use of Saline Aquifers as a Target for Deep Geologic CO2 Storage in Israel." In Springer Hydrogeology, 473–76. Cham: Springer International Publishing, 2020. http://dx.doi.org/10.1007/978-3-030-51148-7_23.
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Kinzelbach, Wolfgang, Haijing Wang, Yu Li, Lu Wang, and Ning Li. "Way Forward." In Springer Water, 137–54. Singapore: Springer Singapore, 2021. http://dx.doi.org/10.1007/978-981-16-5843-3_5.
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AbstractThe combination of fallowing and substituting groundwater by surface water was effective in reducing aquifer depletion in Guantao. The average annual depletion rate after 2014 was about half the value of the pre-project period 2000–2013 and basically limited to the deep aquifer. The goal of closing all deep aquifer wells has only been reached partially, their use being necessary in locations where the shallow aquifer is too saline.
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Xie, Ze-hao, Lie-hui Zhang, Yu-long Zhao, Cheng Cao, Long-xin Li, and De-ping Zhang. "CO2 Storage in Deep Saline Aquifer Injection Types, Well Placement and Well Control Co-optimization." In Springer Series in Geomechanics and Geoengineering, 434–46. Singapore: Springer Nature Singapore, 2024. http://dx.doi.org/10.1007/978-981-97-0268-8_34.
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Sinha, Ranjan, and Ashok Kumar. "Characterization of a Deep Saline Aquifer Using Oil Exploration Data in an Arid Region of Rajasthan, India." In Ground Water Development - Issues and Sustainable Solutions, 69–83. Singapore: Springer Singapore, 2018. http://dx.doi.org/10.1007/978-981-13-1771-2_4.
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Luther, Emmanuel E., Seyed M. Shariatipour, Michael C. Dallaston, and Ran Holtzman. "Solute Driven Transient Convection in Layered Porous Media." In Springer Proceedings in Energy, 3–9. Cham: Springer International Publishing, 2021. http://dx.doi.org/10.1007/978-3-030-63916-7_1.
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AbstractCO2 geological sequestration has been proposed as a climate change mitigation strategy that can contribute towards meeting the Paris Agreement. A key process on which successful injection of CO2 into deep saline aquifer relies on is the dissolution of CO2 in brine. CO2 dissolution improves storage security and reduces risk of leakage by (i) removing the CO2 from a highly mobile fluid phase and (ii) triggering gravity-induced convective instability which accelerates the downward migration of dissolved CO2. Our understanding of CO2 density-driven convection in geologic media is limited. Studies on transient convective instability are mostly in homogeneous systems or in systems with heterogeneity in the form of random permeability distribution or dispersed impermeable barriers. However, layering which exist naturally in sedimentary geological formations has not received much research attention on transient convection. Therefore, we investigate the role of layering on the onset time of convective instability and on the flow pattern beyond the onset time during CO2 storage. We find that while layering has no significant effect on the onset time, it has an impact on the CO2 flux. Our findings suggest that detailed reservoir characterisation is required to forecast the ability of a formation to sequester CO2.
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Pilla, Giorgio, Patrizio Torrese, and Marica Bersan. "The Uprising of Deep Saline Paleo-Waters into the Oltrepò Pavese Aquifer (Northern Italy): Application of Hydro-Chemical and Shallow Geophysical Surveys." In Engineering Geology for Society and Territory - Volume 3, 393–97. Cham: Springer International Publishing, 2014. http://dx.doi.org/10.1007/978-3-319-09054-2_82.
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Ji, Xiaoyan, and Chen Zhu. "CO2 Storage in Deep Saline Aquifers." In Novel Materials for Carbon Dioxide Mitigation Technology, 299–332. Elsevier, 2015. http://dx.doi.org/10.1016/b978-0-444-63259-3.00010-0.
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Kumar, Ajitabh, Myeong H. Noh, Gary A. Pope, Kamy Sepehrnoori, Steven L. Bryant, and Larry W. Lake. "Simulating CO2 Storage in Deep Saline Aquifers." In Carbon Dioxide Capture for Storage in Deep Geologic Formations, 877–96. Elsevier, 2005. http://dx.doi.org/10.1016/b978-008044570-0/50140-9.
Full textConference papers on the topic "Deep saline aquifers"
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Alzayer, Hassan, Tareq Zahrani, and Ahmed Shubbar. "Modeling CO2 Sequestration in Deep Saline Aquifers – Best Practices." In International Petroleum Technology Conference. IPTC, 2022. http://dx.doi.org/10.2523/iptc-22423-ea.
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Abstract Managing carbon emissions has become a major responsibility for the oil and gas industry in a drive to ensure sustainable energy and create a clean environment. Therefore, governments, research centers, IOC’s and NOC’s are actively adopting new guidelines and inventing new technologies to safely circulate carbons. In this paper, the process of modeling CO2 sequestration in a deep saline aquifer will be discussed. Carbon dioxide can be safely stored indefinitely in subsurface geological formations by four trapping mechanisms; structural, residual, soluble, and mineral trapping. These four trapping mechanisms can take hundreds or thousands of years to happen. Furthermore, the oil and gas industry standard recommend that any technology used to store CO2 needs to demonstrate a storage capacity of 1000 years with less than 0.1 per-cent leakage potential per year. Therefore, modelling such process should capture any existing trapping mechanism, even if it happens after several hundreds of years, to ensure long-term secure storage of the CO2. Using our in-house simulator "GigaPOWERS", many sequestration scenarios were conducted to come up with a recommended guideline to maximize the volume of CO2 trapped in deep saline aquifers. This study used a giant synthetic anticline model with a variation in geological properties. The residual and soluble trapping mechanisms were captured through relative permeability hysteresis and extended water PVT tables respectively. Injecting CO2 into water aquifers is a dynamic process where drainage and imbibition cycles are likely to happen. Such processes cause the CO2 to be trapped in the middle of the pores as an immobile phase, which can be a favorable phenomenon maximizing the security of CO2 sequestration. Since CO2 is soluble in water, when it contacts the water phase it will form a carbonated water that is denser than water itself and migrates downward in a phenomenon known as "CO2 fingering". The CO2 solubility in water depends mainly on the salinity and temperature which both need to be accurately captured in the simulation model. Depending on the long-term objective of the sequestration project, the development strategy can be altered to maximize the outcome using the detailed simulation model. In this paper, the simulation best practices for modeling CO2 sequestration for maximum secure long-term storage (1000+ years) are suggested. Carbon dioxide, CO2, sequestration in deep saline aquifers is a well-known method to reduce carbon emissions. However, there is very little published literature on the simulation best practices for modeling the CO2 sequestration process. Therefore, this paper will be a pioneer to guide the industry for accurate simulation of such process.
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Eleoni, M., J. Dredge, Y. De Boer, K. Mansour, A. Ismail, R. ElSayed, I. Merghany, et al. "Unlocking Carbon Capture & Sequestration in Ultra Deep Saline Aquifers in the Western Desert of Egypt." In GOTECH. SPE, 2024. http://dx.doi.org/10.2118/219207-ms.
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Abstract Conventional subsurface reservoir candidates for CO2 Sequestration are usually just deeper than 800 m to ensure CO2 is injected at supercritical state, typically these are shallow, gently dipped, low pressure saline aquifer or completely depleted and abandoned hydrocarbon reservoirs. However, in this study within the western desert of Egypt, none of the reservoirs are abandoned and the saline aquifers below 800 m are too tight with no injectivity. So, the only way was to target ultra deep saline aquifer deeper than 3 km with virgin pressure of more than 5000 psi. These ultra deep aquifers are usually highly titled, surrounded by major faults, and highly saline and those factors act against the typical trapping mechanisms for CO2 sequestration such as structural trapping, residual trapping and CO2 solubility. In this case study, we present a novel approach that relies on innovative technology to solve this unconventional challenge to sequester 0.5 Mton CO2 per annum in ultra deep saline aquifers and open the pathway for carbon storage in unconventional storage sites. The applied approach is divided into three phases. Phase one is site screening to automatically identify the best possible sites for CO2 storage based on a scientific scorecard. Then in Phase two, dynamic simulation of the injected supercritical CO2 plume movement within the formations while honoring advanced trapping mechanisms such as CO2 trapping due to residual trapping and dissolution in saline water. Then the dynamic reservoir simulation models are fully coupled to 3D geomechanics models to study the impact of the injection on the well integrity, cap rock integrity as well as fault reactivation and integrity. Finally in Phase 3, an economical surface facility configuration and pipelining scenarios that fit the subsurface sites’ requirements. It was concluded through an ensemble of geological scenarios that safe CO2 trapping mechanism can be increased by 30% using a time and rate managed sequential injection scheme starting from the bottom of the formation and upwards. the dynamic simulation results show that this technique helps increasing the contact area with the saline water while leveraging high pressure to overcome low solubility in highly saline water and creating convective water density currents, hence increasing CO2 solubility in water as well as residual trapping of CO2 even in structurally marginal sites. The followed scientific approach unlocked the potential for CO2 sequestration in ultra deep saline aquifers within the western desert to be deployed for a long-term and safe sequestration of CO2 while accounting for the complex subsurface structure to pave the way for future successful CCS projects in similar environments.
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Katterbauer, Klemens, Abdallah Al Shehri, Abdulaziz Qasim, and Ali Yousef. "Estimating Dynamical Mineral Dissolution for Co2 Injection Into Saline Aquifers Utilizing Deep Learning in the Ahuroa Saline Aquifer." In SPE Offshore Europe Conference & Exhibition. SPE, 2023. http://dx.doi.org/10.2118/215556-ms.
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Abstract The geological carbon storage (GCS) in subsurface environments, such as deep permeable saline formations, is one of the achievable methods for carbon dioxide storage. There are several commercial projects such as the Sleipner field in Norway, and in Salah in Algeria have demonstrated that carbon dioxide can be safely stored in these reservoirs. The natural environments are capable to store CO2 on geologic time scales, that is mostly caused by solubility trapping. While the geological, physical and chemical conditions for the escape of CO2 are still in the research phase and how CO2 can be efficiently stored, there are several important features that represent prerequisites for the efficient storage (Xu, et al. 2017). A core prerequisite is the availability of sufficient porosity in order to accommodate the desired volumes of carbon dioxide, and the presence of a continuous cap rock that is impermeable to CO2. Deep saline reservoirs are attractive candidates for the geological storage and based on the deep geologic storage temperature and pressure, the CO2 is typically in a supercritical but stable state. The challenge is that the introduction of CO2 into the reservoir may lead to a geochemical process which acidifies the brine via CO2 dissolution. Furthermore, the mineral surfaces are dehydrated by the dispersing CO2 phase. Experimental and field studies indicate that the geochemical reactions caused by the injection of CO2 may vary significantly between different rock types and brine compositions (Michael, et al. 2010). The low permeability of the cap rock, such as shale, have demonstrated to be reactive for higher temperature ranges, which poses additional challenges for the CO2 storage process. The dissolution and re-precipitation of carbonate minerals, and the dissolution of feldspars are generally observed for these CO2 storage reservoir sites that additionally encounter challenges related to the precipitation of clay minerals. This implies that the dissolution and secondary mineral precipitation caused by the injection of CO2 have a major impact on the porosity and permeability of the reservoir environment as well as impact the cap rock integrity (Jiang, et al. 2014).
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Kumar, A., M. Noh, G. A. Pope, K. Sepehrnoori, S. Bryant, and L. W. Lake. "Reservoir Simulation of CO2 Storage in Deep Saline Aquifers." In SPE/DOE Symposium on Improved Oil Recovery. Society of Petroleum Engineers, 2004. http://dx.doi.org/10.2118/89343-ms.
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Ali Khan, Jawad, and Andreas Michael. "Mechanistic Modeling of Wellbore Integrity During CO2 Injection in Deep Saline Aquifers." In SPE International Conference and Exhibition on Formation Damage Control. SPE, 2024. http://dx.doi.org/10.2118/217873-ms.
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Abstract In this paper, we examine wellbore integrity during carbon dioxide (CO2) injection in deep saline aquifers, by modeling stress-distribution evolutions within the casing-cement sheath-rock formation (C/CS/RF) system. For our analysis, a mechanistic model is used, which considers a total of eleven ("10 + 1") modes of mechanical degradation assessing each of the three layers of the C/CS/RF system discretely. The integrity of the wellbore is assessed by modeling the casing layer as a thick-walled cylinder and the adjacent-RF layer as a poroelastic solid, accounting for fluid infiltration into and out of the pores in close proximity to the CS layer. The magnitude of the normal-effective stresses at the C/CS and CS/RF interfaces provide calibration parameters for the stress distributions within the intermediate-CS layer, honoring linear elasticity. This novel method is used to determine the initial state of stress within the C/CS/RF system with balanced conditions inside the wellbore, following cement setting. Using input data from the literature, the integrity of the C/CS/RF system is assessed over a 30-year period of bulk-CO2 injection in a closed (bounded) system and an open (unbounded) system subsurface aquifer. In closed-aquifer configurations, disking failures along with radial and shear cracking tendencies are indicated within the CS layer, providing potential pathways for CO2 leakages back into the atmosphere. In open-aquifer configurations, the three aforementioned tendencies for mechanical degradation remain, albeit at a smaller degree. The generated stress distributions demonstrate no indication of inner debonding along the C/CS interface, while the outer-debonding limit is approached on the CS/RF interface, but never exceeded. Moreover, no tensile failures (via longitudinal or transverse-fracture initiation) is expected along the CS/RF interface, nor casing failures (related to compressive/tensile loads, collapse and burst stress loads). Finally, none of the scenarios considered are expected to generate seismic activity along preexisting faults (PEFs) near the injection well.
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André, L. "Well Injectivity during CO2 Storage Operations in Deep Saline Aquifers." In First EAGE Workshop on Well Injectivity and Productivity in Carbonates. Netherlands: EAGE Publications BV, 2015. http://dx.doi.org/10.3997/2214-4609.201412023.
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Penigin, A., A. Ivanova, P. Grishin, D. Bakulin, T. Yunusov, A. Morkovkin, and A. Cheremisin. "Experimental Investigation of CO2 Storage Parameters for Deep Saline Aquifers." In SPE Conference at Oman Petroleum & Energy Show. SPE, 2024. http://dx.doi.org/10.2118/218823-ms.
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Abstract The storage of CO2 is controlled by a variety of parameters. While it is impossible to quantify or predict their distribution across the inter-well space their accurate measurement in known points (wells and core) are obviously beneficial for making more accurate forecasts. While all the requirements for storage characterization are stated clearly in guiding documents (as in ISO 27914 or DNV RP-J203) and national regulations and codes the specifics as to how to approach lab studies are not included. Therefore, in order to ensure the safety and operational capability of a CO2 storage project a part of lab studies design is proposed with corresponding results and their interpretation. Since the main goal of these projects is to reduce greenhouse gases emission to alleviate climate change and consequently they are bound to be verified across the world an attempt to come to universally accepted approach seems justified and necessary. CO2 storage is influenced by various parameters, which are difficult to quantify or predict in the inter-well space. However, their precise measurement in known locations (such as wells and core samples) can enhance the accuracy of storage forecasts. Although the general requirements for storage characterization are clearly defined in guidance documents (e.g., ISO 27914 or DNV RP-J203) and national regulations and standards, the specific methods for conducting laboratory studies are not specified. Therefore, this paper proposes a partial design of laboratory studies for a CO2 storage project, along with the results and their interpretation. The main objective of these projects is to mitigate climate change by reducing greenhouse gas emissions, which requires global verification. Hence, developing a universally accepted approach is both reasonable and necessary.
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Benson, Sally M. "Multiphase Flow and Trapping of Carbon Dioxide in Deep Saline Aquifers." In Offshore Technology Conference. Offshore Technology Conference, 2008. http://dx.doi.org/10.4043/19244-ms.
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Ji, Xiaoyan, Yuanhui Ji, and Chongwei Xiao. "Thermodynamic and Dynamic Investigation for CO2 Storage in Deep Saline Aquifers." In World Renewable Energy Congress – Sweden, 8–13 May, 2011, Linköping, Sweden. Linköping University Electronic Press, 2011. http://dx.doi.org/10.3384/ecp11057652.
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Mo, Sjur, Peter Zweigel, Erik G. B. Lindeberg, and Idar Akervoll. "Effect of Geologic Parameters on CO2 Storage in Deep Saline Aquifers." In SPE Europec/EAGE Annual Conference. Society of Petroleum Engineers, 2005. http://dx.doi.org/10.2118/93952-ms.
Full textReports on the topic "Deep saline aquifers"
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Mallick, Subhashis, and Vladimir Alvarado. Feasibility of Geophysical Monitoring of Carbon-Sequestrated Deep Saline Aquifers. Office of Scientific and Technical Information (OSTI), September 2013. http://dx.doi.org/10.2172/1158900.
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Lindquist, W. Brent. Up-Scaling Geochemical Reaction Rates for Carbon Dioxide (CO2) in Deep Saline Aquifers. Office of Scientific and Technical Information (OSTI), March 2009. http://dx.doi.org/10.2172/948548.
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Peters, Catherine A. Up-Scaling Geochemical Reaction Rates for Carbon Dioxide (CO2) in Deep Saline Aquifers. Office of Scientific and Technical Information (OSTI), February 2013. http://dx.doi.org/10.2172/1064444.
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Xu, Tianfu, John A. Apps, and Karsten Pruess. Reactive geochemical transport simulation to study mineral trapping for CO2 disposal in deep saline arenaceous aquifers. Office of Scientific and Technical Information (OSTI), April 2002. http://dx.doi.org/10.2172/801952.
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Carter, T. R., C. E. Logan, J K Clark, H. A. J. Russell, E. H. Priebe, and S. Sun. A three-dimensional bedrock hydrostratigraphic model of southern Ontario. Natural Resources Canada/CMSS/Information Management, 2022. http://dx.doi.org/10.4095/331098.
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A hydrostratigraphic framework has been developed for southern Ontario consisting of 15 hydrostratigraphic units and 3 regional hydrochemical regimes. Using this framework, the 54 layer 3-D lithostratigraphic model has been converted into a 15 layer 3-D hydrostratigraphic model. Layers are expressed as either aquifer or aquitard based principally on hydrogeologic characteristics, in particular the permeability and the occurrence/absence of groundwater when intersected by a water well or petroleum well. Hydrostratigraphic aquifer units are sub-divided into up to three distinct hydrochemical regimes: brines (deep), brackish-saline sulphur water (intermediate), and fresh (shallow). The hydrostratigraphic unit assignment provides a standard nomenclature and definition for regional flow modelling of potable water and deeper fluids. Included in the model are: 1) 3-D hydrostratigraphic units, 2) 3-D hydrochemical fluid zones within aquifers, 3) 3-D representations of oil and natural gas reservoirs which form an integral part of the intermediate to deep groundwater regimes, 4) 3-D fluid level surfaces for deep Cambrian brines, for brines and fresh to sulphurous groundwater in the Guelph Aquifer, and the fresh to sulphurous groundwater of the Bass Islands Aquifer and Lucas-Dundee Aquifer, 5) inferred shallow karst, 6) base of fresh water, 7) Lockport Group TDS, and 8) the 3-D lithostratigraphy. The 3-D hydrostratigraphic model is derived from the lithostratigraphic layers of the published 3-D geological model. It is constructed using Leapfrog Works at 400 m grid scale and is distributed in a proprietary format with free viewer software as well as industry standard formats.
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Jean-Philippe Nicot, Renaud Bouroullec, Hugo Castellanos, Susan Hovorka, Srivatsan Lakshminarasimhan, and Jeffrey Paine. Development of Science-Based Permitting Guidance for Geological Sequestration of CO2 in Deep Saline Aquifers Based on Modeling and Risk Assessment. Office of Scientific and Technical Information (OSTI), June 2006. http://dx.doi.org/10.2172/901785.
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Nguyen, Minh, and Philip H. Stauffer. Understanding CO2 Storage Into Deep Saline Aquifers at the Shenhua Site, Ordos Basin using Simulation-based Sensitivity Analysis. Office of Scientific and Technical Information (OSTI), August 2017. http://dx.doi.org/10.2172/1374288.
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Stauffer, Philip H. Pre-feasibility Study to Identify Opportunities for Increasing CO2 Storage in Deep, Saline Aquifers by Active Aquifer Management and Treatment of Produced Water. Office of Scientific and Technical Information (OSTI), September 2014. http://dx.doi.org/10.2172/1154964.
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Harto, Christopher. Quantitative Assesment of Options for Managing Brines Extracted from Deep Saline Aquiflers used for Carbon Storage. Office of Scientific and Technical Information (OSTI), August 2014. http://dx.doi.org/10.2172/1155055.
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