REPP-CO2: Equilibrium Modelling of CO2-Rock-Brine Systems

Klajmon, Martin; Havlová, Václava; Červinka, Radek; Mendoza, Angela; Franců, Juraj; Berenblyum, Roman; Arild, Øystein

doi:10.1016/j.egypro.2017.03.1468

Cited by 12 publications

(10 citation statements)

References 8 publications

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“…The modeling assumes a single stage CO 2 injection kept under a constant temperature and pressure. Due to the limited study of reservoir characteristics (permeability, flow regime), and how previous modeling studies are conducted, [32][33][34]47 the modeling has been done in a static environment where there is no mass flow occurring in the simulated reservoir. The constant temperature assigned corresponds to the reservoir temperature and constant pressure corresponds to the hydrostatic pressure present at the reservoir depth.…”

Section: Geochemical Modelingmentioning

confidence: 99%

“…4). 47 Thus, redefinition of CO 2 dissolution reaction was needed and additional parameters from phreeqc.dat is extended into the llnl.dat database to overcome this limitation. Modeling has been performed in two separate batch namely equilibrium and kinetic modeling.…”

Section: Geochemical Modelingmentioning

confidence: 99%

“…CO 2 dissolution in a 0.35 mol kg −1 water NaCl solution at 40°C taken from Klajmon et al 47 . and the references therein.…”

Section: Geochemical Modelingmentioning

confidence: 99%

“…Geochemical modeling to forecast long‐term effect of CO 2 storage using programs such as PHREEQC, 42 is also conducted because laboratory studies are unable to reconstruct CO 2 storage over geologic time scales. Several researchers have demonstrated the ability of the PHREEQC program in simulating: dissolution and precipitation of minerals after CO 2 injection, 43,44 calculation of CO 2 trapped as minerals, 45 interaction of CO 2 ‐rich brine with calcite, 46 CO 2 –brine rock interaction in siltstone and sandstone dominated oil reservoir 47 . In the case CO 2 storage in volcanic geothermal reservoirs, previous geochemical modeling study is limited to investigating the interaction of CO 2 ‐saturated water with basaltic reservoir 48 .…”

Section: Introductionmentioning

confidence: 99%

“…Several researchers have demonstrated the ability of the PHREEQC program in simulating: dissolution and precipitation of minerals after CO 2 injection, 43,44 calculation of CO 2 trapped as minerals, 45 interaction of CO 2 -rich brine with calcite, 46 CO 2 -brine rock interaction in siltstone and sandstone dominated oil reservoir. 47 In the case CO 2 storage in volcanic geothermal reservoirs, previous geochemical modeling study is limited to investigating the interaction of CO 2 -saturated water with basaltic reservoir. 48 Study related to intermediate reservoir is yet to be observed despite the fact that CO 2 fixation varies considerably with the varying mineral assemblages in different rock types.…”

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confidence: 99%

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Preliminary geochemical investigation of a possible CO₂ injection in the Ungaran geothermal field, Indonesia: equilibrium and kinetic modeling

Utomo

Güleç

2020

Greenhouse Gases

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Carbon capture and storage (CCS) is considered to be an effective method to mitigate anthropogenic carbon emissions that have been the major cause of global warming. One of the possible sites to store CO 2 is in geothermal reservoirs. In this study, an attempt to simulate CO 2-brine reservoir rock interaction inside a geothermal reservoir is carried out using the PHREEQC program. The study utilizes published rock mineralogy of the assumed reservoir lithology and chemistry of the hot water in the Ungaran geothermal field, Java, Indonesia. The simulation is based on equilibrium and kinetic modeling and assumes a single stage CO 2 injection kept at a constant temperature and pressure. The amount of injected CO 2 is determined by solubility modeling of CO 2 in hot water under estimated reservoir conditions. The modeling predicted (i) the effect of solubility trapping at early stages of CO 2-brine rock interaction, (ii) dissolution of Ca-bearing silicates (plagioclases) coupled with calcite precipitation as a potential chemical processes relevant to a possible CO 2 mineralization, (iii) progressive transition from solubility to mineral trapping becoming significant after 30 days following injection, (iv) minor porosity increase (∼0.5%), and (v) achievement of equilibrium between CO 2-brine-rock in 10 years after injection. Sensitivity analysis associated with the uncertainties for altering mineral proportion and rock porosity reveal no significant change in the ability of the modeled reservoir to trap injected CO 2 into mineral phases. Concerning the CCS studies so far carried out in geothermal fields in volcanic reservoirs, this modeling comprises one of the first performed for fields with intermediate volcanics. The result from this study can be utilized as foreknowledge for possible future CCS operations in Indonesian geothermal fields.

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Section: Geochemical Modelingmentioning

confidence: 99%

Section: Geochemical Modelingmentioning

confidence: 99%

“…CO 2 dissolution in a 0.35 mol kg −1 water NaCl solution at 40°C taken from Klajmon et al 47 . and the references therein.…”

Section: Geochemical Modelingmentioning

confidence: 99%

Section: Introductionmentioning

confidence: 99%

mentioning

confidence: 99%

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Preliminary geochemical investigation of a possible CO₂ injection in the Ungaran geothermal field, Indonesia: equilibrium and kinetic modeling

Utomo

Güleç

2020

Greenhouse Gases

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Experimental and numerical investigation of CO₂–brine–rock interactions in the early Palaeozoic mudstones from the Polish part of the Baltic Basin at simulatedin situ conditions

et al. 2020

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This study discusses experiment‐induced alterations of shale rocks collected across the ordovician and silurian boundary at a potential site for carbon dioxide sequestration located in the Polish part of the Baltic Basin. Mudstone samples submerged in brine in custom‐built reactors were subjected to CO2 pressures of 30–35 MPa at a temperature of 80°C for 40 days. After the experiments were completed, the mineralogical composition of the studied rocks, their porosity characteristics, and chemistry of brines were analyzed and compared to the original compositions in order to detect experiment‐induced changes. Comparison of mineral composition before and after the experiments demonstrate a set of subtle but systematic mineral changes. The most conspicuous was a presence of Fe in the form of Fe‐oxyhydroxides that was related to the corrosion of the Fe‐bearing steel pipes supplying the experimental setup with CO2. This effect is important from the perspective of industrial carbon dioxide sequestration. However, the second source of Fe ions in experimental brines was related to the decomposition of chlorites, pyrite, and chloritized biotites. The suggested breakdown of pyrite is in line with the modification of the chemical composition of the experimental brines and observed transfer of S ions to the solution. The appearance of Mg and K ions in the experimental brines was related to the decomposition of chlorites and biotites. In turn, observed transfer of Sr cations to the solution could be attributed to the dissolution of biotites and K‐feldspars. The effects of analogue experiments were confronted with the results of geochemical modeling performed using the PHREEQC program. The numerical modeling not only allowed to reproduce all the main mineral and chemical changes postulated on the basis of our analogue experiment, but also enabled to put constraints on the time scale of occurring geochemical processes. © 2020 Society of Chemical Industry and John Wiley & Sons, Ltd.

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CO₂‐water‐rock interactions in undeformed and sheared claystone caprocks from Northern Europe

et al. 2020

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One of the most promising, cost-effective, and readily available technologies for reducing greenhouse gas emissions to the atmosphere is the capture and separation of CO 2 from large stationary sources and storage in geological formations. Storage security, especially in the early stages of operation, is mostly guaranteed by caprock formations with very low permeability overlying the reservoir, capable of containing the injected fluid. Chemical alterations of the formation brine, caused by CO 2 injection may cause dissolution and precipitation of secondary minerals, potentially increasing the risks of leakage from the reservoir. In order to evaluate these processes and their potential to induce the formation of leakage pathways in ultrafine fault gouges, a series of batch experiments was performed on crushed and sheared samples from three different caprock formations from Northern Europe (Sollingen, Röt and Opalinus claystones). The experiments were supported by numerical models of the kinetics of mineral dissolution and precipitation simulating the same experimental conditions, and over a longer time (10 000 years). Minor mineral alterations were observed after the batch experiments, the most important being: illite dissolution for the Opalinus and Röt formation samples, and dolomite dissolution and the transformation of illite and chlorite into kaolinite for the Sollingen sample.

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REPP-CO2: Equilibrium Modelling of CO2-Rock-Brine Systems

Cited by 12 publications

References 8 publications

Preliminary geochemical investigation of a possible CO₂ injection in the Ungaran geothermal field, Indonesia: equilibrium and kinetic modeling

Preliminary geochemical investigation of a possible CO₂ injection in the Ungaran geothermal field, Indonesia: equilibrium and kinetic modeling

Experimental and numerical investigation of CO₂–brine–rock interactions in the early Palaeozoic mudstones from the Polish part of the Baltic Basin at simulatedin situ conditions

CO₂‐water‐rock interactions in undeformed and sheared claystone caprocks from Northern Europe

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REPP-CO2: Equilibrium Modelling of CO2-Rock-Brine Systems

Cited by 12 publications

References 8 publications

Preliminary geochemical investigation of a possible CO2 injection in the Ungaran geothermal field, Indonesia: equilibrium and kinetic modeling

Preliminary geochemical investigation of a possible CO2 injection in the Ungaran geothermal field, Indonesia: equilibrium and kinetic modeling

Experimental and numerical investigation of CO2–brine–rock interactions in the early Palaeozoic mudstones from the Polish part of the Baltic Basin at simulatedin situ conditions

CO2‐water‐rock interactions in undeformed and sheared claystone caprocks from Northern Europe

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Resources

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Preliminary geochemical investigation of a possible CO₂ injection in the Ungaran geothermal field, Indonesia: equilibrium and kinetic modeling

Preliminary geochemical investigation of a possible CO₂ injection in the Ungaran geothermal field, Indonesia: equilibrium and kinetic modeling

Experimental and numerical investigation of CO₂–brine–rock interactions in the early Palaeozoic mudstones from the Polish part of the Baltic Basin at simulatedin situ conditions

CO₂‐water‐rock interactions in undeformed and sheared claystone caprocks from Northern Europe