Geological storage of carbon dioxide by injection of carbonated water in an Iranian oil reservoir: A case study

Hasanvand, Mahdi Zeinali; Ahmadi, Mohammad Ali; Shadizadeh, Seyed Reza; Behbahani, Reza Mosayebi; Feyzi, Farzaneh

doi:10.1016/j.petrol.2013.09.008

Cited by 32 publications

(13 citation statements)

References 52 publications

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“…According to their study, the maximum nC 10 -CO 2 diffusion coefficients for square and cylindrical capillary tubes are 12.E-8 and 12.E-10, respectively [32].…”

Section: Core Scale Study Of Cwimentioning

confidence: 99%

“…CO 2 concentration in carbonated water is assumed constant but different from that in the oil phase. CO 2 concentration at the interface in the oil phase is determined via Eq.3 [32].…”

Section: Core Scale Study Of Cwimentioning

confidence: 99%

“…Grogan A c c e p t e d M a n u s c r i p t 9 used to determine diffusion coefficient of CO 2 water-oil and swelling factor of oil [32]. On the basis of Fick's law of mass transfer, the diffusion of CO 2 from the displacing phase to the displaced phase is proportional to the concentration gradient.…”

Section: Core Scale Study Of Cwimentioning

confidence: 99%

“…Oil and gas fluid components are C 1 , C 2 , C 3 , C 4 , C 5 , C 6 , C 7 , C 8+ , C 11+ , CO 2 , H 2 S and N 2 . Water is defined as a phase (not a component) into which only CO 2 can dissolve using the SOLUAQA and GASSOL keywords [32]. The static reservoir model consists of 10*83*115 grids in the Z, Y and X directions, respectively ( Figure 3).…”

Section: Field Scale Studymentioning

confidence: 99%

See 3 more Smart Citations

Effect of operational parameters on the performance of carbonated water injection: Experimental and numerical modeling study

Ahmadi

Hasanvand²,

Behbahani

et al. 2016

The Journal of Supercritical Fluids

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“…According to their study, the maximum nC 10 -CO 2 diffusion coefficients for square and cylindrical capillary tubes are 12.E-8 and 12.E-10, respectively [32].…”

Section: Core Scale Study Of Cwimentioning

confidence: 99%

“…CO 2 concentration in carbonated water is assumed constant but different from that in the oil phase. CO 2 concentration at the interface in the oil phase is determined via Eq.3 [32].…”

Section: Core Scale Study Of Cwimentioning

confidence: 99%

Section: Core Scale Study Of Cwimentioning

confidence: 99%

Section: Field Scale Studymentioning

confidence: 99%

See 2 more Smart Citations

Effect of operational parameters on the performance of carbonated water injection: Experimental and numerical modeling study

Ahmadi

Hasanvand²,

Behbahani

et al. 2016

The Journal of Supercritical Fluids

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“…The most common oil production mechanisms in CO 2 -based EOR methods are oil viscosity reduction, oil swelling, condensation, vaporization, and interfacial tension (IFT) reduction (Abedini and Torabi 2014; Ahmadi et al 2015; Bachu 2016; Czarnota et al 2017; Farajzadeh et al 2009; Li et al 2013b, 2015; Shelton et al 2016; Yang et al 2012). Reducing the level of CO 2 emissions in the atmosphere by the use of geological CO 2 storage in depleted oil reservoirs as well as its role in the oil recovery processes highlights the importance of further studies of CO 2 injection operations and the corresponding PVT behavior (Ahmadi et al 2016a, b; Bachu 2016; Davis et al 2010; Jamali and Ettehadtavakkol 2017; Kim and Santamarina 2014; Li et al 2015; Li and Fan 2015; Liu and Wilcox 2012; Luo et al 2013; Orr et al 1982; Sell et al 2012; Shelton et al 2016; Yang et al 2012; Yu et al 2015; zeinali Hasanvand et al 2013). …”

Section: Introductionmentioning

confidence: 99%

Hybrid connectionist model determines CO2–oil swelling factor

2018

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In-depth understanding of interactions between crude oil and CO2 provides insight into the CO2-based enhanced oil recovery (EOR) process design and simulation. When CO2 contacts crude oil, the dissolution process takes place. This phenomenon results in the oil swelling, which depends on the temperature, pressure, and composition of the oil. The residual oil saturation in a CO2-based EOR process is inversely proportional to the oil swelling factor. Hence, it is important to estimate this influential parameter with high precision. The current study suggests the predictive model based on the least-squares support vector machine (LS-SVM) to calculate the CO2–oil swelling factor. A genetic algorithm is used to optimize hyperparameters (γ and σ2) of the LS-SVM model. This model showed a high coefficient of determination (R2 = 0.9953) and a low value for the mean-squared error (MSE = 0.0003) based on the available experimental data while estimating the CO2–oil swelling factor. It was found that LS-SVM is a straightforward and accurate method to determine the CO2–oil swelling factor with negligible uncertainty. This method can be incorporated in commercial reservoir simulators to include the effect of the CO2–oil swelling factor when adequate experimental data are not available.

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Experimental investigation of CO₂–brine–rock interactions in relation with CO₂ sequestration in an Iranian oil reservoir

2020

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The main purpose of this study is to evaluate the feasibility of geologic CO 2 sequestration in terms of CO 2-brine-rock interactions in Ramin oil field, Iran. Static experiments were conducted with carbonate rocks at 70°C and atmospheric pressure for 14, 30, and 60 days. CO 2-brine-rock interactions were inferred from the evaluation of Ca 2+ , Mg 2+ , Cl − , and SO 2− 4 concentrations and a thorough characterization of the carbonate rocks before and after treatment. Scanning electron microscopy (SEM) micrographs revealed the formation of dissolution pits and the growth of new structures. Energy dispersive X-ray spectroscopy (EDS) and X-ray diffraction (XRD) indicated these minerals to be calcite. Porosity of the carbonate rocks increased from an initial value of 4.72% to the maximum value of 11.83%. Then, it decreased to a value of 5.48% until the end of the experiments, that is, 60 days. Chemical analysis of brine suggested the precipitation and dissolution of calcium sulfate. In addition, dolomite dissolution and halite precipitation/dissolution were inferred. Calcite precipitation and porosity reduction suggested that CO 2 can be stored via mineral entrapment in the Ramin oil field, which is desired from the perspective of CO 2 geologic sequestration.

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Geological storage of carbon dioxide by injection of carbonated water in an Iranian oil reservoir: A case study

Cited by 32 publications

References 52 publications

Effect of operational parameters on the performance of carbonated water injection: Experimental and numerical modeling study

Effect of operational parameters on the performance of carbonated water injection: Experimental and numerical modeling study

Hybrid connectionist model determines CO2–oil swelling factor

Experimental investigation of CO₂–brine–rock interactions in relation with CO₂ sequestration in an Iranian oil reservoir

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Geological storage of carbon dioxide by injection of carbonated water in an Iranian oil reservoir: A case study

Cited by 32 publications

References 52 publications

Effect of operational parameters on the performance of carbonated water injection: Experimental and numerical modeling study

Effect of operational parameters on the performance of carbonated water injection: Experimental and numerical modeling study

Hybrid connectionist model determines CO2–oil swelling factor

Experimental investigation of CO2–brine–rock interactions in relation with CO2 sequestration in an Iranian oil reservoir

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Experimental investigation of CO₂–brine–rock interactions in relation with CO₂ sequestration in an Iranian oil reservoir