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Yuri Leonenko
Department of Geography and Environmental Management, University of Waterloo, ON N2L 3G1, Canada

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Journal article
Published: 12 June 2021 in Geosciences
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This study focuses on determining the orientation and constraining the magnitude of present-day stresses in the Dezful Embayment in Iran’s Zagros Fold and Thrust Belt. Two datasets are used: the first includes petrophysical data from 25 wells (3 to 4 km deep), and the second contains 108 earthquake focal mechanisms, mostly occurring in blind active basement faults (5 to 20 km deep). Formal stress inversion analysis of the focal mechanisms demonstrates that there is currently a compressional stress state (Aφ=2.02.2) in the basement. The seismologically determined SHmax direction is 37° ± 10°, nearly perpendicular to the strike of most faults in the region. However, borehole geomechanics analysis using rock strength and drilling evidence leads to the counterintuitive result that the shallow state of stress is a normal/strike-slip regime. These results are consistent with the low seismicity level in the sedimentary cover in the Dezful Embayment, and may be evidence of stress decoupling due to the existence of salt layers. The stress state situation in the field was used to identify the optimally oriented fault planes and the fault friction coefficient. This finding also aligns with the prediction Coulomb faulting theory in that the N-S strike-slip basement Kazerun Fault System has an unfavorable orientation for slip in a reverse fault regime with an average SW-NE SHmax orientation. These results are useful for determining the origin of seismic activity in the basin and better assessing fault-associated seismic hazards in the area.

ACS Style

Ali Yaghoubi; SeyedBijan Mahbaz; Maurice Dusseault; Yuri Leonenko. Seismicity and the State of Stress in the Dezful Embayment, Zagros Fold and Thrust Belt. Geosciences 2021, 11, 254 .

AMA Style

Ali Yaghoubi, SeyedBijan Mahbaz, Maurice Dusseault, Yuri Leonenko. Seismicity and the State of Stress in the Dezful Embayment, Zagros Fold and Thrust Belt. Geosciences. 2021; 11 (6):254.

Chicago/Turabian Style

Ali Yaghoubi; SeyedBijan Mahbaz; Maurice Dusseault; Yuri Leonenko. 2021. "Seismicity and the State of Stress in the Dezful Embayment, Zagros Fold and Thrust Belt." Geosciences 11, no. 6: 254.

Article
Published: 14 March 2021
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This study focuses on determining the orientation and constraining the magnitude of the present-day stress in the Dezful Embayment in Iran's Zagros Fold and Thrust Belt. Two datasets are used: the first includes petrophysical data from 25 wells (3 to 4 km), and the second contains 108 earthquake focal plane mechanisms mostly occurring in blind active basement faults (5 to 20 km). Formal stress inversion analysis of the focal plane mechanism demonstrates that the major basement faults are reverse faults with ( =2.0-2.2). The seismologically determined SHmax direction is 37{degree sign}{plus minus}10{degree sign}, nearly perpendicular to the strike of most faults in the region. However, borehole geomechanics analysis using rock strength and drilling evidence leads to the counterintuitive result that the shallow state of stress is a normal/strike-slip regime. These results are consistent with the low seismicity level in the sedimentary cover in the Dezful Embayment, and may be evidence of stress decoupling due to the existence of salt layers. This finding also aligns with the Mohr-Coulomb faulting theory in that the N-S strike-slip basement Kazerun fault has an unfavourable orientation for slip in a reverse fault regime with an average SW-NE SHmax orientation. The stress state situation in the field was used to identify the optimally oriented fault planes and the fault friction factor. The results are useful for determining the origin of seismic activity in the basin and better assessing fault-associated seismic hazards in the area.

ACS Style

Ali Yaghoubi; SeyedBijan Mahbaz; Maurice Dusseault; Yuri Leonenko. Seismicity and the State of Stress in the Dezful Embayment, Zagros Fold and Thrust Belt. 2021, 1 .

AMA Style

Ali Yaghoubi, SeyedBijan Mahbaz, Maurice Dusseault, Yuri Leonenko. Seismicity and the State of Stress in the Dezful Embayment, Zagros Fold and Thrust Belt. . 2021; ():1.

Chicago/Turabian Style

Ali Yaghoubi; SeyedBijan Mahbaz; Maurice Dusseault; Yuri Leonenko. 2021. "Seismicity and the State of Stress in the Dezful Embayment, Zagros Fold and Thrust Belt." , no. : 1.

Preprint content
Published: 16 February 2021
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In this study, a one-dimensional analytical model to describe heat and mass transfer during methane hydrate dissociation under thermal stimulation in porous media has been developed. The model is based on a similarity solution that considers a moving dissociation boundary which separates the dissociated zone containing produced gas and water from the un-dissociated zone containing only methane hydrate. The results of temperature distribution, pressure distribution, energy efficiency, and parametric study considering various initial and boundary conditions as well as various reservoir properties are presented and compared with previous studies. Sensitivity analysis of gas production on reservoir properties is also presented in this paper. The dissociation boundary moves faster by increasing the heat source temperature while decreasing the heat source pressure simultaneously, but the associated energy efficiency decreases. Increasing the well thickness has a negative effect on the energy efficiency of the process. Among the proposed thermal properties of the system, only the thermal diffusivities and conductivites of the reservoir as well as the porosity of the sediment affect the dissociation. The main contribution of this work is investigating analytically the hydrate dissociation using thermal stimulation by taking into account the effect of wellbore thickness and structure.

ACS Style

Mohammad Roostaie; Yuri Leonenko. Analytical modeling of methane hydrate dissociation under thermal stimulation. 2021, 1 .

AMA Style

Mohammad Roostaie, Yuri Leonenko. Analytical modeling of methane hydrate dissociation under thermal stimulation. . 2021; ():1.

Chicago/Turabian Style

Mohammad Roostaie; Yuri Leonenko. 2021. "Analytical modeling of methane hydrate dissociation under thermal stimulation." , no. : 1.

Journal article
Published: 01 February 2021 in Environmental Geotechnics
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In this paper, a model for diffusion-controlled dissolution of CO2 droplets is presented. This model is applied to a system of co-current turbulent horizontal pipe flow of CO2-brine mixture in order to determine the feasibility of dissolving CO2 within the pipe before injecting underground. Depending on the droplet size there are two regimes of dissolution within pipe: turbulent for large droplet size and laminar (pure diffusion) for smaller sizes. Since the droplet (while dissolving and therefore shrinking in size) may undergo both regimes, the droplet size at which it transitions from turbulent to diffusion controlled dissolution is estimated, and used to find the total time spent in diffusion-controlled dissolution regime. We observed that diffusive dissolution is of similar order of magnitude to turbulent dissolution and so both mechanisms must be taking into account in evaluation the total dissolution time. This diffusive dissolution time should be combined with the time spent in the turbulent regime to determine time pipe lengths required for complete dissolution of CO2 droplets.

ACS Style

Aleksander Cholewinski; Yuri Leonenko. Modelling of ex situ dissolution for CO2 sequestration. Environmental Geotechnics 2021, 8, 28 -37.

AMA Style

Aleksander Cholewinski, Yuri Leonenko. Modelling of ex situ dissolution for CO2 sequestration. Environmental Geotechnics. 2021; 8 (1):28-37.

Chicago/Turabian Style

Aleksander Cholewinski; Yuri Leonenko. 2021. "Modelling of ex situ dissolution for CO2 sequestration." Environmental Geotechnics 8, no. 1: 28-37.

Journal article
Published: 13 January 2021 in Applied Sciences
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Renewable and sustainable energy sources can play an important role in meeting the world’s energy needs and also in addressing environmental challenges such as global warming and climate change. Geothermal well-doublet systems can produce both electrical and thermal energy through extracting heat from hot-water aquifers. In this paper, we examine some potential challenges associated with the operation of well-doublet systems, including heat conductivity, chemical, and mechanical issues. In these systems, geomechanics issues such as thermal short-circuiting and induced seismicity arise from temperature and pressure change impacts on the stress state in stiff rocks and fluid flow in fractured rock masses. Coupled chemical processes also can cause fluid channeling or formation and tubular goods plugging (scaling) with precipitates. Mechanical and chemical disequilibrium conditions lead to increased production uncertainties; hence risk, and therefore coupled geo-risk assessments and optimization analyses are needed for comparative commercialization evaluations among different sites. The challenges related to heat transfer processes are also examined. These studies can help better understand the issues that may arise during the operation of geothermal well-doublet systems and improve their effectiveness, subsequently reducing associated costs and risks.

ACS Style

Seyed Bijan Mahbaz; Ali Yaghoubi; Alireza Dehghani-Sanij; Erfan Sarvaramini; Yuri Leonenko; Maurice B. Dusseault. Well-Doublets: A First-Order Assessment of Geothermal SedHeat Systems. Applied Sciences 2021, 11, 697 .

AMA Style

Seyed Bijan Mahbaz, Ali Yaghoubi, Alireza Dehghani-Sanij, Erfan Sarvaramini, Yuri Leonenko, Maurice B. Dusseault. Well-Doublets: A First-Order Assessment of Geothermal SedHeat Systems. Applied Sciences. 2021; 11 (2):697.

Chicago/Turabian Style

Seyed Bijan Mahbaz; Ali Yaghoubi; Alireza Dehghani-Sanij; Erfan Sarvaramini; Yuri Leonenko; Maurice B. Dusseault. 2021. "Well-Doublets: A First-Order Assessment of Geothermal SedHeat Systems." Applied Sciences 11, no. 2: 697.

Journal article
Published: 11 January 2021 in Energy
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Carbon dioxide (CO2) sequestration is considered to be one of the most effective technologies of mitigating greenhouse gas emissions. In this technology, single phase supercritical CO2 is injected into an underground geological formation such as a deep saline aquifer. Existing sequestration projects demonstrate that successful implementations are possible; however, significant uncertainties associated with the risks of leakage remain an obstacle for broader use of this technology. The security of underground disposal could be considerably increased by dissolving the CO2 in a brine produced from the aquifer, then re-injecting the mixture underground. The dissolution process occurs before the mixture reaches the aquifer; this significantly reduces or completely eliminates the risks of CO2 leakage. This technique can drastically extend the amount of worldwide aquifers available for carbon sequestration. As was previously shown, complete dissolution could be achieved in a surface pipeline operating under the pressure of a target aquifer, where CO2 is injected. In this paper, a comprehensive model of CO2 droplet dissolution in a vertical injection well is presented. The model accounts for droplet breakup, coalescence, and dissolution processes as well as temperature and pressure variations over well depth. Feasibility and results are discussed and compared with surface dissolution options.

ACS Style

Federico Cao; Dmitry Eskin; Yuri Leonenko. Modeling of carbon dioxide dissolution in an injection well for geologic sequestration in aquifers. Energy 2021, 221, 119780 .

AMA Style

Federico Cao, Dmitry Eskin, Yuri Leonenko. Modeling of carbon dioxide dissolution in an injection well for geologic sequestration in aquifers. Energy. 2021; 221 ():119780.

Chicago/Turabian Style

Federico Cao; Dmitry Eskin; Yuri Leonenko. 2021. "Modeling of carbon dioxide dissolution in an injection well for geologic sequestration in aquifers." Energy 221, no. : 119780.

Article
Published: 22 September 2020
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This study focuses on determining the orientation and constraining the magnitude of the present-day stress in the Dezful Embayment in Iran's Zagros Fold and Thrust Belt. Two datasets are used: the first includes petrophysical data from 25 wells (3 to 4 km), and the second contains 108 earthquake focal plane mechanisms mostly occurring in blind active basement faults (5 to 20 km). Formal stress inversion analysis of the focal plane mechanism demonstrates that the major basement faults are reverse faults with ( =2.0-2.2). The seismologically determined SHmax direction is 37{degree sign}{plus minus}10{degree sign}, nearly perpendicular to the strike of most faults in the region. However, borehole geomechanics analysis using rock strength and drilling evidence leads to the counterintuitive result that the shallow state of stress is a normal/strike-slip regime. These results are consistent with the low seismicity level in the sedimentary cover in the Dezful Embayment, and may be evidence of stress decoupling due to the existence of salt layers. This finding also aligns with the Mohr-Coulomb faulting theory in that the N-S strike-slip basement Kazerun fault has an unfavourable orientation for slip in a reverse fault regime with an average SW-NE SHmax orientation. The stress state situation in the field was used to identify the optimally oriented fault planes and the fault friction factor. The results are useful for determining the origin of seismic activity in the basin and better assessing fault-associated seismic hazards in the area.

ACS Style

Ali YaghoubiiD; SeyedBijan Mahbaz; Maurice Dusseault; Yuri Leonenko. Seismicity and the State of Stress in the Dezful Embayment, Zagros Fold and Thrust Belt. 2020, 1 .

AMA Style

Ali YaghoubiiD, SeyedBijan Mahbaz, Maurice Dusseault, Yuri Leonenko. Seismicity and the State of Stress in the Dezful Embayment, Zagros Fold and Thrust Belt. . 2020; ():1.

Chicago/Turabian Style

Ali YaghoubiiD; SeyedBijan Mahbaz; Maurice Dusseault; Yuri Leonenko. 2020. "Seismicity and the State of Stress in the Dezful Embayment, Zagros Fold and Thrust Belt." , no. : 1.

Journal article
Published: 28 February 2020 in Energy Conversion and Management
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In this study, an analytical approach has been developed to couple the wellbore heating process by hot water circulation and the associated methane hydrate dissociation in the reservoir. A coaxial wellbore is assumed as the heat source where both conduction and convection heat transfers are considered. It consists of an inner tube and an outer structure of casing, gravel, and cement layers. In the reservoir, a similarity solution employing a moving boundary separating the dissociated and undissociated zones is employed to build the analytical solution. Two different operating schemes for water supply into wellbore heat source have been studied: i) from the inner tube; and ii) from the annulus section of the wellbore. Temperature distribution along the wellbore, temperature and pressure distributions in the reservoir, hydrate dissociation rate, and energy efficiency considering various initial and boundary conditions and reservoir properties are evaluated. The two different operating schemes have almost the same results with slightly higher gas production in the case of hot water entry into annulus, which is in direct contact with the reservoir. Increasing the inlet water temperature or decreasing the wellbore pressure increases gas production. Applying them simultaneously results in a greater gas production and energy efficiency. Some of the reservoir’s properties, such as porosity, thermal diffusivity, thermal conductivity, and reservoir thickness, have direct relation with the dissociation rate, but the reservoir’s permeability and gas viscosity have almost no impact on the process. The wellbore parameters, such as flow rate of hot water, inlet temperature, and wellbore radius except the inner tube radius, have direct impact on the wellbore mean temperature and the associated results in the dissociation process.

ACS Style

M. Roostaie; Y. Leonenko. Analytical investigation of gas production from methane hydrates and the associated heat and mass transfer upon thermal stimulation employing a coaxial wellbore. Energy Conversion and Management 2020, 209, 112616 .

AMA Style

M. Roostaie, Y. Leonenko. Analytical investigation of gas production from methane hydrates and the associated heat and mass transfer upon thermal stimulation employing a coaxial wellbore. Energy Conversion and Management. 2020; 209 ():112616.

Chicago/Turabian Style

M. Roostaie; Y. Leonenko. 2020. "Analytical investigation of gas production from methane hydrates and the associated heat and mass transfer upon thermal stimulation employing a coaxial wellbore." Energy Conversion and Management 209, no. : 112616.

Preprint
Published: 13 January 2020
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In this study, a radial 2D analytical approach has been developed to couple the wellbore heating process and the associated methane hydrate dissociation in the reservoir. A coaxial wellbore is assumed as the heat source where both conduction and convection heat transfers are considered. It consists of an inner tube and an outer structure of casing, gravel, and cement layers. In the reservoir, a similarity solution employing a moving boundary separating the dissociated and undissociated zones is employed to build the analytical solution. Two different operating schemes for water supply into wellbore heat source have been studied: i) from the inner tube; and ii) from the annulus section of the wellbore. Temperature distribution along the wellbore, temperature and pressure distributions in the reservoir, hydrate dissociation rate, and energy efficiency considering various initial and boundary conditions and reservoir properties are evaluated. The two different operating schemes have almost the same results with slightly higher gas production in the case of hot water entry into annulus, which is in direct contact with the reservoir. Increasing the inlet water temperature or decreasing the wellbore pressure increases gas production. Applying them simultaneously results in a greater gas production and energy efficiency. Some of the reservoir's properties, such as porosity, thermal diffusivity, thermal conductivity, and reservoir thickness, have direct relation with the dissociation rate, but the reservoir's permeability and gas viscosity have almost no impact on the process. The wellbore parameters, such as flow rate of hot water, inlet temperature, and wellbore radius except the inner tube radius, have direct impact on the wellbore mean temperature and the associated results in the dissociation process.

ACS Style

M. Roostaie; Y. Leonenko. Analytical investigation of gas production from methane hydrates and the associated heat and mass transfer upon thermal stimulation employing a coaxial wellbore. 2020, 1 .

AMA Style

M. Roostaie, Y. Leonenko. Analytical investigation of gas production from methane hydrates and the associated heat and mass transfer upon thermal stimulation employing a coaxial wellbore. . 2020; ():1.

Chicago/Turabian Style

M. Roostaie; Y. Leonenko. 2020. "Analytical investigation of gas production from methane hydrates and the associated heat and mass transfer upon thermal stimulation employing a coaxial wellbore." , no. : 1.

Journal article
Published: 27 December 2019 in Energy
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In this study, a radial analytical model for methane hydrate dissociation upon thermal stimulation in porous media considering the wellbore structure’s effect has been developed. The analytical approach is based on a similarity solution employing a moving boundary separating the dissociated and undissociated zones. Two different heat sources are considered: i) line heat-source; and ii) wellbore heat-source with a specific thickness consisting of casing, gravel, and cement. The temperature and pressure distributions, dissociation rate, and energy efficiency considering various reservoir properties and different initial and boundary conditions are investigated. Direct heat transfer from the heat source to the reservoir without considering heat conduction in the wellbore thickness causes a higher dissociation rate and gas production in the line-heat-source model compared to those of the wellbore-heat-source model. Increasing the heat-source temperature or decreasing its pressure increases gas production. However, employing them simultaneously results in greater gas production but reduces energy efficiency. The dissociation rate has direct relation with reservoir’s porosity, thermal diffusivities, and thermal conductivities, but it is not dependent on the reservoir’s permeability.

ACS Style

M. Roostaie; Y. Leonenko. Gas production from methane hydrates upon thermal stimulation; an analytical study employing radial coordinates. Energy 2019, 194, 116815 .

AMA Style

M. Roostaie, Y. Leonenko. Gas production from methane hydrates upon thermal stimulation; an analytical study employing radial coordinates. Energy. 2019; 194 ():116815.

Chicago/Turabian Style

M. Roostaie; Y. Leonenko. 2019. "Gas production from methane hydrates upon thermal stimulation; an analytical study employing radial coordinates." Energy 194, no. : 116815.

Journal article
Published: 20 December 2019 in Journal of Petroleum Science and Engineering
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Underground carbon dioxide (CO2) sequestration is considered to be one of the main methods to mitigate greenhouse gas (GHG) emissions. In this technology, pure CO2 is injected into an underground geological formation and since it is less dense than residual fluids, there is always a risk of leakage to the surface. To increase security of underground CO2 disposal, ex-situ dissolution can be implemented. When CO2 is dissolved in brine before injection, it significantly reduces the risks of leakage. In this approach, pure CO2 is dissolved on the surface before injection. Surface dissolution could be achieved in a pipeline operating under the pressure of a target aquifer into which the CO2 is injected. In a pipeline, CO2 droplets are dissolved being dispersed in a brine turbulent flow. In this paper, a comprehensive model of droplet dissolution along a pipeline is presented. The model accounts for droplet breakup and coalescence processes and is validated against available experimental data.

ACS Style

Federico Cao; Dmitry Eskin; Yuri Leonenko. Modeling of ex-situ dissolution for geologic sequestration of carbon dioxide in aquifers. Journal of Petroleum Science and Engineering 2019, 187, 106835 .

AMA Style

Federico Cao, Dmitry Eskin, Yuri Leonenko. Modeling of ex-situ dissolution for geologic sequestration of carbon dioxide in aquifers. Journal of Petroleum Science and Engineering. 2019; 187 ():106835.

Chicago/Turabian Style

Federico Cao; Dmitry Eskin; Yuri Leonenko. 2019. "Modeling of ex-situ dissolution for geologic sequestration of carbon dioxide in aquifers." Journal of Petroleum Science and Engineering 187, no. : 106835.

Journal article
Published: 23 September 2019 in Journal of Petroleum Science and Engineering
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In this study, a one-dimensional analytical model to describe heat and mass transfer during methane hydrate dissociation under thermal stimulation in porous media has been developed. The model is based on a similarity solution that considers a moving dissociation boundary which separates the dissociated zone containing produced gas and water from the un-dissociated zone containing only methane hydrate. The results of temperature distribution, pressure distribution, energy efficiency, and parametric study considering various initial and boundary conditions as well as various reservoir properties are presented and compared with previous studies. Sensitivity analysis of gas production on reservoir properties is also presented in this paper. The dissociation boundary moves faster by increasing the heat source temperature while decreasing the heat source pressure simultaneously, but the associated energy efficiency decreases. Increasing the well thickness has a negative effect on the energy efficiency of the process. Among the proposed thermal properties of the system, only the thermal diffusivities and conductivities of the reservoir as well as the porosity of the sediment affect the dissociation. The main contribution of this work is investigating analytically the hydrate dissociation using thermal stimulation by taking into account the effect of wellbore thickness and structure.

ACS Style

M. Roostaie; Y. Leonenko. Analytical modeling of methane hydrate dissociation under thermal stimulation. Journal of Petroleum Science and Engineering 2019, 184, 106505 .

AMA Style

M. Roostaie, Y. Leonenko. Analytical modeling of methane hydrate dissociation under thermal stimulation. Journal of Petroleum Science and Engineering. 2019; 184 ():106505.

Chicago/Turabian Style

M. Roostaie; Y. Leonenko. 2019. "Analytical modeling of methane hydrate dissociation under thermal stimulation." Journal of Petroleum Science and Engineering 184, no. : 106505.

Research article
Published: 19 August 2019 in Industrial & Engineering Chemistry Research
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Carbon capture and storage (CCS) technologies have widely emerged as a critical greenhouse gas reduction solution for closing the energy gap, while the world makes continuous efforts towards developing robust carbon-neutral technologies to mitigate climate changes. This research presents an economic optimization model for carbon dioxide (CO2) transportation via a pipeline from a source to a sink, in which the location of the booster stations is strategically determined to minimize the cost while satisfying the design and operational constraints. The work presents a general and flexible computational framework for CO2 pipeline transportation design by considering different factors such as inlet and outlet pipeline pressure, topographical conditions of terrain, pipeline power input and the distance between the sink and the source. Genetic algorithms (GA) are employed to find the best design parameters for minimizing the total cost. Results demonstrate pipeline diameter and pipeline elevation are two factors which significantly affect CO2 pressure drop, optimal design parameters and the associated cost. The computational framework presented in this research is very general, and compatible to incorporate a wide range of cost models and design limitations to generate the optimal design in different scenarios.

ACS Style

Mohammad Mohammadi; Farzad Hourfar; Ali Elkamel; Yuri Leonenko. Economic Optimization Design of CO2 Pipeline Transportation with Booster Stations. Industrial & Engineering Chemistry Research 2019, 58, 16730 -16742.

AMA Style

Mohammad Mohammadi, Farzad Hourfar, Ali Elkamel, Yuri Leonenko. Economic Optimization Design of CO2 Pipeline Transportation with Booster Stations. Industrial & Engineering Chemistry Research. 2019; 58 (36):16730-16742.

Chicago/Turabian Style

Mohammad Mohammadi; Farzad Hourfar; Ali Elkamel; Yuri Leonenko. 2019. "Economic Optimization Design of CO2 Pipeline Transportation with Booster Stations." Industrial & Engineering Chemistry Research 58, no. 36: 16730-16742.

Preprint
Published: 16 August 2019
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Underground carbon dioxide ($CO_2$) sequestration is considered one of the main methods to mitigate greenhouse gas (GHG) emissions. In this technology, pure $CO_2$ is injected into an underground geological formation and since it is less dense than residual fluids, there is always a risk of leakage to the surface. To increase security of underground $CO_2$ disposal, ex-situ dissolution can be implemented. When $CO_2$ is dissolved in brine before injection, it significantly reduces the risks of leakage. In this approach, pure $CO_2$ is dissolved on the surface before injection. Surface dissolution could be achieved in a pipeline operating under the pressure of a target aquifer into which the $CO_2$ is injected. In a pipeline, $CO_2$ droplets are dissolved in brine during turbulent co-current two phase flow. In this paper, a comprehensive model of droplet dissolution along a pipeline is presented. The model accounts for droplet breakup and coalescence processes and is validated against available experimental data.

ACS Style

Federico Cao; Dmitry Eskin; Yuri Leonenko. Modeling of Ex-Situ Dissolution for Geologic Sequestration of Carbon Dioxide in Aquifers. 2019, 1 .

AMA Style

Federico Cao, Dmitry Eskin, Yuri Leonenko. Modeling of Ex-Situ Dissolution for Geologic Sequestration of Carbon Dioxide in Aquifers. . 2019; ():1.

Chicago/Turabian Style

Federico Cao; Dmitry Eskin; Yuri Leonenko. 2019. "Modeling of Ex-Situ Dissolution for Geologic Sequestration of Carbon Dioxide in Aquifers." , no. : 1.

Journal article
Published: 01 November 2016 in Journal of Natural Gas Science and Engineering
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Highlights•Modeling of CO2 injection into aquifers which contain dissolved H2S is presented.•Initially dissolved H2S is exsolved and released into CO2 plume.•Leading edge of CO2 plume may contain 100% H2S which is in free phase. AbstractIn this paper, analytical one-dimensional modeling of CO2 injection into aquifers which contain dissolved H2S is presented. When CO2 is injected into such aquifers, the H2S initially dissolved in the brine will be exsolved and released into CO2 plume. It was shown that depending on reservoir pressure and temperature as well as on initial concentration of H2S the leading edge of CO2 plume may contain 100% H2S which is in free phase. The highly toxic nature of H2S gas suggests the need to account for dissolved H2S in aquifers when establishing risk assessment, monitoring, and management strategies at CO2 storage sites.

ACS Style

Aleksander Cholewinski; John Dengis; Victor Malkov; Yuri Leonenko. Modeling of CO 2 injection into aquifers containing dissolved H 2 S. Journal of Natural Gas Science and Engineering 2016, 36, 1080 -1086.

AMA Style

Aleksander Cholewinski, John Dengis, Victor Malkov, Yuri Leonenko. Modeling of CO 2 injection into aquifers containing dissolved H 2 S. Journal of Natural Gas Science and Engineering. 2016; 36 ():1080-1086.

Chicago/Turabian Style

Aleksander Cholewinski; John Dengis; Victor Malkov; Yuri Leonenko. 2016. "Modeling of CO 2 injection into aquifers containing dissolved H 2 S." Journal of Natural Gas Science and Engineering 36, no. : 1080-1086.

Journal article
Published: 09 February 2015 in Energy Science & Engineering
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A study, entitled “Wabamun Lake Sequestration Project” or “WASP,” was performed to evaluate large‐scale CO2 storage opportunities in the Wabamun area including potential risks. The project examined the feasibility of storing 20 megatons (Mt) of CO2 per year over 50 years. This scale is one order of magnitude larger than the typical benchmark (1 Mt/year) used in academic research and commercial projects that are currently in place or under review. The study was conducted by a group of researchers from several universities as well as industry consultants. This study presents an overview of the reservoir modeling part of this study, which the authors were responsible for. The main objectives of the reservoir modeling for WASP project were as follows: (1) estimation of storage capacity (traditionally, this value is projected based on the available pore space, but we have an additional practical consideration: the maximum amount one can inject within short period of time [~50 years] and within a localized injection area [~30 km × 90 km]); (2) investigation of CO2 plume movement and pressure distribution during and after injection including the effect of formation dip angle on the plume shape and its migration; (3) investigation of the long‐term fate of injection associated with free phase CO2 (risks of leakage) and aquifer pressurization (possible geomechanical changes and related phenomena); (4) investigation of the phase behavior of H2S initially available and dissolved in brine during CO2 sequestration process. The WASP reservoir modeling study mentioned above led to a few important findings. The most important one is that, when CO2 is being injected into a sour aquifer, initially dissolved H2S will release into the expanding CO2 plume and accumulate at the leading edge of the plume. Also, the large‐scale injection scheme (20 Mt/year), which requires multi well injectors, provides very different pressure response compared to a one well (1 Mt/year) scenario.

ACS Style

Seyyed M. Ghaderi; Yuri Leonenko. Reservoir modeling for Wabamun lake sequestration project. Energy Science & Engineering 2015, 3, 98 -114.

AMA Style

Seyyed M. Ghaderi, Yuri Leonenko. Reservoir modeling for Wabamun lake sequestration project. Energy Science & Engineering. 2015; 3 (2):98-114.

Chicago/Turabian Style

Seyyed M. Ghaderi; Yuri Leonenko. 2015. "Reservoir modeling for Wabamun lake sequestration project." Energy Science & Engineering 3, no. 2: 98-114.

Journal article
Published: 01 January 2013 in Energy Procedia
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In this paper, a model for diffusion-controlled dissolution of CO2 droplets during co-current (CO2-brine) horizontal turbulent pipe flow is presented. The objective is to evaluate the feasibility of ex-situ dissolution of CO2 before it is injected underground. Potential maximum droplet sizes for CO2 droplets are calculated, and compared with an estimated inner scale of turbulence. A comparison is made between times to dissolve for turbulent and diffusion dissolution, as well as an estimation of required pipe length needed for purely diffusion-based dissolution

ACS Style

Aleksander Cholewinski; Yuri Leonenko. Ex-situ Dissolution of CO2 for Carbon Sequestration. Energy Procedia 2013, 37, 5427 -5434.

AMA Style

Aleksander Cholewinski, Yuri Leonenko. Ex-situ Dissolution of CO2 for Carbon Sequestration. Energy Procedia. 2013; 37 ():5427-5434.

Chicago/Turabian Style

Aleksander Cholewinski; Yuri Leonenko. 2013. "Ex-situ Dissolution of CO2 for Carbon Sequestration." Energy Procedia 37, no. : 5427-5434.

Journal article
Published: 31 March 2011 in International Journal of Greenhouse Gas Control
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Many deep saline aquifers suitable for carbon dioxide (CO2) sequestration contain measurable concentrations of hydrogen sulfide (H2S). These aquifers are described here as sour saline aquifers and the other ones as ordinary saline aquifers. Sour saline aquifers occur wherever even minor amounts of anhydrite or other sulfate sources are present in the formation. In this paper, compositional modeling of CO2 injection into such aquifers is studied. When CO2 is injected into a sour saline aquifer, the H2S initially dissolved in the brine will be exsolved and released into an expanding CO2 plume. At any time after the start of CO2 injection, the region swept by the plume consists of two sub-regions. The first of these is an inner sub-region extending from the injection well, and is characterized by the absence of H2S in both aqueous and gaseous phases. The dissolved H2S in this inner sub-region is nearly completely removed from the brine via an exsolution process. The second sub-region extends from the outer edge of the inner sub-region to the leading edge of the plume. In this outer sub-region, the mole fraction of H2S in the gas plume gradually increases toward the leading edge and reaches a peak value. While the gas plume is expanding the size of the outer sub-region enlarges. Following the discussion of these phenomena, in the next part of the paper, injection of acid gases (mixtures of H2S and CO2) into sour saline aquifers and ordinary saline aquifers is explored. In contrast to sour aquifers, unsaturated water in an ordinary aquifer will strip away H2S from the CO2 stream and consequently the mole fraction of H2S toward the gas front decreases. The highly toxic nature of H2S gas suggests the need to account for dissolved H2S in sour saline aquifers when establishing risk assessment, monitoring, and management strategies at CO2 storage sites.

ACS Style

Seyyed M. Ghaderi; David W. Keith; Rob Lavoie; Yuri Leonenko. Evolution of hydrogen sulfide in sour saline aquifers during carbon dioxide sequestration. International Journal of Greenhouse Gas Control 2011, 5, 347 -355.

AMA Style

Seyyed M. Ghaderi, David W. Keith, Rob Lavoie, Yuri Leonenko. Evolution of hydrogen sulfide in sour saline aquifers during carbon dioxide sequestration. International Journal of Greenhouse Gas Control. 2011; 5 (2):347-355.

Chicago/Turabian Style

Seyyed M. Ghaderi; David W. Keith; Rob Lavoie; Yuri Leonenko. 2011. "Evolution of hydrogen sulfide in sour saline aquifers during carbon dioxide sequestration." International Journal of Greenhouse Gas Control 5, no. 2: 347-355.

Journal article
Published: 01 January 2011 in Energy Procedia
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Many aquifers suitable for CO2 sequestration contain measurable concentration of dissolved non-hydrocarbon species. In this paper, the compositional modelling of the CO2 injection into aquifers that contain dissolved hydrogen sulfide, described here as sour aquifers, is studied. According to the results of this study, when CO2 is injected into such aquifers, exsolution of dissolved components will occur and gaseous H2S will accumulate at the leading edge of the CO2 plume. At any time after the start of CO2 injection, the region swept by the plume consists of two sub-regions. An inner radial sub-region extending from the injection well is characterized by the absence of H2S in both the aqueous (brine) and gaseous (supercritical CO2) phases. The dissolved H2S in this first sub-region is almost completely removed from the brine and released to the migrating gas phase. The second sub-region extends from the outer edge of the first sub-region to the leading edge of the gas plume. In this outer sub-region, the mole fraction of H2S in the CO2 plume gradually increases toward a constant value at the edge (which is defined by the CO2-H2O-H2S phase equilibrium conditions at specific temperature, pressure, and salinity of the brine) and thereafter only the size of this sub-region progressively increases.For dissolved H2S concentrations typically found in the Western Canada Sedimentary Basin, mole fraction of gaseous H2S in the leading edge of the gas plume can be higher than 50%. This may have important implications for assessing the risk of CO2 injection into sour aquifers. Leakage into abandoned wells, for example, might plausibly occur when the gas phase first reaches the wellbore, so initial leakage may contain substantial amounts of H2S even though the average H2S fraction in the stored CO2 is quite small. H2S is highly toxic, with acute short term toxicity at 100 to 1000 times larger than that of CO2. This suggests that one need to account for this phenomenon when establishing risk assessment, monitoring and management strategies at planned CO2 geo-storage sites

ACS Style

Seyyed M. Ghaderi; David W. Keith; Rob Lavoie; Yuri Leonenko. Risk associated with H2S evolution in sour aquifers during CO2 injection. Energy Procedia 2011, 4, 4117 -4123.

AMA Style

Seyyed M. Ghaderi, David W. Keith, Rob Lavoie, Yuri Leonenko. Risk associated with H2S evolution in sour aquifers during CO2 injection. Energy Procedia. 2011; 4 ():4117-4123.

Chicago/Turabian Style

Seyyed M. Ghaderi; David W. Keith; Rob Lavoie; Yuri Leonenko. 2011. "Risk associated with H2S evolution in sour aquifers during CO2 injection." Energy Procedia 4, no. : 4117-4123.