The Experts below are selected from a list of 222 Experts worldwide ranked by ideXlab platform
Karsten Pruess - One of the best experts on this subject based on the ideXlab platform.
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integrated modeling of co2 storage and leakage scenarios including transitions between super and sub critical conditions and phase change between liquid and gaseous co2
Greenhouse Gases-Science and Technology, 2011Co-Authors: Karsten PruessAbstract:Integrated Modeling of CO 2 Storage and Leakage Scenarios Including Transitions between Super- and Sub-Critical Conditions, and Phase Change between Liquid and Gaseous CO 2 Karsten Pruess Earth Sciences Division, Lawrence Berkeley National Laboratory University of California, Berkeley, CA 94720, USA K_Pruess@lbl.gov ABSTRACT Storage of CO 2 in saline aquifers is intended to be at supercritical pressure and temperature conditions, but CO 2 leaking from a geologic storage reservoir and migrating towards the land surface (through faults, fractures, or improperly abandoned wells) would reach sub-critical conditions at depths shallower than 500-750 m. At these and shallower depths, subcritical CO 2 can form two-phase mixtures of liquid and gaseous CO 2 , with significant latent heat Effects during boiling and condensation. Additional strongly non-isothermal Effects can arise from decompression of gas-like subcritical CO 2 , the so-called Joule-Thomson Effect. Integrated modeling of CO 2 storage and leakage requires the ability to model non-isothermal flows of brine and CO 2 at conditions that range from supercritical to subcritical, including three-phase flow of aqueous phase, and both liquid and gaseous CO 2 . In this paper we describe and demonstrate comprehensive simulation capabilities that can cope with all possible phase conditions in brine- CO 2 systems. Our model formulation includes an accurate description of thermophysical properties of aqueous and CO 2 -rich phases as functions of temperature, pressure, salinity and CO 2 content, including the mutual dissolution of CO 2 and H 2 O; transitions between super- and sub-critical conditions, including phase change between liquid and gaseous CO 2 ; one-, two-, and three-phase flow of brine-CO 2 mixtures, including heat flow; 11 May 2011
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integrated modeling of co2 storage and leakage scenarios including transitions between super and sub critical conditions and phase change between liquid and gaseous co2
Greenhouse Gases-Science and Technology, 2011Co-Authors: Karsten PruessAbstract:Storage of CO 2 in saline aquifers is intended to be at supercritical pressure and temperature conditions, but CO 2 leaking from a geologic storage reservoir and migrating toward the land surface (through faults, fractures, or improperly abandoned wells) would reach subcritical conditions at depths shallower than 500–750 m. At these and shallower depths, subcritical CO 2 can form two‐phase mixtures of liquid and gaseous CO 2 , with significant latent heat Effects during boiling and condensation. Additional strongly non‐isothermal Effects can arise from decompression of gas‐like subcritical CO 2 , the so‐called Joule–Thomson Effect. Integrated modeling of CO 2 storage and leakage requires the ability to model non‐isothermal flows of brine and CO 2 at conditions that range from supercritical to subcritical, including three‐phase flow of aqueous phase, and both liquid and gaseous CO 2 . In this paper, we describe and demonstrate comprehensive simulation capabilities that can cope with all possible phase conditions in brine‐CO 2 systems. Our model formulation includes: an accurate description of thermophysical properties of aqueous and CO 2 ‐rich phases as functions of temperature, pressure, salinity and CO 2 content, including the mutual dissolution of CO 2 and H 2 O; transitions between super‐ and subcritical conditions, including phase change between liquid and gaseous CO 2 ; one‐, two‐, and three‐phase flow of brine‐CO 2 mixtures, including heat flow; non‐isothermal Effects associated with phase change, mutual dissolution of CO 2 and water, and (de‐) compression Effects; and the Effects of dissolved NaCl, and the possibility of precipitating solid halite, with associated porosity and permeability change. Applications to specific leakage scenarios demonstrate that the peculiar thermophysical properties of CO 2 provide a potential for positive as well as negative feedbacks on leakage rates, with a combination of self‐enhancing and self‐limiting Effects. Lower viscosity and density of CO 2 as compared to aqueous fluids provides a potential for self‐enhancing Effects during leakage, while strong cooling Effects from liquid CO 2 boiling into gas, and from expansion of gas rising towards the land surface, act to self‐limit discharges. Strong interference between fluid phases under three‐phase conditions (aqueous – liquid CO 2 – gaseous CO 2 ) also tends to reduce CO 2 fluxes. Feedback on different space and time scales can induce non‐monotonic behavior of CO 2 flow rates. © 2011 Society of Chemical Industry and John Wiley & Sons, Ltd
Zhanping You - One of the best experts on this subject based on the ideXlab platform.
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Dispersion of carbon dioxide released from buried high-pressure pipeline over complex terrain.
Environmental science and pollution research international, 2020Co-Authors: Huiru Wang, Bin Liu, Xiong Liu, Jiajia Deng, Zhanping YouAbstract:To quantitatively assess the risks associated with Carbon Capture and Storage (CCS) technology, a better understanding of the dispersion characteristics of CO2 released from a high-pressure pipeline is necessary. The dispersion process is complicated as CO2 is denser than air, and the Joule-Thomson Effect causes sharp drop of the temperature. In this study, computational fluid dynamics (CFD) technique was used to investigate the CO2 dispersion. The CFD model is validated by simulating a full-size blasting test. The influence of topography and low temperature at the release source on the dispersion of CO2 released from buried CO2 pipelines over complex terrain types was studied. This study provides a viable method for the assessment of the risks associated with CCS.
Huiru Wang - One of the best experts on this subject based on the ideXlab platform.
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Dispersion of carbon dioxide released from buried high-pressure pipeline over complex terrain.
Environmental science and pollution research international, 2020Co-Authors: Huiru Wang, Bin Liu, Xiong Liu, Jiajia Deng, Zhanping YouAbstract:To quantitatively assess the risks associated with Carbon Capture and Storage (CCS) technology, a better understanding of the dispersion characteristics of CO2 released from a high-pressure pipeline is necessary. The dispersion process is complicated as CO2 is denser than air, and the Joule-Thomson Effect causes sharp drop of the temperature. In this study, computational fluid dynamics (CFD) technique was used to investigate the CO2 dispersion. The CFD model is validated by simulating a full-size blasting test. The influence of topography and low temperature at the release source on the dispersion of CO2 released from buried CO2 pipelines over complex terrain types was studied. This study provides a viable method for the assessment of the risks associated with CCS.
Janssen R Van Rosmalen - One of the best experts on this subject based on the ideXlab platform.
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Effect of h2 injection on the thermodynamic and transportation properties of natural gas
International Journal of Hydrogen Energy, 2004Co-Authors: J A Schouten, J P J Michels, Janssen R Van RosmalenAbstract:Abstract Condensation of hydrocarbons due to temperature and pressure changes in the pipelines plays an important role in the transportation of natural gas. Injection of hydrogen might change this condensation behavior considerably. The influence of hydrogen on the thermodynamics upon injection, on the Joule–Thomson Effect at the pressure reduction stations, on the energy density, on the Wobbe index, and on the pressure drop in the pipelines has been calculated. It has been shown that injection of 25% hydrogen may lead to a temperature drop of several degrees, the temperature drop at the pressure reduction stations reduces by 1 3 , and the pressure drop in the transport lines increases only slightly. Moreover, at 40 bar and 258 K the amount of liquid condensate is slightly less in the case of hydrogen if the same amount of energy is transported.
Bin Liu - One of the best experts on this subject based on the ideXlab platform.
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Dispersion of carbon dioxide released from buried high-pressure pipeline over complex terrain.
Environmental science and pollution research international, 2020Co-Authors: Huiru Wang, Bin Liu, Xiong Liu, Jiajia Deng, Zhanping YouAbstract:To quantitatively assess the risks associated with Carbon Capture and Storage (CCS) technology, a better understanding of the dispersion characteristics of CO2 released from a high-pressure pipeline is necessary. The dispersion process is complicated as CO2 is denser than air, and the Joule-Thomson Effect causes sharp drop of the temperature. In this study, computational fluid dynamics (CFD) technique was used to investigate the CO2 dispersion. The CFD model is validated by simulating a full-size blasting test. The influence of topography and low temperature at the release source on the dispersion of CO2 released from buried CO2 pipelines over complex terrain types was studied. This study provides a viable method for the assessment of the risks associated with CCS.
