ECO2N V. 2.0: A New TOUGH2 Fluid Property Module for Mixtures of Water, NaCl, and CO&lt;sub&gt;2&lt;/sub&gt;

Pan, Lehua; Spycher, N.; Doughty, Christine; Pruess, Karsten

doi:10.2172/1170605

Cited by 14 publications

(14 citation statements)

References 16 publications

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“…After 3.35 day, profiles for both pressure and temperature reached the steady-state condition while CO 2 in the wellbore completely became supercritical phase (Figure 2(b)). In summary, due to thermal processes such as frictional effect, heat conduction, and Joule-Thomson effect, temperature of CO 2 which entered the storage formation reached approximately 51-52 ∘ C, which was greater than injected CO 2 (35 ∘ C) but lower than temperature (54)(55) ∘ C) of the storage formation. Figure 3 showed contours for density, viscosity, specific enthalpy, and Joule-Thomson coefficient of CO 2 dependent on temperature and pressure, which were predicted from Span and Wagner [63].…”

Section: Geofluidsmentioning

confidence: 91%

“…In this study, two simulators were compared; one for the EPM model applying to Case 1 was TOUGH2/ECO2N [53,54] and the other for the WR model in Case 2 was T2Well/ECO2N [24,55]. TOUGH2 is the numerical simulator capable of simulating nonisothermal multiphase and multicomponent fluids in multidimensional porous and fractured media [53].…”

Section: Numericalmentioning

confidence: 99%

“…TOUGH2 is the numerical simulator capable of simulating nonisothermal multiphase and multicomponent fluids in multidimensional porous and fractured media [53]. The ECO2N is a fluid property module that describes the thermophysical properties of H 2 O-NaCl-CO 2 system [54,56]. T2Well/ECO2N, which is the suite of the TOUGH2/ECO2N, is the integrated simulator capable of accounting for both wellbore and storage subdomain where they are controlled by different governing equations [24].…”

Section: Numericalmentioning

confidence: 99%

See 2 more Smart Citations

Dynamic Behavior of CO₂ in a Wellbore and Storage Formation: Wellbore-Coupled and Salt-Precipitation Processes during Geologic CO₂ Sequestration

et al. 2018

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For investigating the wellbore flow process in CO 2 injection scenarios, coupled wellbore-reservoir (WR) and conventional equivalent porous media (EPM) models were compared with each other. In WR model, during the injection, conditions for the wellbore including pressure and temperature were dynamically changed from the initial pressure (7.45-8.33 MPa) and temperature (52.0-55.9∘ C) of the storage formation. After 3.35 days, the wellbore flow reached the steady state with adiabatic condition; temperature linearly increased from the well-head (35 ∘ C) to the well-bottom (52 ∘ C). In contrast, the EPM model neglecting the wellbore process revealed that CO 2 temperature was consistently 35∘ C at the screen interval. Differences in temperature from WR and EPM models resulted in density contrast of CO 2 that entered the storage formation (∼200 and ∼600 kg/m 3 , resp.). Subsequently, the WR model causing greater density difference between CO 2 and brine revealed more vertical CO 2 migration and counterflow of brine and also developed the localized salt-precipitation. Finally, a series of sensitivity analyses for the WR model was conducted to assess how the injection conditions influenced interplay between flow system and the localized salt-precipitation in the storage formation.

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Section: Geofluidsmentioning

confidence: 91%

Section: Numericalmentioning

confidence: 99%

Section: Numericalmentioning

confidence: 99%

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Dynamic Behavior of CO₂ in a Wellbore and Storage Formation: Wellbore-Coupled and Salt-Precipitation Processes during Geologic CO₂ Sequestration

et al. 2018

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“…In the reservoir, the flow is described as Darcy's law and in wellbore, it is momentum conservation. To consider a comprehensive description of the thermophysical properties of H 2 O-CO 2 mixtures, the ECO2N V2.0 module was introduced, which reproduces fluid properties including density, viscosity, and specific enthalpy, largely within experimental errors under the temperature and pressure conditions of 10 ∘ C < < 300 ∘ C, < 600 bar [20]. These fundamental flow equations, used in the T2Well code [18], are summarized in Table 4.…”

Section: Governing Equationsmentioning

confidence: 99%

On Fluid and Thermal Dynamics in a Heterogeneous CO₂ Plume Geothermal Reservoir

Zhu

Feng

et al. 2017

Geofluids

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CO 2 is now considered as a novel heat transmission fluid to extract geothermal energy. It can achieve both the energy exploitation and CO 2 geological sequestration. The migration pathway and the process of fluid flow within the reservoirs affect significantly a CO 2 plume geothermal (CPG) system. In this study, we built three-dimensional wellbore-reservoir coupled models using geological and geothermal conditions of Qingshankou Formation in Songliao Basin, China. The performance of the CPG system is evaluated in terms of the temperature, CO 2 plume distribution, flow rate of production fluid, heat extraction rate, and storage of CO 2 . For obtaining a deeper understanding of CO 2 -geothermal system under realistic conditions, heterogeneity of reservoir's hydrological properties (in terms of permeability and porosity) is taken into account. Due to the fortissimo mobility of CO 2 , as long as a highly permeable zone exists between the two wells, it is more likely to flow through the highly permeable zone to reach the production well, even though the flow path is longer. The preferential flow shortens circulation time and reduces heat-exchange area, probably leading to early thermal breakthrough, which makes the production fluid temperature decrease rapidly. The analyses of flow dynamics of CO 2 -water fluid and heat may be useful for future design of a CO 2 -based geothermal development system.

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“…TOUGH2/ECO2N 28,29 had been used in this study as the main simulator to conduct uncertain scenario analysis regarding the plume migration and the potential risk involved. The accuracy and reliability of this simulator had been checked by the developer 20 and used worldwide by users regarding the carbon storage application.…”

Section: Scenario Analysis and Numerical Modelling Define Homogeneousmentioning

confidence: 99%

Injection risk assessment for intra‐formational seal geological model in a carbon sequestration application in Taiwan

Yu¹,

Lei²,

Chiao

et al. 2016

Greenhouse Gases

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As a deep saline aquifer, the Tai‐hsi Foreland Basin in western Taiwan is regarded as an excellent locality to sequester the huge carbon emission from domestic coal‐fired power plants. Existing geological data show that an intra‐formational seal capability characterized by multilayered shale baffles can act as the primary or ultimate cap system. In this study, the relevant ranges of rock parameter of porosity (20∼35%) and permeability (0.0001∼1300 mD), respectively, for the storage layers (sandstone) and seals (shale) have been selected according to large amount of laboratory core test from a nearby pioneering 3000 m drilling and sampling within the southern flank of the Tai‐hsi Basin. Comprehensive geological models considering both homogeneous and heterogeneous cases, and a typical plume migration scenario under a single‐well injection were simulated under a 20‐year continuous injection (1 MtCO2 per year) followed by post‐injection monitoring up to 1000 years. Corresponding 2D maximum horizontal migration distances (MHMD) of CO2 plume in the storage reservoir were calculated with respect to a homogeneous reservoir model and its heterogeneous counterparts. In addition, the induced pressures at critical monitoring points were also evaluated and compared. As a consequence, the ubiquitous shale baffles of intra‐formational seal in a heterogeneous saline aquifers were proven to be a successful trapping mechanism controlling the migration distances of lateral and upward movement. Furthermore, safe carbon storage operation within Tai‐hsi Basin with formation depth range about 2135 to 2450 mRT can be ensured by checking statistically the calculated maximum MHMD and the induced pressure magnitude. © 2016 Society of Chemical Industry and John Wiley & Sons, Ltd.

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ECO2N V. 2.0: A New TOUGH2 Fluid Property Module for Mixtures of Water, NaCl, and CO<sub>2</sub>

Cited by 14 publications

References 16 publications

Dynamic Behavior of CO₂ in a Wellbore and Storage Formation: Wellbore-Coupled and Salt-Precipitation Processes during Geologic CO₂ Sequestration

Dynamic Behavior of CO₂ in a Wellbore and Storage Formation: Wellbore-Coupled and Salt-Precipitation Processes during Geologic CO₂ Sequestration

On Fluid and Thermal Dynamics in a Heterogeneous CO₂ Plume Geothermal Reservoir

Injection risk assessment for intra‐formational seal geological model in a carbon sequestration application in Taiwan

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ECO2N V. 2.0: A New TOUGH2 Fluid Property Module for Mixtures of Water, NaCl, and CO<sub>2</sub>

Cited by 14 publications

References 16 publications

Dynamic Behavior of CO2 in a Wellbore and Storage Formation: Wellbore-Coupled and Salt-Precipitation Processes during Geologic CO2 Sequestration

Dynamic Behavior of CO2 in a Wellbore and Storage Formation: Wellbore-Coupled and Salt-Precipitation Processes during Geologic CO2 Sequestration

On Fluid and Thermal Dynamics in a Heterogeneous CO2 Plume Geothermal Reservoir

Injection risk assessment for intra‐formational seal geological model in a carbon sequestration application in Taiwan

Contact Info

Product

Resources

About

Dynamic Behavior of CO₂ in a Wellbore and Storage Formation: Wellbore-Coupled and Salt-Precipitation Processes during Geologic CO₂ Sequestration

Dynamic Behavior of CO₂ in a Wellbore and Storage Formation: Wellbore-Coupled and Salt-Precipitation Processes during Geologic CO₂ Sequestration

On Fluid and Thermal Dynamics in a Heterogeneous CO₂ Plume Geothermal Reservoir