Auswahl der wissenschaftlichen Literatur zum Thema „CO2 Injectivity“
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Zeitschriftenartikel zum Thema "CO2 Injectivity"
Sokama-Neuyam, Yen Adams, Jann Rune Ursin und Patrick Boakye. „Experimental Investigation of the Mechanisms of Salt Precipitation during CO2 Injection in Sandstone“. C 5, Nr. 1 (08.01.2019): 4. http://dx.doi.org/10.3390/c5010004.
Der volle Inhalt der QuelleGuo, Boyun, und Peng Zhang. „Injectivity Assessment of Radial-Lateral Wells for CO2 Storage in Marine Gas Hydrate Reservoirs“. Energies 16, Nr. 24 (09.12.2023): 7987. http://dx.doi.org/10.3390/en16247987.
Der volle Inhalt der QuelleCarpenter, Chris. „CO2 Injectivity Test Proves Concept of CCUS Field Development“. Journal of Petroleum Technology 76, Nr. 02 (01.02.2024): 63–65. http://dx.doi.org/10.2118/0224-0063-jpt.
Der volle Inhalt der QuelleGanesh, Priya Ravi, und Srikanta Mishra. „Reduced Physics Modeling of CO2 Injectivity“. Energy Procedia 63 (2014): 3116–25. http://dx.doi.org/10.1016/j.egypro.2014.11.336.
Der volle Inhalt der QuelleGasda, Sarah, und Roman Berenblyum. „Intermittent CO2 injection: injectivity and capacity“. Baltic Carbon Forum 2 (13.10.2023): 18–19. http://dx.doi.org/10.21595/bcf.2023.23643.
Der volle Inhalt der QuelleRogers, John D., und Reid B. Grigg. „A Literature Analysis of the WAG Injectivity Abnormalities in the CO2 Process“. SPE Reservoir Evaluation & Engineering 4, Nr. 05 (01.10.2001): 375–86. http://dx.doi.org/10.2118/73830-pa.
Der volle Inhalt der QuelleGong, Jiakun, Yuan Wang, Raj Deo Tewari, Ridhwan-Zhafri B. Kamarul Bahrim und William Rossen. „Effect of Gas Composition on Surfactant Injectivity in a Surfactant-Alternating-Gas Foam Process“. Molecules 29, Nr. 1 (22.12.2023): 100. http://dx.doi.org/10.3390/molecules29010100.
Der volle Inhalt der QuelleHeidarabad, Reyhaneh Ghorbani, und Kyuchul Shin. „Carbon Capture and Storage in Depleted Oil and Gas Reservoirs: The Viewpoint of Wellbore Injectivity“. Energies 17, Nr. 5 (02.03.2024): 1201. http://dx.doi.org/10.3390/en17051201.
Der volle Inhalt der QuelleFokker, P. A., und L. G. H. van der Meer. „The injectivity of coalbed CO2 injection wells“. Energy 29, Nr. 9-10 (Juli 2004): 1423–29. http://dx.doi.org/10.1016/j.energy.2004.03.076.
Der volle Inhalt der QuelleZiaudin Ahamed, M. Nabil, Muhammad Azfar Mohamed, M. Aslam Md Yusof, Iqmal Irshad, Nur Asyraf Md Akhir und Noorzamzarina Sulaiman. „Modeling the Combined Effect of Salt Precipitation and Fines Migration on CO2 Injectivity Changes in Sandstone Formation“. Journal of Petroleum and Geothermal Technology 2, Nr. 2 (28.11.2021): 55. http://dx.doi.org/10.31315/jpgt.v2i2.5421.
Der volle Inhalt der QuelleDissertationen zum Thema "CO2 Injectivity"
Raza, Arshad. „Reservoir Characterization for CO2 Injectivity and Flooding in Petroleum Reservoirs, offshore Malaysia“. Thesis, Curtin University, 2017. http://hdl.handle.net/20.500.11937/57524.
Der volle Inhalt der QuelleSyed, Shafiuddin Amer. „Permeability and injectivity enhancement of the near wellbore region fo CO2 enhanmced coalbed methane recovery and CO2 storage“. Thesis, Imperial College London, 2011. http://ethos.bl.uk/OrderDetails.do?uin=uk.bl.ethos.534965.
Der volle Inhalt der QuelleIssautier, Benoit. „Impact des hétérogénéités sédimentaires sur le stockage géologique du CO2“. Thesis, Aix-Marseille 1, 2011. http://www.theses.fr/2011AIX10136.
Der volle Inhalt der QuelleIn the CO2 storage context, heterogeneity has only been rarely considered in reservoir models to date. To address this key issue, the project aims at developing a workflow that manages the heterogeneity from the field observations up to the reservoir simulation. The characterisation of the Minjur Sandstone (a Triassic formation from Central Saudi Arabia) shows the crucial role of connectivity in the reservoir architecture, and the genetic link between the nature, location and connectivity of the sedimentary bodies in the sequence. Stemming from this study, a conceptual model was established and stochastically reproduced through an algorithm simulating models conditioned to a sedimentary history. Fifty scenarios were simulated, representing various connectivity degrees. Each of these scenarios is composed of two models, identical by their architecture but different in their internal sedimentary fill. This approach allows the study of the impact of the (a) reservoir bodies’ connectivity and (b) their internal sedimentary heterogeneity on the reservoir’s performances. The capacity estimates using a static calculation based on the available pore volumes reveals a mean capacity of 13 Mt (for a 25 x 25 km x 60 m semi finite aquifer at 1000m deep). The sedimentary heterogeneity (shaly deposits called oxbow lakes) is responsible for a 30% difference of capacity. The flow simulations confirm these results and show that the connectivity of the reservoir bodies creates a 23% capacity variation. Moreover, the heterogeneities tend to reduce the amount of CO2 able to reach the uppermost reservoir which may enhance the storage integrity
Beinashor, R. „Effect of halite (NaCl) on sandstone permeability and well injectivity during CO2 storage in saline aquifers“. Thesis, University of Salford, 2017. http://usir.salford.ac.uk/44572/.
Der volle Inhalt der QuelleOsselin, Florian. „Thermochemical-based poroelastic modelling of salt crystallization, and a new multiphase flow experiment : how to assess injectivity evolution in the context of CO2 storage in deep aquifers“. Phd thesis, Université Paris-Est, 2013. http://pastel.archives-ouvertes.fr/pastel-00977430.
Der volle Inhalt der QuelleUzun, Ilkay. „Use Of Pore Scale Simulators To Understand The Effects Of Wettability On Miscible Carbon Dioxide Flooding And Injectivity“. Master's thesis, METU, 2005. http://etd.lib.metu.edu.tr/upload/2/12606876/index.pdf.
Der volle Inhalt der QuelleC) is investigated. And it is found that, the increase in the intrinsic angles causes decrease in relative permeability values. As another scenario, two phase model is developed in which miscible CO2 &
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water is flooded after the primary drainage of the same 2-D network at supercritical temperature (32 °
C). This case is compared with the previous case and the effects of miscibility are investigated such that it causes the relative permeability values to increase. Adsorption is another concern of which its effects are analyzed in a single pore model. The model is compared with the reported experimental data at high temperature and pressures. A reasonable fit is obtained.
Ndjaka, Ange. „THERMOPHYSICAL PROCESSES AND REACTIVE TRANSPORT MECHANISMS INDUCED BY CO2 INJECTION IN DEEP SALINE AQUIFERS“. Electronic Thesis or Diss., Pau, 2022. http://www.theses.fr/2022PAUU3003.
Der volle Inhalt der QuelleCO2 storage in deep saline aquifers has been recognised as one of the most promising ways to mitigate atmospheric CO2 emissions and thus respond to the challenges of climate change. However, the injection of CO2 into the porous medium considerabely disturbs its thermodynamic equilibrium. The near-well injection zone is particularly impacted with a strong geochemical reactivity associated with intense heat exchanges. This has a major impact on injectivity of the reservoir and the integrity of the storage. In addition to these effects, there is the added complexity of the presence of two immiscible phases: brine (wetting fluid) and CO2 (non-wetting fluid). These effects lead to highly coupled Thermo-Hydro-Mechanical-Chemical (THMC) processes, whose interpretations have not yet been completed nor formally implemented into the numerical models.This thesis work, combining experimental measurements and numerical modelling, focuses on the study of the coupling between the thermal gradients and the diffusive reactive transport processes taking place in the deep saline aquifers, particularly in the near-well injection zone. We studied the exchanges between a cold anhydrous CO2 phase flowing in high permeability zones, and a hot salty aqueous phase trapped in the porosity of the rock. The strategy of the study starts with a simple approach in a free medium without CO2 flow, in order to study the reactivity of saline solutions of different chemical compositions, and to evaluate the impact of a thermal gradient on this reaction network.We have developed an experimental cell that allow to superimpose 2 to 3 layers of solution of different concentration and chemical composition. The analysis of the light scattered by the non-equilibrium fluctuations of concentration and temperature allows to obtain the diffusion coefficients of salts in water. Our results are in good agreement with literature values. Regarding the study of diffusive reactive transport, the analysis of the contrast of the images allowed us to highlight the fact that the precipitation of minerals, obtained by superimposing two aqueous layers of reactive, is accompanied by a convective instability that fades with time. Numerical modelling of the experimental results with PHREEQC using a heterogeneous multicomponent diffusion approach has allowed us to account for these convective instabilities. Different temperature gradients were applied to the reactive system, while keeping a mean temperature of 25 °C. The experimental observations and numerical interpretations swhow that the temperature gradient has no significant influence on the behaviour of the system. Subsequently, we numerically studied the desiccation process (evaporation of water) at the interface between a brine trapped in the rock porosity and the CO2 flowing in a draining pore structure, simulating the conditions of the Dogger aquifer of the Paris basin. A model coupling the evaporation of water in the CO2 stream and the heterogeneous multicomponent diffusion of salts predicts the appearance of a mineral assemblage at the evaporation front, mainly composed by halite and anhydrite. Modelling this phenomenon at the reservoir scale would requires taking into account the evaporation rate as a function of the CO2 injection rate and the change in porosity at the interface.This thesis work has made it possible to highlight several physicochemical, thermophysical and diffusive transport phenomena at phase interfaces. This opens up new perspectives for improving numerical approaches and large-scale modelling, in particular of near-well injection of CO2 and geological storage reservoirs, and supports future industrial developments and technologies for the ecological transition
Tian, Liang. „CO2 storage in deep saline aquifers : Models for geological heterogeneity and large domains“. Doctoral thesis, Uppsala universitet, Luft-, vatten och landskapslära, 2016. http://urn.kb.se/resolve?urn=urn:nbn:se:uu:diva-279382.
Der volle Inhalt der QuelleSánchez, Jesús Antonio García. „Estudo do fenômeno da auto-intersecção em um anel anisotrópico“. Universidade de São Paulo, 2008. http://www.teses.usp.br/teses/disponiveis/18/18134/tde-05022009-100510/.
Der volle Inhalt der QuelleThis work concerns a numerical study of a homogeneous circular plate with a centered hole that is under a state of plane strain. The plate is fixed at its inner surface and is under uniform radial compression at its outer surface. The plate is linear, elastic, and anisotropic. An analytical solution for this problem, which satisfies the governing equations of equilibrium, is presented in the context of classical linear elasticity. This solution predicts the spurious behavior of self-intersection in a central region of the plate. To avoid this behavior, a constrained minimization theory is used. This theory concerns the search for a displacement field that minimizes the total potential energy of the body, which is a quadratic functional from the classical linear theory, subjected to the constraint of local injectivity for the associated deformation field. This theory together with an interior penalty method and a standard finite element methodology yield a numerical solution, which is radially symmetric, that preserves injectivity. Here, it is investigated the possibility of finding a rotationally symmetric solution to the constrained problem; one for which the associated displacement field has radial and tangential components, which are both functions of the radius only. The numerical results show, however, that the tangential component is zero. It is also shown that, as the radius of the hole tends to zero, the corresponding sequence of solutions tends to the solution of a solid disk.
Osselin, Florian. „Modélisation thermochimique et poroélastique de la cristallisation de sel, et nouveau dispositif expérimental d'écoulement multiphasique : comment prédire l'évolution de l'injectivité pour le stockage du CO2 en aquifère profond ?“ Phd thesis, Université Paris-Est, 2013. http://tel.archives-ouvertes.fr/tel-00958697.
Der volle Inhalt der QuelleBuchteile zum Thema "CO2 Injectivity"
A. Sokama-Neuyam, Yen, Muhammad A.M. Yusof und Shadrack K. Owusu. „CO2 Injectivity in Deep Saline Formations: The Impact of Salt Precipitation and Fines Mobilization“. In Carbon Sequestration [Working Title]. IntechOpen, 2022. http://dx.doi.org/10.5772/intechopen.104854.
Der volle Inhalt der QuelleFOKKER, P., und L. VANDERMEER. „The Injectivity of Coalbed CO2 Injection Wells“. In Greenhouse Gas Control Technologies - 6th International Conference, 551–56. Elsevier, 2003. http://dx.doi.org/10.1016/b978-008044276-1/50088-x.
Der volle Inhalt der QuelleGoodarzi, Somayeh, Antonin Settari, Mark Zoback und David W. „Thermal Effects on Shear Fracturing and Injectivity During CO2 Storage“. In Effective and Sustainable Hydraulic Fracturing. InTech, 2013. http://dx.doi.org/10.5772/56311.
Der volle Inhalt der QuelleMackay, E. J. „Modelling the injectivity, migration and trapping of CO 2 in carbon capture and storage (CCS)“. In Geological Storage of Carbon Dioxide (CO2), 45–70. Elsevier, 2013. http://dx.doi.org/10.1533/9780857097279.1.45.
Der volle Inhalt der QuelleSHI, J., und S. DURUCAN. „A numerical simulation study of the Allison Unit CO2-ECBM pilotThe impact of matrix shrinkage and swelling on ECBM production and CO2 injectivity“. In Greenhouse Gas Control Technologies 7, 431–39. Elsevier, 2005. http://dx.doi.org/10.1016/b978-008044704-9/50044-6.
Der volle Inhalt der QuelleKonferenzberichte zum Thema "CO2 Injectivity"
Zakrisson, Johan, Ingrid Edman und Yildiray Cinar. „Multiwell Injectivity for CO2 Storage“. In SPE Asia Pacific Oil and Gas Conference and Exhibition. Society of Petroleum Engineers, 2008. http://dx.doi.org/10.2118/116355-ms.
Der volle Inhalt der QuelleNagineni, Venu Gopal Rao, Richard Gary Hughes, David D'Souza und Kenneth Michael Deets. „Evaluation of CO2 Injectivity From Waterflood Values“. In SPE Western Regional Meeting. Society of Petroleum Engineers, 2010. http://dx.doi.org/10.2118/132624-ms.
Der volle Inhalt der QuelleMcMillan, Burton, Navanit Kumar und Steven Lawrence Bryant. „Time-Dependent Injectivity During CO2 Storage in Aquifers“. In SPE Symposium on Improved Oil Recovery. Society of Petroleum Engineers, 2008. http://dx.doi.org/10.2118/113937-ms.
Der volle Inhalt der QuelleJin, M., E. J. Mackay, S. A. Mathias, J. G. Gluyas, W. H. Goldthorpe und G. E. Pickup. „On the Sensitivity of CO2 Injectivity to Reservoir Facies Architecture“. In Fourth EAGE CO2 Geological Storage Workshop. Netherlands: EAGE Publications BV, 2014. http://dx.doi.org/10.3997/2214-4609.20140122.
Der volle Inhalt der QuelleAli*, Syed Anas, Jay R. Black und Ralf Haese. „Geochemical Stimulation in Siliciclastic Reservoirs to Enhance CO2 Injectivity“. In International Conference and Exhibition, Melbourne, Australia 13-16 September 2015. Society of Exploration Geophysicists and American Association of Petroleum Geologists, 2015. http://dx.doi.org/10.1190/ice2015-2210548.
Der volle Inhalt der QuelleKaipov, Y., B. Theuveny, A. Maurya und A. Alawagi. „CO2 Injectivity Test Proves the Concept of CCUS Field Development“. In ADIPEC. SPE, 2023. http://dx.doi.org/10.2118/216673-ms.
Der volle Inhalt der QuelleAndré, L. „Well Injectivity during CO2 Storage Operations in Deep Saline Aquifers“. In First EAGE Workshop on Well Injectivity and Productivity in Carbonates. Netherlands: EAGE Publications BV, 2015. http://dx.doi.org/10.3997/2214-4609.201412023.
Der volle Inhalt der QuelleAlkan, H., und Y. Cinar. „Effects of Capillarity and Solubility in Brine on CO2 Injectivity into an Aquifer“. In First EAGE CO2 Geological Storage Workshop. European Association of Geoscientists & Engineers, 2008. http://dx.doi.org/10.3997/2214-4609.20146171.
Der volle Inhalt der QuelleGrigg, Reid Barlow, und Robert Svec. „Injectivity Changes and CO2 Retention for EOR and Sequestration Projects“. In SPE Symposium on Improved Oil Recovery. Society of Petroleum Engineers, 2008. http://dx.doi.org/10.2118/110760-ms.
Der volle Inhalt der QuelleCrawshaw, J. P., und E. S. Boek. „Asphaltene Precipitation and Deposition from a Heavy Crude Oil with CO2“. In First EAGE Workshop on Well Injectivity and Productivity in Carbonates. Netherlands: EAGE Publications BV, 2015. http://dx.doi.org/10.3997/2214-4609.201412008.
Der volle Inhalt der QuelleBerichte der Organisationen zum Thema "CO2 Injectivity"
Yoshida, Nozomu, und Philip H. Stauffer. Influence of relative permeability parameters on CO2 injectivity. Office of Scientific and Technical Information (OSTI), August 2013. http://dx.doi.org/10.2172/1091808.
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