Modelo integrado del comportamiento de asfaltenos en condiciones de flujo

Ilustraciones, gráficos

Autores:: Cundar Paredes, Cristiam David

Tipo de recurso:: Doctoral thesis

Fecha de publicación:: 2024

Institución:: Universidad Nacional de Colombia

Repositorio:: Universidad Nacional de Colombia

Idioma:: spa

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repository_id_str
dc.title.none.fl_str_mv	Modelo integrado del comportamiento de asfaltenos en condiciones de flujo
dc.title.translated.eng.fl_str_mv	Integrated model of asphaltene behavior in flow conditions
title	Modelo integrado del comportamiento de asfaltenos en condiciones de flujo
spellingShingle	Modelo integrado del comportamiento de asfaltenos en condiciones de flujo 660 - Ingeniería química 620 - Ingeniería y operaciones afines::622 - Minería y operaciones relacionadas Asfaltenos Permeabilidad Dinámica de fluidos Industria energética Termodinámica Formación de daños (Ingeniería de petróleos) Simulación por computadores Pozos petroleros Campos petrolíferos Asfaltenos Ecuación de estado Cinética de agregación Daño de formación Simulación numérica Asphaltenes Equation of state Aggregation kinetics Formation damage Numerical simulation
title_short	Modelo integrado del comportamiento de asfaltenos en condiciones de flujo
title_full	Modelo integrado del comportamiento de asfaltenos en condiciones de flujo
title_fullStr	Modelo integrado del comportamiento de asfaltenos en condiciones de flujo
title_full_unstemmed	Modelo integrado del comportamiento de asfaltenos en condiciones de flujo
title_sort	Modelo integrado del comportamiento de asfaltenos en condiciones de flujo
dc.creator.fl_str_mv	Cundar Paredes, Cristiam David
dc.contributor.advisor.none.fl_str_mv	Benjumea, Pedro Nel
dc.contributor.author.none.fl_str_mv	Cundar Paredes, Cristiam David
dc.contributor.orcid.spa.fl_str_mv	Cundar Paredes, Cristiam David [0000-0002-3409-7862]
dc.subject.ddc.spa.fl_str_mv	660 - Ingeniería química 620 - Ingeniería y operaciones afines::622 - Minería y operaciones relacionadas
topic	660 - Ingeniería química 620 - Ingeniería y operaciones afines::622 - Minería y operaciones relacionadas Asfaltenos Permeabilidad Dinámica de fluidos Industria energética Termodinámica Formación de daños (Ingeniería de petróleos) Simulación por computadores Pozos petroleros Campos petrolíferos Asfaltenos Ecuación de estado Cinética de agregación Daño de formación Simulación numérica Asphaltenes Equation of state Aggregation kinetics Formation damage Numerical simulation
dc.subject.lemb.none.fl_str_mv	Asfaltenos Permeabilidad Dinámica de fluidos Industria energética Termodinámica Formación de daños (Ingeniería de petróleos) Simulación por computadores Pozos petroleros Campos petrolíferos
dc.subject.proposal.spa.fl_str_mv	Asfaltenos Ecuación de estado Cinética de agregación Daño de formación Simulación numérica
dc.subject.proposal.eng.fl_str_mv	Asphaltenes Equation of state Aggregation kinetics Formation damage Numerical simulation
description	Ilustraciones, gráficos
publishDate	2024
dc.date.accessioned.none.fl_str_mv	2024-05-20T16:13:15Z
dc.date.available.none.fl_str_mv	2024-05-20T16:13:15Z
dc.date.issued.none.fl_str_mv	2024-05-20
dc.type.spa.fl_str_mv	Trabajo de grado - Doctorado
dc.type.driver.spa.fl_str_mv	info:eu-repo/semantics/doctoralThesis
dc.type.version.spa.fl_str_mv	info:eu-repo/semantics/acceptedVersion
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dc.type.content.spa.fl_str_mv	Text
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dc.identifier.uri.none.fl_str_mv	https://repositorio.unal.edu.co/handle/unal/86119
dc.identifier.instname.spa.fl_str_mv	Universidad Nacional de Colombia
dc.identifier.reponame.spa.fl_str_mv	Repositorio Institucional Universidad Nacional de Colombia
dc.identifier.repourl.spa.fl_str_mv	https://repositorio.unal.edu.co/
url	https://repositorio.unal.edu.co/handle/unal/86119 https://repositorio.unal.edu.co/
identifier_str_mv	Universidad Nacional de Colombia Repositorio Institucional Universidad Nacional de Colombia
dc.language.iso.spa.fl_str_mv	spa
language	spa
dc.relation.indexed.spa.fl_str_mv	LaReferencia
dc.relation.references.spa.fl_str_mv	Alhammadi, A. A., Vargas, F. M., & Chapman, W. G. (2015). Comparison of cubic-plus-association and perturbed-chain statistical associating fluid theory methods for modeling asphaltene phase behavior and pressure-volume-temperature properties. Energy and Fuels, 29(5), 2864–2875. https://doi.org/10.1021/ef502129p Ali, M. A., & Islam, M. R. (1998). The Effect of Asphaltene Precipitation on Carbonate-Rock Permeability: An Experimental and Numerical Approach. SPE. Al-Noor, N. H., & Assi, N. K. (2020). Rayleigh-Rayleigh Distribution: Properties and Applications. Journal of Physics: Conference Series, 1591(1). https://doi.org/10.1088/1742-6596/1591/1/012038 Arya, A. (2016). Modeling of Asphaltene Systems with Association Models. In Citation. Technical University of Denmark. Arya, A., von Solms, N., & Kontogeorgis, G. M. (2015). Determination of asphaltene onset conditions using the cubic plus association equation of state. Fluid Phase Equilibria, 400, 8–19. https://doi.org/10.1016/j.fluid.2015.04.032 Benesty, J., Chen, J., Huang, Y., & Cohen, israel. (2009). Pearson Correlation Coefficient. In Noise Reduction in Speech Processing . Bikmukhametov, T., & Jäschke, J. (2020). Combining machine learning and process engineering physics towards enhanced accuracy and explainability of data-driven models. Computers and Chemical Engineering, 138. https://doi.org/10.1016/j.compchemeng.2020.106834 Boek, E., Fadili, A., Michael, F., & Williams, J. (2011). Prediction of Asphaltene Deposition in Porous Media by Systematic Upscaling from a Colloidal Pore Scale Model to a Deep Bed Filtration Model. SPE. Boek, E. S., Ladva, H. K., Crawshaw, J. P., & Padding, J. T. (2008). Deposition of colloidal asphaltene in capillary flow: Experiments and mesoscopic simulation. Energy and Fuels, 22(2), 805–813. https://doi.org/10.1021/ef700670f Buenrostro-Gonzalez, E., Lira-Galeana, C., Gil-Villegas, A., & Wu, J. (2004). Asphaltene precipitation in crude oils: Theory and experiments. AIChE Journal, 50(10), 2552–2570. https://doi.org/10.1002/aic.10243 Castellanos Díaz, O., Sánchez-Lemus, M. C., Schoeggl, F. F., Satyro, M. A., Taylor, S. D., & Yarranton, H. W. (2014). Deep-vacuum fractionation of heavy oil and bitumen, part I: Apparatus and standardized procedure. Civan, F. (2006). Reservoir Formation Damage. Civan, F. (2007). FORMATION DAMAGE BY ORGANIC DEPOSITION. In Reservoir Formation Damage. https://doi.org/10.1016/B978-0-7506-7738-7.50015-4 Civan, F. (2016). Modified Formulations of Particle Deposition and Removal Kinetics in Saturated Porous Media. In Transport in Porous Media (Vol. 111, Issue 2, pp. 381–410). Springer Netherlands. https://doi.org/10.1007/s11242-015-0600-z Daigle, H. (2016). Application of critical path analysis for permeability prediction in natural porous media. Advances in Water Resources, 96, 43–54. https://doi.org/10.1016/j.advwatres.2016.06.016 Davudov, D., & Moghanloo, R. G. (2019). A new model for permeability impairment due to asphaltene deposition. Fuel, 235, 239–248. https://doi.org/10.1016/j.fuel.2018.07.079 Eskandari, N. (2020). Asphaltene deposition simulation in porous media during CO 2 injection using Lattice Boltzmann Method. University of Newfoundland Firoozabadi, A. (1999). Thermodynamics of Hydrocarbon Reservoir - Firoozabadi. In McGraw-Hill. Forte, E., & Taylor, S. E. (2015). Thermodynamic modelling of asphaltene precipitation and related phenomena. In Advances in Colloid and Interface Science (Vol. 217, pp. 1–12). Elsevier. https://doi.org/10.1016/j.cis.2014.12.002 Ghanbarian, B., Hunt, A. G., Ewing, R. P., & Skinner, T. E. (2014). Universal scaling of the formation factor in porous media derived by combining percolation and effective medium theories. Geophysical Research Letters, 41(11), 3884–3890. https://doi.org/10.1002/2014GL060180 Gonzalez, D. L., Hirasaki, G. J., Creek, J., & Chapman, W. G. (2007). Modeling of asphaltene precipitation due to changes in composition using the perturbed chain statistical associating fluid theory equation of state. Energy and Fuels, 21(3), 1231–1242. https://doi.org/10.1021/ef060453a Gostick, J., Aghighi, M., Hinebaugh, J., Tranter, T., Hoeh, M. A., Forschungszentrum, \|, Day, J. H., Spellacy, B., Sharqawy, M. H., Burns, A., Lehnert, W., Jülich, F., Aachen, R., & Putz, A. (2016). Section title Software engineering track OpenPNM: A Pore Network Modeling Package. www.scipy.org Gottschalk, M. (2007). Equations of state for complex fluids. Reviews in Mineralogy and Geochemistry, 65, 49–97. https://doi.org/10.2138/rmg.2007.65.3 Gruesbeck, C., & Collins, R. E. (1982). Entrainment and Deposition of Fine Particles in Porous Media. SPE Haji-Akbari, N. (2014). Destabilization and Aggregation Kinetics of Asphaltenes. University of Michigan Huang, S. H., & Radosz, M. (1990). Equation of State for Small, Large, Polydisperse, and Associating Molecules. In 2284 I n d. Eng. Cheni. Res (Vol. 29). Idris, M., & Okoro, L. N. (2013). A review on the effects of asphaltenes on petroleum processing. Chem. Bull, 6, 393–396. https://doi.org/10.17628/ECB.2013.2.393 Jafari Behbahani, T., Ghotbi, C., Taghikhani, V., & Shahrabadi, A. (2013). Asphaltene deposition under dynamic conditions in porous media: Theoretical and experimental investigation. Energy and Fuels, 27(2), 622–639. https://doi.org/10.1021/ef3017255 Jamaluddin, A. K. M. (2002). An Investigation of Asphaltene Instability Under Nitrogen Injection. SPE Journal . Jamaluddin, A., Mcfadden, J., Creek, J., Dcruz, D., Manakalathil, J., Kabir, C., Joshi, N., & Ross, B. (2002a). Laboratory Techniques to Measure Thermodynamic Asphaltene Instability. Jamaluddin, A., Mcfadden, J., Creek, J., Dcruz, D., Manakalathil, J., Kabir, C., Joshi, N., & Ross, B. (2002b). Laboratory Techniques to Measure Thermodynamic Asphaltene Instability. SPE. Jeldres, R. I., Fawell, P. D., & Florio, B. J. (2018). Population balance modelling to describe the particle aggregation process: A review. In Powder Technology (Vol. 326, pp. 190–207). Elsevier B.V. https://doi.org/10.1016/j.powtec.2017.12.033 Jiang, H., & Adidharma, H. (2014). Monte Carlo simulation and equation of state for flexible charged hard-sphere chain fluids: Polyampholyte and polyelectrolyte solutions. Journal of Chemical Physics, 141(17). https://doi.org/10.1063/1.4900985 Kesler M. (1976). Improve Prediction of Enthalpy of Fractions. Hydrocarbon Processing Khelfaoui, F., & Babahani, O. (2019). How to Use the Monte Carlo Simulation Technique? Application: A Study of the Gas Phase during Thin Film Deposition. In Theory, Application, and Implementation of Monte Carlo Method in Science and Technology. Kikuchi, N., Pooley, C. M., Ryder, J. F., & Yeomans, J. M. (2003). Transport coefficients of a mesoscopic fluid dynamics model. Journal of Chemical Physics, 119(12), 6388–6395. https://doi.org/10.1063/1.1603721 Kocabas, I. (2003). Characterization of Asphaltene Precipitation Effect on Reducing Carbonate Rock Permeability. SPE. Kontogeorgis, G. M., Voutsas, E. C., Yakoumis, I. V, & Tassios, D. P. (1996). An Equation of State for Associating Fluids. Kord, S., Miri, R., Ayatollahi, S., & Escrochi, M. (2012). Asphaltene deposition in carbonate rocks: Experimental investigation and numerical simulation. Energy and Fuels, 26(10), 6186–6199. https://doi.org/10.1021/ef300692e Kord, S., Mohammadzadeh, O., Miri, R., & Soulgani, B. S. (2014). Further investigation into the mechanisms of asphaltene deposition and permeability impairment in porous media using a modified analytical model. Fuel, 117(PART A), 259–268. https://doi.org/10.1016/j.fuel.2013.09.038 Lai, C.-D., Murthy, D. N. ;, & Xie, Min. (2006). Weibull Distributions and Their Applications (Springer Handbooks). Leontaritis, K. J. (1998). Asphaltene Near-wellbore Formation Damage Modeling. SPE. Leontaritis, K. J., & Mansoori, G. A. (1988). 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Asphaltenes, Heavy Oils, and Petroleomics Nascimento, F. P., Costa, G. M. N., & Vieira de Melo, S. A. B. (2019). A comparative study of CPA and PC-SAFT equations of state to calculate the asphaltene onset pressure and phase envelope. Fluid Phase Equilibria, 494, 74–92. https://doi.org/10.1016/j.fluid.2019.04.027 Nasrabadi, H., Moortgat, J., & Firoozabadi, A. (2016a). New Three-Phase Multicomponent Compositional Model for Asphaltene Precipitation during CO2 Injection Using CPA-EOS. Energy and Fuels, 30(4), 3306–3319. https://doi.org/10.1021/acs.energyfuels.5b02944 Nasrabadi, H., Moortgat, J., & Firoozabadi, A. (2016b). New Three-Phase Multicomponent Compositional Model for Asphaltene Precipitation during CO2 Injection Using CPA-EOS. Energy and Fuels, 30(4), 3306–3319. https://doi.org/10.1021/acs.energyfuels.5b02944 Nghiem, L. X., Kohse, B. F., Ali, F., & Doan, Q. (2000). Asphaltene Precipitation: Phase Behaviour Modelling and Compositional Simulation. SPE. Nield, D. A., & Bejan, A. (2017). Convection in porous media. In Convection in Porous Media. Springer International Publishing. https://doi.org/10.1007/978-3-319-49562-0 Padding, J. T., & Louis, A. A. (2006). Hydrodynamic interactions and Brownian forces in colloidal suspensions: Coarse-graining over time and length scales. Physical Review E - Statistical, Nonlinear, and Soft Matter Physics, 74(3). https://doi.org/10.1103/PhysRevE.74.031402 Pautz, J. F., & Crocker, M. E. (1989). Relating Water Quality and Formation Permeability to Loss of lnjectivity. SPE. Rahmani, N. H. G., Dabros, T., & Masliyah, J. H. (2004). Evolution of asphaltene floc size distribution in organic solvents under shear. Chemical Engineering Science, 59(3), 685–697. https://doi.org/10.1016/j.ces.2003.10.017 Raoof, A., & Majid Hassanizadeh, S. (2010). A new method for generating pore-network models of porous media. Transport in Porous Media, 81(3), 391–407. https://doi.org/10.1007/s11242-009-9412-3 Seifried, C. M. (2016). 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Journal of Energy Resources Technology, Transactions of the ASME, 127(4), 310–317. https://doi.org/10.1115/1.1924465 Yonebayashi, H., Masuzawa, T., Dabbouk, C., & Urasaki, D. (2009). Reservoir Characterization and Simulation Conference. SPE/EAGE Yonebayashi, H., Miyagawa, Y., Ikarashi, M., Watanabe, T., Maeda, H., & Yazawa, N. (2018). Determination of asphaltene-onset pressure using multiple techniques in parallel. SPE Production and Operations, 33(3), 486–497. https://doi.org/10.2118/181278-PA Zendehboudi, S., Shafiei, A., Bahadori, A., James, L. A., Elkamel, A., & Lohi, A. (2014). Asphaltene precipitation and deposition in oil reservoirs - Technical aspects, experimental and hybrid neural network predictive tools. Chemical Engineering Research and Design, 92(5), 857–875. https://doi.org/10.1016/j.cherd.2013.08.001 Zhang, X. and P. N. and M. T. (2012). Modeling asphaltene phase behavior: comparison of methods for flow assurance studies. Energy & Fuels Zhang, Y., Lin, Q., Raeini, A. 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dc.publisher.spa.fl_str_mv	Universidad Nacional de Colombia
dc.publisher.program.spa.fl_str_mv	Medellín - Minas - Doctorado en Ingeniería - Sistemas Energéticos
dc.publisher.faculty.spa.fl_str_mv	Facultad de Minas
dc.publisher.place.spa.fl_str_mv	Medellín, Colombia
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spelling	Atribución-NoComercial-SinDerivadas 4.0 Internacionalhttp://creativecommons.org/licenses/by-nc-nd/4.0/info:eu-repo/semantics/openAccesshttp://purl.org/coar/access_right/c_abf2Benjumea, Pedro Nel229b0414b1cf72d35d0a101fd2979e53Cundar Paredes, Cristiam David2640c7e15949658b6140f52fdf738879Cundar Paredes, Cristiam David [0000-0002-3409-7862]2024-05-20T16:13:15Z2024-05-20T16:13:15Z2024-05-20https://repositorio.unal.edu.co/handle/unal/86119Universidad Nacional de ColombiaRepositorio Institucional Universidad Nacional de Colombiahttps://repositorio.unal.edu.co/Ilustraciones, gráficosLos asfaltenos se consideran como la fracción más polar del petróleo y su estructura química es desconocida. En general se acepta que los asfaltenos poseen una estructura poli-aromática, incluidos algunos metales, oxígeno, sulfuro y nitrógeno. Este compuesto se define como la fracción de crudo insoluble en alcanos (n-pentano, heptano) y soluble en aromáticos (benceno, tolueno).(Firoozabadi, 1999) A nivel yacimiento, este fenómeno implica una reducción de la transmisibilidad y alteración de la humectabilidad en la roca afectando la productividad de pozos. La desestabilización del componente asfalteno en el fluido de yacimiento se debe a cambios en presión, temperatura, composición y/o solventes o gases externos inyectados en el yacimiento en procesos de recobro mejorado (Firoozabadi, 1999). Los asfaltenos se precipitan y pueden depositarse en el yacimiento cerca a la cara del pozo productor. Lo anterior conlleva a una reducción del flujo de fluidos en el medio poroso a través de la reducción de permeabilidad y alteración de la humectabilidad de la roca. Además, los asfaltenos pueden fluir estables en el medio poroso y desestabilizarse en la línea de producción fondo de pozo superficie, ocasionado obstrucción del flujo por depositación de asfaltenos en las paredes de la tubería de producción; e incluso causando problemas en las líneas de trasporte de crudo en superficie. El modelamiento de la precipitación y depositación de asfaltenos se establece como una herramienta primordial para entender el comportamiento termodinámico del sistema de fluidos presentes en el yacimiento, y permite la predicción de este fenómeno indeseable a diferentes condiciones de presión, temperatura y composición. Dicho modelamiento, a pesar de que ha sido objeto de estudio en las últimas décadas, aún se considera un reto en la industria debido a la naturaleza del asfalteno, el cual es diferente en cada crudo, sus diferentes afinidades asociativas y su estructura (coloidal o macromolecular) desconocida. Por dicha razón, la predicción de la precipitación y posterior depositación hace necesario el entendimiento del modelamiento termodinámico y de flujo de los fluidos presentes en la formación, y las bases de cada modelo con sus limitaciones a la hora de predecir el comportamiento de los asfaltenos en un yacimiento en particular. En el presente proyecto se plantea estudiar el comportamiento de los asfaltenos a condiciones de flujo de fluidos. Para desarrollar este estudio se considera necesario profundizar en 4 ítems: ecuaciones de estado avanzadas, cinéticas de agregación de asfaltenos, diagnóstico del daño de formación y finalmente integración de los fenómenos anteriores en una simulación numérica de yacimientos. (Tomado de la fuente)Asphaltenes are considered the most polar fraction of petroleum and their chemical structure is unknown. It is generally accepted that asphaltenes have a polyaromatic structure, including some metals, oxygen, sulfur, and nitrogen. This compound is defined as the fraction of crude oil that is insoluble in alkanes (n-pentane, heptane) and soluble in aromatics (benzene, toluene). Firoozabadi, 1999) At the reservoir level, this phenomenon implies a reduction in transmissibility and alteration of the rock wettability affecting its productivity. The destabilization of the asphaltene component in the reservoir fluid is due to changes in pressure, temperature, composition and/or solvents or external gases injected into the reservoir in enhanced recovery processes (Firoozabadi, 1999). Asphaltenes precipitate and may be deposited in the reservoir near the face of the producing well. This leads to a reduction in the flow of fluids in the porous medium through the reduction of permeability and alteration of the wettability of the rock. In addition, asphaltenes can flow stable in the porous medium and become destabilized in the production line downhole surface, causing flow obstruction by depositing asphaltenes on the walls of the production tubing; and even causing problems in the crude oil transport lines on the surface. The modeling of the precipitation and deposition of asphaltenes is established as a fundamental tool to understand the thermodynamic behavior of the fluid system present in the reservoir and allows the prediction of this undesirable phenomenon at different conditions of pressure, temperature and composition. Said modeling, despite the fact that it has been the object of study in the last decades, is still considered a challenge in the industry due to the nature of asphaltene, which is different in each crude, its different associative affinities and its structure (colloidal or macromolecular) unknown. For this reason, the prediction of precipitation and subsequent deposition makes it necessary to understand the thermodynamic and flow modeling of the fluids present in the formation, and the bases of each model with its limitations when predicting the behavior of asphaltenes in a particular deposit. In the present project it is proposed to study the behavior of asphaltenes under fluid flow conditions. To develop this study, it is considered necessary to delve into 4 items: advanced equations of state, asphaltene aggregation kinetics, formation damage diagnosis and finally integration of the above phenomena in a numerical simulation of reservoirs.DoctoradoDoctor en IngenieríaHidrocarburosIngeniería Química E Ingeniería De Petróleos.Sede Medellín155 páginasapplication/pdfspaUniversidad Nacional de ColombiaMedellín - Minas - Doctorado en Ingeniería - Sistemas EnergéticosFacultad de MinasMedellín, ColombiaUniversidad Nacional de Colombia - Sede Medellín660 - Ingeniería química620 - Ingeniería y operaciones afines::622 - Minería y operaciones relacionadasAsfaltenosPermeabilidadDinámica de fluidosIndustria energéticaTermodinámicaFormación de daños (Ingeniería de petróleos)Simulación por computadoresPozos petrolerosCampos petrolíferosAsfaltenosEcuación de estadoCinética de agregaciónDaño de formaciónSimulación numéricaAsphaltenesEquation of stateAggregation kineticsFormation damageNumerical simulationModelo integrado del comportamiento de asfaltenos en condiciones de flujoIntegrated model of asphaltene behavior in flow conditionsTrabajo de grado - Doctoradoinfo:eu-repo/semantics/doctoralThesisinfo:eu-repo/semantics/acceptedVersionhttp://purl.org/coar/resource_type/c_db06Texthttp://purl.org/redcol/resource_type/TDLaReferenciaAlhammadi, A. 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Fuel, 316. https://doi.org/10.1016/j.fuel.2022.123202Zidane, A., & Firoozabadi, A. (2022). Higher-order compositional simulation of asphaltene damage and removal in the wellbore by the CPA-EOS. Fuel, 307. https://doi.org/10.1016/j.fuel.2021.121776EstudiantesInvestigadoresMaestrosLICENSElicense.txtlicense.txttext/plain; charset=utf-85879https://repositorio.unal.edu.co/bitstream/unal/86119/1/license.txteb34b1cf90b7e1103fc9dfd26be24b4aMD51ORIGINAL1152186356.2024.pdf1152186356.2024.pdfTesis de Doctorado en Ingeniería - Sistemas Energéticosapplication/pdf5209868https://repositorio.unal.edu.co/bitstream/unal/86119/2/1152186356.2024.pdfc8a59cad667e257108f0e08bfaf391a0MD52THUMBNAIL1152186356.2024.pdf.jpg1152186356.2024.pdf.jpgGenerated Thumbnailimage/jpeg4450https://repositorio.unal.edu.co/bitstream/unal/86119/3/1152186356.2024.pdf.jpg11fde3aff7f00bf34e5fab94a6573d93MD53unal/86119oai:repositorio.unal.edu.co:unal/861192024-05-20 23:04:57.868Repositorio Institucional Universidad Nacional de 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Modelo integrado del comportamiento de asfaltenos en condiciones de flujo

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