Academic literature on the topic 'Asphaltene'
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Journal articles on the topic "Asphaltene"
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Lin, Qunchao, Lei Deng, Ge Dong, et al. "aRDG Analysis of Asphaltene Molecular Viscosity and Molecular Interaction Based on Non-Equilibrium Molecular Dynamics Simulation." Materials 15, no. 24 (2022): 8771. http://dx.doi.org/10.3390/ma15248771.
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Understanding the noncovalent (weak) interactions between asphaltene molecules is crucial to further comprehending the viscosity and aggregation behavior of asphaltenes. In the past, intermolecular interactions were characterized indirectly by calculating the radial distribution function and the numerical distribution of distances/angles between atoms, which are far less intuitive than the average reduced density gradient (aRDG) method. This study selected three representative asphaltene molecules (AsphalteneO, AsphalteneT, and AsphalteneY) to investigate the relationship between viscosity and weak intermolecular interactions. Firstly, a non-equilibrium molecular dynamics (NEMD) simulation was employed to calculate the shear viscosities of these molecules and analyze their aggregation behaviors. In addition, the types of weak intermolecular interactions of asphaltene were visualized by the aRDG method. Finally, the stability of the weak intermolecular interactions was analyzed by the thermal fluctuation index (TFI). The results indicate that AsphalteneY has the highest viscosity. The aggregation behavior of AsphalteneO is mainly face–face stacking, while AsphalteneT and AsphalteneY associate mainly via offset stacking and T-shaped stacking. According to the aRDG analysis, the weak interactions between AshalteneT molecules are similar to those between AshalteneO molecules, mainly due to van der Waals interactions and steric hindrance effects. At the same time, there is a strong attraction between AsphalteneY molecules. Additionally, the results of the TFI analysis show that the weak intermolecular interactions of the three types of asphaltene molecules are relatively stable and not significantly affected by thermal motion. Our results provide a new method for better understanding asphaltene molecules’ viscosity and aggregation behavior.
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Johnston, Robert J., and Thomas G. Mason. "Asphaltene Aggregation Kinetics in Crude Oil Using Confocal Microscopy." Microscopy and Microanalysis 7, S2 (2001): 542–43. http://dx.doi.org/10.1017/s1431927600028786.
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Confocal laser scanning microscopy (CLSM) has been used to study asphaltene aggregation kinetics by employing the microscope's automated acquisition to generate time-lapsed projection maps of aggregating asphaltenes in the autofluorescent matrix of crude oil. Heavy crude oils contain asphaltene particles resulting in the production of optically observable micron-sized asphaltene aggregates. These aggregates form as a result of attractive interactions induced by mixing the heavy crude oil with a poor solvent. This technique has been employed to determine the volume fraction of aggregated asphaltenes, ϕagg, and the time evolution of this phenomenon. The measurements cover a range of various concentrations of asphaltene volume fractions of the heavy asphaltenic oil, ϕm, from ϕm =0.001 to ϕm =0.4.At each ϕm,after the mixtures have been made, approximately 20 μl of the crude oil is placed in a 20 μm deep flat-well quartz cell and immediately placed on a microscope stage.
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Johnston, Robert J., and Thomas G. Mason. "Asphaltene Aggregation Studies of Crude Oil Using 3-D Confocal Microscopy." Microscopy and Microanalysis 6, S2 (2000): 22–23. http://dx.doi.org/10.1017/s1431927600032608.
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Confocal laser scanning microscopy (CLSM) has been used to generate three dimensional projection maps of less fluorescent domains caused by asphaltene aggregates in the autofluorescent matrix of crude oil. Heavy crude oils contain asphaltene particles resulting in the production of optically observable micron sized asphaltene aggregates. This technique has been employed to determine the volume fraction of aggregated asphaltenes, øagg, and the time evolution of this phenomenon. The measurements cover a range of various concentrations of asphaltene volume fractions of the heavy asphaltenic oil, øm, from øm = 0 to øm = 0.6.Examining crude oils for asphaltenes aggregates using CLSM presents a challenge due to the strong absorption of the oils. This is because some molecules of the crude oil fluoresce when excited by optical laser light used as a source in the CLSM. Other molecules of the crude oils absorb light at similar wavelengths.
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Leontaritis, Kosta J. "Asphaltene Near-well-bore Formation Damage Modeling." Journal of Energy Resources Technology 127, no. 3 (2005): 191–200. http://dx.doi.org/10.1115/1.1937416.
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When during oil production the thermodynamic conditions within the near-well-bore formation lie inside the asphaltene deposition envelope of the reservoir fluid, the flocculated asphaltenes cause formation damage. Mathematically, formation damage is a reduction in the hydrocarbon effective mobility, λ, λ=ko∕μo=kkro∕μo. Three possible mechanisms of asphaltene-induced formation damage have been discussed in the literature. Asphaltenes can reduce the hydrocarbon effective mobility by a) blocking pore throats thus reducing the rock permeability, k, b) adsorbing onto the rock and altering the formation wettability from water-wet to oil-wet thus diminishing the effective permeability to oil, ko, and c) increasing the reservoir fluid viscosity, μo, by nucleating water-in-oil emulsions. In the most frequently encountered case of asphaltene-induced formation damage where under-saturated oil is being produced without water, the most dominant damage mechanism is blockage of pore throats by asphaltene particles causing a reduction in rock permeability k. This paper presents a rather simple, yet realistic way of modeling asphaltene-induced near-well formation damage caused by blockage of pore throats by asphaltene particles. The model utilizes both macroscopic and microscopic concepts to represent the pore throat blockages. It also utilizes the Thermodynamic-Colloidal Model of Asphaltene, TCModelSM, an existing AsphWax asphaltene phase behavior model capable of simulating the asphaltene particle size distribution as a function of the thermodynamics of the system. The new asphaltene near-well formation damage model is applied in one case where it is used to track the degree of formation damage as a function of time and the effect it has on near-well-bore and well-bore hydraulics. Similarly the model can be used to study a priori the economics of developing a reservoir known to contain under-saturated asphaltenic oil.
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Mullins, Oliver C. "Review of the Molecular Structure and Aggregation of Asphaltenes and Petroleomics." SPE Journal 13, no. 01 (2008): 48–57. http://dx.doi.org/10.2118/95801-pa.
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Summary Tremendous strides have been made recently in asphaltene science. Many advanced analytical techniques have been applied recently to asphaltenes, elucidating many asphaltene properties. The inability of certain techniques to provide correct asphaltene parameters has also been clarified. Longstanding controversies have been resolved. For example, molecular structural issues of asphaltenes have been resolved; in particular, asphaltene molecular weight is now known. The primary aggregation threshold has recently been established by a variety of techniques. Characterization of asphaltene interfacial activity has advanced considerably. The hierarchy of asphaltene aggregation has emerged into a fairly comprehensive picture, essentially in accord with the Yen model with the additional inclusion of certain constraints. Crude oil and asphaltene science is now poised to develop proper structure-function relations that are the defining objective of the new field: petroleomics. The purpose of this paper is to review these developments in order to present a more clear and accessible picture of asphaltenes, especially considering that the asphaltene literature is a bit opaque. Introduction The asphaltenes are a very important class of compounds in crude oils (Chilingarian and Yen 1978; Bunger and Li 1981; Sheu and Mullins 1995; Mullins and Sheu 1998; Mullins et al. 2007c). The asphaltenes represent a complex mixture of compounds and are defined by their solubility characteristics, not by a specific chemical classification. A common (laboratory) definition of asphaltenes is that they are toluene soluble, n-heptane insoluble. Other light alkanes are sometimes used to isolate asphaltenes. This solubility classification is very useful for crude oils because it captures the most aromatic portion of crude oil. As we will see, this solubility defintion also captures those molecular components of asphaltene that aggregate. Other carbonaceous materials such as coal do possess an asphaltene fraction, but that often will not correspond to the most aromatic fraction. Petroleum asphaltenes, the subject of this paper, can undergo phase transitions that are an impediment in the production of crude oil. Fig. 1 shows a picture of an asphaltene deposit in a pipeline; obviously, asphaltene deposition is detrimental to the production of oil. Immediately it becomes evident that different operational definitions apply for the term asphaltene in the field vs. the lab. Indeed, the field deposit is very enriched in n-heptane-insoluble, toluene-soluble materials, but this field asphaltene deposit is not identically the standard laboratory solubility class. It is common knowledge that a pressure drop on certain live crude oils (containing dissolved gas) can cause asphaltene flocculation, the first step in creating deposits that are seen in Fig. 1. Highly compressible, very undersaturated crude oils are most susceptible to asphaltene deposition problems with a pressure drop (de Boer et al. 1995). In depressurization flocculation, the character of the asphaltene flocs is dependent on the extent of pressure drop, suggesting some variations in the corresponding chemical composition (Hammami et al. 2000; Joshi et al. 2001). Comingling different oils can result in asphaltene precipitation that can resemble solvent precipitation. Asphaltenes are hydrogen-deficient compared to alkanes; thus, either hydrogen must be added or coke removed in crude oil refining to generate transportation fuels. Thus, asphaltene content lowers the economic value of crude oil. Increasing asphaltene content is associated with dramatically increasing viscosity, especially at room temperature; again, this is of operational concern. The strong temperature dependence of viscosity of asphaltic materials is one of their important properties that make them useful for paving and coating; application of asphaltic materials is facile at moderately high temperatures, while desired rheological properties are obtained at ambient temperatures.
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Sultanov, F. R., Ye Tileuberdi, Ye K. Ongarbayev, et al. "Study of Asphaltene Structure Precipitated from Oil Sands." Eurasian Chemico-Technological Journal 15, no. 1 (2012): 77. http://dx.doi.org/10.18321/ectj143.
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<p>In the paper microscopic structure and physicochemical characteristics of asphaltenes were investigated. Asphaltene was precipitated from natural bitumen of oil sand of Munaily-Mola deposit using organic solvent of petroleum ether. According to results of our work, we found that the largest yield of asphaltens was reached by using the petroleum ether in 40-fold amount in relation to the initial hitch of bitumen. Chemical composition of precipitated asphaltenes aggregates were studied on FT-Infra red spectrometer Spectrum-65 at 450-4000 cm<sup>-1</sup>. At the Infrared spectrum, that the broad absorption band of asphaltenes at 3000-3600 cm-1 are characterizing the presence of polycyclic aromatic hydrocarbons and aliphatic chains in the samples of asphaltens. Elemental composition of the samples of asphaltenes on the installation of X-ray fluorescent spectrometer "Focus-M2". Also found the presence of two crystalline phases. One - quartz content is less than one percent. Another phase is also present in very small quantities and is represented by a single line of diffraction d = 4.158 Å. The microstructures and microanalysis of asphaltenes were investigated with an scanning electron microscopy (Quanta 3D 200i) at an accelerated voltage of 20 kV and a pressure of 0.003 Pa at National Nanotechnological Laboratory of Open Type of Kazakh National University. Microscopic images showed that the asphaltenes have a medium-ordered structure, the main component of the surface is<br /> represented by amorphous carbon.</p>
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Korneev, Dmitry S. "Structural-group composition and colloidal stability of synthetic asphalten-like nitrogen bases." Bulletin of the Tomsk Polytechnic University Geo Assets Engineering 336, no. 2 (2025): 116–25. https://doi.org/10.18799/24131830/2025/2/4660.
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Relevance. The need to establish the selective impact of individual structural parameters and heteroatomic functional groups in the structure of asphaltene molecules on their aggregation in order to develop effective ways to prevent sedimentation in technological equipment at the stages of production, transport and processing of heavy hydrocarbon raw materials. Aim. To establish the impact of the structural group composition, the concentration of basic nitrogen in asphaltene substances on their colloidal stability. Objects. Heavy oil of the Republic of Tatarstan (density at 20°C – 940,0 kg/m3; viscosity at 20°C – 742,9 cSt), model oil systems with a basic nitrogen content of 1, 2, 3 wt %, asphaltenes initial and model petroleum systems and their thermolysis products. Methods. Liquid adsorption chromatography, potentiometric titration, elemental analysis, cryoscopy in naphthalene, 1H NMR spectroscopy, structural group analysis, spectrophotometry. Results. Synthetic asphaltene-like nitrogenous bases were obtained by thermolysis of model petroleum systems with different contents of basic nitrogen (quinoline) at 400°C for 4 hours. During thermolysis, 0.3–0.8 wt % of basic nitrogen is additionally incorporated into the molecular structure of synthetic asphaltene-like substances. The molecular weight of synthetic asphaltene-like substances is two times lower than that of the asphaltenes of the initial oil. With an increase in basic nitrogen in synthetic asphaltene-like substances, the aromaticity factor increases by 2–3% with a decrease in the proportion of paraffin carbon. It was established that asphaltenes from thermally converted oil are two times more resistant to sedimentation compared to the initial asphaltenes, due to a twofold decrease in their average molecular weight. It was shown that the sedimentation rate of synthetic asphaltene-like nitrogenous bases is two–three times lower compared to the initial asphaltenes. It was established that the colloidal stability of synthetic asphaltene-like substances increases with the growth in Nbas content in their molecular structure.
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Lindt, Kevin, Bulat Gizatullin, Carlos Mattea, and Siegfried Stapf. "Non-Exponential 1H and 2H NMR Relaxation and Self-Diffusion in Asphaltene-Maltene Solutions." Molecules 26, no. 17 (2021): 5218. http://dx.doi.org/10.3390/molecules26175218.
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The distribution of NMR relaxation times and diffusion coefficients in crude oils results from the vast number of different chemical species. In addition, the presence of asphaltenes provides different relaxation environments for the maltenes, generated by steric hindrance in the asphaltene aggregates and possibly by the spatial distribution of radicals. Since the dynamics of the maltenes is further modified by the interactions between maltenes and asphaltenes, these interactions—either through steric hindrances or promoted by aromatic-aromatic interactions—are of particular interest. Here, we aim at investigating the interaction between individual protonic and deuterated maltene species of different molecular size and aromaticity and the asphaltene macroaggregates by comparing the maltenes’ NMR relaxation (T1 and T2) and translational diffusion (D) properties in the absence and presence of the asphaltene in model solutions. The ratio of the average transverse and longitudinal relaxation rates, describing the non-exponential relaxation of the maltenes in the presence of the asphaltene, and its variation with respect to the asphaltene-free solutions are discussed. The relaxation experiments reveal an apparent slowing down of the maltenes’ dynamics in the presence of asphaltenes, which differs between the individual maltenes. While for single-chained alkylbenzenes, a plateau of the relaxation rate ratio was found for long aliphatic chains, no impact of the maltenes’ aromaticity on the maltene–asphaltene interaction was unambiguously found. In contrast, the reduced diffusion coefficients of the maltenes in presence of the asphaltenes differ little and are attributed to the overall increased viscosity.
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Ismail, Ali I., Ayman M. Atta, Mohamed El-Newehy, and Mohamed E. El-Hefnawy. "Synthesis and Application of New Amphiphilic Asphaltene Ionic Liquid Polymers to Demulsify Arabic Heavy Petroleum Crude Oil Emulsions." Polymers 12, no. 6 (2020): 1273. http://dx.doi.org/10.3390/polym12061273.
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Asphaltenes are heavy petroleum crude oil components which limit the production of petroleum crude oil due to their aggregation and their stabilization for all petroleum crude oil water emulsions. The present study aimed to modify the chemical structures of isolated asphaltenes by converting them into amphiphilic polymers containing ionic liquid moieties (PILs) to demulsify the emulsion and replace the asphaltene layers surrounding the oil or water droplets in petroleum crude oil emulsions. The literature survey indicated that no modification occurred to produce the PILs from the asphaltenes. In this respect, the asphaltenes were modified via oxidation of the lower aliphatic chain through carboxylation followed by conversion to asphaltene acid chloride that reacted with ethoxylated N-alkyl pyridinium derivatives. Moreover, the carboxylation of asphaltenes was carried out through the Diels–Alder reaction with maleic anhydride that was linked with ethoxylated N-alkyl pyridinium derivatives to produce amphiphilic asphaltene PILs. The produced PILs from asphaltenes acid chloride and maleic anhydride were designated as AIL and AIL-2. The chemical structure and thermal stability of the polymeric asphaltene ionic liquids were evaluated. The modified structure of asphaltenes AIL and AIL-2 exhibited different thermal characteristics involving glass transition temperatures (Tg) at −68 °C and −45 °C, respectively. The new asphaltenes ionic liquids were adsorbed at the asphaltenes surfaces to demulsify the heavy petroleum crude emulsions. The demulsification data indicated that the mixing of AIL and AIL-2 100 at different ratios with ethoxylated N-alkyl pyridinium were demulsified with 100% of the water from different compositions of O:W emulsions 50:50, 90:10, and 10:90. The demulsification times for the 50:50, 90:10, and 10:90 O:W emulsions were 120, 120, and 60 min, respectively. The interaction of the PILs with asphaltene and mechanism of demulsification was also investigated.
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Carpenter, Chris. "Data Science Enables Management of Stealth Asphaltene Flow-Assurance Risk." Journal of Petroleum Technology 76, no. 11 (2024): 115–17. http://dx.doi.org/10.2118/1124-0115-jpt.
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_ This article, written by JPT Technology Editor Chris Carpenter, contains highlights of paper SPE 216216, “Managing Stealth Asphaltene Flow-Assurance Potential Risk in Gas-Injection Field Based on Data Science Using Over 20-Year Accumulated Data Set,” by Hideharu Yonebayashi, SPE, and Takeshi Hiraiwa, SPE, Japan Oil Development, and Khuloud T. Al Khlaifi, SPE, ADNOC, et al. The paper has not been peer reviewed. _ Gas injection is recognized generally not only to improve oil recovery but also to increase the risk of asphaltene destabilization. The recent discovery of asphaltene deposits in a subject field motivated the operator to launch an immediate investigation to evaluate what critical risks might exist and consider appropriate mitigation. It was found that precipitated but invisible asphaltenes still can be flowable. This stealth asphaltene behavior could explain a possible mechanism of the first asphaltene observation in the upper reservoir. Introduction The subject giant offshore field in the Arabian Gulf has not experienced asphaltene-induced production deterioration during long-term lean hydrocarbon gas injection. The gas has been injected into the crestal area of two reservoirs (upper and lower) with peripheral powered seawater injection. Both reservoir fluids contain a small amount of asphaltenes (0.1–1.5 wt%) distributed at higher concentration at deeper locations. In May 2022, the first discovery of asphaltene deposits from the historical no-issued area in the upper reservoir motivated an immediate investigation for risk assessment and mitigation. A resulting study captured stealth asphaltenes, which were detected by a laser-light-scattering technique while high-pressure microscopy detected no visible asphaltene solid particles. Historical Asphaltene Data Accumulation The permeability range and pore-throat size of the subject field are relatively low in the lower reservoir compared with the upper. Both reservoirs are under highly unstable asphaltene-stability conditions. The reservoir pressure-maintenance scheme, consisting of dump-floodwater injection followed by peripheral powered seawater injection and crestal gas injection, however, has maintained asphaltene-free production except for the gas-injection pilot (GIP) during 2005–2009. No asphaltenes have been observed in the crestal gas-injection area; however, asphaltene deposits were observed in the GIP area in 2007. The injected gas was enriched gradually by a vaporizing gas-drive process. The previous studies involving numerical modeling analysis and laboratory experiments reported that enriched hydrocarbon gas can more easily allow asphaltene precipitation compared with lean hydrocarbon gas. GIP Asphaltene Risk Analysis (Upper Reservoir). In 2009, an asphaltene flow-assurance risk evaluation was conducted using the single-phase bottomhole sample collected from Well 6, which is 90 ft shallower that the GIP area and far from the crestal gas-injection area. Therefore, the Well 6 reservoir fluid was not affected by injection gas. The bottomhole condition of the GIP production well was entered into the asphaltene precipitation envelope (APE) that was expanded by injection-gas enrichment but never covered by the APE without an enrichment process. Latest Laboratory Analysis (Lower Reservoir). In 2022, an asphaltene flow-assurance risk evaluation was conducted. After the location was narrowed to a depth range, Well 1 was selected by taking an asphaltene gradient into account.
Dissertations / Theses on the topic "Asphaltene"
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Yarranton, Harvey William. "Asphaltene solubility and asphaltene-stabilized water-in-oil emulsions." Thesis, National Library of Canada = Bibliothèque nationale du Canada, 1997. http://www.collectionscanada.ca/obj/s4/f2/dsk3/ftp04/nq23096.pdf.
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Agrawala, Mayur. "Measurement and modeling of asphaltene association." Thesis, National Library of Canada = Bibliothèque nationale du Canada, 2001. http://www.collectionscanada.ca/obj/s4/f2/dsk3/ftp05/mq64992.pdf.
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Ashoori, Siavash. "Mechanisms of Asphaltene deposition in porous media." Thesis, University of Surrey, 2005. http://epubs.surrey.ac.uk/2901/.
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Alkafeef, Saad Feheid. "A study of colloidal asphaltene in petroleum reservoirs." Thesis, Imperial College London, 1997. http://hdl.handle.net/10044/1/11246.
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Ibrahim, Muhammad Nasir. "An Investigation Into Asphaltene Behaviour In The Marrat Reservoir." Thesis, Imperial College London, 2009. http://ethos.bl.uk/OrderDetails.do?uin=uk.bl.ethos.502917.
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Hammond, Christian B. "Real Time Investigations of Aggregation of Sulfur-Rich Asphaltene." Ohio University / OhioLINK, 2020. http://rave.ohiolink.edu/etdc/view?acc_num=ohiou1587405713284981.
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Fossen, Martin. "Aggregation, interfacial properties and structural characteristics of asphaltene solubility fractions." Doctoral thesis, Norwegian University of Science and Technology, Department of Chemical Engineering, 2007. http://urn.kb.se/resolve?urn=urn:nbn:no:ntnu:diva-1722.
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<p>Crude oil is the primary source for energy in the world and serves as the raw material for many daily products. Two topics, important in the daily processing of crude oils, are treated in this thesis. Water-in-oil emulsions must be broken to obtain the desired quality of the crude oil delivered to the refineries with respect to water and salt content and asphaltenes are of concern at all stages of the recovery, transportation and processing of crude oils. The work has been of experimental nature and the results are reported in journal papers and manuscripts.</p><p>A lab-scale continuous separation rig was constructed and later equipped with a compact electro coalescer. The results show that water cut and pressure drop affect the droplet size distribution of water-in-oil emulsions. Moreover, two demulsifiers were tested on crude oil emulsions under high electric fields. The study indicated that it is not trivial which type of demulsifier to choose when an electric field is applied in combination with chemical destabilization.</p><p>Hansen solubility parameters for solvents and binary mixtures were correlated to infrared and near infrared spectra by partial least squares regression. Regression coefficients and errors of validation indicated that the regressions and predictions were good. The models were used to predict solubility parameters for crude oils and SARA fractions and the values obtained were in range of what has been reported in the literature.</p><p>Asphaltenes were separated into several solubility fractions directly from the crude oil by stepwise addition and precipitation by n-pentane. The solubility fractions had very different properties with regard to aggregation onset and interfacial activity which to a certain degree were explained by the differences found in the average size and molecular structures of the fractions. It was shown that the less soluble fractions consisted of molecules with larger average molecular weight, higher aromaticity and more polar aromatic cores. For the more soluble fractions results indicated that the substituted alkyl side chains on the aromatic cores were more branched and contained more of the hydroxylic and carboxylic groups, which again could explain the higher interfacial activity. Experiments also suggested that neither the least nor the most soluble of the asphaltenes under investigation were the ones with the highest interfacial activity, but a middle fraction. The findings suggest the need for looking into solubility fractions of asphaltene in further research and compare with the asphaltenes found in deposits or obtained from pressure drop experiments.</p>
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Nghiem, Long X. "Phase behaviour modelling and compositional simulation of asphaltene deposition in reservoirs." Thesis, National Library of Canada = Bibliothèque nationale du Canada, 1999. http://www.collectionscanada.ca/obj/s4/f2/dsk1/tape8/PQDD_0016/NQ46895.pdf.
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Guzman, Vegas Karina. "Factores moleculares y coloidales de los asfaltenos : su estudio mediante parametros de solubilidad, captura de porfirinas matalicas y punto de fusion." Thesis, Lyon 1, 2014. http://www.theses.fr/2014LYO10190/document.
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Le colloïde asphalténique est une espèce multifonctionnelle composée de quatre types de sous‐fractions : deux fractions dénommées « A1 » et « A2 », les résines et les composés piégés (CP). La composition du colloïde détermine sa solubilité donc son paramètre de solubilité. Si on enlève une des sous fractions, le paramètre de solubilité change ainsi que la solubilité de la particule résultante. Le colloïde peut être considéré comme une solution avec valeurs de RED (différence d'énergie relative, selon l'acronyme en anglais) inférieures à 1 entre tous les composants séparés et avec un paramètre de solubilité global égale à la résultante des paramètres de solubilité des quatre composantes. Nous pouvons distinguer trois types d'interactions principales qui donnent lieu à la formation de ces colloïdes : les forces de dispersion, les interactions polaires et la formation de ponts hydrogène. Ces interactions conduisent à des énergies libres de formation très élevées en valeur absolue, ce qui limite significativement leur capacité de dissociation sous l'effet de la température ou de la polarité du dispersant. Même à des températures très élevées, la formation d'agrégats en milieu dispersant polaire ou non polaire est observée. Les composés piégés (CP) sont des espèces solubles dans l'heptane. Ils sont différents des asphaltènes et des résines. Ils restent piégés dans la structure du colloïde. Les CP sont constitués par plusieurs types de composés qui ont la capacité de s'associer aux asphaltènes par des forces dispersives ou des interactions polaires faibles. Parmi ces composés, nous pouvons nommer les pétroporphyrines métalliques (PPM) de vanadium et de nickel. Ces structures restent masquées dans la matrice moléculaire de l'agrégat asphalténique. Sa libération dépend de la dissociation totale ou partielle du colloïde, laquelle est fortement limitée par la constante d'agrégation très élevée. En outre, les CP établissent des liaisons dans la périphérie du colloïde qui sont relativement faibles par rapport à celles existantes entre les asphaltènes. Quand sous l'effet de la température ou d'autres changements physico‐chimiques, les CP sont enlevés de la périphérie du colloïde, l'association entre eux est favorisée, ce qui donne lieu à la formation de conglomérats. La diminution du paramètre de solubilité et du point de fusion des asphaltènes sont les effets primordiaux des résines associées au colloïde asphalténique ; tous les deux contribuent à l'augmentation de la solubilité des asphaltènes dans le pétrole brut, car la pénétration de ce dernier dans la périphérie colloïdale est favorisée. Pour la détermination du paramètre de solubilité (PS), nous avons utilisé via le logiciel sphère l'équation développée par Hansen en utilisant 61 dispersants différents. A partir des études de solubilité, nous avons obtenu les composantes correspondantes aux interactions moléculaires de dispersion (δD), polaires (δP) et ponts hydrogène (δH) exprimées en Mpa ½. Les résultats sont en accord avec toutes les propriétés de solubilité connues des asphaltènes et ont confirmé la solubilité plus faible de la sousfraction A1 par rapport à la fraction A2, avec tous les solvants employés. A partir de cette méthode, nous avons pu également confirmer la forte affinité qui existe entre les asphaltènes et les sous‐fractions A1 et A2 avec les porphyrines métalliques. La valeur plus élevée de la composante correspondant aux ponts hydrogène obtenue pour la fraction A1 suggère la capacité plus forte de celle‐ci pour former ce type de liaisons. Les échantillons (AsfB, A1 et A2) ont été analysés en employant une technique de chromatographie par perméation de gel couplée à un spectromètre de masse à plasma à couplage inductif (GPC‐ICP‐MS). L'objectif de cette étude était d'identifier les mécanismes de capture des PPM par les asphaltènes par comparaison de profils chromatographiques [etc...]<br>El coloide asfalténico es un cuerpo multifuncional constituido por cuatro clases de subfracciones conocidas como A1, A2, resinas y compuestos atrapados (CA). La composición del cuerpo o partícula coloidal determina su solubilidad o parámetro de solubilidad, de tal forma, que la remoción de cualquiera de sus componentes cambia dicho parámetro y por ende la solubilidad del resto. El coloide, es así una disolución con valores de RED (Diferencia de Energía Relativa, por sus siglas en inglés) inferiores a 1 entre todos sus componentes por separado y con un parámetro de solubilidad global igual a la resultante de los parámetros de solubilidad de cada componente. Pueden distinguirse tres tipos de interacciones principales, que dan lugar a la formación del agregado las cuales son, dispersión, polar y puente de hidrógeno. Estas interacciones actúan en conjunto proporcionando energías libres de formación muy altas en valor absoluto, lo cual limita significativamente su capacidad de disociación por medios tales como temperatura y polaridad del disolvente; formando de esta manera, agregados en disolventes polares y no polares, incluso a temperaturas muy altas. Los CA son compuestos solubles en heptano, que sin ser asfaltenos o resinas quedan atrapados dentro del coloide, ellos están constituidos por muchas clases de compuestos con capacidad para asociarse a los asfaltenos de varias maneras, como enlaces de dispersión y de baja polaridad. Entre muchos otros compuestos, las petroporfirinas metálicas (PPM) de vanadilo y níquel forman parte de estos CA, ellas quedan ocluidas en el entramado molecular del agregado asfalténico. Su liberación depende de la disociación total o parcial del coloide la cual es obstaculizada por la alta constante de agregación. Además de su captura “mecánica” en el laberinto molecular del coloide, los CA se asocian en la periferia coloidal mediante enlaces relativamente débiles en comparación con aquellos que existen entre asfaltenos. Cuando por efecto de la temperatura u otro cambio fisicoquímico, los CA son removidos de la periferia del coloide, se promueve la asociación entre ellos dando lugar a conglomerados. La reducción tanto del parámetro de solubilidad, como del punto de fusión de los asfaltenos son los efectos primordiales de las resinas asociadas al coloide asfáltico; ambos contribuyen a incrementar su solubilidad en el crudo, pues facilitan la penetración del medio en la periferia coloidal. Para la determinación del parámetro de solubilidad (PS) se aplicó el método Sphere desarrollado por Hansen, empleando 61 disolventes distintos, a partir de los cuales se obtuvieron las componentes correspondientes a las interacciones moleculares de dispersión (δD), polares (δP) y las de puente de hidrógeno (δH) en Mpa ½. El método fue consistente con todas las propiedades de solubilidad conocidas del asfalteno y confirmó la menor solubilidad de la subfracción A1 con respecto a la subfracción A2, en todos los solventes ensayados. Mediante el método también se predijo la gran afinidad que existe entre los asfaltenos, las subfracciones A1 y A2 con las porfirinas metálicas. El mayor valor obtenido para A1 en la componente de puente de hidrógeno, hace presumir la mayor capacidad que posee esta fracción en formar enlaces tipo puente de hidrógeno [etc...]
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Garcia-Rodriguez, Francisco. "Asphaltene content effect on the combustion of Mexican heavy fuel oil droplets." Thesis, University of Salford, 1997. http://ethos.bl.uk/OrderDetails.do?uin=uk.bl.ethos.244869.
Full textBooks on the topic "Asphaltene"
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A, Duncan Jeremy, ed. Asphaltenes: Characterization, properties, and applications. Nova Science Publishers, 2009.
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K, Sharma Mahendra, Yen Teh Fu 1927-, Fine Particle Society Meeting, and International Symposium on Asphaltene Particles in Fossil Fuel Exploration, Recovery, Refining, and Production Processes (1992 : Las Vegas, Nev.), eds. Asphaltene particles in fossil fuel exploration, recovery, refining, and production processes. Plenum Press, 1994.
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Sharma, Mahendra K., and Teh Fu Yen, eds. Asphaltene Particles in Fossil Fuel Exploration, Recovery, Refining, and Production Processes. Springer US, 1994. http://dx.doi.org/10.1007/978-1-4615-2456-4.
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J, Glover Charles, Texas. State Dept. of Highways and Public Transportation., and United States. Federal Highway Administration., eds. Characterization of asphalts using gel permeation chromatography and other methods. Texas Transportation Institute, Texas A&M University, 1987.
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Paczuski, Maciej. Fizykochemia dyspersji naftowych w optymalizacji technologii rafineryjnej. Oficyna Wydawnicza Politechniki Warszawskiej, 2008.
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Sheu, Eric Y., and Oliver C. Mullins, eds. Asphaltenes. Springer US, 1995. http://dx.doi.org/10.1007/978-1-4757-9293-5.
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1927-, Yen Teh Fu, and Chilingar George V. 1929-, eds. Asphaltenes and asphalts. Elsevier Science, 1994.
Find full textBook chapters on the topic "Asphaltene"
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Gudmundsson, Jon Steinar. "Asphaltene." In Flow Assurance Solids in Oil and Gas Production. CRC Press, 2017. http://dx.doi.org/10.1201/9781315185118-3.
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Speight, James G. "Asphaltene Constituents in Feedstocks." In Refinery Feedstocks. CRC Press, 2020. http://dx.doi.org/10.1201/9780429398285-5.
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Moir, Michael E. "The Quantum Mechanics of Asphaltene Aggregation." In ACS Symposium Series. American Chemical Society, 2019. http://dx.doi.org/10.1021/bk-2019-1320.ch005.
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Ru, Teoh Wan, and Ali F. Alta’ee. "Investigation of Asphaltene Onset Pressure (AOP) in Low Asphaltenic Light Oil Samples." In ICIPEG 2014. Springer Singapore, 2015. http://dx.doi.org/10.1007/978-981-287-368-2_3.
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Sjöblom, Johan, Øystein Sæther, Øivind Midttun, Marit-Helen Ese, Olav Urdahl, and Harald Førdedal. "Asphaltene and Resin Stabilized Crude Oil Emulsions." In Structures and Dynamics of Asphaltenes. Springer US, 1998. http://dx.doi.org/10.1007/978-1-4899-1615-0_11.
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Lin, Jiunn-Ren, Hsienjen Lian, Kazem M. Sadeghi, and Teh Fu Yen. "Asphaltene Particle Size Distribution Studies by Fractals." In Particle Technology and Surface Phenomena in Minerals and Petroleum. Springer US, 1991. http://dx.doi.org/10.1007/978-1-4899-0617-5_3.
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Kawanaka, S., K. J. Leontaritis, S. J. Park, and G. A. Mansoori. "Thermodynamic and Colloidal Models of Asphaltene Flocculation." In ACS Symposium Series. American Chemical Society, 1989. http://dx.doi.org/10.1021/bk-1989-0396.ch024.
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Chakma, A. "Asphaltene Conversion During Coal-Bitumen Co-Processing." In Asphaltene Particles in Fossil Fuel Exploration, Recovery, Refining, and Production Processes. Springer US, 1994. http://dx.doi.org/10.1007/978-1-4615-2456-4_4.
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Lian, H. J., and T. F. Yen. "Classification Of Asphalt Types By Asphaltene Aromaticity." In Asphaltene Particles in Fossil Fuel Exploration, Recovery, Refining, and Production Processes. Springer US, 1994. http://dx.doi.org/10.1007/978-1-4615-2456-4_5.
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Chen, Zhentao, Linzhou Zhang, Suoqi Zhao, Quan Shi, and Chunming Xu. "Molecular Structure and Association Behavior of Petroleum Asphaltene." In Structure and Modeling of Complex Petroleum Mixtures. Springer International Publishing, 2015. http://dx.doi.org/10.1007/430_2015_181.
Full textConference papers on the topic "Asphaltene"
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Morales, J. L., J. J. Perdomo, M. Ramirez, and A. Viloria. "Effect of Crude Oil Contaminants on the Internal Corrosion in Gas Pipelines." In CORROSION 2000. NACE International, 2000. https://doi.org/10.5006/c2000-00040.
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Abstract Some crude oils from eastern Venezuela, contain large amounts of high molecular weight components such as asphaltenes and waxes. Due to both the foaming characteristics of the crude oil and sluggish efficiency of the oil/gas separation process at the flow stations, both hydrocarbon contaminants asphaltene and wax are carried over to the gas gathering and transmission lines. These contaminants may deposit onto the inner wall of the pipelines producing some operational problems such as a decrease on the transmission capacity of the system and an increase of the cleaning frequency of gas pipelines. On the other hand, asphaltene and wax deposits may create a non-uniform barrier between the wall metal surface and the corrosive agents, interacting with corrosion inhibitors and reducing the corrosion rates. The scope of this paper is to describe the potential benefits of asphalthene and wax deposition as corrosion inhibitors in gas pipelines, as well to present the experimental set up and some preliminary results from an ongoing research project. Test conducted with a rotating cylinder electrode in gas sweetening conditions (temperature: 42 °C, PpCO2: saturated) and flow velocities up to 8 m/s showed a reduction of 50% on the corrosion rate of API-5LB without inhibition and with a prefilmed wax treatment. For prefilmed asphaltene coupons at the same tests conditions, the reduction on corrosion rates were even higher with more than 70% of reduction in the range of 0 to 8 m/s.
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Ajmera, Pankaj, Win Robbins, Sonja Richter, and Srdjan Nesic. "The Role of Asphaltenes in Inhibiting Corrosion and Altering the Wettability of the Steel Surface." In CORROSION 2010. NACE International, 2010. https://doi.org/10.5006/c2010-10329.
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Abstract Asphaltenes (heptane insolubles) from a variety of crude oils have been previously identified as contributors to inhibition of internal corrosion of mild steel pipelines. However, the mechanism of inhibition is unknown. To explore the mechanism, CO2 corrosion rates and wettability (oil/water contact angles) have been measured using Arab Heavy crude oil and its asphaltenes. Inhibition of CO2 corrosion rates for carbon steel was measured by electrochemical methods in a glass cell; wettability was assessed using contact angle measurements in a multiphase goniometer. The phase behavior of asphaltenes in corrosion and wetting was evaluated in the crude, toluene or heptol (70:30 mixture of heptane and toluene). To evaluate the strength of the asphaltene interactions, tests were repeated on solutions containing mixtures of asphaltenes with acridine (previously identified as surface active using these tests). Inhibition on steel exposed to hydrocarbon phases increased with concentration of asphaltenes in toluene. Inhibition by asphaltenes in toluene appears to be more effective than in the whole crude. At 5% in toluene asphaltenes form a strong protective layer on the carbon steel surface, which reduces the corrosion rate and makes the surface hydrophobic. Heptol appears to have little effect on the wetting. However, in heptol, inhibition begins at lower asphaltene concentrations and is nearly complete at 5%.
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Palacios, T., A. Carlos, José L. Morales, and Alfredo Vitoria. "Effect of Asphaltene Deposition on the Internal Corrosion in the Oil and Gas Industry." In CORROSION 1997. NACE International, 1997. https://doi.org/10.5006/c1997-97006.
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Abstract Crude oil from Norte de Monagas field, in Venezuela, contains large amounts of asphaltenes. Some of them are very unstable with a tendency to precipitate. Because liquid is carried over from the separation process in the flow stations, asphaltenes are also present in the gas gathering and transmission lines, precipitating on the inner wall of pipelines. The gas gathering and transmission lines contain gas with high partial pressures of CO2, some H2S and are water saturated; therefore, inhibitors are used to control internal corrosion. There is uncertainty on how inhibitors perform in the presence of asphaltene deposition. The purpose of this paper is to describe the causes that enhance asphaltene deposition in gas pipelines and present some results from an ongoing research project carried out by the Venezuelan Oil Companies.
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Janak, Kevin E., Steven Colby, Tre Bertrand, and Brittany Fontenot. "Development of an Asphaltene Deposit Cleaning Technology Using a QCMB Technique." In CORROSION 2019. NACE International, 2019. https://doi.org/10.5006/c2019-12821.
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Absrract Asphaltenes are a components of crude oil defined as a solubility class, i.e., as a component of crude oil insoluble in n-pentane (C5 asphaltenes) or n-heptane (C7 asphaltenes) but soluble in aromatic solvents such as toluene, and are complex, polyaromatic, macrocyclic structures with an overall varied composition. Asphaltene deposition, remediation, and inhibition are important considerations for flow assurance in upstream processes, but methodologies to assess performance for cleaning purposes can provide variable results. We report on the development of a dispersant additive for aromatic solvent systems using a QCMB technique for evaluating the cleaning of a deposit. Further, we report the performance of the additive in a case study and, hence, the utility of the technique to provide an assessment for potential field use.
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Quainoo, Kwamena Ato, Imqam Abdulmohsin, and Cornelius Borecho Bavoh. "Kinetic Experimental and Modeling Evaluations of Asphaltene Morphology and Growth Rate under Varying Temperature and Brine Conditions." In SPE International Conference on Oilfield Chemistry. SPE, 2023. http://dx.doi.org/10.2118/213811-ms.
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ABSTRACT The utilization of predictive mechanisms to resolve asphaltene precipitation during oil production is a cleaner and less expensive means than the mechanical/chemical remediation techniques currently employed. Existing models lack predictive success due to opposing views on temperature-asphaltene precipitation interactions. In this study, the effect of varying temperatures (40, 50, 60, 70 80 and 90 °C) and brine concentrations (0 – 5 wt.%) on the long-time kinetics of asphaltene precipitations was evaluated. A series of experiments were conducted using the filtration technique and the confocal microscopy to study asphaltene precipitation on a model oil system consisting of asphaltenes, a precipitant, and a solvent. Furthermore, the Avrami modeling technique was employed to predict the morphology, and growth rate of the precipitating asphaltenes. The experimental results suggested that temperature significantly affects asphaltene precipitation including imparting its precipitation mechanism with a cross-behavioral pattern. Asphaltene precipitation in the system displayed an initial fast kinetics upon increasing temperature. The fast kinetics observed in the early times is due to the increasing dipole-dipole interactions between asphaltene sub-micron particles stimulated by increased temperature. However, the pattern changes into slower precipitations as the time progresses upon continuous heating of the reservoir fluid. The reason is the increased solubility of the asphaltenes imparted into the model oil system upon further increments in temperature. The presence of brine in the model-oil system also enhanced the rate and precipitation of asphaltenes. The experimental data were further analyzed with the Avrami crystallization fitting model to predict the formation, growth, morphology, and growth geometry of the precipitating asphaltenes. The Avrami model successfully predicted the asphaltene morphologies, growth rates and the crystal growth geometries. The growth geometries (rods, discs, or spheres) of the asphaltenes in the model oil systems upon temperature increments, ranged from 1.4 – 3.5. These values are indicative that temperature impacts the growth process of asphaltenes in the model system causing variations from a rod-like sporadic process (1.0 ≤ n ≤ 1.9) to a spherical sporadic growth process (3.0 ≤ n ≤ 3.9). This work precisely emphasizes the impact of temperature on asphaltene precipitations under long kinetic time, thus, providing a clear pathway for developing successful kinetic and thermodynamic models capable of predicting asphaltene precipitation reliably. The accurate prediction of asphaltene precipitation will eliminate the need for the use of harmful remediation solvents like benzene/toluene/ethylbenzene/xylene (BTEX). This study is therefore a critical step in the right direction to achieving accurate predictive model evaluations of asphaltene precipitations.
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Mohamed, Tarek S., Morten Kristensen, Carlos Torres-Verdín, Yucel Akkutlu, and Oliver C. Mullins. "Forward Modeling the Formation of Viscous Oils and Tar Mats Over Geologic Time via History-Matching of Reservoir Charge." In SPE Annual Technical Conference and Exhibition. SPE, 2024. http://dx.doi.org/10.2118/221055-ms.
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Abstract Asphaltenes are nanocolloidal structurespresent in various petroleum deposits. High asphaltene content in heavy oils causes the formation of clusters, the largest asphaltene nanocolloidal particles, driving a large gravity gradient of asphaltenes. Viscosity is highly correlated with asphaltene content; therefore, heavy oils are often associated with large viscosity gradients. Large oil-to-water viscosity ratios result in the fingering of injection water into oil columns and reduce sweep efficiency during production. Cluster accumulation at the base of a heavy oil column often leads to tar mat formation at the oil-water contact (OWC), sealing the aquifer from the oil and precluding pressure support and aquifer sweep. Thus, modeling the formation of viscous oils and tar mats is critical for production planning. Asphaltenes are established to have a nanocolloidal structure in a large, anticlinal Middle East reservoir that is well connected as proven by equilibrated asphaltenes, production data, and pressure measurements, and contains black oil in the crest and 100-km rim of heavy oil underlain by ~10m tar mat. Asphaltenes in the black oil exist as nanoaggregates causing a small gradient under the influence of gravity, while asphaltene clusters in the heavy oil exhibit large gradients in density and viscosity. Both asphaltene gradients are matched by Flory-Huggins-Zuo equation of state (FHZ EoS). Over 60m of depth, asphaltene concentrations and viscosity values increase by factors of 10 and 1000, respectively. We use reservoir flow simulation of charge to show the formation of the viscous oil and tar mat. Our simulations honor the well-established nanocolloidal structure of asphaltenes and show how to generate gradients under the influence of gravity. We also investigate the impact of simulation parameters (e.g., reservoir geometry, dip angle) and charge conditions (e.g., charge duration) on asphaltene distributions. We model the following reservoir fluid geodynamic processes leading to current fluid measurements. First, the reservoir is charged with heavy oil. Second, gravity gradients are established from vertical migration of heavy asphaltenes to lower positions (base of the crest or base of the formation interval). This creates a density inversion; the heavier oil at the base of the interval upstructure is more dense than the asphaltene-depleted oil at the top of the interval downstructure. Third, this density inversion causes Boycott convection which transports newly-created heavier oil to the base of the reservoir and lighter oil to the top of the reservoir. Subsequent to Boycott convection, asphaltene equilibration at the base of the column yields very high asphaltene concentrations at the oil-water contact. If the asphaltene concentration exceeds the solvency capacity of the oil for asphaltenes, then asphaltene phase-separation and deposition proceed creating a tar mat. The modeling mechanism is consistent with geochemical measurements, saturation pressure, and gas-oil ratio (~100 SCF/STB). Core plugs from six tar mat wells exhibit significant variation in asphaltene content from 30% to 65%. Tar mat wells establish that 1) tar mat is a two-phase system of very high asphaltene and oil phases and 2) the mechanism proposed agrees with tar mat well properties. Asphaltene nanocolloidal gravity gradients are established vertically while Boycott convection transports dense oil to the base of the reservoir leading to formation of viscous oil and tar mat. The simulations also show that upwelling at the oil-water contact associated with countercurrent flow of Boycott convection precludes asphaltene colloidal settling at the OWC which is required to obtain very high asphaltene concentrations and tar mat formation. Thus, tar mats form when charge is complete but generally not prior to the completion of charge. Here we show for the first time that reservoir flow simulation of charge can honor the basic physics of mass transport in the reservoir and predict tar mat formation.
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Farok, Mohd Munir Bin Mohd, B. Davidescu, R. E. Hincapie, et al. "Understanding Asphaltene Precipitation Dynamics in Flow Assurance Risk Management of an Offshore Field in Abu Dhabi." In ADIPEC. SPE, 2024. http://dx.doi.org/10.2118/222024-ms.
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Abstract Asphaltenes are polyaromatic fractions of crude oil that can precipitate due to temperature, pressure, or composition changes inherent in oil recovery processes. In Field A, the precipitation and deposition of asphaltenes at various points along the production path poses challenges: deposition in tubing blocks well access, while deposition in multi-phase flowmeters leads to inaccurate readings. Furthermore, precipitation can lead to facilities process upset. Understanding and managing asphaltene behavior is crucial for efficient and profitable operations. The insights of a flow assurance evaluation including asphaltene evaluation were integrated with additional analysis for de-risking purposes. The study involved a comprehensive approach from bottom hole sampling to asphaltene phase diagram (P-T) by measuring saturation and Asphaltene Onset Pressures (AOP) at different temperatures. High-pressure microscopy (HPM) was used to understand asphaltene deposition particles' morphological characteristics. The amount of asphaltenes precipitated was determined through a high-pressure filtration system. The effects of hydrocarbon gas injection on reservoir fluids were also investigated in the laboratory, using the same technique to establish the AOP with Pressure-Gas Concentration diagram (P-X). The initial validation analysis showed that the collected bottom hole samples were representative of PVT behavior and reservoir fluid composition. However, high variability in asphaltene precipitation behavior was observed due to different sampling techniques. Asphaltene was detected in the reservoir fluid at lower temperatures during the isothermal depressurization experiment and in hydrocarbon gas injections at different temperatures. Asphaltene particle size distributions were quantified through statistical image analysis. Bottom hole sampling technique with a nitrogen chamber for pressure compensation was the most suitable for asphaltene samples, as the likelihood of asphaltene precipitation increases with higher hydrocarbon gas concentrations and lower temperatures. Analyzing asphaltene behavior, using single-phase samples providing critical insights for accurate AOP data, helps operators to take preventive measures to avoid costly downtime. In Field A, suitable well intervention procedures were developed for wells where asphaltene precipitation is predicted, while pro-active solvent flushing schedules were implemented in multi-phase flowmeters to ensure accurate readings. Similarly, facility design was adapted, and operational procedures implemented to smoothly handle precipitated asphaltenes. Accurate assessment of asphaltene onset pressure is crucial for managing flow assurance risk in offshore oil fields. It helps operators devise strategies to maintain uninterrupted oil production and mitigate risks associated with deposition and blockages along the entire oil production path. Accurate assessment of asphaltene onset pressure is essential for maximizing operational efficiency and minimizing downtime.
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Punase, Abhishek, Antonio Pedro Oliveira, and Jonathan Wylde. "Green and Sustainable Asphaltene Dispersant with Cardanol Derivatives for Medium and Heavy Asphaltenic Oil Application." In SPE Eastern Regional Meeting. SPE, 2022. http://dx.doi.org/10.2118/211872-ms.
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Abstract Phenolic resins are major class of polymeric compounds used for treating asphaltene instability related challenges. Such compounds often act like as artificial resins naturally present in crudes to prevent the aggregation of asphaltene molecules and therefore their tendency to deposit on solid surfaces. However, these phenolic resins are known to have toxicity and biodegradability issues. Aim of this work is to elucidate and compare cardanol ethoxylates derivatives as asphaltene dispersants in comparison with commonly used phenolic resins chemistries. To characterize the effects of cardanol chemistries, a series of laboratory tests were conducted. The thermo-electric properties of the crude oils were studied both with and without chemical treatments to establish state of asphaltenes and their disaggregation. Optical dispersion testing confirmed whether cardanol formulations affected the sedimentation rate and particle size distribution of flocculated asphaltenes within the oil matrix. An Asphaltene Dynamic Deposition Loop (ADDL) test verified the effectiveness of the cardanol ethoxylates on the overall asphaltene deposition rate under flow conditions. Finally, the rheology and viscoelastic properties of the treated oil were examined at various temperatures and shear rates with specific focus on steady state and low shear environments. Results were compared against commercially available resin-based products. In a thermodynamically stable crude oil medium, the asphaltene molecules exist in an equilibrium state and contributes least towards the overall thermo-electric reading of the test sample. Addition of an effective asphaltene inhibitor disrupts this equilibrium and disperses the polar asphaltene molecules within the crude matrix, leading to higher thermo-electric values. For the crude samples tested, it was observed that the addition of cardanol derivatives increased the thermo-electric response thus improving the asphaltene dispersion. Further validation of this improvement was confirmed with the optical dispersion test results. Relative to the blank or untreated sample, adding formulations with cardanol ethoxylates resulted in lower sedimentation rate and settling velocity of the heavy asphaltene fraction. Furthermore, effectiveness of cardanol as a surface-active agent that can avert the preferential sticking of the polar asphaltene fraction onto the metal surface of production and transportation flowlines was also assessed using the ADDL test. Lastly, the low-shear rheological analyses of the treated and untreated crude samples also corroborate synergistic efficiency of cardanol containing formulations to decrease the bulk sample viscosity. Cardanol ethoxylates belong to a class of surfactants derived from renewable and sustainable raw materials that can be considered as a viable option for upstream oilfield applications. Results from this study are quite encouraging and could set the stage for development of new asphaltene inhibitors and improve our capability to control asphaltene flocculation in more complex fluids and production systems including high asphaltenic crudes.
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Rodriguez M., Fernancelys. "Characterization and Modeling of Asphaltenes for Complex Reservoirs in Venezuela: State of the Art." In ASME 2020 39th International Conference on Ocean, Offshore and Arctic Engineering. American Society of Mechanical Engineers, 2020. http://dx.doi.org/10.1115/omae2020-18502.
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Abstract Asphaltenes are complex hydrocarbon molecules that are in suspension in the oil, stabilized by resins, which may cause severe production issues at reservoir and surface conditions. High asphaltene and resin contents is one of the main characteristics of the Venezuelan unconventional oils (highly viscous oils) in the Orinoco Oil Belt. This high concentration of resins in the oil maintains the aggregates of asphaltenes dissolved in the continue oil phase avoiding asphaltene precipitation/ flocculation/deposition issues at field conditions as some Venezuelan conventional oil reservoirs located in northern Monagas State in which unfavorable resins/asphaltene (R/A) ratios promote the precipitation of asphaltenes. Conventional oil reservoirs in northern Monagas show gravitational segregation, this is the case of Carito-Mulata and Santa Barbara Field, varying from an upper zone of critical fluid behavior to a black oil zone in the lowest part of the structure in which the current pressure levels induce asphaltene precipitation, causing problems by plugging reservoirs, wells and pipelines, severely affecting oil and gas production. This causes increased production costs (chemical cleaning) and/or irreversible formation damage when reservoir pressures are less than asphaltene precipitation/flocculation onset pressures. Therefore it is necessary to characterize the asphaltene thermodynamic behavior and include this in reservoir numerical-simulation models, with the aim of increasing the reliability of the results and optimizing production strategies. Reproducing the thermodynamic behavior of asphaltenes is very complex, both experimentally and in numerical simulation, especially in terms of description and measurement of the degree of asphaltene-porous media interaction and the effect of injected fluids into the reservoir (EOR methods such as miscible/non-miscible gas injection or chemical flooding). Nevertheless, efforts have been done by the Venezuelan National Oil Company and collaborators, both at laboratory and simulation scales, to study the asphaltene thermodynamic behavior and the effect of permeability reduction in the porous media and its impact on the production profiles for complex Venezuelan reservoirs. This article presents a literature review of the Venezuelan experience for the characterization and modeling of asphaltenes for conventional and heavy oil reservoirs.
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Mullins, Oliver, Andrew Pomerantz, and Yunlong Zhang. "Asphaltenes: Fundamental Principles to Oilfield Applications." In SPE Annual Technical Conference and Exhibition. SPE, 2021. http://dx.doi.org/10.2118/206091-ms.
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Abstract The sophisticated molecular imaging methods, atomic force microscopy (AFM) and scanning tunneling microscopy (STM), have been utilized to image individual asphaltene molecules, both their atoms and bonds, and their electronic structure. The stunning images have confirmed previous results and have all but resolved the long-standing uncertainties regarding asphaltene molecular architecture. Asphaltenes are also known to have a strong propensity to aggregate. The dominante asphaltene molecular structure and hierarchical nanocolloidal structures have been resolved and codified in the Yen-Mullins model. Use of this model in a simple polymer solution theory has given the first equation of state (EoS) for asphaltene gradients in oilfield reservoirs, the Flory-Huggins-Zuo EoS. With this EoS it is now possible to address reservoir connectivity in new ways; equilibrated asphaltenes imply reservoir connectivity. For reservoirs with disequilibrium of contained fluids, there is often a fluid process occurring in geologic time that precludes equilibrium. The collection of processes leading to equilibrium and those that preclude equilibrium constitute a new technical discipline, reservoir fluid geodynamics (RFG). Several reservoirs are reviewed employing RFG evaluation of connectivity via asphaltene thermodynamics. RFG processes in reservoris often include diffusion, RFG models incorporating simple solution to the diffusion equation coupled with quasi-equilibrium with the FHZ EoS are shown to apply for timelines up to 50 million years, the age of charge in a reservoir. When gas (or condensates) diffuse into oil, the asphaltenes are destabilized and can convect to the base of the reservoir. Increasing asphaltene onset pressure as well as viscous oil and tar mats can be consequences. Depending on specifics of the process, either gooey tar or coal-like asphaltene deposits can form. In addition, the asphaltene structures illuminated by AFM are now being used to account for interfacial properties using simple thermodynamics. At long last, asphaltenes are no longer the enigmatic component of crude oil, instead the resolution of asphaltene structures and dynamics has led to new thermodynamic applications in reservoirs, the new discipline RFG, and a new understanding of tar mats.
Reports on the topic "Asphaltene"
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Deo, M. D., and F. V. Hanson. Asphaltene reaction via supercritical fluid extraction. Office of Scientific and Technical Information (OSTI), 1993. http://dx.doi.org/10.2172/10134823.
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Chung, F., P. Sarathi, and R. Jones. Modeling of asphaltene and wax precipitation. Office of Scientific and Technical Information (OSTI), 1991. http://dx.doi.org/10.2172/6347484.
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Wu, Jianzhong, and J. M. Prausnitz. Molecular thermodynamics for prevention of asphaltene precipitation. Office of Scientific and Technical Information (OSTI), 1996. http://dx.doi.org/10.2172/374166.
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Clelland, I., H. Sawatzky, B. Farnand, and G. Smiley. Effect of oil from sludge on asphaltene deposition. Natural Resources Canada/ESS/Scientific and Technical Publishing Services, 1992. http://dx.doi.org/10.4095/304553.
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Wu, J., J. M. Prausnitz, and A. Firoozabadi. A molecular-thermodynamic framework for asphaltene-oil equilibria. Office of Scientific and Technical Information (OSTI), 1997. http://dx.doi.org/10.2172/459352.
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Deo, Milind D. Enhancing the Effectiveness of Carbon Dioxide Flooding by Managing Asphaltene Precipitation. Office of Scientific and Technical Information (OSTI), 2002. http://dx.doi.org/10.2172/791834.
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Deo, Milind D. Enhancing the Effectiveness of Carbon Dioxide Flooding by Managing Asphaltene Precipitation. Office of Scientific and Technical Information (OSTI), 2002. http://dx.doi.org/10.2172/791835.
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