Melting and crystallization of paraffins

Afanas'ev, A. N.; Matishev, V. A.; Syunyaev, Z. I.; Farafonov, V. V.

doi:10.1007/bf00723968

Cited by 6 publications

(4 citation statements)

References 2 publications

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“…It can be observed that the bee, as probed at high temperature presents mainly a softer phase and that phase contrast image keeps no direct relation to the topography. After 95 min at 56°C, it can be observed that this softer phase presents a layered structure similar to the structure observed for the crystallization of paraffin (Afanasev et al 1993).…”

Section: Resultssupporting

confidence: 66%

High temperature AFM study of CAP 30/45 pen grade bitumen

Moraes

Pereira

Simão

et al. 2010

Journal of Microscopy

119

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SummaryBitumen is a complex mixture of hydrocarbons for which microstructural understanding is incomplete. In an effort to detail this microstructure, a asphalt cement sample (CAP 30/45) was analysed by thermal phase detection atomic force microscopy. Phase contrast and topography images showed that sample morphology is highly dependent on temperature. The 'bee structure' changed considerably at temperatures between 50• C and 56• C. A decrease of the oscillation amplitude was observed upon heating and the 'bees' completely disappeared at temperatures above 57• C. When the temperature was decreased after melting at 170• C, the 'bees' began to nucleate gradually at temperatures of 57• C and its evolution with time was followed. Changes in morphology were compared to thermal analysis results and a model for the 'bee' structure was proposed.

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Section: Resultssupporting

confidence: 66%

High temperature AFM study of CAP 30/45 pen grade bitumen

Moraes

Pereira

Simão

et al. 2010

Journal of Microscopy

119

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“…Special separation techniques (Heath et al 1997;Musser and Kilpatrick 1998;Thanh et al 1999) were not practical for this study, because these techniques are proposed for only a few ml of crude oils, and due to the low asphaltene content (5-200 mg/l crude oil), a few hundred ml of crude oil was needed to isolate sufficient amounts of asphaltenes for this research. Because high-wax compounds start to precipitate at low temperatures (Afanasev et al 1993;Hsieh 1999), asphaltenes was isolated using the 60-fold excess of hot n-heptane solvent (65°C). After 48 h of settlement, the mixture was again stirred for a few minutes by ultrasonic device, then heated up (65°C) and finally filtrated.…”

Section: Sample Preparationmentioning

confidence: 99%

Geochemical characterization of crude oils from well ‘X’, Agbada formation, onshore Nigeria

Nyantakyi

Nagre

et al. 2016

Arab J Geosci

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This article characterizes crude oil samples from well 'X' in onshore Nigeria. The objective of this research is to characterize the geochemical features of crude oils. A total of 10 crude oil samples collected from well X, onshore Nigeria were characterized geochemically. The analytical results reveal that all crude oil samples are at the same stage of maturity and correspond to a vitrinite reflectance of about 0.8 % Ro. These oils show minor facies variations probably due to different terrestrial organic matter input indicated by their biomarker distributions. All biodegraded oil samples have similar facies pointing to the same oil with different ranks of biodegradation. The extent of biodegradation for the most degraded oils was from 1 to 4/5. The light hydrocarbon parameters distinguished unaltered from biodegraded oils. Biodegraded oils had higher initial saturations of solution gas, and therefore would lose more gas than black oils during evaporitic fractionation.

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“…Diamondoids and paraffin/wax may cause deposition due to lowering of the crude oil temperature and formation of crystalline solids (Afanas'ev, et al, 1993). For instance, by examining each heavy organic compound separately one may argue that mercaptdans and organometallics cause deposition due to dissociation or solubility effects.…”

Section: Demirbas°dmentioning

confidence: 99%

Physical and Chemical Characterizations of Asphaltenes From Different Sources

Demırbas¹

2002

Petroleum Science and Technology

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Asphaltenes and resins are two of the several, but important, heavy organics present in petroleum fluids. Asphaltenes are operationally defined as the non-colatile and polar fraction of petroleum that is insoluble in n-alkanes (i.e., n-pentane). Conversely resins are defined as the non-colatile and polar fraction of petroleum that is soluble in n-alkanes (i.e., n-pentane), and aromatic solvents (i.e., toluene), and insoluble in ethyl acetate. A commonly accepted view in the petroleum chemistry is that crude oil asphaltenes form micelles which are stabilized by adsorbed resins kept in solution by aromatics. Two key parameters that control the stability of asphaltene micelles in a crude oil are the ratio of aromatics to saturates and that of resins to asphaltenes. When these ratios decrease, asphaltene micelles will coalesce and form larger aggregates. The precipitation of asphaltene aggregates can cause problems such as reservoir plugging and wettability reversal. 485

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Melting and crystallization of paraffins

Cited by 6 publications

References 2 publications

High temperature AFM study of CAP 30/45 pen grade bitumen

High temperature AFM study of CAP 30/45 pen grade bitumen

Geochemical characterization of crude oils from well ‘X’, Agbada formation, onshore Nigeria

Physical and Chemical Characterizations of Asphaltenes From Different Sources

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