Determination of Asphaltenes, Oils, and Resins in Asphalt

Hubbard, Robert L.; Stanfield, K.E.

doi:10.1021/ac60017a015

Cited by 48 publications

(20 citation statements)

References 8 publications

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“…In this method, bitumen is decomposed into three main groups of molecules: resin, oil and asphaltene. After that, Koots [ 26 ], Lian [ 27 ], and Hubbard [ 28 ] also contributed in this area. Some national standards also pay attention to this area.…”

Section: Phase Dynamicsmentioning

confidence: 99%

Characterization of Bitumen Micro-Mechanical Behaviors Using AFM, Phase Dynamics Theory and MD Simulation

Hou

Wang

et al. 2017

Materials

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Fundamental understanding of micro-mechanical behaviors in bitumen, including phase separation, micro-friction, micro-abrasion, etc., can help the pavement engineers better understand the bitumen mechanical performances at macroscale. Recent researches show that the microstructure evolution in bitumen will directly affect its surface structure and micro-mechanical performance. In this study, the bitumen microstructure and micro-mechanical behaviors are studied using Atomic Force Microscopy (AFM) experiments, Phase Dynamics Theory and Molecular Dynamics (MD) Simulation. The AFM experiment results show that different phase-structure will occur at the surface of the bitumen samples under certain thermodynamic conditions at microscale. The phenomenon can be explained using the phase dynamics theory, where the effects of stability parameter and temperature on bitumen microstructure and micro-mechanical behavior are studied combined with MD Simulation. Simulation results show that the saturates phase, in contrast to the naphthene aromatics phase, plays a major role in bitumen micro-mechanical behavior. A high stress zone occurs at the interface between the saturates phase and the naphthene aromatics phase, which may form discontinuities that further affect the bitumen frictional performance.

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Section: Phase Dynamicsmentioning

confidence: 99%

Characterization of Bitumen Micro-Mechanical Behaviors Using AFM, Phase Dynamics Theory and MD Simulation

Hou

Wang

et al. 2017

Materials

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“…The asphaltene content of oil samples was measured 1 3 by asphaltene precipitation with n-heptane (ASTM D2007-80). Resin content was estimated according to Hubbard and Stanfield (1948) method, and the acid number of the crude oils was determined by titration method.…”

Section: Reservoir Rock and Crude Oil Analysismentioning

confidence: 99%

Enhanced oil recovery by alkaline-surfactant-alternated-gas/CO2 flooding

Phukan

Gogoi

Tiwari

2018

J Petrol Explor Prod Technol

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The volumetric sweep efficiencies of CO 2 flooding for enhanced oil recovery (EOR) are generally low due to problems of viscous fingering and gravity override. This paper attempts to study a relatively new and promising method to reduce the mobility of CO 2 flooding and increase oil recovery under reservoir conditions. Referred to as alkaline-surfactant-alternatedgas/CO 2 (ASAG) flooding, this method is essentially the synergic combination of chemical and immiscible CO 2 flooding. In this work, chemical formulations were identified through foam stability tests based on their foaming ability coefficients.The selected formulations were further tested for their capabilities to reduce oil-water interfacial tensions (IFT) to ultra-low value. With the best performing formulations, the laboratory-scale core flooding experiments were conducted to evaluate their EOR potential. The core flooding experiments were performed with sandstone reservoir core samples from two different depths of a major depleted oil field of Upper Assam Basin, India. This study reports the successful application of a natural anionic surfactant (black liquor) as a co-surfactant and foaming agent during ASAG flooding. It was observed that higher oil recovery of 14.26% original oil in place (OOIP) was obtained by surfactant-alternated-gas (SAG) flooding compared to 12.03% OOIP by immiscible CO 2 alternated with brine (WAG) flooding. The highest residual oil recovery of 20% OOIP was obtained for ASAG flooding with the alkali, surfactant and black liquor in the chemical slug. Oil recovery performances during SAG and ASAG flooding were found to be better for core samples with lower porosity-permeability due to stronger foam formation in lower permeability cores.

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“…Over the past several decades much effort has been expended to isolate fractions of similar chemical finctionality or reactivity from asphalt (Hoiberg and Garris, 1944;Hubbard and Stanfield, 1948;Rostler and Sternberg, 1949;Traxler and Schweyer, 1953;Kleinschmidt, 1955;Corbett and Swarbick, 1960;Corbett, 1969). Nearly all of these efforts have been focused on describing asphalt composition in terms of a relatively few number of pseudo-components or group-type fractions.…”

Section: Standrd Fractionation Me Thomentioning

confidence: 99%