The factors controlling the abundance and migration of heavy versus light oils, as constrained by data from the Gulf of Suez. Part I. The effect of expelled petroleum composition, PVT properties and petroleum system geometry

“…The details of the methods were given by Khavari- Khorasani et al (1998). The thermal stability of coals and of coal asphaltenes was estimated, using multiheating rate bulk flow pyrolysis and the Lawrence Livermore Kinetics program (Braun and Burnham, 1990).…”

Section: Methodsmentioning

confidence: 99%

“…The calibration data are provided by the on-line, temperature-resolved flash Py-GC data from coal, the bulk composition of the retained petroleum (average group type proportions) in the coal at different levels of maturity, source rock mass balance and solubility calculations (Sandvik et al, 1992). The method was described in detail by Khavari-Khorasani et al (1998).…”

Section: Methodsmentioning

confidence: 99%

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The Physics and Efficiency of Petroleum Expulsion from Coal

Michelsen

Khavari-Khorasani²

1999

Coalbed Methane: Scientific, Environmental and Economic Evaluation

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Many coals, in particular coals of Mesozoic and Cenozoic age, generate significant quantities of "oil" constituents. At the same time few commercial oil deposits can be demonstrated to have originated from coal derived fluids. In this paper we examine mass loss and volumetric changes of coals during petroleum generation. We do not find evidence for the view that coals do not expel fluids before secondary cracking have eliminated the oil potential. Mass balance and sorption data indicate that coal constituents have lower retention capacity than e.g., classic oil source rocks. It is concluded that there must be a direct link between the generation/desorption of petroleum and the deformation of the coal. A continuum physics approach is applied to evaluate possible coal rheologies and the compaction behavior, given the state and forces which acts on the coal during petroleum generation. The coal during generation must behave in a fluid like manner. The diffusive micro scale transport of petroleum molecules in the coal matrix causes the coal to deform with a viscous rheology. The desorption of petroleum from the coal matrix instantaneously creates a mechanically unstable state, and a related fluid potential gradient in the petroleum will drive the petroleum out of the coal together with related compaction of the coal. The expulsion will be particularly efficient in normally pressured sedimentary sections, where petroleum is expelled nearly symmetrically in both directions. In sections with hard overpressure prior to generation/expulsion, there will be a stronger tendency for upward expulsion. The main driving force for expulsion is independent of the volume expansion of the organic matter. The deficiency of oil deposits from coals, must be related to factors other than the expulsion efficiency. 517 M. Mastalerz et al. (eds.),

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“…Pioneering work was carried out by Zhuze & Yushkevitz (1959), Zhuze et al (1962Zhuze et al ( , 1963 and Zhuze & Ushakova (1981). Geochemical evaluations of vapour-liquid equilibria and PVT data include Price et al (1983), Thompson (1987Thompson ( , 1988Thompson ( , 1992Thompson ( , 2002, England and co-workers (1989England and co-workers ( , 1991England and co-workers ( , 2002, Larter & Mills (1991), Knudsen & Meisingset (1991), Dzou & Hughes (1993), Curiale & Bromley (1996), Meulbroek et al (1998), di Primio (1998, Khavari-Khorasani et al (1998), van Graas et al (2000, Meulbroek (2002) and Losh et al (2002). Meulbroek, as well as di Primio, are contributors to this volume.…”

mentioning

confidence: 99%

Interpretation of charging phenomena based on reservoir fluid (PVT) data

Thompson¹

2004

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Molar concentration profiles of reservoir fluids reveal accumulation history and alteration. Slope Factors (SF) define rates of exponential decrease in concentration of light n-alkanes (C3-nC5) and liquid pseudo-components (P10+) with increasing carbon number. Most petroleum fluids are substantially characterized by SF(C3-nCs) and SF(PI0+), the former invariably being the greater. Specific paired values of SF(C3-nCs) and SF(P10+) are process-diagnostic. In oils, maturation, gas injection, evaporative fractionation and migration depletion involving loss of gas, are recognizable. SF data are interpreted in the light of PVT analyses representing oils (principally from western Canada) and gas-condensates (from numerous basins), also asphaltene pyrolysis experiments and equation of state calculations. Covariant increase of SF(C3-nCs) and SF(P10+) during maturation is demonstrated, but correlation is frequently destroyed by modification of the light ends by the admixture of allochthonous gas, increasing only SF(C3-nCs). Secondary gas-enrichment is a requisite process for the generation of gas-condensates by evaporative fractionation. Compositional criteria for the recognition of enrichment are provided for the first time, particularly attainment of a value of SF(C3-nCs) exceeding 1.69 (a tentative limit). Available data indicate that the process has occurred in a large proportion of oil accumulations, ranging from 23% of 30 reservoirs in the Jurassic Smackover Formation in Alabama, to 78% of 36 in the northern North Sea.

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The factors controlling the abundance and migration of heavy versus light oils, as constrained by data from the Gulf of Suez. Part I. The effect of expelled petroleum composition, PVT properties and petroleum system geometry

Cited by 26 publications

References 27 publications

Evaluation of the petroleum composition and quality with increasing thermal maturity as simulated by hydrous pyrolysis: A case study using a Brazilian source rock with Type I kerogen

Evaluation of the petroleum composition and quality with increasing thermal maturity as simulated by hydrous pyrolysis: A case study using a Brazilian source rock with Type I kerogen

The Physics and Efficiency of Petroleum Expulsion from Coal

Interpretation of charging phenomena based on reservoir fluid (PVT) data

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