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Choosing the right kerogen for hydrocarbon (oil and gas) generation kinetics to predict hydrocarbon phase and properties such as API gravity and GOR using petroleum systems models is usually a challenge. Common procedure in industry is to select a multi-component kinetics dataset based on available geochemical data and a basin analogue. This kinetics is usually derived from a measurement of 1 or 2 samples of an immature source rock representing a specific kerogen type or source facies. Testing indicates that it currently makes little difference whether a programmed default is used or a basin-specific dataset is utilized. The important question remains, how well does a selected sample represent the source rock variability within the fetch area? This question is quite often neglected. In addition to this conceptual issue, the alteration of hydrocarbons during migration and within the trap are usually not explicitly modeled, largely as a result of the limited understanding of the processes involved, which precludes their quantification. Examples from the South Atlantic continental margins, applying this new solution, which implicitly includes many of the important factors such as source rock variability and migration effects, will be presented. The proposed solution results in significantly improved prediction of the quality of hydrocarbon product, phase, and properties such as GOR, API gravity, and viscosity.

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