Fluid-mineral Interactions in Clastic Petroleum Reservoirs

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Prof. Timothy P. Bata
Abubakar Tafawa Balewa University, Nigeria
Email: t.p.bata00@aberdeen.ac.uk

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Clastic petroleum reservoirs are composed primarily of sand, silt and clay, water, and hydrocarbon fluids, along with minor amounts of other minerals. Although there can be considerable variation, a typical clastic petroleum reservoir is approximately composed of 80–85 wt% sand, clay (aluminosilicate minerals), and other mineral matter, 5–10 wt% water, and 1–18 wt% hydrocarbon fluid. The arrangement of the mineral grains, water, and hydrocarbon fluids in clastic petroleum reservoir is believed to be an arrangement whereby each particle of the mineral grain is water wet and a film of oil envelops the water-wetted mineral grains. The balance of the void volume is filled with oil, connate water, or gas; fine material, such as clay, also occurs within the water envelope.

In general, the reservoir quality of sandstone is controlled by factors such as (i) depositional porosity and permeability. These are in turn strongly influenced by sorting, grain size, grain morphology and sand/mud matrix ratio - the depositional environment. Other factors that influence sandstone reservoir quality include the degree of mechanical and chemical compaction, the amount and type of pore-filling cement, and geothermal gradient. Paragenetic relationships between hydrocarbons and inorganic minerals in oil reservoirs can provide information on the relative timing of hydrocarbon migration and the migration of other fluids. This special edition is aimed at increasing our understanding on the interactions of mineral grains and hydrocarbon fluids in various clastic petroleum reservoirs.

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Oluwadare O. A., Olowokere M. T., Taoili F., Enikanselu P. A., Abraham-Adejumo R. M.
AIMS Geosciences, 2020, 6(3): 378-396. doi: 10.3934/geosci.2020021
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