Formation impairment due to fines migration during productionrncontinues to cause inflow reduction. Proper fines managementrncan optimise productivity, safeguard facilities and cut down onrnwell maintenance cost. Today’s core flood test limitations keeprnus away from being capable of limiting or avoiding fracturerndamage. The limitations include: safety aspects which preventrnutilisation of hydrocarbon gas in multiphase fluids in confinedrnlaboratories, core sample conditions due to recovery problems,rnreliability of scaling up to field extent, and so forth. Hencernbased on such limitations, unique approaches were carried outrnfor damage risk assessments.rnThis paper presents unique techniques to analyse conditionsrnleading to fracture damage, ability to characterise the damagernimpact and prediction of well performance. The techniquesrnincorporate a CFD and 3D reservoir simulation packages.rnResults suggest that in high permeability sands, the finer therngrain size (10 -100microns) the lesser the pressure declinernrates. When 150 - 200 fines microns were simulated, therndeclines in pressure were comparatively sharper. Thernsensitivity of grain size in normal matrix formation is lessrncompared to that found in fractured or very permeablernformations as in the letter, higher magnitudes of permeabilityrndecline were revealed in which case possible shallow invasionrndamage mechanisms were likely. Unlike the grain sizerninfluence to pressure drop and permeability declines, thernsimulated fines concentration ranging from 20% to 50% byrnvolume of crude along horizontal direction, did have differentrnimpact compared to results of same concentration across thernwidth of the sand body. Water cut sensitivity on the other handrnrevealed significant permeability drops between 0% and 10%rnwater cut at fixed fines concentration.rnIn these analyses, solid fines velocities were exclusively beingrnmonitored in the multiphase flow and could be distinguishedrnfrom fluid velocities.
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