Faults play very important roles in hydrocarbon trapping systems. Fault Seals have a primary control on the trap in many hydrocarbon reservoirs, and also divide a large hydrocarbon reservoir into compartments. Faults seal when: reservoir sands juxtapose a low permeable rock such as shale with a high entry pressure, and/or when preferential cementation along an originally permeable rock occurs in which porosity is partially or totally removed leading to a hydraulic seal. Two types of lithology dependent attributes are defined: shale gouge ratio and clay smear factor. Cross fault flow resistance controls were determined by capillary membrane pressure, and rate controlled Darcy flow. Structural interpretation of seismic data and well log data incorporation was used to build a stratigraphic model with volume of clay values juxtaposed across the modelled faults in order to evaluate juxtapositions. From clay content we defined fault rock properties by calibrating in-situ measurements from the trend curves thereby obtaining the permeability and capillary threshold pressure. Hydrocarbon height prediction and shale gouge ratio calculations showed that the spatial sealing characteristics of a single fault are likely to be heterogeneous with sand levels greater than the threshold value of 20% for Niger Delta reservoir rocks.