The most important area of a producing reservoir is the near wellbore which is within 5fts into the formation. All fluids have to flow through it, usually at high flow rates. Problems associated with formation damage near wellbore occur frequently, resulting in permeability impairments and increased pressure losses. During drilling, emulsion formation affects reservoir deliverability and ultimate recovery. Most of the existing methods to aid mitigation near oil well damages involve the use of empirical models. Conducting experiments, frequent shut down of wells for proper well test analysis and pressure maintenance are highly expensive and time consuming. Therefore, this paper aimed at optimizing reservoir pressure using cross section comparisons of mathematical tools and experimental for improved emulsion transport near wellbore. Formation damage mechanisms are highlighted for the purpose of reservoir engineers. The engineers must be vigilant about the potential formation damages near wellbore and then can mitigate the impact of damages by understanding its mechanisms how various types of damages might impact production, Assessment, control and remediation. The transient hydraulic diffusivity partial differential equations (THDPDE) models developed. The model equations were resolved using finite difference method and implemented by writing codes in MATLAB language. The solutions obtained were validated using field data and experimental work. The results indicated pressure depletion over time without injection but increases under the influence of increased injection rates enhancing the oil recovery. Experiments were also carried out to evaluate the effectiveness of the emulsions as displacing fluid for enhanced oil reservoir. In this paper, a new modeling scheme is proposed and is based entirely on cross section comparisons involving modification of Darcy’s equation with experimental work in an attempt to optimize reservoir pressure and improved oil-in-water emulsions near wellbore. The knowledge that oil-in-water emulsion type exists and that a new scheme to uniquely characterize the near wellbore damage is developed. The present authors suggest cross section comparisons of both modeling and experimental section for predictions of the data in the study area. Numerical simulation has proved to be effective in simulating emulsions near wellbore. The formulated models indicate pressure depletion over time, but increased thereafter, resulting to increased oil recovery and significant improvement in emulsions transport near wellbore.
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