Crude evacuation to the export terminals takes more than 45% of the operating expenditure of some marginal field operators (MFOs) in Nigeria. Many studies on marginal field investment focus more on composite operating cost analysis, hence overlooking its components. Crude evacuation is a major challenge for MFOs because economics of their operations may not support wholistic value chain investment of which crude transportation is a part. Oil pipeline evacuation is the primary onshore crude transportation model available to MFOs. The next option is the virtual pipelines with high risk potentials. Therefore, the market for pipeline crude evacuation becomes a monopoly cemented on several agreements with stringent terms and conditions. One recurrent feature in most of these agreements is the charge on the reserved production capacity (RPC). This cost takes more than 70% of the ullage value in a typical marginal field budget. Are there ways to navigate past this monopoly? This paper seeks to explore economics of various crude evacuation options available in the marginal field terrain onshore and develop integrated evacuation models to highlight the effect of the idiosyncratic monopoly to profitability. The approach x-rays the various crude handling, transportation, terminaling and sales agreements available to MFOs. Hydrocarbon accounting model is incorporated for both pipeline and virtual pipeline evacuations. Iteration of tariff charges and injection split optimization are done on the integrated model. Forecasts are carried out in the face of changing oil prices, oil injection profiles and crude agreements terms and conditions over a period to ascertain the effect on the MFO's bottom-line. The model may be used for policy formulations, sector regulations and the marginal field investment analysis.

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