Browsing by Author "Chikwe, A. O."

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    Optimum tubing size prediction model for vertical multiphase flow during flow production period of oil wells
    (Springer, 2020-10-04) Nwanwe, C. C.; Nwanwe, U. I.; Nwanwe, O. I.; Chikwe, A. O.; Ojiabo, K. T.; Umeojiako, C. T.
    Optimum tubing size (OTS) selection was traditionally done by using nodal analysis to perform sensitivity analysis on the different tubing sizes. This approach was found to be both cumbersome and time-consuming. This study developed a user-friendly and time-efficient OTS prediction computer model that could allow Petroleum Production Engineers to select the best tubing size for any vertical oil well. The tubing size selection was based on the present operating low rate, economic considerations and future operating low rate as defined by the OTS selection criteria of this study. The robustness of the model was tested using tubing sizes ranging from 0.824 to 6.0 inch in a vertical well producing from both saturated and undersaturated oil reservoirs. The 2.750-inch tubing was found the OTS for both scenarios. In the validation, the results obtained from the novel OTS prediction model and Guo et al. (Petroleum production engineering: a computer-assisted approach, Gulf Professional Publishing, Cambridge) spreadsheet program using the Pettman–Carpenter method were in excellent agreement for operating low rate but not for operating pressure. Furthermore, the novel OTS prediction model was in excellent agreement with the same spreadsheet program based on modified Hagedorn–Brown correlation for both operating fowl rate and pressure. The results showed that the model developed in this study is reliable and can be used in the field for vertical oil wells. The new model could as well inform the Production Engineer when the well would need artificial lifts for economic production of the well. It was recommended that Newton–Raphson and modified Hagedorn–Brown methods be used in future study.
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    Water flooding process of oil recovery in the Niger Delta region of Nigeria
    (U. P., 2020) Chikwe, A. O.; Duru, U. I.; Obasi, E. C.
    Water flooding is a process of hydrocarbon recovery where water is injected through injection wells into the reservoir to recover oil from the production well. It is usually injected in a reservoir rock that has fluid communication with the producing reservoir. Waterflooding is secondary recovery mechanism whose purpose is to maintain and support reservoir pressure thus displacing hydrocarbon towards the producing wellbore. In this study a reservoir in the Niger Delta, Reservoir OZ-70 is used for evaluation and economic analysis of the water flooding project using five spot pattern. Reservoir OZ-70 had oil at the start of the flood to be 2.38MMSTB. The reservoir was left depleted with the unrecovered oil in it. But based on the analysis carried out on secondary oil recovery by water flooding, 0.98 MMSTB was recovered from 2.38 MMSTB about 41.1% at a breakthrough period of 428 days. When water viscosity was increased from 0.60 to 0.65, 0.99MMSTB about 41.7% was recovered. Economic evaluation of the reservoir oz-70 water flooding project was also performed. Net present value (NPV) was calculated to be $8.74million while internal rate of return (IRR) at a discount rate of 10% was 126.3%. Therefore, since the NPV is greater than zero and IRR greater than hurdle rate (10%) the project is economically viable.