Papers by nyelebuchi amadichuku
World Journal of Advanced Engineering Technology and Sciences, Feb 28, 2024
Optimum acid selection based on reservoir condition is one of the key elements in achieving a suc... more Optimum acid selection based on reservoir condition is one of the key elements in achieving a successful treatment in sandstone matrix acidizing. This work will investigate the effectiveness of several type of acid in sand stone reservoir stimulation. PROSPER well modeling package was utilized for the model development. Pre-acid job analysis was carried out to establish the well performance before acidization. Acid stimulation was implemented with Hydrochloric (HCl), Formic, Acetic, Propionic and ChloroAcetic acids. Thereafter, post-job analysis was done to ascertain the improvement in well productivity index for each of the acids. Result shows that the reservoir will deliver 11296.5 STB/day of liquid into the wellbore for a production index of 3-STB/day-psi without acid stimulation and the well will produce 6726.05 STB/day of liquid. Results reveals a decrease in productivity index as the treatment acid was change from HCl acid to formic acid, acetic acid and propionic acid. A productivity index values of 3.07074STB/day-psi, 3.0375 STB/day-psi, 3.01038 STB/day-psi, 3.00791 STB/day-psi were obtained when the formation was acidized with HCl acid, formic acid, acetic acid and propionic acid. A percentage increase of 15.1973%, 7.5731%, 1.95684% and 1.47001% in permeability was observed as the formation was treated with HCl acid, formic acid, Acetic acid and Propionic acid. Results reveals that HCl acid resulted in highest permeability increase. It was therefore concluded that the formation should be acidized with HCl acid since it gave the highest productivity index, percentage increase in permeability, porosity and the highest improvement in skin factor.
World Journal of Advanced Engineering Technology and Sciences, Feb 28, 2024
This work maximizes oil production from a network of gas lift wells and determines the optimal am... more This work maximizes oil production from a network of gas lift wells and determines the optimal amount of lift gas with PIPESIM network optimizer. PIPESIM was used to build a couple wellbore-flowline model and its network optimizer was utilized to maximize oil production from a network of gas lifted wells. Two wells were created (Well A and B) and connected to their respective flow lines to a manifold and from the manifold to the central processing facility (CPF) represented by a sink node. A comparison of the oil production rate from Well B with and without constraint on water production rate shows that 7337.432STB/day of oil was produced without any constraints on water production while 7373.479 STB/day of oil was produced with constraint on water production and Well A, 280.6693 STB/day of oil was produced without any constraints on water production while 3.266503 STB/day of oil was produced with constraint on water production. For the injection of 4MMscf/day of gas with a constraint of 1800STB/day on water production, results reveals that a total gas lift rate of 3.723612MMscf/day was required to lift a total oil rate of 7484.669STB/day. Therefore, out of the 4MMscf/day of gas available, 3.723612MMscf/day should be allocated to the network to optimized production.
Effect of Infinite Volume on Structural Trapping Performance during Carbon dioxide Sequestration Processes
Journal of Petroleum and Mining Engineering, Jun 28, 2024
Investigation of the Impact of Surfactant Concentration on Gas Well Deliquification
Day 3 Wed, August 02, 2023
This work investigates the effect of surfactant concentrations on gas well deliquification and qu... more This work investigates the effect of surfactant concentrations on gas well deliquification and quantify the incremental gas production rate. A base model was built to verify the possibility of liquid loading behavior using the Turner velocity criteria. Foam lift was enabled and the well flow path was defined including the micro-annular space between the coiled tubing and the tubing strings. Different Surfactant concentrations of 0.05, 0.1, 0.15, 0.2, 0.25, 0.3, 0.35, 0.4, 0.45 and 0.5mass percent were injected for an optimum concentration required to unload liquid from the gas well. Results reveals that the reservoir will deliver 13.315MMscf/day of gas across the completion into the wellbore when the pressure drawdown is maximum.The intersection of the inflow and outflow performance curves shows that the well was producing 2.09787 MMscf/day of gas which occurs where the Turner velocity criteria shows a potential issue (liquid loading). A gas production rate of 2.09787 MMscf/day was ...
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Papers by nyelebuchi amadichuku