Department of Petroleum Engineering.

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    SIMULATION OF IONIC LIQUIDS FOR THE REMOVAL OF ACID GASES IN NATURAL GAS PROCESSES
    (Covenant University Ota, 2025-08) Udogri, Obaro; Covenant University Dissertation
    This study presents a comprehensive simulation-based investigation integrating Aspen HYSYS and Density Functional Theory (DFT) to evaluate the performance of an ionic liquid (IL), 1-methyl-1-propylpiperidinium bis(trifluoromethanesulfonyl)-imide, for the effective removal of hydrogen sulfide (H₂S) and carbon dioxide (CO₂) from an untreated natural gas stream. The IL was selected based on its low toxicity, thermal stability, and favorable interaction with acid gases. The treatment phase involved modeling the gas absorption process in Aspen HYSYS and analyzing molecular interactions using DFT. Results showed that CO₂ preferentially binds to the anion ([TFSI]), while H₂S bonds to the cation ([MPPIP]). The calculated binding energies for both gases were minimal, indicating low energy requirements and a strong potential for efficient absorption. Under initial simulation conditions—206°C and 22.5 bar—the process achieved a 73.5% acid gas removal rate. Following this, optimization was performed to enhance the system’s performance. Sensitivity analyses revealed that temperature, pressure, and IL concentration significantly influenced gas absorption efficiency. The optimal operating conditions were found to be within a temperature range of 50°C to 78°C and a pressure of 18 bar. Although increasing the IL concentration improved acid gas absorption, it also reduced sweet gas recovery due to mass transfer effects. A balanced IL flowrate of 500 kmol/h was identified to maintain high efficiency while minimizing sweet gas loss. Statistical analysis using a two-factor interaction (2FI) model demonstrated a good model fit with an R² value of 83.2% and 87.6% of data closely matching the regression line. Final optimization using 3D response surface modeling revealed that the absorption efficiency could be increased from 73.5% to 95% by adjusting the operating conditions to 224°C and 28.5 bar.
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    ENHANCING THE PERFORMANCE OF WATER BASED MUD FOR HIGH TEMPERATURE HIGH PRESSURE (HTHP) APPLICATIONS USING BIO-BASED POLYMER AND NANOPARTICLES
    (SSRN, 2022-12) Abiodun Adeyemi Gbadegesin; Samson Fadairo Adesina; ling Kegang; Ayodeji Ayoola A.; Owen Erhabor Lewis
    The increased need for energy and petroleum products has led to the exploration of deep and ultradeep wells such as geothermal and harsh formation. Oil-Based Muds (OBM) fluid has the best qualities because of its stability but its environmental challenge is of great concern. In many parts of the world, environmental rules continue to ban the use of oil-based muds, although very effective yet polluting and expensive. Water-Based Muds Fluids (WBMFs) which are environmentally friendly and inexpensive to produce are considered as alternatives, but under the high temperature and high-pressure conditions, their stability is compromised. Addition of biopolymer to WBMFs was consider since it is ecologically acceptable, but at elevated temperature the biopolymer is break down and reduces the drilling fluid's viscosity, suspension, and fluid loss capacity. As a result, there is need to formulate of high-performance water-based drilling fluids that are stable at high temperatures. This research paper investigated the thermal stability of Polyethylene-Glycol (PEG) in the formulated drilling fluid with biopolymers (Potato Peel powder, PPP) suspended in bentonitewater and buffered with eggshell nanoparticles (ESNP). The resultant samples were evaluated at normal temperature 25oC and high temperature150oC, and it was discovered that the addition of ESNP and PEG improved the drilling fluids' rheological behavior by 70.8% and 46.2%, respectively. Also, the filtration properties of the various samples were also analyzed at different concentrations and varying temperatures from 40oC to 220oC. These additives ESNP and PEG greatly slowed down the degradation of the biopolymer formulated mud up to 220 °C. This newly formulated fluid system, is stable at high temperatures, can meet the demands of high-temperature formation during drilling.
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    Programme: Petroleum Engineering
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