Teamwork is a crucial soft skill that need to be instilled to the undergraduates from Petroleum Engineering course in order to address the 10th and 12th Program Outcome outlined by the Engineering Accreditation Council for Malaysia higher education institution. Teamwork is beneficial to the students in order to build their self-confidence, exchange their opinions, develop critical and creative thinking to improve their learning process and serves as a life-long learning skill that could be utilized in the oil and gas industry and other engineering sectors. The key objective of this study is to investigate the teamwork in capstone project which is a summative assessment to address the affective domains to produce well rounded graduate. This study aims to examine the impact of teamwork in the process of project-based learning in the compulsory capstone course for final year students to their individual performance. Its assessment was claimed to be designed based on capstone project requirements by the Engineering Accreditation Council. The capstone course design is a project-based learning (PBL) approach as it is designed for group activity that will go on for two semesters. The research measured for the teamwork performance in four dimensions which is Working with Others, Planning and Organising, Effectiveness under Stress and Commitment to job. Additionally, this study deployed a quantitative method through a set of questionnaires. The design capstone course is unable to accommodate or evaluate excel teams of Teamwork performance and it addresses heavily on the cognitive domain through their Coursework performance. These findings could be an eye-opener to lecturers in designing appropriate student-centred learning approaches.

Upstream oil production using dual string completion, i.e., two tubing inside a well casing, is common due to its cost advantage. High pressure gas is employed to lift the oil to the surface when there is insufficient reservoir energy to overcome the liquids static head in the tubing. However, gas lifting for this type of completion can be complicated. This is due to the operating condition where total gas is injected into the common annulus and then allowed to be distributed among the two strings without any surface control. High uncertainties often result from the methods used to determine the split factor—the ratio between the gas lift rate to one string over the total gas injected. A hybrid model which combined three platforms: the Visual Basics for Application programme, PROSPER (a nodal analysis tool) and Excel spreadsheet, is proposed for the estimation of the split factor. The model takes into consideration two important parameters, i.e., the lift gas pressure gradient along the annulus and the multiphase pressure drop inside the tubing to estimate the gas lift rate to the individual string and subsequently the split factor. The proposed model is able to predict the split factor to within 2% to 7% accuracy from the field measured data. Accurate knowledge of the amount of gas injected into each string leads to a more efficient use of lift gas, improving the energy efficiency of the oil productions facilities and contributing toward the sustainability of fossil fuel.

Sequestration of Carbon Dioxide (CO2) in sandstone formation filled by brine aquifers is widely considered a promising option to reduce the CO2 concentration in the atmosphere. However, the injection of reactive CO2 into sandstone rock creates injectivity problems because of CO2-brine-rock interactions. The injection flow rate and CO2-fluid-rock exposure conditions are important factors that control the intensity of the reactions. The focus of this research was therefore on evaluating the petrophysical modifications in sandstone core samples at distinct flow rates using different CO2 injection schemes. In this research, the porosity and permeability of Berea sandstone samples were measured using PoroPerm equipment. The core samples were initially saturated with dead brine (30 g/l NaCl) followed by injection either by supercritical CO2 (scCO2) only, CO2-saturated brine only and CO2-saturated brine together with scCO2 at different flow rates. During injection, the differential pressure between the core inlet face and outlet face were recorded. Fines from the produced effluent were separated and collected for characterization using Field Emission Scanning Electron Microscope and Energy Dispersive X-ray Spectroscopy (FESEM-EDX). Post-injection porosity and permeability of the core samples were measured and compared with the pre-injection data to monitor changes. All sandstone core specimens showed favorable storage capability features in the form of capillary residual trapping with residual CO2 saturation ranging from 40% to 48%. In addition, all samples experienced important changes in their petrophysical characteristics, which were more pronounced in the event of absolute porosity and permeability, which decreased from 20%–51% to 4%–32%. The suggested harm mechanism is primarily owing to salt precipitation and fines migration. Supported by FESEM images, the proposed damage mechanism is mainly due to salt precipitation and fines migration.

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