Journal of Applied Research of Chemical -Polymer Engineering

Abstract Research subject: Oil and gas transmission pipelines are considered critical energy transportation arteries and are exposed to various threats. Natural phenomena, such as earthquakes and floods, as well as human-related factors, including unsafe excavation activities and operational failures, are among the main causes of leakage and performance disruptions in transmission lines. The 16-inch Mansouri oil field pipeline, with a length of 33 km, transports 75,000 barrels of crude oil per day from the field’s gathering center to the Ahvaz booster pump station. In this study, the pressure drop along the pipeline and the volume of fluid released into the environment due to leaks of different sizes were calculated using transient flow simulation.
Research approach: Transient multiphase flow simulations were performed using the OLGA simulator. Operational and field data were used to construct the initial model. The initial hydraulics of the pipeline model were calibrated by adjusting parameters such as internal pipe roughness, fluid viscosity, and gas–oil ratio (GOR) to minimize deviation from actual operating conditions. The calibrated model was then used to predict pressure drops and leakage flow rates. The modeling results can support the design of leak detection and warning systems, particularly real-time transient model–based systems.
Main results: The results indicate that, for leak diameters of 1 cm, 10 cm, and a full-bore rupture, the pressure drop rate at the pipeline inlet is approximately 0.0001 bar/s, 0.06–0.28 bar/s, and 0.25–5 bar/s, respectively. These pressure drop rates are critical for determining the automatic shutdown time in real-time transient model (RTTM) systems.

Abstract Research subject: The growing global water crisis has intensified the need to advance desalination technologies. In this regard, thermal desalination methods such as Multi-Stage Flash (MSF) and Multi-Effect Distillation (MED) are considered suitable options in regions where saline water sources are located near petrochemical and refinery plants. Their suitability stems from their capability to utilize low-grade thermal energy sources, such as flue gases from industrial processes.
Research approach: This study investigates and compares the performance of MSF and MED technologies within a flue gas heat recovery scenario. A detailed mathematical modeling framework is developed for both systems, incorporating mass and energy balance equations, heat transfer mechanisms, and economic evaluation metrics. The models are validated through comparison with experimental data obtained from various industrial units to ensure reliability and accuracy.
Main results: Simulation outcomes show that MSF, operating at a 50% recovery rate using flue gas as a heat source, has a water production cost of approximately $0.80 per cubic meter, while MED, under similar conditions, achieves a lower cost of $0.40 per cubic meter. Furthermore, the specific energy consumption is calculated to be about 15.9 kWh/m³ for MSF and 11.3 kWh/m³ for MED. Greenhouse gas emissions in the MED system are estimated to be 41% lower than in MSF at the same recovery level. From an environmental standpoint, the pollutant intensity of the concentrated brine generated by the two technologies is essentially the same. Overall, MED demonstrates superior performance over MSF in the context of flue gas heat recovery integration, due to its lower energy consumption, reduced operational cost, decreased greenhouse gas emissions, and minimized environmental impact. This study provides a comprehensive and validated numerical framework that can support simulation-based optimization of thermal desalination systems for sustainable water production.

 

Abstract Research subject: Enhanced oil recovery (EOR) is one of the key methods to increase oil recovery from reservoirs, utilizing chemical, physical, or thermal techniques. Among chemical methods, ionic liquids (ILs) have attracted attention as potential alternatives to traditional materials such as surfactants and polymers due to their unique properties, including stability under harsh environmental conditions such as high temperature and salinity, and tunability for specific reservoir conditions.
Research approach: Ionic liquids can serve as surfactant substitutes in enhanced oil recovery processes, but they require proper synthesis and development. Higher environmental sustainability and reduced water consumption are advantages of these materials compared to traditional methods. However, research shows that their impact on EOR performance is relatively limited and requires further optimization, laboratory tests, and simulations. In this article, recent research on the application of ionic liquids in enhanced oil recovery operations is comprehensively reviewed, focusing on their characteristics, mechanisms, experimental results, challenges, and future prospects.
Main results: A review of recent studies shows that ionic liquids can significantly reduce the water/oil interfacial tension and alter the wettability of reservoir rock, both of which are key factors in improving oil transport. For example, the ionic liquid 1-decyl-3-methylimidazolium triflate has shown the ability to reduce interfacial tension significantly. Tests suggest that these materials can recover up to 30% more of the original oil in place.Many ionic liquids also show a strong affinity for asphaltenes and act as solvents and dispersants. This property helps prevent asphaltenes from settling and depositing in the wellbore and around its production zone, which can significantly improve oil flow and production. Ionic liquids can reduce the viscosity of crude oil, making it easier to flow through the reservoir and reducing pressure gradients. However, most studies have been conducted on sandstone reservoirs, and research in carbonate reservoirs is limited, highlighting the need for further investigations.