## 1 Introduction  
Energy demands continuously grow due to technological advancements, leading to concerns about meeting these increased needs. According to the Institute for Energy Research, energy consumption will increase by roughly 50% in 2050 [1]. Fossil fuels have always been the primary energy source for humankind, and this trend will continue for the foreseeable future to meet the energy demand. Despite significant attempts to shift the energy source to other nonconventional and environmentally friendly sources, fossil fuels have stayed the primary source of energy supply. Among various resources, crude oil contributed 46.2% of total energy demand in 1973 and still accounts for almost 31% as of 2019, proving to be the highest among all the energy sources [2]. These data show that crude oil is an indispensable energy reserve to mitigate the energy crisis until a prominent environmentally friendly option is available. Unfortunately, crude oil is continuously depleting, as its reserve is finite [3]. Therefore, oil extraction must be performed as efficiently as possible to maintain the proportional oil supply. Fortunately, numerous enhanced oil recovery (EOR) methods have been implemented to recover as much oil as possible from depleted reservoirs. The conventional oil extraction process has been mainly classified into three stages. The first stage, or primary stage, is where oil is naturally extracted by five driving forces: dissolved gas-driven, water-driven, gravity drainage-driven, gas cap-driven, and combination-driven [4]. Even with the aid of additional pumping systems to pump the oil out of the production well, the first stage of oil recovery produces a small percentage of the original oil in place (OOIP). It is then followed by the second stage of oil recovery, where external fluids like water and gas are flooded through strategically located wells around the production well to recover more oil through a volumetric sweep by maintaining the positive pressure in the reservoir. Both first- and second-stage oil recovery produces around 33% of the OOIP [5]. Even with the implementation of two stages, approximately 65% of OOIP remains in the reservoir because the oil is trapped within small pores of the heterogeneous reservoir structure with higher capillary forces and viscosity [6]. The tertiary recovery stage, or EOR, is implemented to extract the remaining oil using various methods like thermal, chemical injections, and gas injections [7]. These methods alter the reservoir surface and oil properties, including wettability, interfacial tension (IFT), viscosity, and capillary pressure, potentially leading to increased oil recovery. Different EOR methods are implemented based on the reservoir conditions. Thermal methods like stem injection, electrical heating, and various energy input techniques are used to increase the reservoir temperature, reduce oil viscosity, and increase oil mobility [8]. In chemical methods, various surfactants, nanoparticles, or polymers are used to alter the wettability of the reservoir surface to make it more water-wet by reducing the IFT of oil and flooding fluid [9; 10]. In gas EOR, air, carbon dioxide (CO\({}_{2}\)), nitrogen (N\({}_{2}\)), and water, alternating gas injections are used to reduce oil viscosity. This is achieved through the expansion of oil volume by gas dissolution and the miscibility between oil and gas [11]. Among all these EOR methods, thermal methods account for 67% of all the global EOR projects due to their comparatively high performance [8]. However, thermal methods cannot be applied effectively in deep reservoirs or thin pay zone reservoirs, which contain comparatively narrow hydrocarbon layers, primarily due to significant heat losses in these environments [12]. Moreover, thermal techniques are energy-intensive and have higher operational costs, limiting their feasibility in regions with challenging geological conditions.