Abstract
The ubiquitous consumption of hydrocarbon fuels in a vast majority of industrial purposes has been dramatically increased in the coming decades. Therefore, the reason why numerous studies experimental investigations are being done is to enhance the oil recovery factor. Low salinity water injection is considered as the significant proposed enhanced oil recovery techniques in which the salinity percentage of the injected water is adjusted to improve oil displacement efficiency. Hence, low salinity water injection is considerably influenced by the oil recovery factor regarding altering wettability condition. The objective of this study is to simulate the low salinity water injection under different reservoir characteristics of rock compressibility, porosity and net to gross (NTG) on the amount of total field oil production (FOPT), total field gas production (FGPT), field pressure ratio (FPR) and field gas-oil ratio (FGOR) for 7400 days . Consequently, rock compressibility has less impact on the amount of total field oil production, total field gas production, field pressure ratio, and field gas-oil ratio. By increasing the amount of porosity and NTG, the amount of FOPT, FGPT, and FGOR are raised dramatically, and it is evident that this parameter is directly influenced by this type of reservoir. On the contrary, the amount of FOPT, FGPT, and FGOR are decreased in the NTG period of 0.5 to 1.
Highlights
The daily increase of fossil fuels as the primary sources of energy has caused to explore a wide range of laboratory measurements to achieve the optimum and economical (Davarpanah and Mirshekari, 2019a,b; Armin Razmjoo et al, 2019; Bagheri et al, 2019)
By increasing the amount of porosity and Net to Gross (NTG), the amount of field oil production (FOPT), field gas production (FGPT), and Field Gas-Oil Ratio (FGOR) are raised dramatically, and it is evident that this parameter is directly influenced by this type of reservoir
The amount of FOPT, FGPT, and FGOR are decreased in the NTG period of 0.5 to 1
Summary
The daily increase of fossil fuels as the primary sources of energy has caused to explore a wide range of laboratory measurements to achieve the optimum and economical (Davarpanah and Mirshekari, 2019a,b; Armin Razmjoo et al, 2019; Bagheri et al, 2019). Thereby, several energy management scenarios and considerations should be taken into account by petroleum industries to serve the purpose of oil production enhancements by virtually eliminating the unnecessary expenses (Alboudwarej and Sheffield, 2016; Clements, 2017; Dai and et al, 2013; Davarpanah and Mirshekari, 2019d; Davarpanah et al, 2019d). Secondary and tertiary oil recovery techniques have not altered the physical properties of reservoir fluids and rocks (Davarpanah, 2018; Davarpanah et al, 2019a; Luo et al, 2014; Lyu et al, 2017; Mohsenzadeh et al, 2016). Waterflooding is considered as one of the efficient and widely used techniques to oil recovery enhancement and numerous studies were reported in the literature to demonstrate the emphasis of this phenomenon due to its affordability and ubiquity (Davarpanah and Mirshekari, 2019c; Davarpanah et al, 2019c; Djuraev et al, 2017; Kondash and Vengosh, 2015; Rowan et al, 2015; Sorbie, 2013; Xuezhong et al, 2016)
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