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Thermodynamics and Physical Properties in Process Innovation
Published in David A. Palmer, Handbook of Applied Thermodynamics, 2019
Some gas and oil production companies are achieving enhanced recovery of petroleum using carbon dioxide flooding. The prediction of the effects of such miscible gas flooding on reservoir properties has required the use of sophisticated equations of state. Data for determination of the interaction parameters have been measured by several organizations, including but not limited to the National Bureau of Standards (NBS), Texas A & M University, and the American Institute of Chemical Engineers’ (AIChE) Design Institute for Physical Property Data (DIPPR).
Investigation of the effects of carbon dioxide injection on the rock and fluid intraction in high permeable sandstone reserviors
Published in Petroleum Science and Technology, 2023
Seyyed Jamal Aldin Arous, Danial Madani Tehrani, Mohammad Bazvand
In this study, the effect of carbon dioxide injection on the properties of rock and fluid as well as the effect of pressure, flow rate and orientation parameters of the sandpack model in these interactions have been investigated. From the experimental work conducted, the following conclusion can be drawn:Carbon dioxide flooding in sand stone reservoirs causes alteration in porosity and permeability, and this change in vertical injection strategy is more than that of horizontal one.Changes in the concentration of calcium, magnesium and iron in the vertical injection mode are higher than the horizontal injection mode, which may indicate that more carbonate minerals are dissolved in the process of CO2 injection into a vertical state.The amount of Asphaltene precipitated in the sandpack model in the vertical is more than horizontal state.The Asphaltene precipitation increases as the injected pore volume increases.As pore volume of gas injected increases, the oil recovery factor increases.
CFD modeling of virtual mass force and pressure gradient force on deposition rate of asphaltene aggregates in oil wells
Published in Petroleum Science and Technology, 2022
Xiaodong Gao, Pingchuan Dong, Xiaoxi Chen, Luc Yvan Nkok, Shaowei Zhang, Yuan Yuan
Asphaltenes may precipitate out of the crude oil due to the changes in temperature, pressure, precipitants properties, as well as CO2 injection. Therefore, many scholars have carried out relevant studies. For instance, Ali, Dahraj, and Haider (2015) investigated the effect of CO2 injection velocity in light oil on quantity of asphaltene through three core flooding experiments. The results showed that the precipitation amount decreases with increasing injection flow rate of CO2. Later, different crude oil (heavy, medium, and light) was considered and the wettability alteration of Indiana Lime Stone was investigated during miscible carbon dioxide flooding (Ali et al. 2017). It was found that the wettability was altered from oil-wet to intermediate-wet. Also, it was also observed that the wettability alteration was subjected to other parameters Scenario, such as organic surface concentration (Ali 2018), organic acid concentration (Ali et al. 2020), environment-friendly nonionic surfactant (Haghighi et al. 2020) as well as novel biosynthesized nanocomposite (Nazarahari et al. 2021). In addition, the deposition can also occur on the metal surface and it can partially or completely clog the available cross-sectional flow area for moving crude oil. It was reported that the severe asphaltene deposition reached up 2/3 of the tubing radius (Haskett and Tartera 1965). These adverse effects not only require time-consuming intervention methods, but it is also responsible for significant downtime and hefty economic losses (Table 2). Hence, it is vital to predicting the deposition rate of asphaltene aggregates during production.
Probing the mechanism of external fluids invasion of nanopores in fractured tight sandstone reservoir
Published in Journal of Dispersion Science and Technology, 2023
Zhe Wang, Guangsheng Cao, Yujie Bai, Xin Wang, Dan Li
With the continuous exploitation of oil and gas resources, the reserves of conventional reservoirs continue to deplete, and the proportion of tight sandstone exploitation is increasing.[1] The matrix permeability of tight sandstone is <0.1 × 10−3 μm2, and the porosity is <10%.[2] Tight sandstone is difficult to exploit using the conventional method, and the output is low.[3] Additionally, because of the low porosity, low permeability, and strong capillary force of tight sandstone,[4] reservoir damage has a greater impact on the productivity of tight sandstone reservoirs than on that of conventional reservoirs.[5] The main methods for mining tight sandstone include hydraulic fracturing, imbibition oil recovery,[6] carbon-dioxide flooding,[7] and hydraulic fracturing.[8] Tight sandstone usually contains natural fractures that are not only storage spaces but also important seepage channels that can increase the average permeability of the reservoir by two orders of magnitude.[9] Moreover, natural fractures can interact with artificial fractures after hydraulic fracturing; this is conducive to forming a network of cracks, thereby increasing the productivity. However, the development of cracks increases the loss of the working fluid.[10] Additionally, once the external fluids enter the formation, the permeability of the formation decreases, and the reservoir is damaged.[11] Most reservoir rocks contain clay minerals such as montmorillonite and kaolinite.[12] Hence, once the water-containing external fluid enters the formation, the clay particles are dispersed and migrate with a high probability, shrinking the large pores and blocking the small pores;[13] this reduces the permeability. External fluids also redistribute bound water and free water in equilibrium in the original formation,[14] change the original structure of the reservoir, and reduce the permeability. For nanopores in tight sandstone reservoirs, it is difficult for external fluids to enter the matrix rock during conventional mining. In contrast, during drilling and fracturing, the external drilling fluid and fracturing fluid enter the matrix rock under the action of microfracture formation at a high working pressure.