Aim: The aim of this study was to evaluate the effect of cold sand pack on vascular complications and pain in patients who undergoing percutaneous coronary intervention.
Methods: This randomized controlled interventional trial was conducted in a hospital between November 30, 2021 and April 3, 2022. The patients were randomly assigned to CSP and NSP. A 5 kg sand pack was applied on the femoral area of the patients in the CSP group at an average temperature of 18.9°C for the first 20 minutes. A 5 kg sand pack was applied at an average temperature of 24.1°C after the procedure on the femoral region of the patients in the NSP group.
Results: After percutaneous coronary intervention, less bleeding developed in the CSP group at hours 2, 3, and 12 when compared to the NSP group, and the ecchymosis diameters measured at hours 1, 2, 3, 4, 5, 6, 12, and 24 were higher than those of the NSP patients (p < 0.05). It was detected that the pain score of the NSP group was higher at hours 1, 2, 3, 4, 5, 6, 12, and 24 on the femoral region when compared to the CSP group.
Conclusion: It was detected that the cold sand pack applied for the first 20 minutes prevented bleeding and reduced ecchymosis diameter and pain intensity.
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http://dx.doi.org/10.5152/FNJN.2024.23074 | DOI Listing |
Sci Rep
January 2025
Petrochemicals Department, Egyptian Petroleum Research Institute, 1 Ahmed El Zomor St., Nasr City, Cairo, 11727, Egypt.
Recovering the remaining oil after primary and secondary extraction methods poses a significant challenge. Enhanced oil recovery (EOR) techniques, which involve injecting fluids into reservoirs, aim to increase recovery rates. Ionic liquids, known for their adaptability, are emerging as promising agents in EOR, improving oil displacement by reshaping fluid properties and interacting with reservoir rocks.
View Article and Find Full Text PDFACS Omega
December 2024
School of Petroleum Engineering, China University of Petroleum (East China), Qingdao, Shandong 266580, China.
Pickering emulsions stabilized by surfactant-modified SiO nanoparticles demonstrate good stability against droplet coalescence, showing application potential for enhanced oil recovery in high-temperature and high-salinity environments. Adjusting the adsorption ratio of surfactant on the nanoparticles significantly affects the wettability of nanoparticles and therefore regulates the microstructure and properties of Pickering emulsions. In this study, a saturated monolayer adsorption occurs at a surfactant-to-nanoparticles ratio of 0.
View Article and Find Full Text PDFExcessive reservoir water poses significant challenges in the oil and gas industry by diminishing hydrocarbon recovery efficiency and generating environmental and economic complications. Conventional polymer flooding techniques, although beneficial, often prove inadequate under conditions of elevated temperature and salinity, highlighting the need for more resilient materials. In this research, two types of acrylamide-based preformed particle gels (PPGs) were synthesized, as follows: polyelectrolyte and polyampholyte.
View Article and Find Full Text PDFACS Omega
August 2024
College of Mechanical and Vehicle Engineering, Chongqing University, Chongqing 400044, China.
To solve the problem of poor stability and low enhanced oil recovery efficiency of conventional foam, nanoparticle-surfactant-stabilized nitrogen foam was prepared, and the influence of temperature, salinity, oil content, and pressure on foam performance was systematically investigated. Then, the flow behavior of conventional foam and nanoparticle-surfactant-stabilized foam in porous media was studied. Parallel sand pack flooding and visualization microflooding experiments were performed to investigate the enhanced oil recovery ability of nanoparticle-surfactant-stabilized foam from core-scale to pore-scale.
View Article and Find Full Text PDFGels
July 2024
College of Petroleum Engineering, China University of Petroleum (East China), Qingdao 266555, China.
Heterogeneous phase combined flooding (HPCF) has been a promising technology used for enhancing oil recovery in heterogeneous mature reservoirs. However, the injectivity and propagation behavior of preformed particle gel (PPG) in low-medium-permeability reservoir porous media is crucial for HPCF treatment in a low-medium-permeability reservoir. Thus, the injectivity and propagation behavior of preformed particle gel in a low-medium-permeability reservoir were systematically studied by conducting a series of sand pack flooding experiments.
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