Hybrid journal (It can contain Open Access articles) ISSN (Print) 1753-3309 - ISSN (Online) 1753-3317 Published by Inderscience Publishers[439 journals]
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Authors:Sanggono Adisasmito, Rhesa Muhammad Faisal Pages: 103 - 121 Abstract: A microfluidic test kit with a flowrate capacity of 0.01-100 µL/min and pressure of 0-50 psig was designed and fabricated to test four series of salinity injections and subsequently compare the recovery factor (RF). Homogeneous rock patterns with PMMA material were used to create a microfluidic chip with a porosity of 27.8% and a permeability of 2.8 Darcy. The crude oil has an API of 31.9, while the formation water has 10,958 ppm in salinity. The injection solutions were NaCl with 600, 6,000, and 11,000 ppm salinity. The injection was then visualised and processed by a program in Python language to obtain saturation data and recovery factor. An increase in RF was observed in the NaCl injections with salinity lower than formation water. The highest RF, up to 30%, was generated from 600 ppm of NaCl injection. [Received: November 23, 2021; Accepted: August 7, 2022] Keywords: enhanced oil recovery; low salinity waterflooding; microfluidic test kit; recovery factor; experimental investigation; homogeneous rock pattern; polymethyl methacrylate; PMMA; microfluidic device Citation: International Journal of Oil, Gas and Coal Technology, Vol. 33, No. 2 (2023) pp. 103 - 121 PubDate: 2023-05-17T23:20:50-05:00 DOI: 10.1504/IJOGCT.2023.130994 Issue No:Vol. 33, No. 2 (2023)
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Authors:Marwa Ali Al-Nuumani, Adel M. Al-Ajmi, Mohammed Hamed Al-Aamri, Hamoud K. Al-Hadrami Pages: 122 - 146 Abstract: In drilling operation, breakout formations with allowable width can be accepted although it is a type of formation damages. The study presents a geomechanical analysis which mimics field conditions using a new 3D geomechanical model to predict the allowable breakout width in vertical wells using Mogi-Coulomb criterion with the linear elastic consecutive solution of Kirsch. The classical Moher-Coulomb criterion is used to verify the effect of the intermediate principal stress in determining the breakout width. The impact of the rock parameters and in situ stresses are studied in different in situ stress regimes. It has been found that the friction angle, cohesion, and the minimum horizontal stress are the most critical parameters on the breakout width formation. The studied fields show that using Mogi-Coulomb law gives results within the applied field conditions. Furthermore, adopting the classical Moher-Coulomb failure criterion in the analysis will raise uncertainty in borehole breakout width predictions. [Received: November 3, 2022; Accepted: January 11, 2023] Keywords: allowable breakout width; in situ stresses; geomechanical model; Mogi-Coulomb criterion Citation: International Journal of Oil, Gas and Coal Technology, Vol. 33, No. 2 (2023) pp. 122 - 146 PubDate: 2023-05-17T23:20:50-05:00 DOI: 10.1504/IJOGCT.2023.130997 Issue No:Vol. 33, No. 2 (2023)
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Authors:Fachun Liang, Lingqi Xin, Jingwen Zhao, Shen Song, Sigang Wang Pages: 147 - 169 Abstract: The objective of this paper is to study the gas-liquid separation performance and its improvement of a new combined T-junctions separator by experiments. This separator is constructed of large-diameter T-junctions (50 mm and 60 mm), symmetrically arranged in annulus. The test conditions include complete separation and incomplete separation. The gas-liquid flow characteristics of the combined T-junctions were visually observed and analysed during the separation process. The separation characteristic was quantified (F) and the effects of liquid level, inlet superficial velocities (JG1 and JL1) and outlet valve opening degree on the separation efficiency (F) were confirmed. The results show the connections between the parameters and separation efficiency. Based on the above, a self-regulating level controller is designed, which can significantly extend the range of inlet gas velocity (JG1) to 4.5 times and inlet liquid velocity (JL1) to two times for complete separation, but the level controller fails when the inlet gas-liquid velocities are too high (JG1 > 10.27 m/s, JL1 > 0.52 m/s). [Received: December 14, 2021; Accepted: August 7, 2022] Keywords: gas-liquid separation; combined T-junctions; experimental study; liquid level control Citation: International Journal of Oil, Gas and Coal Technology, Vol. 33, No. 2 (2023) pp. 147 - 169 PubDate: 2023-05-17T23:20:50-05:00 DOI: 10.1504/IJOGCT.2023.130993 Issue No:Vol. 33, No. 2 (2023)
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Authors:Fachun Liang, Lingqi Xin, Jingwen Zhao, Shen Song, Sigang Wang Pages: 170 - 187 Abstract: Alkali-surfactant-polymer (ASP) flooding is one of the most effective methods for enhancing heavy oil recovery. However, for heavy oil reservoirs with high content of Ca<SUP align="right">2+</SUP> and Mg<SUP align="right">2+</SUP> ions in the formation water, the scaling in ASP flooding affects the injection and displacing effect. In this study, a scale inhibitor containing polyaspartic acid sodium (PASP) and polyamino polyether methylene phosphonate (PAPEMP) were simultaneously applied with alkanolamide to form a scale-resistant and friendly environmental ASP flooding system, whose optimised composition is 1% NaCO<SUB align="right">3, 0.2% alkanolamide (type '1:2'), 0.15% partially hydrolysed polyacrylamide (molecular weight of 8 × 10<SUP align="right">6</SUP> g/mol) 0.1% sodium dodecyl sulfonate (SDS), 0.025% scale inhibitor. This system has a better anti-scaling effect. The interfacial tension (IFT) test shows that the IFT of the ASP system and W8 crude oil can reduce to the order of 10<SUP align="right">-3</SUP>mN.m<SUP align="right">-1</SUP> within 2 min, forming a relatively stable oil-in-water (O/W) emulsion. The addition of SDS can improve the solubility of alkanolamide, with a uniform and transparent solution. Furthermore, core flooding results showed that the oil recovery rate of the ASP flooding increased by 20%, exhibiting an obvious flooding effect, mainly due to the swept efficiency and displacement efficiency. [Received: May 19, 2022; Accepted: January 24, 2023] Keywords: ASP flooding system; anti-scaling; heavy oil; alkaline flooding system Citation: International Journal of Oil, Gas and Coal Technology, Vol. 33, No. 2 (2023) pp. 170 - 187 PubDate: 2023-05-17T23:20:50-05:00 DOI: 10.1504/IJOGCT.2023.130996 Issue No:Vol. 33, No. 2 (2023)
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Authors:Zhaowei Si, Defang Liu, Fawu Lin, Hongli Peng Pages: 188 - 204 Abstract: Multi-stage development results in complex lithology and variable pore structure in volcanic reservoirs. Therefore, it is difficult to calculate fracture porosity and determine the volcanic reservoir type. In this study, we use the deep volcanic rock of the Nanpu No. 5 structure as an example to use a matrix porosity logging evaluation model in different lithology reservoirs. Dual Laterolog has a large detection range and is sensitive to fractures. Therefore, the relationship between igneous fracture and logging response characteristics is analysed via numerical simulation. Then, the method used for calculating fracture parameters was verified by combining formation MicroScanner image (FMI) logging technology with Dual Laterolog. For accurate reservoir classification, a fracture porosity less than 0.0005 is ineffective since the formation fluid cannot be transported. The quantitative fracture evaluation of volcanic rock reservoir was completed based on calculation model. The agreement with the actual production proved the effectiveness of the method. [Received: September 9, 2022; Accepted: December 30, 2022] Keywords: volcanic rock; reservoir classification; well logging; quantitative evaluation; matrix porosity; lithology; Dual Laterolog; formation MicroScanner image; FMI; fracture porosity; accuracy Citation: International Journal of Oil, Gas and Coal Technology, Vol. 33, No. 2 (2023) pp. 188 - 204 PubDate: 2023-05-17T23:20:50-05:00 DOI: 10.1504/IJOGCT.2023.130999 Issue No:Vol. 33, No. 2 (2023)
Hybrid journal (It can contain Open Access articles)
[439 journals]
