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Journal articles on the topic 'Alkaline-surfactant flooding'

Author: Grafiati

Published: 5 June 2025

Last updated: 2 August 2025

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1

Nurxat, N., I. Gussenov, G. Tatykhanova, T. Akhmedzhanov, and S. Kudaibergenov. "Alkaline/Surfactant/Polymer (ASP) Flooding." International Journal of Biology and Chemistry 8, no. 1 (2015): 30–42. http://dx.doi.org/10.26577/2218-7979-2015-8-1-30-42.

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Liu, Yinsong, Xiumei Zhang, Xiaolin Wu, Zhaowei Hou, Min Wang, and Erlong Yang. "Research on Microbial Community Structure in Different Blocks of Alkaline–Surfactant–Polymer Flooding to Confirm Optimal Stage of Indigenous Microbial Flooding." Applied Sciences 14, no. 12 (2024): 5243. http://dx.doi.org/10.3390/app14125243.

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The microbial communities associated with alkaline–surfactant–polymer (ASP)-flooded reservoirs have rarely been investigated. In this study, high-throughput sequencing was used to analyse the indigenous microbial communities in two different blocks, the water flooding after the alkaline–surfactant–polymer flooding block and the alkaline–surfactant–polymer flooding block, and to ascertain the optimal stage for the implementation of indigenous microbial oil recovery technology. The different displacement blocks had significant effects on the indigenous microbial community at the genus level acco

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3

Ge, Ji Jiang, Hai Hua Pei, Gui Cai Zhang, Xiao Dong Hu, and Lu Chao Jin. "Investigation into the Functions of Alkali and Surfactant in Chemical Flooding for Enhanced Heavy-Oil Recovery." Advanced Materials Research 524-527 (May 2012): 1816–20. http://dx.doi.org/10.4028/www.scientific.net/amr.524-527.1816.

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In this study, a comparative study of alkaline flooding and alkali-surfactant flooding were conducted for Zhuangxi heavy oil with viscosity of 325 mPa•s at 55 °C. The results of core flooding tests show that the tertiary oil recovery of alkali-surfactant flooding are lower than those of alkaline-only flooding, in spite of the coexistence of the surfactant and alkali can reduce the IFT between the heavy oil and aqueous phase to an ultralow level. Further flood study via glass-etching micromodel tests demonstrates that injected alkaline-only solution can penetrate into the oil phase and creates

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4

Amalate Ann Obuebite, Digieneni Yousuo, and Obumneme Okwonna. "Spontaneous imbibition and core flooding analysis of pH adjusted alkali and surfactant system in high salinity sandstone reservoir." World Journal of Advanced Engineering Technology and Sciences 8, no. 2 (2023): 254–66. http://dx.doi.org/10.30574/wjaets.2023.8.2.0102.

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Some of the limitations of a cost-effective alkaline surfactant flooding method include chemical precipitation and other formation damage issue which has greatly affected the application of chemical flooding especially in high salinity reservoirs. This study ascertains the chelating attributes of Ethylene-diamine-tetracetic Acid-(EDTA/NaOH), investigates the ability of EDTA/NaOH and an anionic surfactant to improve oil recovery in heavy oil sandstone formation. Petrophysical analysis of the crude oil and core samples were performed. Hard brine at 5.1% optimal salinity and 0.2 wt.% surfactant i

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5

Peru, Deborah A., and Philip B. Lorenz. "Surfactant-Enhanced Low-pH Alkaline Flooding." SPE Reservoir Engineering 5, no. 03 (1990): 327–32. http://dx.doi.org/10.2118/17117-pa.

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6

Jeff, Rudin, and Darsh T. Wasan. "Surfactant-Enhanced Alkaline Flooding: Buffering at Intermediate Alkaline pH." SPE Reservoir Engineering 8, no. 04 (1993): 275–80. http://dx.doi.org/10.2118/21027-pa.

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7

Liu, Shunhua, Danhua Zhang, Wei Yan, Maura Puerto, George J. Hirasaki, and Clarence A. Miller. "Favorable Attributes of Alkaline-Surfactant-Polymer Flooding." SPE Journal 13, no. 01 (2008): 5–16. http://dx.doi.org/10.2118/99744-pa.

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Summary A laboratory study of the alkaline-surfactant-polymer (ASP) process was conducted. It was found from phase-behavior studies that for a given synthetic surfactant and crude oil containing naphthenic acids, optimal salinity depends only on the ratio of the moles of soap formed from the acids to the moles of synthetic surfactant present. Adsorption of anionic surfactants on carbonate surfaces is reduced substantially by sodium carbonate, but not by sodium hydroxide. The magnitude of the reduction with sodium carbonate decreases with increasing salinity. Particular attention was given to a

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8

Pei, Haihua, Guicai Zhang, Jijiang Ge, Mingguang Tang, and Yufei Zheng. "Comparative Effectiveness of Alkaline Flooding and Alkaline–Surfactant Flooding for Improved Heavy-Oil Recovery." Energy & Fuels 26, no. 5 (2012): 2911–19. http://dx.doi.org/10.1021/ef300206u.

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9

AN, El-hoshoudy. "Investigation of Oil Recovery Improving through Surfactant Flooding; Design Program Scenario." Petroleum & Petrochemical Engineering Journal 5, no. 1 (2021): 1–24. http://dx.doi.org/10.23880/ppej-16000258.

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Chemical flooding is one of the major EOR techniques particularly for reservoirs where thermal methods are not applicable, that chemical flooding may be polymer flooding, alkaline flooding, surfactant flooding, or a combination of them. The application of designing a chemical flooding program is strongly affected by the current economics, reservoir oil type, and crude oil price. In this project, mechanisms of different chemical methods will be discussed, and design chemical flooding program by using a laboratory scale and programming method, this project is mainly about making a design of surf

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10

Alli, Yani Faozani, Edward ML Tobing, and Usman Usman. "MICROEMULSION FLOODING MECHANISM FOR OPTIMUM OIL RECOVERY ON CHEMICAL INJECTION." Scientific Contributions Oil and Gas 40, no. 2 (2018): 85–90. http://dx.doi.org/10.29017/scog.40.2.43.

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The formation of microemulsion in the injection of surfactant at chemical flooding is crucial for the effectiveness of injection. Microemulsion can be obtained either by mixing the surfactant and oil at the surface or injecting surfactant into the reservoir to form in situ microemulsion. Its translucent homogeneous mixtures of oil and water in the presence of surfactant is believed to displace the remaining oil in the reservoir. Previously, we showed the effect of microemulsion-based surfactant formulation to reduce the interfacial tension (IFT) of oil and water to the ultralow level that suff

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11

Dauyltayeva, Amina, Aibek Mukhtarov, Dilyara Sagandykova, Mariam Shakeel, Peyman Pourafshary, and Darya Musharova. "Screening of Chemicals to Enhance Oil Recovery in a Mature Sandstone Oilfield in Kazakhstan: Overcoming Challenges of High Residual Oil." Applied Sciences 13, no. 18 (2023): 10307. http://dx.doi.org/10.3390/app131810307.

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Chemical flooding, such as alkaline-surfactant (AS) or nanoparticles-surfactant (NS) flooding, is an enhanced oil recovery (EOR) technique that has been increasingly utilized to enhance the oil production rate and recovery factor while reducing chemical adsorption. The AS/NS flooding process involves the injection of a mixture of surfactant and alkali/nanoparticles solutions into an oil reservoir to reduce the interfacial tension between the oil and water phases by surfactant and lower surfactant adsorption by alkali or nanoparticles (NPs) to improve the residual oil recovery. In this study, t

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12

SHEDID, Shedid A., and Al-Abbas A. ABBAS. "Experimental Investigation of Surfactant Alkaline Steam Flooding Process." Journal of The Japan Petroleum Institute 43, no. 4 (2000): 310–16. http://dx.doi.org/10.1627/jpi1958.43.310.

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13

Bybee, Karen. "Alkaline-Surfactant/Polymer Flooding off the Cambridge Field." Journal of Petroleum Technology 52, no. 01 (2000): 48–49. http://dx.doi.org/10.2118/0100-0048-jpt.

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14

Bai, Yongqiang, Yang Chunmei, Liu Mei, and Jiang Zhenxue. "Variations of Micropores in Oil Reservoir Before and After Strong Alkaline Alkaline-surfactant-polymer Flooding." Open Petroleum Engineering Journal 9, no. 1 (2016): 257–67. http://dx.doi.org/10.2174/1874834101609010257.

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Enhanced oil recovery (EOR) provides a significant contribution for increasing output of crude oil. Alkaline-surfactant-polymer (ASP), as an effective chemical method of EOR, has played an important role in advancing crude oil output of the Daqing oilfield, China. Chemical flooding utilized in the process of ASP EOR has produced concerned damage to the reservoir, especially from the strong alkali of ASP, and variations of micropore structure of sandstones in the oil reservoirs restrain output of crude oil in the late stages of oilfield development. Laboratory flooding experiments were conducte

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15

Saengnil, Siwasilp, and Kreangkrai Maneeintr. "Interfacial Tension Measurement on Sodium Hydroxide Solution as Alkaline Flooding for Light Oil from Thailand." Applied Mechanics and Materials 799-800 (October 2015): 905–9. http://dx.doi.org/10.4028/www.scientific.net/amm.799-800.905.

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Because of an increasing world-energy demand, water-flooding is not the practical technology to produce more oil due to the high interfacial tension or IFT. To achieve this, enhanced-oil-recovery (EOR) technique like alkaline-flooding becomes more significant. For alkaline-flooding by sodium hydroxide, in-situ surfactant is created between the alkaline solution and the organic acids in oil to reduce IFT thus making oil flow easily. Consequently, the objective of this research is to investigate the effects of alkaline concentration, brine salinity, temperature and pressure on oil production and

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16

Al-Saedi, Hasan N., Ralph E. Flori, Soura K. Al-Jaberi, and Waleed Al-Bazzaz. "Low-Salinity Water, CO2, Alkaline, and Surfactant EOR Methods Applied to Heavy Oil in Sandstone Cores." SPE Journal 25, no. 04 (2020): 1729–44. http://dx.doi.org/10.2118/200488-pa.

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Summary Generally, injecting carbon dioxide (CO2) into oil reservoirs is an effective enhanced oil recovery (EOR) technique that improves oil recovery, but injecting CO2 alone can be compromised by problems, such as early breakthrough, viscous fingering, and gravity override. The base CO2 injection method was improved by water-alternating-gas (WAG) injection with formation water (FW) and with low-salinity (LS) water (LSW), with LSW WAG achieving greater recovery than WAG with FW. This study investigates various combinations of standard waterflooding (with FW); flooding with nonmiscible gaseous

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17

Li, Weirong, Xin Wei, Zhengbo Wang, et al. "Numerical Investigation on Alkaline-Surfactant-Polymer Alternating CO2 Flooding." Processes 12, no. 5 (2024): 916. http://dx.doi.org/10.3390/pr12050916.

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For over four decades, carbon dioxide (CO2) has been instrumental in enhancing oil extraction through advanced recovery techniques. One such method, water alternating gas (WAG) injection, while effective, grapples with limitations like gas channeling and gravity segregation. To tackle the aforementioned issues, this paper proposes an upgrade coupling method named alkaline-surfactant-polymer alternating gas (ASPAG). ASP flooding and CO2 are injected alternately into the reservoir to enhance the recovery of the WAG process. The uniqueness of this method lies in the fact that polymers could help

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18

Li, Guoqiao, Zhaohui Zhou, Jian Fan, et al. "Study on Microscopic Oil Displacement Mechanism of Alkaline–Surfactant–Polymer Ternary Flooding." Materials 17, no. 18 (2024): 4457. http://dx.doi.org/10.3390/ma17184457.

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Alkali–surfactant–polymer (ASP) flooding is one of the most effective and promising ways to enhance oil recovery (EOR). The synergistic effect between alkali, surfactant, and polymer can respectively promote emulsification performance, reduce interfacial tension, and improve bulk phase viscosity, thus effectively improving flooding efficiency. However, the displacement mechanism of ASP flooding and the contribution of different components to the oil displacement effect still need further discussion. In this study, five groups of chemical slugs were injected into the fracture model after water

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19

Wang, Qing Ji. "Development and Application of ASP Flooding Produced Fluid Demulsifier." Applied Mechanics and Materials 556-562 (May 2014): 603–6. http://dx.doi.org/10.4028/www.scientific.net/amm.556-562.603.

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Alkaline/surfactant/polymer (ASP) flooding has been applied to oil extraction in Daqing oilfield in several years. It is a great technology to improve oil recovery after polymer flooding. However, the agent would produce lots of fluid compositions, including a lot of polymer, alkaline and surfactant chemicals, which can improve the output of crude oil but increase the difficulty to disposal, such as fluid emulsion serious, smaller oil bead particle size and higher sewage viscosity and so on. An efficient demulsifier is urgent researched. In the paper, some development and application of common

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20

Vargo, Jay, Jim Turner, Vergnani Bob, et al. "Alkaline-Surfactant-Polymer Flooding of the Cambridge Minnelusa Field." SPE Reservoir Evaluation & Engineering 3, no. 06 (2000): 552–58. http://dx.doi.org/10.2118/68285-pa.

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Summary The Cambridge Minnelusa field alkaline-surfactant-polymer (ASP) flood was an economic and technical success, with ultimate incremental oil of 1,143,000 bbl at a cost of $2.42 per barrel. This success was due to an integrated approach of the application, including: reservoir engineering and geologic studies, laboratory chemical system design, numerical simulation, facilities design, and ongoing monitoring. This paper discusses how each of these was used in the design and evaluation of the Cambridge ASP project. Introduction The purpose of the alkaline-surfactant-polymer technology is to

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21

Stoll, W. M., H. al Shureqi, J. Finol, et al. "Alkaline/Surfactant/Polymer Flood: From the Laboratory to the Field." SPE Reservoir Evaluation & Engineering 14, no. 06 (2011): 702–12. http://dx.doi.org/10.2118/129164-pa.

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Summary After two decades of relative calm, chemical enhanced-oil-recovery (EOR) technologies are currently revitalized globally. Techniques such as alkaline/surfactant/polymer (ASP) flooding, originally developed by Shell, have the potential to recover significant fractions of remaining oil at a CO2 footprint that is low compared with, for example, thermal EOR, and they do not depend on a valuable miscible agent such as hydrocarbon gas. On the other hand, chemical EOR technologies typically require large quantities of chemical products such as surfactants and polymers, which must be transport

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22

Naukenova, A. Zh, B. E. Bekbauov та A. G. Amangossova. "Developing methodology and experimental procedure эfor experimental microfluidic study of chemical enhanced oil recovery". Bulletin of the National Engineering Academy of the Republic of Kazakhstan 87, № 1 (2023): 149–59. http://dx.doi.org/10.47533/2020.1606-146x.226.

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The concern of this research was to review the different methodology on microfluidic experiments conducted to study chemical enhanced oil recovery methods on micromodel chips. In general, there are several ways to study EOR methods such core flooding and microfluidics. The disadvantage of first method is that the flow processes inside the core sample cannot be imagined. Hence, the second method helps us to fully visualize how fluid flow behaviour occurs though the porous medium of the rocks. The various chemical EOR processes such as surfactant flooding, polymer flooding and ASP flooding were

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23

Wei, Nan Ning, and Liu Shuai Su. "Influence of Scaling in Alkaline/Surfactant/Polymer Flooding Surface Process." Advanced Materials Research 734-737 (August 2013): 1395–99. http://dx.doi.org/10.4028/www.scientific.net/amr.734-737.1395.

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With the Alkaline-surfactant-polymer (ASP) flooding production processs developing, deposition and scaling problems are serious in ground watering and gathering system, pronounced at watering pipeline and heating furnace. So challenges must be faced with in oilfield development process, such as energy consumption increase, equipments and pipelines are damaged easily, and equipments service life shortens. The component of scale sample, which is took from ASP flooding area of Xingbei Oilfield in Daqing Oilfield, in surface watering system is investigated. The influence factors and regulation of

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24

Naukenova, A. Zh, N. D. Sarsenbekov, and B. Ye Bekbauov. "A comprehensive review of polymer and alkaline/surfactant/polymer flooding applied and researched in Kazakhstan." Bulletin of the Karaganda University. "Chemistry" series 95, no. 3 (2019): 96–101. http://dx.doi.org/10.31489/2019ch3/96-101.

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25

Al Kalbani, Munther, Myles Jordan, Eric Mackay, Ken Sorbie, and Long Nghiem. "Modelling the impact of Alkaline-surfactant and Alkaline-surfactant-polymer flooding processes on scale precipitation and management." Journal of Petroleum Science and Engineering 205 (October 2021): 108777. http://dx.doi.org/10.1016/j.petrol.2021.108777.

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26

Tengku Mohd, Tengku Amran, Muhammad Ikhram Abdul Wahib, Nik Khairul Irfan Nik Ab Lah, et al. "Adsorption of anionic surfactant on surface of reservoir minerals in alkaline-surfactant-polymer system." Malaysian Journal of Chemical Engineering and Technology (MJCET) 4, no. 2 (2021): 124. http://dx.doi.org/10.24191/mjcet.v4i2.14986.

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Alkaline-surfactant-polymer (ASP) flooding is significant to the oil and gas industry due to synergistic interaction between alkaline, surfactant and polymer. However, chemical losses due to adsorptions of surfactant and polymer on the rock surface could lead to inefficiency of the process. There are also significant uncertainties on adsorption mechanism when surfactant is flooded with presence of alkaline and polymer. This study highlights the static adsorption tests using anionic sodium dodecyl sulphate (SDS), hydrolysed polyacrylamide (HPAM) and sodium carbonate (Na2CO3) as the surfactant,

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27

Korrani, Aboulghasem Kazemi, Kamy Sepehrnoori, and Mojdeh Delshad. "A Mechanistic Integrated Geochemical and Chemical-Flooding Tool for Alkaline/Surfactant/Polymer Floods." SPE Journal 21, no. 01 (2016): 32–54. http://dx.doi.org/10.2118/169094-pa.

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Summary Mechanistic simulation of alkaline/surfactant/polymer (ASP) flooding considers chemical reactions between the alkali and the oil to form in-situ soap and reactions between the alkali and the minerals and brine. A comprehensive mechanistic modeling of such process remains a challenge, mainly caused by the complicated ASP phase behavior and the complexity of geochemical reactions that occur in the reservoir. Because of the lack of the microemulsion phase and/or lack of reactions that may lead to the consumption of alkali and resulting lag in the pH, a simplified ASP phase behavior is oft

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28

Bús, Csaba, Bence Kutus, Áron Ágoston, László Janovák, and Pál Sipos. "Characterization of the Solution Properties of Sodium Dodecylsulphate Containing Alkaline–Surfactant–Polymer Flooding Media." Foundations 4, no. 2 (2024): 273–87. http://dx.doi.org/10.3390/foundations4020018.

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Alkaline–surfactant–polymer (ASP) flooding by means of which alkali additives, surfactant and polymer are inserted as the same slug is one of the most favourable worldwide focuses of Chemical Enhanced Oil Recovery (cEOR) research and field trials, due to the individual synergy of the three chemical components. To develop efficient oil recovery chemicals, it is essential to fully understand the mechanism behind ASP flooding. Nonetheless, there are hardly any studies reporting a systematic characterization of the ASP process. Thus, the present paper focuses on modelling this process in a laborat

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29

Turnaeva, E. A., E. A. Sidorovskaya, D. S. Adakhovskij, et al. "Oil emulsion characteristics as significance in efficiency forecast of oil-displacing formulations based on surfactants." Oil and Gas Studies, no. 3 (July 15, 2021): 91–107. http://dx.doi.org/10.31660/0445-0108-2021-3-91-107.

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Enhanced oil recovery in mature fields can be implemented using chemical flooding with the addition of surfactants using surfactant-polymer (SP) or alkaline-surfactant-polymer (ASP) flooding. Chemical flooding design is implemented taking into account reservoir conditions and composition of reservoir fluids. The surfactant in the oil-displacing formulation allows changing the rock wettability, reducing the interfacial tension, increasing the capillary number, and forming an oil emulsion, which provides a significant increase in the efficiency of oil displacement. The article is devoted with a

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30

Tengku Mohd, Tengku Amran, Nur Amelina Bohairah, Muhammad Shafiq Mat Shayuti, Nik Khairul Irfan Nik Ab Lah, Munawar Zaman Shahruddin, and Mohd Zaidi Jaafar. "Minimizing Adsorption of Anionic Surfactant in Alkaline-Surfactant-Polymer System: Effects of pH and Surfactant Concentration." Key Engineering Materials 939 (January 25, 2023): 75–82. http://dx.doi.org/10.4028/p-0huhs2.

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Alkaline-surfactant-polymer (ASP) flooding has been identified as the most effective enhanced oil recovery (EOR) technique to boost up the production of crude oil and improve the recoverable reserves. However, surfactant loss into the formation due to adsorption has been one of the issues, which could degrade the efficiency of the process. This study highlights the static adsorption of anionic sodium dodecyl sulphate (SDS) surfactant on the quartz sand with presences of alkaline and polymer at different pH and surfactant concentration. The critical micellar concentration (CMC) of SDS was deter

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Yin, Dandan, Dongfeng Zhao, Jianfeng Gao, and Jian Gai. "Experimental Study of Enhancing Oil Recovery with Weak Base Alkaline/Surfactant/Polymer." International Journal of Polymer Science 2017 (2017): 1–7. http://dx.doi.org/10.1155/2017/4652181.

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Na2CO3 was used together with surfactant and polymer to form the Alkaline/Surfactant/Polymer (ASP) flooding system. Interfacial tension (IFT) and emulsification of Dagang oil and chemical solutions were studied in the paper. The experiment results show that the ASP system can form super-low interfacial tension with crude oil and emulsified phase. The stability of the emulsion is enhanced by the Na2CO3, surfactant, and the soap generated at oil/water contact. Six core flooding experiments are conducted in order to investigate the influence of Na2CO3 concentration on oil recovery. The results sh

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32

Phukan, Ranjan, Subrata Borgohain Gogoi, and Pankaj Tiwari. "Alkaline-surfactant-alternated-gas/CO2 flooding: Effects of key parameters." Journal of Petroleum Science and Engineering 173 (February 2019): 547–57. http://dx.doi.org/10.1016/j.petrol.2018.10.043.

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Phukan, Ranjan, Subrata Borgohain Gogoi, and Pankaj Tiwari. "Enhanced oil recovery by alkaline-surfactant-alternated-gas/CO2 flooding." Journal of Petroleum Exploration and Production Technology 9, no. 1 (2018): 247–60. http://dx.doi.org/10.1007/s13202-018-0465-0.

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Liu, Qiang, Mingzhe Dong, Shanzhou Ma, and Yun Tu. "Surfactant enhanced alkaline flooding for Western Canadian heavy oil recovery." Colloids and Surfaces A: Physicochemical and Engineering Aspects 293, no. 1-3 (2007): 63–71. http://dx.doi.org/10.1016/j.colsurfa.2006.07.013.

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35

Sui, Xin, Zhao Chen, Ivan Kurnia, Xu Han, Jianjia Yu, and Guoyin Zhang. "Alkaline-surfactant-polymer flooding of active oil under reservoir conditions." Fuel 262 (February 2020): 116647. http://dx.doi.org/10.1016/j.fuel.2019.116647.

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Riswati, Shabrina Sri, Wisup Bae, Changhyup Park, Asep K. Permadi, and Adi Novriansyah. "Nonionic Surfactant to Enhance the Performances of Alkaline–Surfactant–Polymer Flooding with a Low Salinity Constraint." Applied Sciences 10, no. 11 (2020): 3752. http://dx.doi.org/10.3390/app10113752.

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This paper presents a nonionic surfactant in the anionic surfactant pair (ternary mixture) that influences the hydrophobicity of the alkaline–surfactant–polymer (ASP) slug within low-salinity formation water, an environment that constrains optimal designs of the salinity gradient and phase types. The hydrophobicity effectively reduced the optimum salinity, but achieving as much by mixing various surfactants has been challenging. We conducted a phase behavior test and a coreflooding test, and the results prove the effectiveness of the nonionic surfactant in enlarging the chemical applicability

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Sui, Xin, Hai Ming Wu, Bao Hui Wang, et al. "Scaling Laws and Forecasting Techniques of Silicate in ASP Flooding." Advanced Materials Research 850-851 (December 2013): 221–24. http://dx.doi.org/10.4028/www.scientific.net/amr.850-851.221.

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Served as alkaline-surfactant-polymer flooding for the enhanced oil recovery, alkaline-surfactant-polymer has widely been employed for Chinese oil production. In the practical opinion, the silicate scaling, which was formed by alkali, would harm layer gradually and affect oilfield production seriously. For the reason, in this paper, the phase diagrams of silicate scale were obtained in three different systems, including single silicon system, calcium/ magnesium/ silicon coexistence system, and calcium/ magnesium/ silicon/ aluminum coexistence system. The results showed that, other ions would a

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38

Andi Radi, Andi Mohd Syaiful, Mazlin Idress, and Farah Rosmaniza Redzuan. "THE STUDY OF THE EFFECT OF TEMPERATURE AND PH VALUE ON ADSORPTION CHARACTERISTICS OF UREA BASED SACRIFICIAL AGENT IN CLAY MINERALS." Platform : A Journal of Engineering 6, no. 4 (2022): 22. http://dx.doi.org/10.61762/pajevol6iss4art20973.

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The Enhanced Oil Recovery (EOR) process has grown within the time oil exploration was conducted, and many recovery methods were invented to maximize production. One of the promising recovery techniques is carbon dioxide (CO2) flooding. However, CO2 flooding has its disadvantages where due to different mobility and heterogeneity between CO2 and reservoir, the sweep efficiency is reduced because of gas channelling and viscous fingering. Thus, the application of surfactant is introduced to solve the problem. But, by using surfactants in CO2 flooding, loss of surfactant to the formation is observe

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39

Tengku Mohd, Tengku Amran, and Mohd Zaidi Jaafar. "Influences of Alkaline and Salinity on Adsorption Capacity of Anionic Sodium Dodecyl Sulfate Surfactant." Asia Proceedings of Social Sciences 2, no. 1 (2018): 19–23. http://dx.doi.org/10.31580/apss.v2i1.275.

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Chemical losses in surfactant flooding could substantially degrade the efficiency of the process. This study aims to analyze the prospect of alkaline in minimizing surfactant adsorption. Static adsorption tests were conducted to investigate the adsorption of anionic sodium dodecyl sulfate (SDS) surfactant on local sand and kaolinite surfaces. Alkaline (sodium carbonate) ranging from 1wt% to 3wt% were added into the surfactant formulation with local sand or kaolinite at fixed volume to mass ratio of 5:1. Brine (sodium chloride) concentrations were varied from 1wt% to 3wt%. Equilibrium adsorptio

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40

Novriansyah, Adi, Wisup Bae, Changhyup Park, Asep K. Permadi, and Shabrina Sri Riswati. "Optimal Design of Alkaline–Surfactant–Polymer Flooding under Low Salinity Environment." Polymers 12, no. 3 (2020): 626. http://dx.doi.org/10.3390/polym12030626.

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This paper presents an optimal design of alkaline–surfactant–polymer (ASP) flooding and an experimental analysis on the effects of ASP components under low formation salinity, where the assignment of salinity gradients and various phase types are limited. The phase behavior and coreflooding tests confirmed the ASP formula is optimal, i.e., 1 wt % sodium carbonate (Na2CO3) as the alkaline, 1:4 weight ratio for linear alkylbenzene sulfonate (LAS) and dioctyl sulfosuccinate (DOSS) as a surfactant, 5 wt % diethylene glycol monobutyl ether (DGBE) as a co-solvent, and hydrolyzed polyacrylamide (HPAM

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41

Adeyinka, Samson Oluwafemi, and Ijeoma Irene Mbachu. "An Experimental Investigation on Enhanced oil Recovery using Local Alkaline-Surfactant Solution for Niger-Delta Formation." Journal of Scientific and Engineering Research 10, no. 12 (2023): 47–58. https://doi.org/10.5281/zenodo.10466083.

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<strong>Abstract </strong>Ineffective methods of increasing oil recovery have been one of the challenges in the oil and gas industry, whose solutions are constantly sought after as the number of under-produced reservoirs increases daily. About 60% of crude Oil still lay trapped in the reservoir even after primary and secondary recovery process have been completed, hence the need for a method that further improves oil recovery. To mitigate these challenges and encourage the utilization of local contents, locally soured alkaline and surfactant were used in this research work as an Enhanced Oil R

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42

Demin, Wang, Zhang Zhenhua, Cheng Jiecheng, Yang Jingchun, Gao Shutang, and Lin Li. "Pilot Test of Alkaline Surfactant Polymer Flooding in Daqing Oil Field." SPE Reservoir Engineering 12, no. 04 (1997): 229–33. http://dx.doi.org/10.2118/36748-pa.

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Flaaten, Adam K., Quoc P. Nguyen, Jieyuan Zhang, Hourshad Mohammadi, and Gary A. Pope. "Alkaline/Surfactant/Polymer Chemical Flooding Without the Need for Soft Water." SPE Journal 15, no. 01 (2009): 184–96. http://dx.doi.org/10.2118/116754-pa.

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Summary Alkaline/surfactant/polymer (ASP) flooding using conventional alkali requires soft water. However, soft water is not always available, and softening hard brines may be very costly or infeasible in many cases depending on the location, the brine composition, and other factors. For instance, conventional ASP uses sodium carbonate to reduce the adsorption of the surfactant and generate soap in-situ by reacting with acidic crude oils; however, calcium carbonate precipitates unless the brine is soft. A form of borax known as metaborate has been found to sequester divalent cations such as Ca

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44

Mahat, Siti Qurratu’ Aini, Ismail Mohd Saaid, and Bhajan Lal. "Green silica scale inhibitors for Alkaline-Surfactant-Polymer flooding: a review." Journal of Petroleum Exploration and Production Technology 6, no. 3 (2015): 379–85. http://dx.doi.org/10.1007/s13202-015-0187-5.

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Fortenberry, R., D. H. H. Kim, N. Nizamidin, et al. "Use of Cosolvents To Improve Alkaline/Polymer Flooding." SPE Journal 20, no. 02 (2014): 255–66. http://dx.doi.org/10.2118/166478-pa.

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Summary We have found that the addition of low concentrations of certain inexpensive light cosolvents to alkaline/polymer (AP) solutions dramatically improves the performance of AP corefloods in two important ways. First, the addition of cosolvent promotes the formation of low-viscosity microemulsions rather than viscous macroemulsions. Second, these light cosolvents greatly improve the phase behavior in a way that can be tailored to a particular oil, temperature, and salinity. This new chemical enhanced-oil-recovery (EOR) technology uses polymer for mobility control and has been termed alkali

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Mohsenatabar Firozjaii, Ali, Amin Derakhshan, and Seyed Reza Shadizadeh. "An investigation into surfactant flooding and alkaline-surfactant-polymer flooding for enhancing oil recovery from carbonate reservoirs: Experimental study and simulation." Energy Sources, Part A: Recovery, Utilization, and Environmental Effects 40, no. 24 (2018): 2974–85. http://dx.doi.org/10.1080/15567036.2018.1514439.

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Li, Jiexun, Yang Liu, Zhihua Wang, Jigang Wang, and Tianyu Yu. "Case Study: Fluorocarbon Coating Provides Corrosion Protection in Oilfield Flooding System." Materials Performance 55, no. 9 (2016): 40–44. https://doi.org/10.5006/mp2016_55_9-40.

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Fluorocarbon coating technology is promising for addressing coating failures in oilfield facilities. Internal corrosion in the alkaline-surfactant-polymer flooding system in China’s Daqing Oilfield was surveyed, and several anti-corrosion measures were demonstrated. A program of coating the facilities with fluorocarbons has been proposed. The mechanical properties of the fluorocarbon coating were tested, along with an evaluation of the corrosion mechanism involved and the corrosion resistance of the coating.

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Zolfaghari, Reza, Luqman C. Abdullah, Dayang R. A. Biak, and Shahidan Radiman. "Cationic Surfactants for Demulsification of Produced Water from Alkaline–Surfactant–Polymer Flooding." Energy & Fuels 33, no. 1 (2018): 115–26. http://dx.doi.org/10.1021/acs.energyfuels.8b03266.

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Sedaghat, Mohammad Hossein, Mohammad Hossein Ghazanfari, and Mohsen Masihi. "Simultaneous/sequential alkaline-surfactant-polymer flooding in fractured/non-fractured carbonate reservoirs." Canadian Journal of Chemical Engineering 92, no. 5 (2014): 918–27. http://dx.doi.org/10.1002/cjce.21984.

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Zhou, Yazhou, and Daiyin Yin. "Preparation and Performance Evaluation of Alkali-resistant Gel-type Deep Profile Agent." Open Fuels & Energy Science Journal 9, no. 1 (2016): 21–27. http://dx.doi.org/10.2174/1876973x01609010021.

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Currently, most profile control agents would be degraded in strong alkaline condition. They could not be applied in ASP (alkaline, surfactant and partially hydrolyzed polyacrylamide) flooding. To solve this problem, a new kind of alkali-resistant gel for deep profile has been studied. Based on the profile control mechanism of profile agent and the crosslinking mechanism of the polymer, the selection of the chemical agent with different type and concentration was carried out in strong alkaline (pH=12), using ordinary polymer as the main agent, organic and inorganic chemical crosslinking agent.

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