Log in

Relevant bibliographies by topics / Surfactant/polymer flooding / Journal articles

To see the other types of publications on this topic, follow the link: Surfactant/polymer flooding.

Journal articles on the topic 'Surfactant/polymer flooding'

Author: Grafiati

Published: 4 June 2021

Last updated: 14 February 2022

Create a spot-on reference in APA, MLA, Chicago, Harvard, and other styles

Select a source type:

Consult the top 50 journal articles for your research on the topic 'Surfactant/polymer flooding.'

Next to every source in the list of references, there is an 'Add to bibliography' button. Press on it, and we will generate automatically the bibliographic reference to the chosen work in the citation style you need: APA, MLA, Harvard, Chicago, Vancouver, etc.

You can also download the full text of the academic publication as pdf and read online its abstract whenever available in the metadata.

Browse journal articles on a wide variety of disciplines and organise your bibliography correctly.

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.

Full text

APA, Harvard, Vancouver, ISO, and other styles

2

Zhou, Haiyan, and Afshin Davarpanah. "Hybrid Chemical Enhanced Oil Recovery Techniques: A Simulation Study." Symmetry 12, no. 7 (2020): 1086. http://dx.doi.org/10.3390/sym12071086.

Full text

Abstract:

Simultaneous utilization of surfactant and preformed particle gel (henceforth; PPG) flooding on the oil recovery enhancement has been widely investigated as a preferable enhanced oil recovery technique after the polymer flooding. In this paper, a numerical model is developed to simulate the profound impact of hybrid chemical enhanced oil recovery methods (PPG/polymer/surfactant) in sandstone reservoirs. Moreover, the gel particle conformance control is considered in the developed model after polymer flooding performances on the oil recovery enhancement. To validate the developed model, two set

APA, Harvard, Vancouver, ISO, and other styles

3

Han, Xu, Ming Lu, Yixuan Fan, Yuxi Li, and Krister Holmberg. "Recent Developments on Surfactants for Enhanced Oil Recovery." Tenside Surfactants Detergents 58, no. 3 (2021): 164–76. http://dx.doi.org/10.1515/tsd-2020-2340.

Full text

Abstract:

Abstract This review discusses surfactants used for chemical flooding, including surfactant-polymer flooding and alkali-surfactant-polymer flooding. The review, unlike most previous reviews in the field, has a surfactant focus, not a focus on the flooding process. It deals with recent results, mainly from 2010 and onward. Older literature is referred to when needed in order to put more recent findings into a perspective.

APA, Harvard, Vancouver, ISO, and other styles

4

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.

Full text

Abstract:

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

APA, Harvard, Vancouver, ISO, and other styles

5

Cong, Su Nan, and Wei Dong Liu. "Microscopic Displacement Mechanism of Surfactant/Polymer Driving Residual Oil in Conglomerate Reservoir." Advanced Materials Research 301-303 (July 2011): 483–87. http://dx.doi.org/10.4028/www.scientific.net/amr.301-303.483.

Full text

Abstract:

According to microcosmic porous and throats model’s experiment which will be performed in Kexia layer, Qizhong district of conglomerate reservoir in Xinjiang oil fields, microscopic displacement mechanism of surfactant/polymer flooding was researched. Surfactant/polymer flooding has a significant effect on enhancing oil recovery because of the effect from the polymer’s viscosity and the surfactant’s interfacial tension. According to microcosmic porous and throats model’s experiment, the best polymer viscosity and surfactant interfacial tension were determined.

APA, Harvard, Vancouver, ISO, and other styles

6

Sun, Chen, and Yiqiang Li. "Polymer Blocking Distribution and Causes Analysis during Surfactant/Polymer Flooding in Conglomerate Reservoir." International Journal of Chemical Engineering and Applications 7, no. 5 (2016): 336–39. http://dx.doi.org/10.18178/ijcea.2016.7.5.601.

Full text

APA, Harvard, Vancouver, ISO, and other styles

7

Jiang, Wen Chao, Jian Zhang, Kao Ping Song, En Gao Tang, and Bin Huang. "Study on the Surfactant/Polymer Combination Flooding Relative Permeability Curves in Offshore Heavy Oil Reservoirs." Advanced Materials Research 887-888 (February 2014): 53–56. http://dx.doi.org/10.4028/www.scientific.net/amr.887-888.53.

Full text

Abstract:

Different kinds of compound solutions were prepared by using different concentrations of hydrophobically associating polymers and sulfonate type surfactant. The static viscosity and interfacial tension of these solutions were measured. On the experimental conditions of the Suizhong 36-1 oilfield, the relative permeability curves of the water flooding and the surfactant/polymer combination flooding were measured through the constant speed unsteady method and the experimental data were processed through the way of J.B.N. The several existing kinds of viscosity processing methods of non-newtonian

APA, Harvard, Vancouver, ISO, and other styles

8

Druetta, Pablo, and Francesco Picchioni. "Surfactant-Polymer Interactions in a Combined Enhanced Oil Recovery Flooding." Energies 13, no. 24 (2020): 6520. http://dx.doi.org/10.3390/en13246520.

Full text

Abstract:

The traditional Enhanced Oil Recovery (EOR) processes allow improving the performance of mature oilfields after waterflooding projects. Chemical EOR processes modify different physical properties of the fluids and/or the rock in order to mobilize the oil that remains trapped. Furthermore, combined processes have been proposed to improve the performance, using the properties and synergy of the chemical agents. This paper presents a novel simulator developed for a combined surfactant/polymer flooding in EOR processes. It studies the flow of a two-phase, five-component system (aqueous and organic

APA, Harvard, Vancouver, ISO, and other styles

9

Ding, Lei, Qianhui Wu, Lei Zhang, and Dominique Guérillot. "Application of Fractional Flow Theory for Analytical Modeling of Surfactant Flooding, Polymer Flooding, and Surfactant/Polymer Flooding for Chemical Enhanced Oil Recovery." Water 12, no. 8 (2020): 2195. http://dx.doi.org/10.3390/w12082195.

Full text

Abstract:

Fractional flow theory still serves as a powerful tool for validation of numerical reservoir models, understanding of the mechanisms, and interpretation of transport behavior in porous media during the Chemical-Enhanced Oil Recovery (CEOR) process. With the enrichment of CEOR mechanisms, it is important to revisit the application of fractional flow theory to CEOR at this stage. For surfactant flooding, the effects of surfactant adsorption, surfactant partition, initial oil saturation, interfacial tension, and injection slug size have been systematically investigated. In terms of polymer floodi

APA, Harvard, Vancouver, ISO, and other styles

10

Li, Jierui, Weidong Liu, Guangzhi Liao, Linghui Sun, Sunan Cong, and Ruixuan Jia. "Chemical Migration and Emulsification of Surfactant-Polymer Flooding." Journal of Chemistry 2019 (October 20, 2019): 1–8. http://dx.doi.org/10.1155/2019/3187075.

Full text

Abstract:

With a long sand-packed core with multiple sample points, a laboratory surfactant-polymer flooding experiment was performed to study the emulsification mechanism, chemical migration mechanism, and the chromatographic separation of surfactant-polymer flooding system. After water flooding, the surfactant-polymer flooding with an emulsified system enhances oil recovery by 17.88%. The water cut of produced fluid began to decrease at the injection of 0.4 pore volume (PV) surfactant-polymer slug and got the minimum at 1.2 PV. During the surfactant-polymer flooding process, the loss of polymer is sma

APA, Harvard, Vancouver, ISO, and other styles

11

Fathaddin, Muhammad Taufiq, Asri Nugrahanti, Putri Nurizatulshira Buang, and Khaled Abdalla Elraies. "SURFACTANT-POLYMER FLOODING PERFORMANCE IN HETEROGENEOUS TWO-LAYERED POROUS MEDIA." IIUM Engineering Journal 12, no. 1 (2011): 31–38. http://dx.doi.org/10.31436/iiumej.v12i1.37.

Full text

Abstract:

In this paper, simulation study was conducted to investigate the effect of spatial heterogeneity of multiple porosity fields on oil recovery, residual oil and microemulsion saturation. The generated porosity fields were applied into UTCHEM for simulating surfactant-polymer flooding in heterogeneous two-layered porous media. From the analysis, surfactant-polymer flooding was more sensitive than water flooding to the spatial distribution of multiple porosity fields. Residual oil saturation in upper and lower layers after water and polymer flooding was about the same with the reservoir heterogene

APA, Harvard, Vancouver, ISO, and other styles

12

Li, Yi Qiang, Zhe Yu Liu, Yan Yue Li, and Yi Bo Xu. "Research on the Remaining Oil Starting Mechanism in Different Pores of Polymer Surfactants Using NMR Analysis." Advanced Materials Research 1010-1012 (August 2014): 1727–34. http://dx.doi.org/10.4028/www.scientific.net/amr.1010-1012.1727.

Full text

Abstract:

With its unique structure and properties, polymer surfactants have been used in chemical flooding. Compared with ordinary polymer, polymer surfactants have a higher recovery degree. However, remaining oil starting mechanism in different pores using different polymer surfactants after water flooding is still unclear. NMR (Nuclear Magnetic Resonance) has a good effect on determination of rock oil saturation and analysis of pore structure. In this paper, oil displacement experiment using kerosene which contains no hydrogen was conducted and the problem caused by the similarity between oil phase r

APA, Harvard, Vancouver, ISO, and other styles

13

Wu, Wen Xiang, Deng Hui Mu, and Qing Dong Liu. "Study on Physical Simulation Experiments of Different Chemical Displacement Systems." Advanced Materials Research 201-203 (February 2011): 2562–66. http://dx.doi.org/10.4028/www.scientific.net/amr.201-203.2562.

Full text

Abstract:

In the reservoir condition of Liaohe oil field, the indoor physical simulation experiments of polymer / surfactant binary combination flooding and polymer / surfactant / alkali (ASP) flooding in the artificial cores have been conducted. The results show that enhanced oil recovery of polymer flooding is about 24.4%, by utilizing experiment project that polymer molecular weight is 19 million, main slug concentration is 1500mg/L. Binary flooding system that molecular weight of polymer is 19 million, main slug concentration is 1500mg/L, 0.3% surfactant YR has improved the oil recovery by 30.1%. Th

APA, Harvard, Vancouver, ISO, and other styles

14

Zhang, Ji Hong, Yu Wang, Xi Ling Chen, Zi Wei Qu, and Dong Ke Qin. "The Effect of Following Water after Polymer Flooding on the Displacement Efficiency with Alternately Injecting Slug of Gel and Polymer/Surfactant." Advanced Materials Research 734-737 (August 2013): 1290–93. http://dx.doi.org/10.4028/www.scientific.net/amr.734-737.1290.

Full text

Abstract:

Aiming at the development of remaining oil after polymer flooding, the author develops an oil displacement technology, alternately injecting the slug of the gel and polymer/surfactant compound system, which can advanced improve the remained oil after polymer flooding. By using the artificial large flat-panel model, the oil displacement experiments are carried on to study the injection characteristics and the displacement efficiency of the alternately injecting the slug of gel and polymer/surfactant compound system, and whether the following water should be injected after polymer flooding has b

APA, Harvard, Vancouver, ISO, and other styles

15

He, Chen, Yu, Wen, and Liu. "Optimization Design of Injection Strategy for Surfactant-Polymer Flooding Process in Heterogeneous Reservoir under Low Oil Prices." Energies 12, no. 19 (2019): 3789. http://dx.doi.org/10.3390/en12193789.

Full text

Abstract:

Surfactant–polymer (SP) flooding has significant potential to enhance oil recovery after water flooding in mature reservoirs. However, the economic benefit of the SP flooding process is unsatisfactory under low oil prices. Thus, it is necessary to reduce the chemical costs and improve SP flooding efficiency to make SP flooding more profitable. Our goal was to maximize the incremental oil recovery of the SP flooding process after water flooding by using the equal chemical consumption cost to ensure the economic viability of the SP flooding process. Thus, a systematic study was carried out to in

APA, Harvard, Vancouver, ISO, and other styles

16

Chen, Yuqiu, Hong He, Qun Yu, et al. "Insights into Enhanced Oil Recovery by Polymer-Viscosity Reducing Surfactant Combination Flooding in Conventional Heavy Oil Reservoir." Geofluids 2021 (May 22, 2021): 1–12. http://dx.doi.org/10.1155/2021/7110414.

Full text

Abstract:

Polymer flooding has a significant potential to enhance oil recovery in a light oil reservoir. However, for polymer flooding in a conventional heavy oil reservoir, due to unfavorable mobility ratio between water and oil, the improvement of sweep efficiency is limited, resulting in a low incremental oil recovery and failure to achieve high-efficiency development for polymer flooding in a conventional heavy oil reservoir. Inspired by the EOR mechanisms of the surfactant-polymer (SP) flooding process, the polymer-viscosity reducing surfactant flooding (P-VRSF) system was proposed to enhance conve

APA, Harvard, Vancouver, ISO, and other styles

17

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.

Full text

APA, Harvard, Vancouver, ISO, and other styles

18

Wang, Guo Feng, Lian Zhen Song, Zhi Li Wei, and Xue Wu Wang. "A Laboratory Study of Polymer and Surfactant Binary Combination Flooding in Reservoirs with Low to Medium Permeability." Advanced Materials Research 718-720 (July 2013): 233–38. http://dx.doi.org/10.4028/www.scientific.net/amr.718-720.233.

Full text

Abstract:

Based on the viscosity of 10mPa.s after high speed shearing and the limit surfactants up to ultra-low interfacial tension, polymers and surfactant systems suitable for Longhupao oilfield were optimized by means of mixing formation simulation water with different polymers and surfactants. The relationship between the interfacial tension of the compound system and the component concentration, the effect of surfactants on viscosity, the injectivity of the compound system, etc. were studied on the basis of the research on the binary compound system. The results indicate that the viscosity of the c

APA, Harvard, Vancouver, ISO, and other styles

19

Jin, Baoguang, Hanqiao Jiang, Xiansong Zhang, Jing Wang, Jing Yang, and Wei Zheng. "Numerical Simulation of Surfactant-Polymer Flooding." Chemistry and Technology of Fuels and Oils 50, no. 1 (2014): 55–70. http://dx.doi.org/10.1007/s10553-014-0490-8.

Full text

APA, Harvard, Vancouver, ISO, and other styles

20

Yuan, Fu Qing, and Zhen Quan Li. "An Easy Calculation Method on Sweep Efficiency of Chemical Flooding." Applied Mechanics and Materials 275-277 (January 2013): 496–501. http://dx.doi.org/10.4028/www.scientific.net/amm.275-277.496.

Full text

Abstract:

According to the geological parameters of Shengli Oilfield, sweep efficiency of chemical flooding was analyzed according to injection volume, injection-production parameters of polymer flooding or surfactant-polymer compound flooding. The orthogonal design method was employed to select the important factors influencing on expanding sweep efficiency by chemical flooding. Numerical simulation method was utilized to analyze oil recovery and sweep efficiency of different flooding methods, such as water flooding, polymer flooding and surfactant-polymer compound flooding. Finally, two easy calculati

APA, Harvard, Vancouver, ISO, and other styles

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.

Full text

Abstract:

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

APA, Harvard, Vancouver, ISO, and other styles

22

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.

Full text

Abstract:

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

APA, Harvard, Vancouver, ISO, and other styles

23

Taiwo, Oluwaseun, Kelani Bello, Ismaila Mohammed, and Olalekan Olafuyi. "Characterization of Surfactant Flooding for Light Oil Using Gum Arabic." International Journal of Engineering Research in Africa 21 (December 2015): 136–47. http://dx.doi.org/10.4028/www.scientific.net/jera.21.136.

Full text

Abstract:

Surfactant flooding, a chemical IOR technique is one of the viable EOR processes for recovering additional oil after water flooding. This is because it reduces the interfacial tension between the oil and water and allows trapped oil to be released for mobilization by a polymer.In this research, two sets of experiments were performed. First, the optimum surfactant concentration was determined through surfactant polymer flooding using a range of surfactant concentration of 0.1% to 0.6% and 15% of polymer. Secondly, another set of experiments to determine the optimum flow rate for surfactant floo

APA, Harvard, Vancouver, ISO, and other styles

24

Shakeel, Mariam, Aida Samanova, Peyman Pourafshary, and Muhammad Rehan Hashmet. "Capillary Desaturation Tendency of Hybrid Engineered Water-Based Chemical Enhanced Oil Recovery Methods." Energies 14, no. 14 (2021): 4368. http://dx.doi.org/10.3390/en14144368.

Full text

Abstract:

Several studies have shown the synergetic benefits of combining various chemical enhanced oil recovery (CEOR) methods with engineered waterflooding (EWF) in both sandstones and carbonate formations. This paper compares the capillary desaturation tendency of various hybrid combinations of engineered water (EW) and CEOR methods with their conventional counterparts. Several coreflood experiments were conducted, including EW-surfactant flooding (EWSF), EW-polymer flooding (EWPF), EW-alkali-surfactant flooding (EWASF), EW-surfactant-polymer flooding (EWSPF), and EW-alkali-surfactant-polymer floodin

APA, Harvard, Vancouver, ISO, and other styles

25

Yan, Limin, Zhenggang Cui, Binglei Song, Xiaomei Pei, and Jianzhong Jiang. "Dioctyl Glyceryl Ether Ethoxylates as Surfactants for Surfactant–Polymer Flooding." Energy & Fuels 30, no. 7 (2016): 5425–31. http://dx.doi.org/10.1021/acs.energyfuels.6b00472.

Full text

APA, Harvard, Vancouver, ISO, and other styles

26

Zhang, Rong Jun, Xiao Ke Wang, Jin Lin Zhao, Zheng Peng Zhou, and Gang Chen. "Evaluation of a Composite Flooding Formula Used to Enhance the Oil Recovery of Ansai Oil Field." Materials Science Forum 984 (April 2020): 183–88. http://dx.doi.org/10.4028/www.scientific.net/msf.984.183.

Full text

Abstract:

The composite flooding formula utilizes the characteristics of polymer flooding and surfactant flooding to compensate for the shortage of single component chemical flooding, reduce the oil-water interfacial tension to a certain extent, and broaden the maintenance range of low interfacial tension. The combined effects and synergies in the oil displacement process enhance oil recovery and allow it to adapt to a wider range of reservoir conditions. In this paper, the high surface active polymer-surfactant flooding formula suitable for the Chang 6 reservoir in Ansai Oilfield was evaluated. The gen

APA, Harvard, Vancouver, ISO, and other styles

27

Al Kalbani, M. M., M. M. Jordan, E. J. Mackay, K. S. Sorbie, and L. Nghiem. "Barium Sulfate Scaling and Control during Polymer, Surfactant, and Surfactant/Polymer Flooding." SPE Production & Operations 35, no. 01 (2020): 068–84. http://dx.doi.org/10.2118/193575-pa.

Full text

APA, Harvard, Vancouver, ISO, and other styles

28

Liu, Yang, Jian Zhang, Xingcai Wu, et al. "Experimental Investigation on a Novel Particle Polymer for Enhanced Oil Recovery in High Temperature and High Salinity Reservoirs." Journal of Chemistry 2021 (April 22, 2021): 1–8. http://dx.doi.org/10.1155/2021/5593038.

Full text

Abstract:

Conventional polymer flooding include polymer flooding, surfactant-polymer flooding (SP), alkaline-surfactant-polymer flooding (ASP), and crosslinked polymer gel flooding. However, these technologies in oilfield, especially in high temperature and high salinity, are limited due to the poor ability of temperature and salinity resistance of polymer. In this work, a novel polymer particle (soft microgel, SMG) is used as the research object under the reservoir condition of high salinity (20 × 104 mg/L) to evaluate the physical and chemical properties of submillimeter-scale SMG and the effect of pr

APA, Harvard, Vancouver, ISO, and other styles

29

Sun, Chen, Hu Guo, Yiqiang Li, and Kaoping Song. "Recent Advances of Surfactant-Polymer (SP) Flooding Enhanced Oil Recovery Field Tests in China." Geofluids 2020 (May 26, 2020): 1–16. http://dx.doi.org/10.1155/2020/8286706.

Full text

Abstract:

Recently, there are increasing interests in chemical enhanced oil recovery (EOR) especially surfactant-polymer (SP) flooding. Although alkali-surfactant-polymer (ASP) flooding can make an incremental oil recovery factor (IORF) of 18% original oil in place (OOIP) according to large-scale field tests in Daqing, the complex antiscaling and emulsion breaking technology as well as potential environment influence makes some people turn to alkali-free SP flooding. With the benefit of high IORF in laboratory and no scaling issue to worry, SP flooding is theoretically better than ASP flooding when high

APA, Harvard, Vancouver, ISO, and other styles

30

Tang, Shan Fa, Xiao Dong Hu, Xiang Nan Ouyang, Shuang Xi Yan, Shou Cheng Wen, and Yan Ling Lai. "Experimental Study of Anionic Gemini Surfactant Enhancing Waterflooding Recovery Ratio." Advanced Materials Research 361-363 (October 2011): 469–72. http://dx.doi.org/10.4028/www.scientific.net/amr.361-363.469.

Full text

Abstract:

The oil-water interfacial tension measurement and enhancing water displacement recovery experiment were carried out, and the effects of various parameters such as category of surfactants, anionic Gemini surfactant concentration, water medium salinity, core permeability, polymer and non-ionic surfactant on anionic Gemini surfactants enhancing water displacement recovery were investigated in detail. The results show that surfactants category is different, its enhancing water flooding recovery efficiency is different, and effect of enhanced oil recovery is consistent with surfactant ability to re

APA, Harvard, Vancouver, ISO, and other styles

31

Rai, Khyati, Russell T. Johns, Mojdeh Delshad, Larry W. Lake, and Ali Goudarzi. "Oil-recovery predictions for surfactant polymer flooding." Journal of Petroleum Science and Engineering 112 (December 2013): 341–50. http://dx.doi.org/10.1016/j.petrol.2013.11.028.

Full text

APA, Harvard, Vancouver, ISO, and other styles

32

Liu, Yang, and Jiu Hong Feng. "The Evaluation Experiment Research on Sp Binary Composite System Performance and the Oil Displacement Effect." Advanced Materials Research 807-809 (September 2013): 2534–43. http://dx.doi.org/10.4028/www.scientific.net/amr.807-809.2534.

Full text

Abstract:

SP binary composite system can reduce the interfacial tension, has good viscoelasticity, and has similar displacement effect with ASP ternary composite system. In addition, the scaling formation can be weaken because it does not contain alkali. Therefore, it plays a important role in guiding the formulas of SP binary composite system and designing the injection scheme to evaluate the main performance and oil displacement effect of SP binary composite system. Experiments on the main performance evaluation, microscopic simulation model for oil displacement and oil displacement in cores have been

APA, Harvard, Vancouver, ISO, and other styles

33

Li, Jierui, Weidong Liu, Linghui Sun, et al. "Effect of Emulsification on Surfactant Partitioning in Surfactant‐Polymer Flooding." Journal of Surfactants and Detergents 22, no. 6 (2019): 1387–94. http://dx.doi.org/10.1002/jsde.12353.

Full text

APA, Harvard, Vancouver, ISO, and other styles

34

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.

Full text

Abstract:

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

APA, Harvard, Vancouver, ISO, and other styles

35

Wang, Ke Liang, Guang Pu Jiao, Han Feng, and Tian Tian Fu. "Experiment Research of Flooding Efficiency on Alternative Injection of Low-Tension System and Foam System." Advanced Materials Research 524-527 (May 2012): 1389–94. http://dx.doi.org/10.4028/www.scientific.net/amr.524-527.1389.

Full text

Abstract:

To make binary low-tension system play a vital role in improving oil displacement efficiency and foam system expand swept volume, binary low-tension system alternates with binary foam system flooding laboratory research is carried out after the polymer flooding technology. The method of airflow is used to proceed with foaming performance experiments by nitrogen gas. Surfactant CYL which foaming performance is stronger has good compatibility with alkali-free surfactant. The evaluation of the interfacial tension experiments shows that surfactant HLX has a low interfacial tension; the HLX's abili

APA, Harvard, Vancouver, ISO, and other styles

36

Wang, Ke-Liang, Lei-Lei Zhang, Xue Li, and Yang-Yang Ming. "Experimental Study on the Properties and Displacement Effects of Polymer Surfactant Solution." Journal of Chemistry 2013 (2013): 1–6. http://dx.doi.org/10.1155/2013/956027.

Full text

Abstract:

Based on the characteristics of oil reservoirs and the requirements of further enhancing oil recovery at high water cut stage of Pubei Oilfield, the displacement performance of polymer surfactant is evaluated. Reasonable injection parameters and oil displacement effects after water flooding are also researched. Compared with conventional polymer with intermediate molecular weight, polymer surfactant has the properties of higher viscosity at low concentration condition and lower interfacial tension. Laboratory experiments indicate that the displacement effect of polymer surfactant is much bette

APA, Harvard, Vancouver, ISO, and other styles

37

Lv, Peng, Ming Yuan Li, and Mei Qin Lin. "Optimization of Surfactant and Polymer for SP Flooding of Zahra Oil." Applied Mechanics and Materials 535 (February 2014): 701–4. http://dx.doi.org/10.4028/www.scientific.net/amm.535.701.

Full text

Abstract:

Producing ultra-low interfacial tensions and maintaining high viscosity is the most important mechanism relating to SP flooding for enhanced oil recovery. The interfacial tension between surfactant (PJZ-2 and BE)/polymer solution and Zahra oil was evaluated in the work. Based on the evaluatiojn of interfacial tension, the polymer FP6040s/surfactant BE system was selected as the SP flooding system for Zahra oil field.

APA, Harvard, Vancouver, ISO, and other styles

38

Guo, Yaohao, Lei Zhang, Guangpu Zhu, et al. "A Pore-Scale Investigation of Residual Oil Distributions and Enhanced Oil Recovery Methods." Energies 12, no. 19 (2019): 3732. http://dx.doi.org/10.3390/en12193732.

Full text

Abstract:

Water flooding is an economic method commonly used in secondary recovery, but a large quantity of crude oil is still trapped in reservoirs after water flooding. A deep understanding of the distribution of residual oil is essential for the subsequent development of water flooding. In this study, a pore-scale model is developed to study the formation process and distribution characteristics of residual oil. The Navier–Stokes equation coupled with a phase field method is employed to describe the flooding process and track the interface of fluids. The results show a significant difference in resid

APA, Harvard, Vancouver, ISO, and other styles

39

Han, Choongyong, Mojdeh Delshad, Kamy Sepehrnoori, and Gary Arnold Pope. "A Fully Implicit, Parallel, Compositional Chemical Flooding Simulator." SPE Journal 12, no. 03 (2007): 322–38. http://dx.doi.org/10.2118/97217-pa.

Full text

Abstract:

Summary A fully implicit, parallel, compositional reservoir simulator has been developed that includes both a cubic equation of state model for the hydrocarbon phase behavior and Hand's rule for the surfactant/oil/brine phase behavior. The aqueous species in the chemical model include surfactant, polymer, and salt. The physical property models include surfactant/oil/brine phase behavior, interfacial tension, viscosity, adsorption, and relative permeability as a function of trapping number. The fully implicit simulation results were validated by comparison with results from our IMPEC chemical f

APA, Harvard, Vancouver, ISO, and other styles

40

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.

Full text

Abstract:

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

APA, Harvard, Vancouver, ISO, and other styles

41

Skripkin, A. G., I. N. Koltsov, and S. V. Milchakov. "Experimental studies of the capillary desaturation curve in polymer-surfactant flooding." PROneft’. Proffessional’no o nefti 6, no. 1 (2021): 40–46. http://dx.doi.org/10.51890/2587-7399-2021-6-1-40-46.

Full text

Abstract:

The paper presents the results of laboratory studies of polymer-surfactant flooding on core samples of different permeability. The obtained data are used in hydrodynamic modeling. Experimental studies included: • study of the dynamics of oil displacement, plotting the dependence of the residual oil saturation on the surfactant concentration – interfacial tension at the interface of the surfactant-oil solution; • comparative experimental studies of residual oil saturation when oil is displaced by surfactant compositions of various manufacturers; • comparative studies of

APA, Harvard, Vancouver, ISO, and other styles

42

Feng, Ru-Sen, Yong-Jun Guo, Xin-Min Zhang, Jun Hu, and Hua-Bing Li. "Alkali/Surfactant/Polymer Flooding in the Daqing Oilfield Class II Reservoirs Using Associating Polymer." Journal of Chemistry 2013 (2013): 1–6. http://dx.doi.org/10.1155/2013/275943.

Full text

Abstract:

Hydrophobically modified associating polyacrylamide (HAPAM) has good compatibility with the Daqing heavy alkylbenzene sulfonate surfactant. The HAPAM alkali/surfactant/polymer (ASP) system can generate ultralow interfacial tension in a wide range of alkali/surfactant concentrations and maintain stable viscosity and interfacial tension for 120 days. The HAPAM ASP system has good injectivity for the Daqing class II reservoirs (100–300 × 10−3 μm2) and can improve oil recovery by more than 25% on top of water flooding. In the presence of both the alkali and the surfactant, the surfactant interacts

APA, Harvard, Vancouver, ISO, and other styles

43

Xiao, Han Min, Ling Hui Sun, and Hui Hui Kou. "Mass Transfer Mechanisms of ASP Flooding in Porous Media." Advanced Materials Research 550-553 (July 2012): 2738–44. http://dx.doi.org/10.4028/www.scientific.net/amr.550-553.2738.

Full text

Abstract:

Experiments on chromatography separation are taken for ASP flooding. Mass transfer equation is estabilished and mutiple adsorption factor is obtained. Mutiple adsorption factor is used to analyze the experiment results. The Mass transfer property of alkali, surfactant and polymer during single fooding and ASP flooding and the effect on interfacial tension of oil/solution are discussed. The results show the diffrence of hesteris degree of alkali, surfactant and polymer deduce the chromatography separation, lowing the active of ASP flooding. Accoding to interfacial tension, the efficent length o

APA, Harvard, Vancouver, ISO, and other styles

44

Xuan, Yinglong, Desheng Ma, Minghui Zhou, and Ming Gao. "Significance of polymer on emulsion stability in surfactant-polymer flooding." Journal of Applied Polymer Science 132, no. 26 (2015): n/a. http://dx.doi.org/10.1002/app.42171.

Full text

APA, Harvard, Vancouver, ISO, and other styles

45

Yin, Dandan, and Dongfeng Zhao. "Main Controlling Factor of Polymer-Surfactant Flooding to Improve Recovery in Heterogeneous Reservoir." Advances in Materials Science and Engineering 2017 (2017): 1–8. http://dx.doi.org/10.1155/2017/5247305.

Full text

Abstract:

This study aims to analyze the influence of viscosity and interfacial tension (IFT) on the recovery in heterogeneous reservoir and determines the main controlling factors of the polymer-surfactant (SP) flooding. The influence of the salinity and shearing action on the polymer viscosity and effects of the surfactant concentration on the IFT and emulsion behavior between chemical agent and oil were studied through the static and flooding experiments. The results show that increasing the concentration of polymer GF-11 (HPAM) can reduce the influence of the salinity and GF-11 has high shear-resist

APA, Harvard, Vancouver, ISO, and other styles

46

Wu, Wen Xiang, and Zhong Qi Yu. "Research on Oil-Water Interfacial Properties Effect of Polymer / Surfactant Binary Flooding System." Advanced Materials Research 201-203 (February 2011): 2558–61. http://dx.doi.org/10.4028/www.scientific.net/amr.201-203.2558.

Full text

Abstract:

The formula of surfactant(QY-3、SHSA-HN6、SS) and polymer compound system, and the interfacial characteristics between oil and water of Henan oil field were evaluated, the binary composite system formula adapt to the field was explored. The results show that the binary composite system (surfactant QY-3 and polymer 1630S) and oil-water in Henan can achieve ultra-low interfacial tension(＜10-3mN/m); If the addition agent NaCl was added to the composite system (Surfactant Ss and polymer ZL-Ⅱ or Surfactant Ss and polymer KYPAM) that the interfacial tension between oil and water can be reduced effecti

APA, Harvard, Vancouver, ISO, and other styles

47

Haq, Bashirul, Jishan Liu, and Keyu Liu. "Green enhanced oil recovery (GEOR)." APPEA Journal 57, no. 1 (2017): 150. http://dx.doi.org/10.1071/aj16116.

Full text

Abstract:

Green enhanced oil recovery (GEOR) is a chemical enhanced oil recovery (EOR) method involving the injection of specific green chemicals (surfactants/alcohols/polymers) that effectively displace oil because of their phase-behaviour properties, which decrease the interfacial tension (IFT) between the displacing liquid and the oil. In this process, the primary displacing liquid slug is a complex chemical system called a micellar solution, containing green surfactants, co-surfactants, oil, electrolytes and water. The surfactant slug is relatively small, typically 10% pore volume (PV). It may be fo

APA, Harvard, Vancouver, ISO, and other styles

48

Cui, Wei Lin, Wu Ju Xu, and Ling Jian Song. "The Influence of Different Kinds of Surfactants on Rheology in Polymer/Surfactant Complex Flooding." Applied Mechanics and Materials 437 (October 2013): 1089–92. http://dx.doi.org/10.4028/www.scientific.net/amm.437.1089.

Full text

Abstract:

Because of alkaline declining the sweep efficiency, causing scale formation problem in the reservoir and the well bottom and the tubular pipes, so polymer/surfactant compound flooding technology is the emphasis in the research of enhanced recovery. So the articles study the regulation of different kinds of surface active agents at different temperature by MARS Rheometer. The testing result showed that the variation of viscocity under the interaction between the surface active agent and association polymer according to “three stage” model .The linear viscoelastic region of stress decrease when

APA, Harvard, Vancouver, ISO, and other styles

49

Tavassoli, Shayan, Aboulghasem Kazemi Korrani, Gary A. Pope, and Kamy Sepehrnoori. "Low-Salinity Surfactant Flooding—A Multimechanistic Enhanced-Oil-Recovery Method." SPE Journal 21, no. 03 (2016): 0744–60. http://dx.doi.org/10.2118/173801-pa.

Full text

Abstract:

Summary We have applied UTCHEM-IPhreeqc to investigate low-salinity (LS) waterflooding and LS surfactant (LSS) flooding. Numerical-simulation results were compared with laboratory experiments reported by Alagic and Skauge (2010). UTCHEM-IPhreeqc combines the UTCHEM numerical chemical-flooding simulator with IPhreeqc, the United States Geological Survey geochemical model. The IPhreeqc model was coupled to UTCHEM to model LS waterflooding as a function of geochemical reactions. The surfactant coreflood experiments were performed in vertical cores without using polymer or other mobility-control a

APA, Harvard, Vancouver, ISO, and other styles

50

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.

Full text

APA, Harvard, Vancouver, ISO, and other styles

We offer discounts on all premium plans for authors whose works are included in thematic literature selections. Contact us to get a unique promo code!