Relevant bibliographies by topics / Crude oil foam

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  1. Journal articles
  2. Dissertations / Theses
  3. Books
  4. Book chapters
  5. Conference papers

Academic literature on the topic 'Crude oil foam'

Author: Grafiati
Published: 4 June 2021
Last updated: 1 February 2022

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Journal articles on the topic "Crude oil foam"

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Callaghan, I. C., A. L. McKechnie, J. E. Ray, and J. C. Wainwright. "Identification of Crude Oil Components Responsible for Foaming." Society of Petroleum Engineers Journal 25, no. 02 (April 1, 1985): 171–75. http://dx.doi.org/10.2118/12342-pa.

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Abstract The foaming characteristics of a number of crude oils from a variety of sources were determined by Bikerman's pneumatic method. Extraction of these crudes with both pneumatic method. Extraction of these crudes with both alkali and acid indicated that the crude oil components responsible for the foam stability were removed by the alkali extraction. Further examination of the alkali extract revealed that after neutralization it was the chloroform soluble part of this extract (0.02% wt% of the whole crude) that was responsible for the foaming properties of the crudes investigated. This latter point was confirmed by demonstrating that the surface rheological properties of one of the extracted crudes could be restored by adding back the chloroform-soluble portion of the neutralized alkali extract. Analysis of this extract indicated that the foam-stabilizing materials were short-chain carboxylic acids and phenols of molecular weight -400. In principle, such analytical information could be used to identify principle, such analytical information could be used to identify crude oils likely to present severe foaming problems in the field. Such information could enable the process engineer to take appropriate corrective measures early in the life of a new field, thus avoiding the need for high capital expenditure at a later stage. Introduction Crude oil foams can pose major problems for operators of gas/oil separation plants, causing a loss of crude in the separated gas stream and consequent loss of revenue and possible damage to downstream compressors. Thus, an possible damage to downstream compressors. Thus, an understanding of the factors controlling crude oil foam stability is highly desirable, since it should lead to better methods of foam prediction and control. With this end in mind, we have attempted to identify those crude oil components responsible for foam stabilization. This paper outlines our findings to date and attempts to demonstrate that a similar suite of compounds is responsible for the stabilization of a wide range of crude oil foams. Experimental Materials Crude Oils. Chemical-free samples of 16 different stock-tank crude oils were obtained from a variety of sources (see Table 1). Particular care was taken to ensure that these samples were stored under nitrogen to prevent oxidation of the crudes. prevent oxidation of the crudes. Reagents used were cyclohexane, spectroscopic grade (from BDH); chloroform, general purpose reagent grade (from BDH); diethyl ether, general purpose reagent grade (from BDH); sodium hydroxide pellets, technical grade (from BDH); and SIL-PREP reagent: Applied Science Laboratories Ltd. All solvents were distilled before use, and only an 80% heart cut was taken. Techniques Foaminess Index Measurements. The foaming column used in this work consisted of a graduated glass tube approximately 30 cm [12 in.] in length with two fine sintered glass disks placed 1 cm [0.4 in.] apart, situated at the base of the tube just above the gas inlet. The gas used to create the foam is admitted to the column by way of a pressure reduction and flow meter assembly (see Ref. 1). The measurements were initiated by pipetting an aliquot of crude oil, just sufficient to cover the upper sintered disk, into the foaming column. The oil was allowed to spread over the sintered disk. Compressed air (or natural gas), flowing at a constant rate (40 cm3/sec [40 mL/min]), then was admitted to the column by way of the sintered disk and the crude oil was taken up into the froth. The bubbling was continued for 5 minutes after all the liquid had been taken up into the foam. When a homogeneous foam had been achieved, the height of the upper foam/gas interface was recorded. Three runs were performed on each crude oil studied. The foaminess index performed on each crude oil studied. The foaminess index (E) of each of the stripped and complete stock-tank crude oils then was determined by Bikerman's method. (1) where V, is the constant foam volume at time t and V is the volume of gas injected during time t. Extraction of Crude Oil Surfactants. Treatment with dilute aqueous sodium hydroxide solution was found to be the best means of extracting the acidic components in the crude oils. The oils were dissolved in cyclohexane to give 10% vol/vol solutions, thereby reducing viscosity and thus facilitating rapid phase separation. Despite this precaution some oil still was removed with the aqueous precaution some oil still was removed with the aqueous phase, which necessitated thorough back extraction with phase, which necessitated thorough back extraction with fresh solvent to ensure the selectivity of the separation. The sodium salts in the aqueous extract then were converted back to the free acids by treatment with excess mineral acid. The concentrate obtained was derived for analysis by combined gas chromatography/mass spectrometry (GC/MS). SPEJ P. 171
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Sun, Lin, Wanfen Pu, Jun Xin, Peng Wei, Bing Wang, Yibo Li, and Chengdong Yuan. "High temperature and oil tolerance of surfactant foam/polymer–surfactant foam." RSC Advances 5, no. 30 (2015): 23410–18. http://dx.doi.org/10.1039/c4ra17216g.

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Schramm, Laurier L., and Jerry J. Novosad. "Micro-visualization of foam interactions with a crude oil." Colloids and Surfaces 46, no. 1 (January 1990): 21–43. http://dx.doi.org/10.1016/0166-6622(90)80046-7.

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Anto-Darkwah, Evans, Muhammed Rehan Hashmet, and Ali M. Alsumaiti. "Laboratory Investigation of Static Bulk-Foam Tests in the Absence and Presence of Crude Oil." International Journal of Chemical Engineering and Applications 8, no. 2 (April 2017): 112–16. http://dx.doi.org/10.18178/ijcea.2017.8.2.640.

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Memon, Muhammad Khan, Khaled Abdalla Elraies, and Mohammed Idrees Ali Al-Mossawy. "Surfactant screening to generate strong foam with formation water and crude oil." Journal of Petroleum Exploration and Production Technology 11, no. 9 (August 5, 2021): 3521–32. http://dx.doi.org/10.1007/s13202-021-01251-w.

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AbstractMost of the available commercial surfactants precipitate due to the hardness of formation water. The study of surfactant generated foam and its stability is very complex due to its multifaceted pattern and common physicochemical properties. This research involved the study of foam generation by using the blended surfactants and their evaluation in terms of enhanced oil recovery (EOR). The objective of this study is to systematic screening of surfactants based on their capability to produce stable foam in the presence of two different categories of crude oil. Surfactant types such as non-ionic, anionic and amphoteric were selected for the experimental study. The foam was generated with crude oil, and the synthetic brine water of 34,107 ppm used as formation water. Surfactant concentration with the both types of crude oil, foam decay, liquid drainage and foam longevity was investigated by measuring the generated foam volume above the liquid level. The surfactant with concentration of 0.6wt%AOSC14-16, 1.2wt%AOSC14-16, 0.6wt%AOSC14-16 + 0.6wt%TX100 and 0.6wt%AOSC14-16 + 0.6wt%LMDO resulted in the maximum foam longevity with formation water and two categories of crude oil. The 50% liquid drainage and foam decay of surfactant solutions with concentration of 0.6wt%AOSC14-16 + 0.6wt%LMDO and 0.6wt%AOSC14-16 + 0.6wt%TX100 were noted with the maximum time. The findings of this research demonstrated that the generated foam and its longevity is dependent on the type of surfactant either individual or blended with their concentration. The blend of surfactant solution combines excellent foam properties.
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Abd Rahim, Nurul Suhana, Ismail Mohd Saaid, and Abubakar Abubakar Umar. "Evaluation of foam performance at different temperature for enhanced oil recovery process." World Journal of Engineering 16, no. 3 (June 10, 2019): 412–18. http://dx.doi.org/10.1108/wje-06-2018-0210.

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Purpose Application of foam in enhanced oil recovery requires a production of foam that is strong and stable enough to withstand a long period. There are numerous factors that may affect the performance of foam, among which is temperature. Therefore, this study aims to observe the foam performance at different temperature by evaluating the foamability and the stability of the foam. Design/methodology/approach In this study, bulk foam test using FoamScan was conducted to examine the effect of temperature on foam in the presence of crude oil. Nitrogen gas was sparged through the mixture of crude oil, an in-house developed surfactant, and sodium chloride solution as the brine at different temperatures to produce foam at a certain height. The crude oil was extracted from an oilfield in East Malaysia and the in-house developed surfactant was a mixture of amphoteric and anionic surfactants. A camera continuously recorded the height of foam during the generation and the collapse of the foam. The foamability and foam stability properties of each sample were taken as the indicators for foam performance. Furthermore, the entering, spreading and bridging analysis was run to observe the effect of the presence of crude oil on foam performance. Findings In general, the higher the temperature, the less stable the foam is. As the stability of foam is associated with the rate of liquid drainage, it was observed that as temperature increases, the rate of liquid drainage also increases. On the other hand, the entering, spreading and bridging analysis shows that there is entering of oil droplet happening on the interface of foam film that may promote the rupture of the foam film even more. Originality/value It was found that the temperature has a small impact on foamability, whereas the foam stability was significantly affected by the temperature. Therefore, it can be concluded that foamability is not necessarily interrelated to foam stability, contradicting to the findings of few authors.
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Keshawy, Mohamed, Reem K. Farag, and Amany Gaffer. "Egyptian crude oil sorbent based on coated polyurethane foam waste." Egyptian Journal of Petroleum 29, no. 1 (March 2020): 67–73. http://dx.doi.org/10.1016/j.ejpe.2019.11.001.

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Gomes, Alvaro Luiz, and Felipe Nascimento. "A new water-based foam controller for gas/oil separation on crude oil." Rio Oil and Gas Expo and Conference 20, no. 2020 (December 1, 2020): 185–86. http://dx.doi.org/10.48072/2525-7579.rog.2020.185.

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Ghosh, Pinaki, and Kishore K. Mohanty. "Novel Application of Cationic Surfactants for Foams With Wettability Alteration in Oil-Wet Low-Permeability Carbonate Rocks." SPE Journal 23, no. 06 (September 26, 2018): 2218–31. http://dx.doi.org/10.2118/179598-pa.

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Summary Carbonate rocks are typically heterogeneous at many scales, leading to low waterflood recoveries. Polymers and gels cannot be injected into nonfractured low-permeability carbonates (k < 10 md) because pore throats are smaller than the polymers. Foams have the potential to improve both oil-displacement efficiency and sweep efficiency in such carbonate rocks. However, foams have to overcome two adverse conditions in carbonates: oil-wettability and low permeability. This study evaluates several cationic-foam formulations that combine wettability alteration and foaming in low-permeability oil-wet carbonate cores. Contact-angle experiments were performed on initially oil-wet media to evaluate the wettability-altering capabilities of the surfactant formulations. Static foam-stability tests were conducted to evaluate their foaming performance in bulk; foam-flow experiments (without crude oil) were performed in porous media to estimate the foam strength. Finally, oil-displacement experiments were performed with a crude oil after a secondary gasflood. Two different injection strategies were studied in this work: surfactant slug followed by gas injection and coinjection of surfactant with gas at a constant foam quality. Systematic study of oil-displacement experiments in porous media showed the importance of wettability alteration in increasing tertiary oil recovery for oil-wet media. Several blends of cationic, nonionic, and zwitterionic surfactants were used in the experiments. In-house-developed Gemini cationic surfactant GC 580 was able to alter the wettability from oil-wet to water-wet and also formed strong bulk foam. Static foam tests showed an increase in bulk foam stability with the addition of zwitterionic surfactants to GC 580. Oil-displacement experiments in oil-wet carbonate cores revealed that tertiary oil recovery with injection of a wettability-altering surfactant and foam can recover a significant amount of oil [approximately 25 to 52% original oil in place (OOIP)] over the secondary gasflood. The foam rheology in the presence of oil suggested propagation of only weak foam in oil-wet low-permeability carbonate cores.
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Telmadarreie, Ali, and Japan J. Trivedi. "New Insight on Carbonate-Heavy-Oil Recovery: Pore-Scale Mechanisms of Post-Solvent Carbon Dioxide Foam/Polymer-Enhanced-Foam Flooding." SPE Journal 21, no. 05 (March 23, 2016): 1655–68. http://dx.doi.org/10.2118/174510-pa.

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Summary Carbonate reservoirs, deposited in the Western Canadian Sedimentary Basin (WCSB), hold significant reserves of heavy crude oil that can be recovered by nonthermal processes. Solvent, gas, water, and water-alternating-gas (WAG) injections are the main methods for carbonate-heavy-oil recovery in the WCSB. Because of the fractured nature of carbonate formations, many advantages of these production methods are usually in contrast with their low recovery factor. Alternative processes are therefore needed to increase oil-sweep efficiency from carbonate reservoirs. Foam/polymer-enhanced-foam (PEF) injection has gained interest in conventional heavy-oil recovery in recent times. However, the oil-recovery process by foam, especially PEF, in conjunction with solvent injection is less understood in fractured heavy-oil-carbonate reservoirs. The challenge is to understand how the combination of surfactant, gas, and polymer allows us to better access the matrix and efficiently sweep the oil. This study introduces a new approach to access the unrecovered heavy oil in fractured-carbonate reservoirs. Carbon dioxide (CO2) foam and CO2 PEF were used to decrease oil saturation after solvent injection, and their performance was compared with gas injection. A specially designed fractured micromodel was used to visualize the pore-scale phenomena during CO2-foam/PEF injection. In addition, the static bulk performances of CO2 foam/PEF were analyzed in the presence of heavy crude oil. A high-definition camera was used to capture high-quality images. The results showed that in both static and dynamic studies the PEF had high stability. Unlike CO2 PEF, CO2 foam lamella broke much faster and resulted in the collapse of the foam during heavy-oil recovery after solvent flooding. It appeared that foam played a greater role than just gas-mobility control. Foam showed outstanding improvement in heavy-oil recovery over gas injection. The presence of foam bubbles was the main reason to improve heavy-oil-sweep efficiency in heterogeneous porous media. When the foam bubbles advanced through pore throats, the local capillary number increased enough to displace the emulsified oil. PEF bubbles generated an additional force to divert surfactant/polymer into the matrix. Overall, CO2 foam and PEF remarkably increased heavy-oil recovery after solvent injection into the fractured reservoir.
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Dissertations / Theses on the topic "Crude oil foam"

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Blazquez, Egea Christian. "Formation, stabilité et cassage des mousses non aqueuses : Contribution à l'étude des mousses pétrolières." Thesis, Paris 6, 2014. http://www.theses.fr/2014PA066215/document.

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Les mousses rencontrées dans l’industrie pétrolière comptent parmi les mousses les plus complexes et problématiques. Lors de la production du pétrole brut, la présence de mousses stables peut entraîner de gros problèmes dans les équipements de traitement en surface à cause de la dépressurisation et de la nucléation de bulles provenant du gaz naturellement dissous dans le fluide de réservoir. Cette mousse peut rapidement occuper la moitié du volume des séparateurs et provoquer des dommages opérationnels graves, liés à des difficultés de contrôle des niveaux, à l’entraînement de liquide dans la ligne gaz et à l’entraînement de gaz dans la ligne liquide. Le contrôle de ces mousses pétrolières constitue donc un véritable enjeu, et les diverses solutions proposées sont basées sur l’utilisation de moyens physiques (chauffage, utilisation d’internes spécifiques) mais surtout sur l’utilisation d’additifs antimousses ou démoussants et plus particulièrement de silicones PDMS. Cependant, il n’existe pas encore d’optimisation possible de ces traitements du fait du manque d’études détaillées sur le comportement de ces systèmes complexes. L’objectif principal de ce travail a donc été de contribuer à la compréhension des mécanismes de formation, de stabilisation et de rupture des mousses non aqueuses et plus particulièrement des mousses de pétrole brut. Dans un premier temps, nous avons développé une nouvelle méthodologie expérimentale permettant de former des mousses représentatives des mousses pétrolières afin de comparer quantitativement différents systèmes moussants à base de pétroles bruts ainsi que l’efficacité de différentes familles d’additifs chimiques. Ensuite, nous avons étudié les cinétiques de cassage et développé un modèle de type sigmoïde permettant de décrire les courbes expérimentales de manière satisfaisante, et ouvrant la voie à une analyse quantitative de ces systèmes. Grâce à ce type de modélisation, il est possible de comparer l’efficacité des additifs chimiques en tant que démoussants et/ou antimousses et donc d’optimiser le choix du meilleur additif requis.Enfin ces développements permettent de proposer une première analyse de l’influence des caractéristiques physico chimiques de ces systèmes complexes sur leurs propriétés de moussage
Crude oil foams are present in most steps of the oil industry, being one of the most complex and problematic non aqueous foams. During the crude oil exploitation, the presence of stable foams may cause major problems on surface equipment because of the depressurisation between the reservoir and the wellhead and the nucleation of the bubbles from the natural gas solubilised in the reservoir oil. These foams can fill up rapidly the half of the volume of the separators and cause serious damages due to the loss of the level control capacity, by dragging gas to the liquid line or liquid to the gas line, which leads to a reduction of the efficiency of the operation. The control of these foams is therefore a real issue. Several methods are used to control the foam based on its physical destruction (by mechanical devices, heating, special design of the unit internals...) but, by far, the most common method is the chemical destruction by adding different chemical compounds (called defoamers and antifoamers), particularly PDMS silicones. However, there is still no possible optimization of these treatments because of the lack of detailed studies on the behaviour of these complex systems. With this work we wanted to contribute to the understanding of the formation, stabilization and breaking mechanisms of this kind of non-aqueous foams. With this in mind, our first objective was the development of a new experimental methodology that allows to form crude oil foams which are representative of the oilfield foams, in order to compare the different foamy systems as well as the efficiency of different families of chemical additives. After that, we used a sigmoid model which describes in a satisfactory way the experimental curves of foam breaking. Besides, this kind of modelling allows to compare the efficiency of the different chemical additives in terms of defoaming and antifoaming effects, leading to the optimal selection of the additive in each case. Finally, these developments allow us to propose a first analysis of the influence of the physicochemical characteristics of these complex systems on their foaming properties
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Dang, Yu. "Value-added Conversion of Waste Cooking Oil, Post-consumer PET Bottles and Soybean Meal into Biodiesel and Polyurethane Products." The Ohio State University, 2016. http://rave.ohiolink.edu/etdc/view?acc_num=osu1468591615.

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Babic, Marijan. "Role of Interfacial Chemistry on Wettability and Carbon Dioxide Corrosion of Mild Steels." Ohio University / OhioLINK, 2017. http://rave.ohiolink.edu/etdc/view?acc_num=ohiou1483543296145156.

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Yen, Chia-Yuan, and 晏家元. "UV-resistant crude oil degrading microorganisms isolated form the contaminated shorelines." Thesis, 2011. http://ndltd.ncl.edu.tw/handle/49009304758979328629.

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碩士
國立臺灣海洋大學
海洋生物研究所
99
The main objective of this study was to isolate and identify UV-resistant oil-degrading microorganisms from the oil polluted shoreline located in the North coast of Shimen area. 21 yeast strains and 1 bacterial strain were isolated. Yeast strain SA-4 showed the strongest total petroleum hydrocarbon (TPH) degrading ability (remove 47.0% of 1% crude oil during 30 days incubation) under UV A and B radiation. Among the isolated strains, 21 strains of Candida tropicalis showed stronger TPH degrading ability (remove 2.3-46.8% of 1% crude oil during 30 days incubation) than that of bacterial strain under UV A and B radiation. Bacterial strain Ochrobactrum tritici B32 showed the strongest total petroleum hydrocarbon (TPH) degrading ability (remove 76.5% of 1% crude oil during 30 days incubation)when incubation without UV A and B radiation. Yeast strains (remove 28.4-67.1%) all showed stronger oil degrading ability without UV radiation than under UV radiation. Candida tropicalis strains posses lipase and catechol 1,2-dioxygenase, but not catechol 2,3-dioxygenase activity. 89% of the cells of bacterial strain and 92-99% of Candida strains survived after under UVA and UVB radiation for 5 h .Cells of E. coli were not survived under this conditions. Under UV C radiation (800 J/M2), all the Candida tropicalis strains had similar ability for UV C resistance as that of Deinococcus radiodurans, however, bacterial strain could not survived under this conditions.
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Lin, Wen-chi, and 林雯琪. "The Impact of Crude Oil Price Change on Stock Returns: Evidence form Taiwan Listed Companies." Thesis, 2013. http://ndltd.ncl.edu.tw/handle/34539251290661577427.

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碩士
南華大學
財務金融學系財務管理碩士班
101
Oil is one of the major energy resources currently with its price fluctuation remarkably affecting the economy and politics of every nation around the world. Because we heavily depend on imported oil, the soaring oil prices on international markets recently cause a severe issue to the overall economy of Taiwan. The soaring oil prices have added our financial burden to badly impede our export competitiveness due to cost-up pressure with revenue reduced among local business organizations. Therefore, the fluctuation of the oil prices on international markets is quite an issue worthy of our emphasis. 　 　　This study was based on the Multi-factor Market Model proposed by Sadorsky (2001) to explore the influence on the investment return of stock prices caused by the fluctuation of oil prices during the period from 2001 to 2012. In this article, the data collected from the industries separately of shipping, plastic, LED, architecture & construction and banking on the public stock market listed in the Taiwan Stock Exchange Corporation for empirical analysis. It was hoped through cross-industrial comparisons, it was available to delineate the practical influence on the stock prices of the corporations from different industries exerted by the fluctuation of oil prices. This study was conducted by using two major variables, namely the factors of the overall economic side (change rates of oil prices, market excess return, interest spreads and exchange rates) and the individual characteristics of corporations (volume, P/B ratios, revenue and earning ratios). 　 　　The empirical results show that for those corporations viewing petroleum as important raw material, the changes happening to oil prices exerted significantly positive influence on stock prices. Other industries showed a remarkable variance because different models were set different models. The investment return on stocks were also affected by the characteristics of different corporations separately.
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Books on the topic "Crude oil foam"

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Bolt, Paul J., and Sharyl N. Cross. Energy and the Economic Foundations of the Sino–Russian Relationship. Oxford University Press, 2018. http://dx.doi.org/10.1093/oso/9780198719519.003.0002.

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Chapter 2 explores the economic relationship between Russia and China. Both governments have made it a priority to enhance economic linkages, with “One Belt, One Road” possibly being a vehicle for stronger integration. However, rising trade was disrupted in 2015 by slowed growth in China and a serious economic downturn in Russia, and structural features inhibit trade. Energy ties are the most important form of economic exchange between the two countries, with Russia being a major energy exporter and China needing secure, reliable supplies of oil and natural gas. Pipelines now deliver crude oil from Russia to China. Natural gas pipelines have been contracted but not yet built. Russia seems to have become more open to Chinese investments in energy and other fields since 2014, although it remains to be seen whether economic ties will eventually match the depth of the political relationship.
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Crane, Hewitt, Edwin Kinderman, and Ripudaman Malhotra. A Cubic Mile of Oil. Oxford University Press, 2010. http://dx.doi.org/10.1093/oso/9780195325546.001.0001.

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One cubic mile of oil (CMO) corresponds very closely to the world's current total annual consumption of crude oil. The world's total annual energy consumption - from all energy sources- is currently 3.0 CMO. By the middle of this century the world will need between 6 and 9 CMO of energy per year to provide for its citizens. Adequate energy is needed remove the scourge of poverty and provide food, clothing, and shelter for the people around the world, and more will be needed for measures to mitigate the potential effects of climate change such as building dikes and desalinating water. A Cubic Mile of Oil describes the various energy sources and how we use them, projects their future contributions, and delineates what it would take to develop them to annually produce a CMO from each of them. The requirement for additional energy in the future is so daunting that we will need to use all resources. We also examine how improved efficiency and conservation measures can reduce future demand substantially, and help distinguish approaches that make a significant impact as opposed to merely making us feel good. Use of CMO eliminates a multitude of units like tons of coal, gallons of oil, and cubic feet of gas; obviates the need for mind-numbing multipliers such as billions, trillions, and quadrillions; and replaces them with an easy-to-understand volumetric unit. It evokes a visceral response and allows experts, policy makers and the general public alike to form a mental picture of the magnitude of the challenge we face. In the absence of an appreciation of the scale of the problem, we risk squandering efforts and resources in pursuing options that will not meet tomorrow's global energy needs. We must make critical choices, and a common understandable language is essential for a sustained meaningful dialog.
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Book chapters on the topic "Crude oil foam"

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Schramm, Laurier L. "Foam Sensitivity to Crude Oil in Porous Media." In Advances in Chemistry, 165–97. Washington, DC: American Chemical Society, 1994. http://dx.doi.org/10.1021/ba-1994-0242.ch004.

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Callaghan, I. C. "Non-Aqueous Foams: A Study of Crude Oil Foam Stability." In Foams: Physics, Chemistry and Structure, 89–104. London: Springer London, 1989. http://dx.doi.org/10.1007/978-1-4471-3807-5_7.

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Xing, Xiaokai, Heng Zhou, and Xuhui Guo. "Defoaming Characteristics of Crude Oil Foams Containing CO2." In Proceedings of the International Petroleum and Petrochemical Technology Conference 2018, 178–86. Singapore: Springer Singapore, 2018. http://dx.doi.org/10.1007/978-981-13-2173-3_17.

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Meddich, Abdelilah, Abderrahim Boutasknit, Mohamed Anli, Meriame Ait Ahmed, Abdelilah El Abbassi, Hanane Boutaj, Mohamed Ait-El-Mokhtar, and Ali Boumezzough. "Use of Olive Mill Wastewaters as Bio-Insecticides for the Control of Potosia Opaca in Date Palm (Phoenix dactylifera L.)." In Biomass [Working Title]. IntechOpen, 2020. http://dx.doi.org/10.5772/intechopen.93537.

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The date palm is one of the most economically important perennial plants of the North Africa and in Morocco, where it is extensively cultivated for food and many other commercial purposes. Palm trees are threatened by many pests such as Potosia opaca newly identified in Morocco, especially in Marrakesh and Errachidia regions. In addition, olive mill wastewaters (OMW) are an environmental problem in olive oil producing countries such as Morocco. Generally, these effluents are drained into ecosystems without any pre-treatment. To reduce their negative impact and to get benefits in particular from their high phenolic content, OMW were used as bio-insecticides in crude form. The results showed that crude OMW were effective to control this pest causing a weight loss similar to Cordus insecticide (17% vs. 15%) and mortality almost similar to Kemaban insecticide. OMW’s biocide potential was related principally to their high phenolic content. Based on HPLC analysis, ten phenolic molecules were identified, including two which were revealed as the major monomeric phenolic compounds in OMW, 0.248 g/L of hydroxytyrosol and 0.201 g/L of tyrosol. In this chapter, the potential use of OMW as bio-insecticides for the control of P. opaca in date palm is discussed.
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D. Olagunju, Busola, and Oludolapo A. Olanrewaju. "Life Cycle Assessment of Ordinary Portland Cement (OPC) Using both Problem Oriented (Midpoint) Approach and Damage Oriented Approach (Endpoint)." In Product Life Cycle - Opportunities for Digital and Sustainable Transformation [Working Title]. IntechOpen, 2021. http://dx.doi.org/10.5772/intechopen.98398.

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The concern for environmental related impacts of the cement industry is fast growing in recent times. The industry is challenged with high environmental impact which spans through the entire production process. Life cycle assessment (LCA) evaluates the environmental impact of product or process throughout the cycle of production. This can be done using either or both midpoint (process-oriented) and endpoint (damage-oriented) approaches of life cycle impact assessment (LCIA). This study assessed the environmental impact of 1 kg Ordinary Portland Cement (OPC) using both approaches of LCIA. This analysis was carried out using a data modeled after the rest of the world other than China, India, Europe, US and Switzerland. The dataset was taken from Ecoinvent database incorporated in the SimaPro 9.0.49 software. The result of the analysis showed that clinker production phase produced the highest impact and CO2 is the highest pollutant emitter at both endpoint and midpoint approaches. This is responsible for global warming known to affect both human health and the ecosystem. Also, toxicity in form of emission of high copper affects the ecosystem as well as humans. In addition, high fossil resources (crude oil) are consumed and pose the possibility for scarcity.
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Correia, A. C., and S. Ferreira-Dias. "The effect of impurities of crude olive residue oil on the operational stability of the Candida rugosa lipase immobilized in polyurethane foams." In Progress in Biotechnology, 71–76. Elsevier, 1998. http://dx.doi.org/10.1016/s0921-0423(98)80012-9.

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Conference papers on the topic "Crude oil foam"

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AlYousef, Zuhair, Ayrat Gizzatov, Hana AlMatouq, and Guoqing Jian. "Effect of Crude Oil on CO–Foam Stability." In Offshore Technology Conference Asia. Offshore Technology Conference, 2020. http://dx.doi.org/10.4043/30210-ms.

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Hussain, A., S. Vincent-Bonnieu, R. Kamarul Bahrim, R. Pilus, and W. Rossen. "Impact of Crude Oil on Pre-generated Foam in Porous Media." In IOR 2019 – 20th European Symposium on Improved Oil Recovery. European Association of Geoscientists & Engineers, 2019. http://dx.doi.org/10.3997/2214-4609.201900146.

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binti Mustafa Kamal, Siti Nurbaya, Ismail B. Mohd Saaid, and Birol M. R. Demiral. "Effect of flow rate on foam mobility — Malaysia crude oil." In 2011 National Postgraduate Conference (NPC). IEEE, 2011. http://dx.doi.org/10.1109/natpc.2011.6136538.

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Al-Saedi, Hasan Naeem, Soura Kassim Al-Jaberi, Waleed Al-Bazzaz, and Ralph Emil Flori. "Experimental Study of Flooding both Low Salinity Water and Foam in Sandstone Reservoirs Bearing Heavy Crude Oil." In SPE Gas & Oil Technology Showcase and Conference. Society of Petroleum Engineers, 2019. http://dx.doi.org/10.2118/198675-ms.

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Hassan, Anas M., Mohammed Ayoub, Mysara Eissa, Hans Bruining, Abdullah Al-Mansour, and Abdulrahman Al-Quraishi. "A New Hybrid Improved and Enhanced Oil Recovery IOR/EOR Process Using Smart Water Assisted Foam SWAF Flooding in Carbonate Rocks; A Laboratory Study Approach." In International Petroleum Technology Conference. IPTC, 2021. http://dx.doi.org/10.2523/iptc-21381-ms.

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Abstract Given the increasing demand for energy globally and depleting oil and gas resources, it is crucial to increase the production from existing reservoirs by introducing new technologies for Improved/Enhanced Oil Recovery (IOR/EOR). This contribution presents a novel hybrid IOR/EOR method, which combines smart water (SW) and foam flooding, known as Smart Water Assisted Foam (SWAF) flooding. The optimal conditions of the SWAF technology will be interpreted using experimental laboratory design (i.e., experimental data). The experimental design was divided into three main steps. The first step is obtaining rock wettability measurements using contact angle measurements. This step aims to select the optimum SW composition that changes the carbonate rock's wettability from oil-wet towards more water-wet and faster oil recoveries. The water-wet condition leads to high residual oil saturations and low end-point permeabilities. This is conductive to favourable mobility ratios and efficient water-oil displacement. However, high residual oil saturations are unfavourable to the high ultimate oil recovery as much oil stays behind. Secondly, the chemical screening follows, where two tests were performed, viz., (i) an Aqueous Stability Test (AST), (ii) and a Foamability and Foam Stability Tests (FT/FST). This step aims to generate a stable foam (i.e., surfactant aqueous solution + gas) in the absence and presence of crude oil with different TAN (Total Acid Number) and TBN (Total Base Number), viz., crude oils Type-A and Type-B. Favourable mobility ratio is achieved by the presence of foam, which leads to excellent displacement efficiency. Thirdly, core flooding tests are performed. This step aims to select the best formulations through SWAF core flooding tests to obtain the ultimate recovery factor under different injection scenarios. The optimal SWAF condition combines high ultimate recovery with the best displacement efficiency. It is shown that the enormous changes in wettability were seen for SW (MgCl2) solution at 3500 (ppm) for both crude oils Type-A and Type-B. It has been shown that the use of a cationic surfactant CTAB (i.e., cetyltrimethylammonium-bromide) in the positively charged carbonates (with an isoelectric point of pH = 9) is more effective than the use of anionic surfactant, e.g., Alpha Olefin Sulfonate (AOS). The aim is to create an optimum surfactant aqueous solution (SAS). The SAS stability is considerably affected by the concentration of both the SW (MgCl2) and surfactant (CTAB). In the absence of oil, the strength of foam (SAS and Gas) is highly dependent on the concentration and composition of the SW in the SAS. In the presence of oil, foam generation and stability are better when the crude oil has a low TAN and high TBN. From the core flooding tests for crude oils Type-A and Type-B, the ultimate residual oil recovery was achieved by the MgCl2 - foam injection combination (i.e., incremental oil recovery of 42%, which is equivalent to a cumulative oil recovery of 92%). In summary, SWAF under the optimum conditions is a promising method to increase the oil recovery from carbonate reservoirs.
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Borhan, N., I. Salleh, J. M. B. M. Ibrahim, A. R. Farrell, D. A. Nichols, and G. M. Graham. "Investigation of Naphthenates Crude Oil Types and Behaviour to Induce Soaps-Microemulsion and Soap-Fines Foam in Malaysian EOR Fields." In International Petroleum Technology Conference. International Petroleum Technology Conference, 2016. http://dx.doi.org/10.2523/iptc-18948-ms.

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Razali, Norzafirah, Ivy Chai Ching Hsia, Suzalina Zainal, and Arif Azhan A. Manap. "Nano-Sized Particle as Foam Stabiliser Designed for Application at High Temperature and Light Crude Oil Condition for Enhanced Oil Recovery - A Fluid-Fluid Case Study." In Offshore Technology Conference Asia. Offshore Technology Conference, 2018. http://dx.doi.org/10.4043/28431-ms.

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Marcano, Luis, Xiomara Santana Gutierrez, Beatriz Perez, and Edward Martinez. "Effect of Some Physical-Chemical Variables on the Formation and Stability of Foam in Oil-Gas Systems and Their Correlation With the Formation of Foaming Crude Oil." In Latin American and Caribbean Petroleum Engineering Conference. Society of Petroleum Engineers, 2009. http://dx.doi.org/10.2118/123060-ms.

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Telmadarreie, Ali, Christopher Johnsen, and Steven L. Bryant. "A Novel Hybrid Solvent-Based Complex Fluid for Enhanced Heavy Oil Recovery." In SPE Western Regional Meeting. SPE, 2021. http://dx.doi.org/10.2118/200857-ms.

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Abstract This study designs a novel complex fluid (foam/emulsion) using as main components gas, low-toxicity solvents (green solvents) which may promote oil mobilization, and synergistic foam stabilizers (i.e. nanoparticles and surfactants) to improve sweep efficiency. This nanoparticle-enabled green solvent foam (NGS-foam) avoids major greenhouse gas emissions from the thermal recovery process and improves the performance of conventional green solvent-based methods (non-thermal) by increasing the sweep efficiency, utilizing less solvent while producing more oil. Surfactants and nanoparticles were screened in static tests to generate foam in the presence of a water-soluble/oil-soluble solvent and heavy crude oil from a Canadian oil field (1600 cp). The liquid phase of NGS-foam contains surfactant, nanoparticle, and green solvent (GS) all dispersed in the water phase. Nitrogen was used as the gas phase. Fluid flow experiments in porous media with heterogeneous permeability structure mimicking natural environments were performed to demonstrate the dynamic stability of the NGS-foam for heavy oil recovery. The propagation of the pre-generated foam was monitored at 10 cm intervals over the length of porous media (40 cm). Apparent viscosity, pressure gradient, inline measurement of effluent density, and oil recovery were recorded/calculated to evaluate the NGS-foam performance. The outcomes of static experiments revealed that surfactant alone cannot stabilize the green solvent foam and the presence of carefully chosen nanoparticles is crucial to have stable foam in the presence of heavy oil. The results of NGS-foam flow in heterogeneous porous media demonstrated a step-change improvement in oil production such that more than 60% of residual heavy oil was recovered after initial waterflood. This value of residual oil recovery was significantly higher than other scenarios tested in this study (i.e. GS- water and gas co-injection, conventional foam without GS, GS-foam stabilized with surfactant only and GS-waterflood). The increased production occurred because NGS-foam remained stable in the flowing condition, improves the sweep efficiency and increases the contact area of the solvent with oil. The latter factor is significant: comparing to GS-waterflood, NGS-foam produces a unit volume of oil faster with less solvent and up to 80% less water. Consequently, the cost of solvent per barrel of incremental oil will be lower than for previously described solvent applications. In addition, due to its water solubility, the solvent can be readily recovered from the reservoir by post flush of water and thus re-used. The NGS-foam has several potential applications: recovery from post-CHOPS reservoirs (controlling mobility in wormholes and improving the sweep efficiency while reducing oil viscosity), fracturing fluid (high apparent viscosity to carry proppant and solvent to promote hydrocarbon recovery from matrix while minimizing water invasion), and thermal oil recovery (hot NGS-foam for efficient oil viscosity reduction and sweep efficiency improvement).
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Novosad, Jerry J., and Karin Mannhardt. "The Interaction Between Foam And Crude Oils." In Annual Technical Meeting. Petroleum Society of Canada, 1989. http://dx.doi.org/10.2118/89-40-29.

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